UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 20-F
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2015
Commission file number: 1-12102
YPF Sociedad Anónima
(Exact name of registrant as specified in its charter)
Republic of Argentina
(Jurisdiction of incorporation or organization)
Macacha Güemes 515
C1106BKK Ciudad Autónoma de Buenos Aires, Argentina
(Address of principal executive offices)
Diego M. Pando
Tel: (011-54-11) 5441-3500
Facsimile Number: (011-54-11) 5441-3726
Macacha Güemes 515
C1106BKK Ciudad Autónoma de Buenos Aires, Argentina
(Name, Telephone, E-mail and/or Facsimile number and Address of Company Contact Person)
Securities registered or to be registered pursuant to Section 12(b) of the Act:
Title of Each Class
American Depositary Shares, each representing one Class D
Share, par value 10 pesos per share
Class D Shares
Name of Each Exchange on Which Registered
New York Stock Exchange
New York Stock Exchange*
*
Listed not for trading but only in connection with the registration of American Depositary Shares.
Securities registered or to be registered pursuant to Section 12(g) of the Act: None
Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act: None
The number of outstanding shares of each class of stock of YPF Sociedad Anónima as of December 31, 2015 was:
Class A Shares
Class B Shares
Class C Shares
Class D Shares
3,764
7,624
40,422
393,260,983
393,312,793
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities
Act. Yes ⌧ No (cid:133)
If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to
Section 13 or 15(d) of the Securities Exchange Act of 1934. Yes (cid:133) No ⌧
Note – Checking the box above will not relieve any registrant required to file reports pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934 from their obligations under those Sections.
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities
Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports),
and (2) has been subject to such filing requirements for the past 90 days. Yes ⌧ No (cid:133)
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every
Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during
the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes (cid:133) No (cid:133)
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition
of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):
Large accelerated filer ⌧ Accelerated filer (cid:133) Non-accelerated filer (cid:133)
Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:
U.S. GAAP (cid:133)
International Financial Reporting Standards as issued by the
International Accounting Standards Board: ⌧
Other (cid:133)
Indicate by check mark which financial statement item the registrant has elected to follow. Item 17 Item 18 ⌧
If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange
Act) Yes (cid:133) No ⌧
2
TABLE OF CONTENTS
Conversion Table
References
Disclosure of Certain Information
Forward-Looking Statements
Oil and Gas Terms
PART I
ITEM 1. Identity of Directors, Senior Managers and Advisers
ITEM 2. Offer Statistics and Expected Timetable
ITEM 3. Key Information
Selected Financial Data
Exchange Regulations
Risk Factors
ITEM 4. Information on the Company
History and Development of YPF
The Argentine Market
History of YPF
Business Organization
Exploration and Production Overview
Downstream
Research and Development
Competition
Environmental Matters
Property, Plant and Equipment
Insurance
Regulatory Framework and Relationship with the Argentine Government
ITEM 4A. Unresolved Staff Comments.
ITEM 5. Operating and Financial Review and Prospects
Overview
Presentation of Financial Information
Segment Reporting
Summarized Statement of Comprehensive Income
Factors Affecting Our Operations
Critical Accounting Policies
Off-Balance Sheet Arrangements
Research and Development, Patents and Licenses, etc.
ITEM 6. Directors, Senior Management and Employees
3
Page
6
6
6
6
7
9
9
9
9
9
11
12
28
28
31
32
34
35
70
83
84
86
90
90
93
120
120
121
121
121
121
122
131
148
148
148
Management of the Company
Board of Directors
Senior Management
The Audit Committee
Disclosure Committee
Compliance with New York Stock Exchange Listing Standards on Corporate Governance
Compensation of members of our Board of Directors and Supervisory Committee
Supervisory Committee
Employee Matters
ITEM 7. Major Shareholders and Related Party Transactions
Related Party Transactions
Argentine Law Concerning Related Party Transactions
ITEM 8. Financial Information
Financial Statements
Legal Proceedings
Dividend Policy
Significant Changes
ITEM 9. The Offer and Listing
Shares and ADSs
Argentine Securities Market
ITEM 10. Additional Information
Memorandum and Articles of Association
Directors
Dividends
Amount Available for Distribution
Preemptive and Accretion Rights
Voting of the Underlying Class D Shares
Certain Provisions Relating to Acquisitions of Shares
Material Contracts
Exchange Regulations
Taxation
Argentine Tax Considerations
United States Federal Income Tax Considerations
Available Information
ITEM 11. Quantitative and Qualitative Disclosures about Market Risk
ITEM 12. Description of Securities Other than Equity Securities
PART II
ITEM 13. Defaults, Dividend Arrearages and Delinquencies
ITEM 14. Material Modifications to the Rights of Security Holders and Use of Proceeds
4
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148
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155
157
158
159
159
161
162
163
164
164
164
164
185
185
185
185
187
191
192
193
194
195
196
197
198
199
200
200
200
202
204
204
206
207
207
207
ITEM 15. Controls and Procedures
ITEM 16.
ITEM 16A. Audit Committee Financial Expert
ITEM 16B. Code of Ethics
ITEM 16C. Principal Accountant Fees and Services
ITEM 16D. Exemptions from the Listing Standards for Audit Committees
ITEM 16E. Purchases of Equity Securities by the Issuer and Affiliated Purchasers
ITEM 16F. Change in Registrant’s Certifying Accountant
ITEM 16G. Corporate Governance
PART III
ITEM 17. Financial Statements
ITEM 18. Financial Statements
ITEM 19. Exhibits
SIGNATURES
5
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208
208
208
209
209
209
210
210
210
210
210
210
211
Conversion Table
1 ton = 1 metric ton = 1,000 kilograms = 2,204 pounds
1 barrel = 42 U.S. gallons
1 ton of oil = approximately 7.3 barrels (assuming a specific gravity of 34 degrees API (American Petroleum Institute))
1 barrel of oil equivalent = 5,615 cubic feet of gas = 1 barrel of oil, condensate or natural gas liquids
1 kilometer = 0.63 miles
1 million Btu = 252 termies
1 cubic meter of gas = 35.3147 cubic feet of gas
1 cubic meter of gas = 10 termies
1,000 acres = approximately 4 square kilometers
References
YPF Sociedad Anónima is a stock corporation organized under the laws of the Republic of Argentina (“Argentina”). As used in this annual
report, “YPF,” “the Company,” “we,” “our” and “us” refer to YPF Sociedad Anónima and its controlled companies or, if the context requires, its
predecessor companies. “YPF Sociedad Anónima” refers to YPF Sociedad Anónima only. “Repsol” refers to Repsol S.A., its affiliates and
consolidated companies. We maintain our financial books and records and publish our financial statements in Argentine pesos. In this annual
report, references to “pesos” or “Ps.” are to Argentine pesos, and references to “dollars,” “U.S. dollars” or “U.S.$” are to United States dollars.
Disclosure of Certain Information
In this annual report, references to “Audited Consolidated Financial Statements” are to YPF’s audited consolidated statement of financial
position as of December 31, 2015, 2014 and 2013, YPF’s audited consolidated statements of comprehensive income for the years ended
December 31, 2015, 2014 and 2013, YPF’s audited consolidated statements of cash flows for the years ended December 31, 2015, 2014 and 2013,
YPF’s audited consolidated statements of changes in shareholders’ equity for the years ended December 31, 2015, 2014 and 2013 and the related
notes thereto.
Unless otherwise indicated, the information contained in this annual report reflects:
•
•
for the subsidiaries that were consolidated using the global integration method at the date or for the periods indicated, 100% of the
assets, liabilities and results of operations of such subsidiaries without excluding minority interests, and
for those joint operations whose results were consolidated using the proportional integration method, a pro rata amount of the assets,
liabilities and results of operations for such joint operations at the date or for the periods indicated.
For information regarding consolidation, see Notes 1.a and 1.b.5 to the Audited Consolidated Financial Statements.
Certain monetary amounts and other figures included in this annual report have been subject to rounding adjustments. Any discrepancies in
any tables between the totals and the sums of the amounts are due to rounding.
Forward-Looking Statements
This annual report, including any documents incorporated by reference, contains statements that we believe constitute forward-looking
statements within the meaning of the Private Securities Litigation Reform Act of 1995. These forward-looking statements may include statements
regarding the intent, belief or current expectations of us and our management, including statements with respect to trends affecting our financial
condition, financial ratios, results of operations, business, strategy, geographic concentration, reserves, future hydrocarbon production volumes and
the Company’s ability to satisfy our long-term sales commitments from future supplies available to the Company, our ability to pay dividends in
the future and to service our outstanding debt, dates or periods in which production is scheduled or expected to come onstream, as well as our plans
with respect to capital expenditures, business, strategy, geographic concentration, cost savings, investments and dividends payout policies. These
statements are not a guarantee of future performance and are subject to material risks, uncertainties, changes and other factors which may be
beyond our control or may be difficult to predict. Accordingly, our future financial condition, prices, financial ratios, results of operations,
business, strategy, geographic concentration, production volumes, reserves, capital expenditures, cost savings, WACC (weighted average cost of
capital) investments and ability to meet our long-term sales commitments or pay dividends or service our outstanding debt could differ materially
from those expressed or implied in any such forward-looking statements. Such factors include, but are not limited to, currency fluctuations,
inflation, the price of petroleum products, the domestic and international prices for crude oil, the ability to realize cost reductions and operating
efficiencies without unduly disrupting business operations, replacement of hydrocarbon reserves, environmental, regulatory and legal
considerations, including the imposition of further government restrictions on the Company’s business, changes in our business strategy and
operations, our ability to find partners or raise funding under our current control, the ability to maintain the Company’s concessions, and general
economic and business conditions in Argentina, as well as those factors described in the filings made by YPF and its affiliates with the Securities
and Exchange Commission, in particular, those described in “Item 3. Key Information—Risk Factors” and “Item 5. Operating and Financial
Review and Prospects.” YPF does not undertake to publicly update or revise these forward-looking statements even if experience or future changes
make it clear that the projected results or condition expressed or implied therein will not be realized.
6
Oil and Gas Terms
Oil and gas reserves definitions used in this annual report are in accordance with Regulations S-X and S-K, as amended by the
U.S. Securities and Exchange Commission’s (“SEC”) final rule, Modernization of Oil and Gas Reporting (Release Nos. 33-8995; 34-
59192; FR-78; File No. S7-15-08; December 31, 2008) and relevant guidance notes and letters issued by the SEC’s Staff.
The reported reserves contained in this annual report include only our proved reserves and do not include probable reserves or
possible reserves.
The following terms have the meanings shown below unless the context indicates otherwise:
“acreage”: The total area, expressed in acres or km2, over which YPF has interests in exploration or production. Net acreage is
YPF’s interest in the relevant exploration or production area.
“basin”: A depression in the crust of the Earth formed by plate tectonic activity in which sediments accumulate. Continued
sediment accumulation can cause further depression or subsidence.
“block”: Areas defined by concession contracts or operating contracts signed by YPF.
“concession contracts”: A grant of access for a defined area and time period that transfers certain entitlements to produce
hydrocarbons from the host country to an enterprise. The company holding the concession generally has rights and responsibilities for
the exploration, development, production and sale of hydrocarbons, and typically, an obligation to make payments at the signing of
the concession and once production begins pursuant to applicable laws and regulations.
“crude oil”: Crude oil with respect to YPF’s production and reserves includes condensate.
“field”: One or more reservoirs grouped by or related to the same general geologic structural feature or stratigraphic condition.
“formation”: The fundamental unit of lithostratigraphy. A body of rock that is sufficiently distinctive and continuous that it can
be mapped.
“gas”: Natural gas.
“hydrocarbons”: Crude oil, natural gas liquids and natural gas.
“surface conditions”: Represents the pressure and temperature conditions at which volumes of oil, gas, condensate and natural
gas liquids are measured for reporting purposes. It is also referred to as standard conditions. For YPF these conditions are 14.7 psi for
pressure and 60 degrees Fahrenheit for temperature. All volume units expressed in this report are at surface conditions.
7
Abbreviations:
“bbl”
“bbl/d”
“bcf”
“bcf/d”
“bcm”
“bcm/d”
“boe”
“boe/d”
“cm”
“cm/d”
“dam 3”
“GWh”
“HP”
“km”
“km2”
“liquids”
“LNG”
“LPG”
“m”
“mbbl”
“mbbl/d”
“mcf”
“mcf/d”
“mcm”
“mcm/d”
“mboe”
“mboe/d”
“mm”
“mmbbl”
“mmbbl/d”
“mmboe”
“mmboe/d”
“mmBtu”
“mmcf”
“mmcf/d”
“mmcm”
“mmcm/d”
“mtn”
“MW”
“NGL”
“psi”
“WTI”
Barrels.
Barrels per day.
Billion cubic feet.
Billion cubic feet per day.
Billion cubic meters.
Billion cubic meters per day.
Barrels of oil equivalent.
Barrels of oil equivalent per day.
Cubic meter.
Cubic meters per day.
Cubic dekameters (thousand cubic meters).
Gigawatt hours.
Horsepower.
Kilometers.
Square kilometers.
Crude oil, condensate and natural gas liquids.
Liquefied natural gas.
Liquefied petroleum gas.
Thousand.
Thousand barrels.
Thousand barrels per day.
Thousand cubic feet.
Thousand cubic feet per day.
Thousand cubic meters.
Thousand cubic meters per day.
Thousand barrels of oil equivalent.
Thousand barrels of oil equivalent per day.
Million.
Million barrels.
Million barrels per day.
Million barrels of oil equivalent.
Million barrels of oil equivalent per day.
Million British thermal units.
Million cubic feet.
Million cubic feet per day.
Million cubic meters.
Million cubic meters per day.
Thousand tons.
Megawatts.
Natural gas liquids.
Pound per square inch.
West Texas Intermediate.
8
PART I
ITEM 1.
Identity of Directors, Senior Managers and Advisers
Not applicable.
ITEM 2. Offer Statistics and Expected Timetable
Not applicable.
ITEM 3. Key Information
Selected Financial Data
The following tables present our selected financial data. You should read this information in conjunction with our Audited
Consolidated Financial Statements, and the information under “Item 5. Operating and Financial Review and Prospects” included
elsewhere in this annual report.
Our Audited Consolidated Financial Statements are prepared in accordance with International Financial Reporting Standards
(“IFRS”) as issued by the International Accounting Standards Board (“IASB”).
In this annual report, except as otherwise specified, references to “$,” “U.S.$” and “dollars” are to U.S. dollars, and references
to “Ps.” and “pesos” are to Argentine pesos. Solely for the convenience of the reader, peso amounts as of and for the year ended
December 31, 2015 have been translated into U.S. dollars at the exchange rate quoted by the Argentine Central Bank (Banco Central
de la República Argentina) (the “Central Bank”) on December 31, 2015 of Ps. 13.01 to U.S.$1.00, unless otherwise specified. The
exchange rate quoted by the Central Bank on March 15, 2016 was Ps. 14.61 to U.S.$1.00. The U.S. dollar equivalent information
should not be construed to imply that the peso amounts represent, or could have been or could be converted into U.S. dollars at such
rates or any other rate. See “—Exchange Rates.”
The financial data contained in this annual report as of and for the years ended December 31, 2015, 2014 and 2013 has been
derived from our Audited Consolidated Financial Statements included in this annual report. See Note 20 to the Audited Consolidated
Financial Statements. The financial data contained in this annual report as of December 31, 2012 and 2011 and for the years ended
December 31, 2012 and 2011 have been derived from our consolidated financial statements as of and for the years ended
December 31, 2013, 2012 and 2011 included in our 2013 20-F.
As of and for the year ended December 31,
2015
2014
2013
(in millions of pesos, except for per share
and per ADS data)
2012
2011
Consolidated Statement of Comprehensive Income Data(1) :
Revenues (2)
Gross profit
Administrative expenses
Selling expenses
Exploration expenses
Other operating results, net
Operating income
Income on long-term investments
Interest expense
Other financial income (expense), net
Income before income tax
Income tax
Net income
Total other Comprehensive income
Total comprehensive income
Earnings per share and per ADS(4)
Dividends per share and per ADS (4) (in pesos)
Dividends per share and per ADS (4)(5) (in U.S. dollars)
Consolidated Statement of Financial Position Data
Cash
Working capital (3)
Total assets
Total loans (6)
558
(829)
227
156,136 141,942 90,113 67,174 56,211
37,450 22,019 16,907 15,068
36,599
(1,822)
(4,530) (2,686) (2,232)
(5,586)
(5,438)
(10,114) (7,571) (5,662)
(11,099)
(574)
(582)
(2,034)
(2,473)
(46)
(1,030)
(853)
(528)
7,188
19,742 11,160 7,903
16,588
685
318
114
(1,045)
(7,336) (3,833) (1,557)
(10,605)
758
9,108 6,668 2,105
22,762
7,586
22,072 14,348 8,565
29,063
(3,141)
(13,223) (9,269) (4,663)
(24,637)
4,445
8,849 5,079 3,902
4,426
1,852
16,276 12,031 4,241
43,758
6,297
25,125 17,110 8,143
48,184
11.30
22.95 13.05 9.92
11.68
14.15
0.83 0.77
1.28
3.39
0.13 0.16
0.14
1.18
0.14
353
15,387
(2,818)
9,758 10,713 4,747
(11,266) 1,706 (2,582)
1,112
(7,750)
363,453 208,554 135,595 79,949 60,990
49,305 31,890 17,104 12,198
105,751
Shareholders’ equity (7)
Other Consolidated Financial Data
Fixed assets depreciation and intangible assets amortization
Cash used in fixed asset acquisitions and intangible assets
120,461
72,781 48,240 31,260 23,420
27,008
63,774
6,499
20,405 11,433 8,281
50,213 27,639 16,403 12,156
(1) The consolidated financial statements reflect the effect of the application on the functional and reporting currency. See Note
1.b.1 to the Audited Consolidated Financial Statements.
(2) Revenues are net of payments on account of fuel transfer taxes and turnover taxes. Customs duties on hydrocarbon exports are
disclosed in taxes, charges and contributions, as indicated in Note 6.n to the Audited Consolidated Financial Statements.
Royalties with respect to our production are accounted for as a cost of production and are not deducted in determining revenues.
See Note 1.b.15 to the Audited Consolidated Financial Statements.
(3) Working capital consists of consolidated total current assets minus consolidated total current liabilities as of December 31,
(4)
2015, December 31, 2014, December 31, 2013, December 31, 2012 and December 31, 2011.
Information has been calculated based on our outstanding share capital of 393,312,793 shares. Each ADS represents one Class
D share. There were no differences between basic and diluted earnings per share and ADS for any of the years disclosed.
(5) Amounts expressed in U.S. dollars are based on the exchange rate as of the date of the dividend payment.
(6) Total loans include non-current loans of Ps. 77,934 million, Ps. 36,030 million, Ps. 23,076 million, Ps. 12,100 million and Ps.
4,435 million as of December 31, 2015, 2014, 2013, 2012 and 2011, respectively, and current loans of Ps. 27,817 million, Ps.
13,275 million, Ps. 8,814 million, Ps. 5,004 million and Ps. 7,763 million as of December 31, 2015, 2014, 2013, 2012 and 2011,
respectively. See Note 6.j to the Audited Consolidated Financial Statements.
(7) Our subscribed share capital as of December 31, 2015 is represented by 393,312,793 shares of common stock and divided into
four classes of shares, with a par value of Ps. 10 and one vote per share. These shares are fully subscribed, paid-in and
authorized for stock exchange listing. See “Item 6. Directors, Senior Management and Employees—Compensation of members
of our Board of Directors and Supervisory Committee,” “Item 16E. Purchases of Equity Securities by the Issuer and Affiliated
Purchasers” and Note 1.b.10.iii to the Audited Consolidated Financial Statements in relation to shares purchased by YPF and
allocated to our employees as part of our employee compensation plans.
9
Exchange Rates
From April 1, 1991 until the end of 2001, the Convertibility Law (Law No. 23,928) established a fixed exchange rate which
required the Central Bank to sell U.S. dollars at one peso per U.S. dollar. On January 6, 2002, the Argentine congress enacted the
Public Emergency and Foreign Exchange System Reform Law (Law No. 25,561, the “Public Emergency Law”), formally putting an
end to the Convertibility Law regime and abandoning over ten years of U.S. dollar-peso parity. The Public Emergency Law, which
has been extended until December 31, 2017 by Law No. 27,200, grants the National Executive Office the power to set the exchange
rate between the peso and foreign currencies and to issue regulations related to the foreign exchange market. Following a brief period
during which the Argentine government established a temporary dual exchange rate system pursuant to the Public Emergency Law,
the peso has been allowed to float freely against other currencies since February 2002, although the government has the power to
intervene by buying and selling foreign currency for its own account, a practice in which it engages on a regular basis. The annual
rate of devaluation of the peso was approximately 52.1% from December 31, 2014 to December 31, 2015, based on the period-end
exchange rates for U.S. dollars as of December 31, 2015 and 2014, and the Argentine peso was subject to a devaluation of
approximately 34.2% during December 2015. See “—Risk Factors—Risks Relating to Argentina—Our business is highly dependent
upon economic conditions in Argentina.”
The following table sets forth the annual high, low, average and period-end exchange rates for U.S. dollars for the periods
indicated, expressed in nominal pesos per U.S. dollar, based on rates quoted by the Central Bank. The Federal Reserve Bank of New
York does not report a noon buying rate for Argentine pesos.
Year ended December 31,
2011
2012
2013
2014
2015
Month
September 2015
October 2015
November 2015
December 2015
January 2016
February 2016
March 2016 (2)
Low
High
Average (1)
Period End
(pesos per U.S. dollar)
3.97
4.30
4.92
6.54
8.73
9.30
9.43
9.56
9.70
13.07
14.09
14.61
4.30
4.92
6.52
8.56
13.76
9.42
9.55
9.69
13.76
13.94
15.58
15.92
4.15
4.58
5.54
8.23
9.39
9.37
9.49
9.63
11.43
13.65
14.81
15.30
4.30
4.92
6.52
8.55
13.01
9.42
9.55
9.69
13.01
13.90
15.58
14.61
Source: Central Bank
(1) Represents the average of the exchange rates on the last day of each month during the period.
(2) Through March 15, 2016.
No representation is made that peso amounts have been, could have been or could be converted into U.S. dollars at the foregoing
rates on any of the dates indicated.
10
Exchange Regulations
Prior to December 1989, the Argentine foreign exchange market was subject to exchange controls. From December 1989 until
April 1991, Argentina had a freely floating exchange rate for all foreign currency transactions, and the transfer of dividend payments
in foreign currency abroad and the repatriation of capital were permitted without prior approval of the Central Bank. From April 1,
1991, when the Convertibility Law became effective, until December 21, 2001, when the Central Bank closed the foreign exchange
market, the Argentine peso was freely convertible into U.S. dollars.
On December 3, 2001, the Argentine government imposed a number of monetary and currency exchange control measures
through Decree 1570/01, which included restrictions on the free disposition of funds deposited with banks and tight restrictions on
transferring funds abroad (including the transfer of funds to pay dividends) without the Central Bank’s prior authorization subject to
specific exceptions for transfers related to foreign trade. In June 2003, the Argentine government set restrictions on capital flows into
Argentina, which mainly consisted of a prohibition against the transfer abroad of any funds until 180 days after their entry into the
country. In June 2005, the government established new regulations on capital flows into Argentina, including increasing the period
that certain incoming funds must remain in Argentina to 365 calendar days and requiring that 30% of incoming funds be deposited
with a bank in Argentina in a non-assignable, non-interest-bearing account for 365 calendar days (the “Mandatory Deposit”).
However, in December 2015, the Ministry of Budget and Finance reduced the period in which the incoming funds must remain in
Argentina from 365 calendar days to 120 calendar days and also reduced the Mandatory Deposit from 30% to 0%. In addition, the
Argentine Central Bank lifted many of the restrictions imposed on transferring funds abroad and on capital flows into Argentina. In
this regard, the Argentine Central Bank’s regulation provides that Argentine individuals and legal entities do not need the Central
Bank’s prior approval to acquire foreign currency used for portfolio investments abroad. This includes investment in real estate
located abroad, loans to non-residents, direct investments made by Argentine residents abroad, portfolio investments made by
Argentine residents abroad, other investments abroad made by Argentine residents, portfolio investments made by legal entities
abroad, purchase of foreign currency in Argentina, purchase of travelers checks and donations, as long as the purchases do not exceed
an aggregate amount of U.S.$2,000,000 per calendar month and all the entities are authorized to trade in foreign currency. Under the
exchange regulations currently in force, restrictions exist in respect of the repatriation of funds or investments by non-Argentine
residents. For instance, the repatriation by non-Argentine residents of funds received as a result of the sale of the Class D shares in the
secondary market is subject to demonstrating that the funds used to make the investment in the Class D shares were transferred to
Argentina at least 120 days before the proposed repatriation and obtaining a certificate from an Argentine financial entity or
Argentine stock exchange stating the date and amount of the settlement of the funds in the Argentine exchange market from the
investment in Class D shares. The transfer abroad of dividend payments is currently authorized by applicable regulations to the extent
that such dividend payments are made in connection with audited financial statements and are approved by a shareholders’ meeting.
See “—Risk Factors—Risks Relating to Argentina—We are subject to exchange and capital controls.”
11
Risk Factors
The risks and uncertainties described below are those known by us as of the date of this report. However, such risks and uncertainties
may not be the only ones that we could face. Additional risks and uncertainties that are unknown to us or that we currently think are
immaterial also may impair our business operations.
Risks Relating to Argentina
The Argentine federal government controls the Company according to domestic energy policies in accordance with Law No. 26,741
(the “Expropriation Law”).
The Argentine federal government controls the Company, and consequently, the federal government is able to determine
substantially all matters requiring approval by a majority of our shareholders, including the election of a majority of our directors, and is
able to direct our operations. The Expropriation Law has declared achieving self-sufficiency in the supply of hydrocarbons as well as in
the exploitation, industrialization, transportation and sale of hydrocarbons, a national public interest and a priority for Argentina. In
addition, its stated goal is to guarantee socially equitable economic development, the creation of jobs, the increase of the competitiveness
of various economic sectors and the equitable and sustainable growth of the Argentine provinces and regions. In addition, should
Argentina be unable to meet its energy requirements, this could have a material adverse impact on the Argentine economy and negatively
impact our results of operations. We cannot assure you that the decisions taken by our controlling shareholders for the purpose of
achieving the targets set forth in the Expropriation Law would not differ from your interests as a shareholder. In addition, according to the
Argentine Constitution, presidential elections take place every four years. Accordingly, changes in policy may result in changes in our
management and/or our strategy. We cannot assure you if and when any such changes may occur, nor the impact they may have on our
business.
Our business is largely dependent upon economic conditions in Argentina.
Substantially all of our operations, properties and customers are located in Argentina, and, as a result, our business is to a large
extent dependent upon economic conditions prevailing in Argentina. The changes in economic, political and regulatory conditions in
Argentina and measures taken by the Argentine government have had and are expected to continue to have a significant impact on us.
You should make your own investigation about Argentina and prevailing conditions in that country before making an investment in us.
The Argentine economy has experienced significant volatility in past decades, including numerous periods of low or negative
growth and high and variable levels of inflation and devaluation. In 2012, the Argentine economy experienced a slowdown with gross
domestic product (“GDP”) increasing at a rate of 1.9% on an annualized basis compared to the preceding year according to the
methodology of calculation prevailing until March 2014. On March 27, 2014, the Argentine government announced a new method of
calculating GDP using 2004 as the base year as opposed to 1993, which was the base reference year under the prior method of calculating
GDP. As a result of this new method, the estimated GDP growth rate for 2013 was revised from 4.9% to 2.9%. As of the date of this
annual report, the provisional figures of the Argentina’s estimated GDP growth rate for 2014 and the first half of 2015 published by the
National Statistics Institute (Instituto Nacional de Estadística y Censos) (“INDEC”) are 0.5% and 2.2%, respectively. No assurances can
be given that the rate of growth experienced over past years will be achieved in subsequent years or that the economy will not contract. If
economic conditions in Argentina were to slow down, or contract, if inflation were to accelerate further, or if the Argentine government’s
measures to attract or retain foreign investment and international financing in the future are unsuccessful, such developments could
adversely affect Argentina’s economic growth and in turn affect our financial condition and results of operations.
Argentina has confronted and continues to confront inflationary pressures. According to inflation data published by INDEC, from
2008 to 2013, the Argentine consumer price index (“CPI”) increased 7.2%, 7.7%, 10.9%, 9.5%, 10.8% and 10.9%, respectively, and the
wholesale price index increased 8.8%, 10.3%, 14.5%, 12.7%, 13.1% and 14.7%, respectively. In 2014, the Argentine government
established a new consumer price index, known as the “IPCNU,” that more broadly reflects consumer prices by considering price
information from the 24 provinces of the country, divided into six regions. According to INDEC, the IPCNU increased 23.9% in 2014
and increased 10.7% from January 2015 to September 2015. The wholesale price index increased 28.3% in 2014 and increased 11.9%
from January 2015 to October 2015. Before the new administration took office, certain private sector analysts believed that the inflation
rate was significantly higher than the rate published by INDEC. On January 7, 2016 through Decree No. 55/2016, the new leadership of
INDEC issued a report declaring a “national statistical emergency.” INDEC stated that its administration since 2006 was irregular and it
would reorganize. As a result, INDEC would not publish new information until at least June 2016. There can be no assurance of the
potential impact these changes may have on our results of operations and financial condition. According to a price index published by the
government of the City of Buenos Aires, inflation in the city was 3.9%, 4.1% and 4.0% in December 2015, January 2016 and February
2016, respectively. Previously, from December 2014 to November 2015, inflation averaged less than 2.0% per month. Increased rates of
inflation in Argentina could increase our costs of operation, and may negatively impact our results of operations and financial condition.
There can be no assurance that inflation rates will not increase in the future.
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Argentine economic results are dependent on a variety of factors, including, but not limited to, the following:
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international demand for Argentina’s principal exports;
international prices for Argentina’s principal commodity exports;
stability and competitiveness of the peso against foreign currencies;
competitiveness and efficiency of domestic industries and services;
levels of consumer consumption and foreign and domestic investment and financing; and
the rate of inflation.
The Argentine economy is also particularly sensitive to local political developments. Mauricio Macri was elected president of
Argentina, and his administration took office on December 10, 2015. The new administration faces challenges in respect of Argentina’s
economy, such as reducing the rate of inflation and a further devaluation of the Argentine peso, improving the competitiveness of the
local industries and normalizing or adjusting prices of certain goods and services, such as electricity and natural gas in certain residential
consumers of Argentina. Some of the measures necessary to meet these objectives could be unpopular and generate political and social
opposition or unrest. As a result, it is difficult to predict the impact of these measures on the Argentine economy as a whole and the
energy sector in particular, including revisions and reforms to pricing mechanisms for oil and gas and elimination of energy subsidies, as
well as other policy changes that may affect the energy sector. This includes decisions that the new administration has already taken, such
as the elimination of exchange restrictions, or future measures it may take to address inflation or changes to the exchange rate.
Uncertainty regarding the measures to be taken by the new administration on the economy could further lead to price volatility of
Argentine companies, including in particular companies like ours in the energy sector, given the high level of regulation. In addition,
there can be no assurance that current government programs and policies that apply to the oil and gas sector will continue in place in the
future. See “—Limitations on local pricing in Argentina may adversely affect our results of operations” and “—Oil and gas prices,
including the recent decline in global prices for oil and gas, could affect our business.”
Argentina’s economy is also vulnerable to adverse developments affecting its principal trading partners. A continued deterioration
of economic conditions in Brazil, Argentina’s main trading partner, and a deterioration of the economies of Argentina’s other major
trading partners, such as China or the United States, could have a material adverse impact on Argentina’s balance of trade and adversely
affect Argentina’s economic growth and may consequently adversely affect our financial condition and results of operations.
Furthermore, a significant devaluation of the currencies of our trading partners or trade competitors may adversely affect the
competitiveness of Argentina and consequently adversely affect Argentina’s economic and our financial condition and results of
operations.
As part of the challenging macroeconomic scenario in Argentina, including peso devaluation and increasing inflation, in 2015,
despite an increase of 10.0% in our net revenue, to Ps. 156,136 million from Ps. 141,942 million in 2014, our operating income decreased
by 16%, to Ps. 16,588 million from Ps. 19,742 million in 2014, and our net income decreased by 50.0%, to Ps. 4,426 million from Ps.
8,849 million in 2014. If these trends continue our results of operation and financial condition would be negatively affected.
In 2005, Argentina restructured a substantial portion of its bond indebtedness with approximately 76% of its bondholders, and in
2006 it settled all of its debt with the International Monetary Fund (“IMF”). In June 2010, Argentina restructured additional defaulted
bond indebtedness that was not swapped in 2005. As a result of the 2005 and 2010 debt swaps, over 92% of the bond indebtedness on
which Argentina had defaulted in 2002 has been restructured (“Exchange Bonds”).
Certain holders of bonds that were not swapped in the debt restructuring have sued Argentina for payment (“Holdout
Bondholders”). On December 7, 2011, the U.S. District Court for the Southern District of New York held that Argentina was required by
the pari passu clause in the 1994 Fiscal Agency Agreement governing the defaulted bonds to rank its payment obligations to the Holdout
Bondholders equally with those of its other debt, including the Exchange Bonds. On February 23, 2012, the District Court enjoined
Argentina from making payments on the Exchange Bonds without making ratable payments on the defaulted debt, and on October 2012,
the District Court’s injunction was affirmed by the U.S. Court of Appeals for the Second Circuit.
On November 21, 2012, the District Court issued an amended order requiring Argentina to pay 100% of the amounts due to the
Holdout Bondholders upon payment of the amounts due on the next maturity date to the Exchange Bondholders. Argentina appealed the
District Court’s November 21, 2012 order to the Second Circuit Court of Appeals, which granted Argentina’s request for a stay of the
order. On August 30, 2013, the Second Circuit Court of Appeals affirmed the District Court’s November 21, 2012 order, but stayed its
decision pending an appeal to the U.S. Supreme Court. On June 16, 2014, the U.S. Supreme Court denied Argentina’s appeal, and with
the appeal process exhausted, the Second Circuit Court of Appeals lifted its stay of the District Court’s order on June 18, 2014.
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On June 26, 2014, Argentina deposited U.S.$832 million due to the Exchange Bondholders for the payment of interest that
matured on June 30, 2014, of which U.S.$539 million was deposited in accounts of the Bank of New York Mellon (“BoNY”), as
indenture trustee, in the Central Bank of Argentina. On June 27, 2014, the District Court referred to such funds as an illegal payment.
On October 22, 2014, the Second Circuit Court of Appeals dismissed Argentina’s appeal of the District Court’s decision finding that
the payment on the Exchange Bonds was illegal and that BoNY, therefore, should retain such funds.
BoNY has invoked the decision of the District Court to not deliver the funds deposited by Argentina to the Exchange
Bondholders. Argentina has asserted that it has complied with its obligation to the Exchange Bondholders by making said deposit,
and that BoNY, as the indenture trustee, has the obligation to deliver those funds to their beneficiaries.
On September 11, 2014, Argentina promulgated Law No. 26,984, which provided for various mechanisms to pay 100% of the
amounts owed on the Exchange Bonds, authorizing for that purpose, among other things, the Minister of Economy and Public
Finance to replace BoNY as indenture trustee and appoint Nación Fideicomisos S.A. instead, and to deposit funds owed to the
Exchange Bondholders in an account created to that end, providing also the possibility for the bondholders to change the trustee, the
jurisdiction or the governing law of the bonds.
On September 29, 2014, the District Court declared Argentina in contempt of court but did not impose sanctions. On October 3,
2014, the District Court ordered Argentina to repair its relations with BoNY, remove Nación Fideicomisos as indenture trustee and
resolve the situation with the Holdout Bondholders.
On March 12, 2015, the District Court held that U.S. dollar-denominated bonds issued by Argentina under Argentine Law
constitute external indebtedness, and, therefore, are covered by the court’s amended injunction dated November 21, 2012.
On May 11, 2015, certain Holdout Bondholders moved to amend the complaint to add two claims: (i) a claim for a declaratory
judgment stating that the “BONAR 2024” bonds issued by Argentina are considered foreign debt, and (ii) a claim for a pari passu
order stating that Argentina must make ratable payments to claimants each time the BONAR 2024 bonds or other amounts are paid
on past or future external debt. On July 16, 2015, the District Court accepted the amended complaint.
Other holders of bonds that were not exchanged in the 2005 and 2010 debt swaps have sought relief similar to that sought by the
Holdout Bondholder plaintiffs (“Me Too Plaintiffs”). On June 5, 2015, the District Court granted summary judgment in 36 of these
cases, declaring that Argentina was in breach of the pari passu clause contained in their bonds. By an order of October 22, 2014, the
District Court granted identical summary judgment in fifteen other Me Too Plaintiffs actions. On August 14, 2015, certain Me Too
Plaintiffs submitted motions requesting a pari passu order similar to that previously obtained by other Holdout Bondholders. Those
Me Too Plaintiffs were afterwards followed by many others, and on October 30, 2015, the District Court granted 49 such motions.
Since the pari passu injunction became effective, litigation has continued regarding Argentina’s efforts to make payments to
Exchange Bondholders. Payments by Argentina have been blocked from reaching the Exchange Bondholders by judicial orders, and
various Exchange Bondholders have sought release of such funds through litigation before the District Court and in various
jurisdictions.
In connection with the Holdout Bondholder litigation against Argentina, the Holdout Bondholders served subpoenas on various
financial institutions in New York seeking the production of documents concerning the accounts and transfers of hundreds of entities
allegedly owned or controlled, in whole or in part, by Argentina, including YPF. During a hearing on September 3, 2013, the District
Court ruled that such discovery could proceed as to, among others, YPF, in order for the Holdout Bondholders to determine if those
documents supported an argument that YPF is an alter ego of Argentina. YPF is not a recipient of any such subpoenas and, as such,
has no obligation to produce documents or otherwise participate in discovery.
On June 17, 2015, the plaintiff NML and other Holdout Bondholders submitted a motion to the District Court alleging
Argentina did not comply with the court’s discovery order dated September 25, 2013 and seeking sanctions, including precluding
Argentina from disputing the Holdout Bondholder’s alter ego allegations as to the Central Bank of Argentina, Energía Argentina
Sociedad Anónima (“ENARSA”), and YPF, and deeming that Argentina’s assets in United States were used for commercial
purposes. During a hearing on August 12, 2015, the District Court found that Argentina had not complied with the September 25,
2013 discovery order and ordered that Argentina’s assets in the United States, except for diplomatic and military assets, be deemed to
be used for commercial purposes. The District Court made no determination as to sanctions, if any, with respect to the alter ego
issues.
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Notably, the District Court has previously held that Banco de la Nación Argentina, or BNA, is not an alter ego of Argentina, and on
August 31, 2015, the Second Circuit Court of Appeals ruled that the Central Bank of Argentina is not an alter ego of Argentina and dismissed
claims asserted against it on that basis. On January 7, 2016, NML filed a writ of certiorari before the Supreme Court of the United States on
appeal of this issue. In addition, the U.S. District Court for the Northern District of California on December 1, 2015 affirmed a magistrate
judge’s ruling that the Holdout Bondholders’ assertion that YPF was an alter ego of Argentina was insufficient to support discovery
concerning YPF. This decision was appealed by NML on December 23, 2015.
In February 2016, Argentina negotiated and reached agreements in principle with respect to a substantial number of the Holdout
Bondholders. On February 5, 2016, Argentina published its proposal to other Holdout Bondholder plaintiffs. Argentina has indicated that it
estimates that the settlement payments for the Holdout Bondholders covered by the pari passu injunctions, if made, would total approximately
U.S.$6.5 billion in cash.
On February 19, 2016, the District Court issued an indicative ruling stating that in light of Argentina’s settlement proposal, and upon
remand of Argentina’s motion to vacate the pari passu injunctions in the Me Too Plaintiffs’ actions from the Court of Appeals, it would grant
a motion to vacate the injunctions in all cases upon the occurrence of two conditions: (1) Argentina’s repeal of the legislative obstacles to
settlement and (2) Argentina’s payment to all Holdout Bondholders that entered into agreements in principle with Argentina on or before
February 29, 2016 in accordance with the terms of such agreements, and notification of such payment to the District Court.
On February 24, 2016, the Court of Appeals remanded the pari passu cases on appeal to the District Court, stating that the order
formalizing the indicative ruling was subject to a motion from Argentina, with notice to all parties and an opportunity to be heard, and that
any such order will be stayed for up to two weeks. Argentina submitted that motion, and the District Court held a hearing of oral arguments on
March 1, 2016. On March 2, 2016, the District Court vacated the injunctions on all actions upon the occurrence of the conditions set forth in
the indicative ruling. During the two week stay, plaintiffs filed appeals and consented to an extended stay. On March 11, the Second Circuit
entered an order staying enforcement of the District Court’s March 2 order pending resolution of the appeals.
There can be no assurance that Argentina will be able to raise sufficient capital or have available cash to fund the payments to the
Holdout Bondholders and other payments it might need to make to settle ongoing litigation, or whether the outcome of this or other potential
future litigation, or the efforts of bondholders to obtain payment from Argentina through other means, such as alter ego theories, will not have
a material adverse effect on Argentina’s economy, YPF’s assets, and/or YPF’s ability to access international financing to repay its obligations.
For additional information related to the evolution of the Argentine economy see “Item 5. Operating and Financial Review and
Prospects—Macroeconomic Conditions.”
Certain risks are inherent in any investment in a company operating in an emerging market such as Argentina.
Argentina is an emerging market economy, and investing in emerging markets generally carries risks. These risks include political,
social and economic instability that may affect Argentina’s economic results which can stem from many factors, including the following:
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high interest rates;
abrupt changes in currency values;
high levels of inflation;
exchange controls;
wage and price controls;
regulations to import equipment and other necessities relevant for operations;
changes in governmental economic or tax policies; and
political and social tensions.
In particular, we continue to actively manage our schedule of work, contracting, procurement and supply-chain activities to effectively
manage costs. However, price levels for capital and exploratory costs and operating expenses associated with the production of crude oil and
natural gas can be subject to external factors beyond our control including, among other things, the general level of inflation, commodity
prices and prices charged by the industry’s material and service providers, which can be affected by the volatility of the industry’s own supply
and demand for such materials and services. In recent years, we and the oil and gas industry generally experienced an increase in certain costs
that exceeded the general trend of inflation. We cannot guarantee that these cost pressures will lessen as result of the decline in prices of crude
oil and other commodities in 2014 and 2015.
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Any of these factors, as well as volatility in the capital markets, may adversely affect our financial condition and results of
operations or the liquidity, trading markets and value of our securities.
The Argentine economy has been adversely affected by economic developments in other markets.
Financial and securities markets in Argentina, and also the Argentine economy, are influenced by economic and market
conditions in other markets worldwide. Considering the recent international turmoil, Argentina’s economy remains vulnerable to
external shocks, including those relating to or similar to the global economic crisis that began in 2008 and the recent uncertainties
surrounding European sovereign debt. For example, the challenges faced by the European Union to stabilize some of its member
economies, such as Greece, Ireland, Italy, Portugal and Spain, have had international implications affecting the stability of global
financial markets, which has hindered economies worldwide. Although economic conditions vary from country to country, investors’
perceptions of events occurring in one country may substantially affect capital flows into and investments in securities from issuers in
other countries, including Argentina.
Consequently, there can be no assurance that the Argentine financial system and securities markets will not continue to be
adversely affected by events in developed countries’ economies or events in other emerging markets, which could in turn, adversely
affect the Argentine economy and, as a consequence, the Company’s results of operations and financial condition.
The implementation of new export duties, other taxes and import regulations could adversely affect our results.
Since 2002, new duties have been implemented on exports, and have been progressively increased over the years. See “Item 4.
Information on the Company—Regulatory Framework and Relationship with the Argentine Government—Market Regulation.”
As a result of the aforementioned export tax increases, we may be, and in certain cases have already been, forced to seek the
renegotiation of export contracts that had previously been authorized by the Argentine government. We cannot provide assurances
that we will be able to renegotiate such contracts on terms acceptable to us.
In addition, in 2012, the Argentine government adopted an import procedure pursuant to which local authorities must pre-
approve any import of products and services to Argentina as a precondition for the importer to have access to the foreign exchange
market to pay for the imported products and services. This procedure was recently modified by the new administration through
Resolution 3823/15, which set forth the “Comprehensive Monitoring System of Imports,” known as “SIMI,” to provide statistical
information in advance of an importation, in order to allow timely analysis of Argentina’s imports, analyze trade defense measures
and avoid delays in delivering imported items to various industries. See “Item 4. Information on the Company—Regulatory
Framework and Relationship with the Argentine Government—Market Regulation.”
We cannot assure you that these taxes and import regulations will not be modified in the future or that other new taxes or import
regulations will not be imposed.
In addition, to address recent declining international crude oil prices, as of December 30, 2014 the Argentine government
reduced certain export taxes to the minimum allowed by law, so that exporting producers of certain hydrocarbon products, including
crude oil, could also partially compensate for the decrease in the price of such products. See “Item 4. Information on the Company—
Regulatory Framework and Relationship with the Argentine Government—Market Regulation.”
We may be exposed to fluctuations in foreign exchange rates.
Our results of operations are exposed to currency fluctuations, and any devaluation of the peso against the U.S. dollar and other
hard currencies may adversely affect our business and results of operations. The value of the peso has fluctuated significantly in the
past, such as in January 2014 when the Argentine peso declined approximately 23% against the U.S. dollar and in December 2015
when the Argentine peso declined approximately 40% against the U.S. dollar. The peso may fluctuate in the future. See “Item 5.
Operating and Financial Review and Prospects—Macroeconomic Conditions” for additional information. The main effects of the
devaluation of the Argentine peso on our net income are related to the accounting treatement of (i) deferred income tax related mainly
to fixed assets, which we expect would have a negative effect; (ii) current income tax, which we expect would have a positive effect;
(iii) increased depreciation and amortization resulting from the remeasurement in pesos of our fixed and intangible assets; and
(iv) exchange rate differences as a result of our exposure to the peso, which we expect would have a positive effect due to the fact that
our functional currency is the U.S. dollar.
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We are unable to predict whether, and to what extent, the value of the peso may further depreciate or appreciate against the U.S. dollar
and how any such fluctuations would affect our business.
Variations in interest rates and exchange rate on our current and/or future financing arrangements may result in significant increases in
our borrowing costs.
We are permitted to borrow funds to finance the purchase of assets, incur capital expenditures, repay other obligations and finance
working capital. As of December 31, 2015, a significant part of our total debt is sensitive to changes in interest rates. See “Item 11.
Quantitative and Qualitative Disclosures about Market Risk—Interest rate exposure.” Consequently, variations in interest rates could result in
significant changes in the amount required to be expected to cover to debt service obligations and in our interest expense thus affecting our
results and financial condition.
In addition, interest and principal amounts payable pursuant to debt obligations denominated in or indexed to U.S. dollars are subject to
variations in the Argentine/U.S. currency exchange rate that could result in a significant increase in the amount of the interest and principal
payments in respect of such debt obligations.
We are subject to exchange and capital controls.
In the past, Argentina imposed exchange controls and transfer restrictions substantially limiting the ability of companies to retain foreign
currency or make payments abroad. Beginning in 2011, additional foreign exchange controls have been imposed that restrict or limit
purchases of foreign currency and transfers of foreign currency abroad. Since 2011, oil and gas companies (including YPF), among other
entities, were required to repatriate 100% of their foreign currency export receivables. See “Item 4. Information on the Company—Regulatory
Framework and Relationship with the Argentine Government—Repatriation of Foreign Currency.”
In December 2015, the new administration eliminated certain exchange controls imposed by the previous administration, such as (i) the
requirement that foreign currency be deposited and exchanged in Argentina in respect of finance transactions outside Argentina, and (ii) the
requirement that 30% of funds in U.S. dollars held in Argentina be frozen pursuant to Decree No. 616/05. Following these changes, the peso
fell to Ps. 12.99 per U.S.$1.00, as of December 31, 2015, a decrease of approximately 52% compared to December 31, 2014. Between
December 16, 2015 and December 31, 2015, the peso decreased approximately 40% against the U.S. dollar. As of March 15, 2016, the peso
fell to Ps. 14.61 per U.S.$1.00, a decrease of approximately 12% compared to December 31, 2015. There can be no assurance that future
regulatory changes related to exchange and capital controls will not adversely affect our financial condition or results of operations, our ability
to meet our obligations denominated in foreign currency or our ability to execute our financing and capital expenditure plans.
Our access to international capital markets and the market price of our shares are influenced by the perception of risk in Argentina and
other emerging economies.
International investors consider Argentina to be an emerging market. Economic and market conditions in other emerging market
countries, especially those in Latin America, influence the market for securities issued by Argentine companies. Volatility in securities
markets in Latin America and in other emerging market countries may have a negative impact on the trading value of our securities and on our
ability and the terms on which we are able to access international capital markets.
Moreover, recent regulatory and policy developments in Argentina, including the enactment of the Expropriation Law, as well as the
litigation of the Argentine government with Holdout Bondholders have led to considerable volatility in the market price of our shares and
ADSs. See “—Our business is largely dependent upon economic conditions in Argentina.” We cannot assure that the perception of risk in
Argentina and other emerging markets may not have a material adverse effect on our ability to raise capital and on the trading values of our
debt or equity securities. We can give no assurance as to potential adverse impact of the factors discussed above on our financial condition
and/or results of operations. See “Item 4. Information on the Company—History and Development of YPF.”
We could be required to reveal confidential information.
On November 10, 2015, the Argentine Supreme Court ordered us to furnish information regarding an agreement we entered into based
on the requirements of Decree No. 1172/03, which regulates access to information considered public. The agreement aims to develop
hydrocarbon resources in Argentina. The information was delivered to the court on February 23, 2016. We believe that public disclosure of
confidential information could put us at a competitive disadvantage in relation to our contracting parties and potential partners. For this
reason, and given the business, industrial, technical, economic and financial value as well as the nature of the information requested, we are
pursuing all avenues to preserve its confidentiality. We have stated we intend to comply with the requirements of the aforementioned decree
while preserving our rights to keep certain industrial, commercial, financial and technical issues matters confidential as provided by the
decree. Notwithstanding the foregoing, on March 14, 2016, the judge ordered us to deliver within five business days the requested agreement
without a chance to keep certain information confidential as requested by us and in accordance with the exemptions contemplated by Decree
No. 1172/03. On March 16, 2016, the Company appealed that decision.
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As a result, there can be no assurance that the application of Decree No. 1172/03 in respect of the disclosure of confidential
information regarding our operations will not affect our ability to conduct certain business or access the financing through potential
new agreements with other partners, the occurrence of which could affect our results of operations and financial condition.
Risks Relating to the Argentine Oil and Gas Business and Our Business
Our domestic operations are subject to extensive regulation.
The oil and gas industry is subject to government regulation and control. As a result, our business is to a large extent dependent
upon regulatory and political conditions prevailing in Argentina and our results of operations may be adversely affected by regulatory
and political changes in Argentina. Therefore, we face risks and challenges relating to government regulation and control of the
energy sector, including those set forth below and elsewhere in these risk factors:
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limitations on our ability to increase local prices or to reflect the effects of higher domestic taxes, increases in
production costs or increases in international prices of crude oil and other hydrocarbon fuels and exchange rate
fluctuations on our domestic prices. See “—Limitations on local pricing in Argentina may adversely affect our
results of operations;”
higher taxes on exports of hydrocarbons;
restrictions on hydrocarbon export volumes driven mainly by the requirement to satisfy domestic demand;
in connection with the Argentine government’s policy to provide absolute priority to domestic demand, regulatory
orders to supply natural gas and other hydrocarbon products to the domestic retail market in excess of previously
contracted amounts;
in connection with the former and current incentive programs established by the Argentine government for the oil
and gas industry, such as the Natural Gas Additional Injection Stimulus Program (“Gas Plan”) (see “Risk Factors—
A significant percentage of our cash flow from operations is derived from counterparties that are governmental
entities”), cash collection of balances with the Argentine government;
legislation and regulatory initiatives relating to hydraulic stimulation and other drilling activities for unconventional
oil and gas hydrocarbons which could increase our cost of doing business or cause delays and adversely affect our
operations;
restrictions on imports of products which could affect our ability to meet our delivery commitments or growth plans,
as the case may be; and
the implementation or imposition of stricter quality requirements for petroleum products in Argentina.
The Argentine government has made certain changes in regulations and policies governing the energy sector to give absolute
priority to domestic supply at stable prices in order to sustain economic recovery. As a result of the above-mentioned changes, for
example, on days during which a gas shortage occurs, exports of natural gas (which are also affected by other government curtailment
orders) and the provision of gas supplies to industries, electricity generation plants and service stations selling compressed natural gas
are interrupted for priority to be given to residential consumers at lower prices. More recently, the Expropriation Law has declared
achieving self-sufficiency in the supply of hydrocarbons as well as in the exploitation, industrialization, transportation and sale of
hydrocarbons, a national public interest and a priority for Argentina. In addition, its stated goal is to guarantee socially equitable
economic development, the creation of jobs, the increase of the competitiveness of various economic sectors and the equitable and
sustainable growth of the Argentine provinces and regions. See “Item 4. Information on the Company—Regulatory Framework and
Relationship with the Argentine Government—The Expropriation Law”, and “—Risks Relating to Argentina—The Argentine federal
government will control the Company according to domestic energy policies in accordance with Law No. 26,741 (the “Expropriation
Law”).” Moreover, we cannot assure you that changes in applicable laws and regulations, or adverse judicial or administrative
interpretations of such laws and regulations, will not adversely affect our results of operations. See “Item 4. Information on the
Company—Regulatory Framework and Relationship with the Argentine Government.”
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Limitations on local pricing in Argentina may adversely affect our results of operations.
Due to regulatory, economic and government policy factors, our domestic gasoline, diesel and other fuel prices have
substantially differed from those prevailing international and regional market prices for such products, and our ability to increase
prices in connection with international price increases or domestic cost increases has been limited. In addition, revenues we obtain as
a result of selling natural gas in Argentina (including amounts received through the Gas Plan, see “Item 4. Information on the
Company—Regulatory Framework and Relationship with the Argentine Government—Market Regulation—Natural gas”) are subject
to government regulations and could be negatively affected, principally if the Gas Plan were modified, canceled or not extended past
its current expiration date. The prices that we are able to obtain for our hydrocarbon products affect the viability of investments in
new exploration, development and refining and, as a result, the timing and amount of our projected capital expenditures for such
purposes. We budget capital expenditures by taking into account, among other things, market prices for our hydrocarbon products.
For additional information on domestic pricing for our products, see “Item 4. Information on the Company—Regulatory Framework
and Relationship with the Argentine Government—Market Regulation.” We cannot provide any assurances that we will be able to
increase the domestic prices of our products to reflect the effects of increased production costs, domestic taxes and exchange rate
fluctuations. Limitations on our ability to do so would adversely affect our financial condition and results of operations. Similarly, we
cannot assure you that hydrocarbon prices in Argentina will match the increases or decreases in hydrocarbon prices at the
international or regional levels.
A significant percentage of our cash flow from operations is derived from counterparties that are governmental entities.
In the normal course of business, and considering that YPF is the primary oil and gas company in Argentina, its portfolio of
clients and suppliers includes both private sector and governmental entities. All material transactions and balances with related parties
as of December 31, 2015 are set forth in Note 6 to the Audited Consolidated Financial Statements, including those related to the
Natural Gas Additional Injection Stimulus Program and the Oil Production Stimulus Program. As of December 31, 2015, the
accounts receivable balance corresponding to the Natural Gas Additional Injection Stimulus Program reflects nine months of accrued,
unpaid payments, representing approximately Ps. 9.9 billion. This receivable is due to an increase in the standard payment timetable
under the program that in the past was an average of between four to six months from the month of accrual. As of the date of this
annual report, we have not yet received any payments related to amounts accrued and unpaid as of December 31, 2015 under such
programs. We cannot guarantee that new regulations or interpretations of current regulations would not impair our rights in
connection with such amounts due from national, provincial and municipal governmental entities. This could consequently affect our
financial condition and results of operations. In addition, if certain governmental counterparties were (i) not able to pay or redeem
such accrued amounts in cash or cash equivalents, or (ii) not able to make such payments or redemptions according to our estimated
schedule, our financial condition and results of operations would be adversely affected.
We are subject to direct and indirect export restrictions, which have affected our results of operations and caused us to declare
force majeure under certain of our export contracts.
The Argentine Hydrocarbons Law, Law No. 17,319, allows for hydrocarbon exports as long as they are not required for the
domestic market and are sold at reasonable prices. In the case of natural gas, Law No. 24,076 and related regulations require that the
needs of the domestic market be taken into account when authorizing long-term natural gas exports.
During the last several years, the Argentine authorities have adopted a number of measures that have resulted in restrictions on
exports of natural gas from Argentina. Due to the foregoing, we have been obliged to sell a part of our natural gas production
previously destined for the export market in the local Argentine market and have not been able to meet our contractual gas export
commitments in whole or, in some cases, in part, leading to disputes with our export clients and forcing us to declare force majeure
under our export sales agreements. We believe that the measures mentioned above constitute force majeure events that relieve us
from any contingent liability for the failure to comply with our contractual obligations, although no assurance can be given that this
position will prevail.
See “Item 4. Information on the Company—Exploration and Production—Delivery commitments—Natural gas supply
contracts,” “Item 4. Information on the Company—Exploration and Production—The Argentine natural gas market,” and “Item 8.
Financial Information—Legal Proceedings.”
Crude oil exports, as well as the export of most of our hydrocarbon products, currently require prior authorization from the
Argentine Secretariat of Energy pursuant to the regime established under Resolution S.E. No. 1679/04, as amended and supplemented
by other regulation. Oil companies seeking to export crude oil or LPG must first demonstrate that the local demand for such product
is satisfied or that an offer to sell the product to local purchasers has been made and rejected. Oil refineries seeking to export diesel
must also first demonstrate that the local demand for diesel is duly satisfied. Because domestic diesel production does not currently
satisfy Argentine domestic consumption needs, we have been prevented since 2005 from selling diesel production in the export
market, and we are obliged to sell in the local market at prevailing domestic prices.
19
We are unable to predict how long these export restrictions will be in place, or whether any further measures will be adopted that
adversely affect our ability to export gas, crude oil and diesel or other products and, accordingly, our results of operations.
Oil and gas prices, including the recent decline in global prices for oil and gas, could affect our business.
We budget capital expenditures related to exploration, development, refining and distribution activities by taking into account, among
other things, current and expected local and international market prices for our hydrocarbon products.
The international price of crude oil has fluctuated significantly in the past and may continue to do so the future. In recent months, the
international price of a barrel of Brent crude oil fell below U.S.$35. This is a decrease of approximately U.S.$17 per barrel from the 2015
average of U.S.$52.30 per barrel, representing an approximately 33% decrease. While in the past, domestic oil prices in Argentina have not
reflected increases or decreases in international oil prices, the significant decline discussed above resulted in an approximately U.S.$7.00
reduction during 2015 of the domestic price per barrel compared to the price in effect on December 31, 2014, and an additional
approximately 10% reduction in 2016 compared to the price in effect on December 31, 2015, resulting in a price of U.S.$67.50 and
U.S.$54.90 per barrel for Medanito and Escalante crude, respectively. If international crude prices remain at current levels or continue to
drop for an extended period of time and this is reflected in the domestic price of oil, which we cannot control, it could cause the economic
viability of drilling projects to be reduced. This could lead to changes to our development plans, which could in turn lead to the loss of
proved reserves and proved undeveloped reserves. It could also affect our assumptions and estimates and, as a result, affect the recovery
value of certain assets. Furthermore, if these conditions are reflected in the domestic prices of our refined products, which as of the date of
this annual report are in general above international prices, our ability to generate cash and our results of operations could be adversely
affected.
In light of the above and assuming current domestic prices for certain products do not match cost increases (including those related to
the increase in the value of the U.S. dollar against the Argentine peso) in accordance with higher and more complex investments, mainly as a
result of the development of unconventional resources, and also with evolution of the economy, our ability to improve our hydrocarbon
recovery rates, find new reserves, develop unconventional resources and carry out certain of our other capital expenditure plans could be
adversely affected, which in turn would have an adverse effect on our financial conditions and results of operations. Furthermore, we may be
required to write down the carrying value of our properties if oil prices decline or if we have substantial downward adjustments to our
estimated proved reserves, increases in our operating costs, among others. See additionally “Item 5. Operating and Financing Review and
Prospects—Critical Accounting Policies” for information regarding our sensitivity analysis related to impairment. In addition, if a reduction
in our capital expenditures materializes, including the capital expenditures of our domestic competitors, it would likely have a negative
impact on the number of active drilling rigs, workovers and pulling equipment in Argentina, including related services, thus affecting the
number of active workers in the industry. We are unable to predict whether, and to what extent, the potential consequences of such measures
would affect our business, mainly the impact on our production and consequently our financial condition and results of operations. See “—
We could be subject to organized labor action.”
Our reserves and production are likely to decline.
Most of our existing oil and gas producing fields in Argentina are mature and, as a result, our reserves and production are likely to
decline as reserves are depleted. Our production declined by approximately 8.4% in 2011 and 0.6% in 2012 on a boe/d basis. However, as a
result of increased development and exploration activity in 2013, 2014 and 2015, including the production that came from our acquired
properties, our production increased by approximately 1.7%, 13.5% and 3.0%, respectively, on a boe/d basis. In addition, the reserves
replacement ratio (increases in reserves in the year, net divided by the production of the year) was 154% in 2013, 163% in 2014 and 107% in
2015.
We face certain challenges in order to replace our proved reserves with other categories of hydrocarbons. However, the continuous
comprehensive technical review of our oil and gas fields allows us to identify opportunities to rejuvenate mature fields and optimize new
fields developments in Argentine basins with the aim of achieving results similar to those achieved by mature fields in other regions of the
world (which have achieved substantially higher recovery factors with the application of new technology). Additionally, we have been
completing the renewal of most of our concessions, allowing us to develop certain strategic projects related to waterflooding, enhanced oil
recovery and unconventional resources, which represent an important opportunity not only for the Company but also for Argentina. We
expect that unconventional development will require higher investment in future years, principally in connection with the Vaca Muerta
formation. These investments are expected to yield substantial economies of scale and to significantly increase recovery rates from this
resource play. Other resource plays, unconventional prospects, exist in Argentina and have positioned the country amongst the most
attractive in terms of worldwide unconventional resource potential. Nevertheless, the financial viability of these investments and reserve
recovery efforts will generally depend on the prevailing economic and regulatory conditions in Argentina, as well as the market prices of
hydrocarbon products, and are also subject to material risks inherent to the oil and gas industry and may prove unsuccessful. See “—Our
business plan includes future drilling activities for unconventional oil and gas reserves, such as shale oil and gas extraction, and if we are
unable to successfully acquire and use the necessary new technologies and other support as well as obtain financing and venture partners,
our business may be adversely affected.”
20
Our oil and natural gas reserves are estimates.
Our oil and gas proved reserves are estimated using geological and engineering data to determine with reasonable certainty
whether the crude oil or natural gas in known reservoirs is recoverable under existing economic and operating conditions. The
accuracy of proved reserve estimates depends on a number of factors, assumptions and variables, some of which are beyond our
control. Factors susceptible to our control include drilling, testing and production after the date of the estimates, which may require
substantial revisions to reserves estimates; the quality of available geological, technical and economic data used by us and our
interpretation thereof; the production performance of our reservoirs and our recovery rates, both of which depend in significant part
on available technologies as well as our ability to implement such technologies and the relevant know-how; the selection of third
parties with which we enter into business; and the accuracy of our estimates of initial hydrocarbons in place, which may prove to be
incorrect or require substantial revisions. Factors mainly beyond our control include changes in prevailing oil and natural gas prices,
which could have an effect on the quantities of our proved reserves (since the estimates of reserves are calculated under existing
economic conditions when such estimates are made); changes in the prevailing tax rules, other government regulations and
contractual conditions after the date estimates are made (which could make reserves no longer economically viable to exploit); and
certain actions of third parties, including the operators of fields in which we have an interest.
Information on net proved reserves as of December 31, 2015, 2014 and 2013 was calculated in accordance with SEC rules and
FASB’s ASC 932, as amended. Accordingly, crude oil prices used to determine reserves were calculated each month, for crude oils of
different quality produced by us.
As previously discussed, domestic prices for oil and gas products and derivatives have demonstrated in recent years they do not
follow international prices both in the down and upside, mainly as a result of domestic economic variables affecting Argentina such
as regulations, labor costs, labor unions, political, economic and social constraints, among others. Accordingly, for calculations of our
net proved reserves as of December 31, 2015, we considered the realized prices for crude oil in the domestic market, which are higher
than those prevailing in the international market, taking into account the unweighted average price for each month within the twelve-
month period ending December 31, 2015.
Commodity prices in general have declined significantly since 2014. If these prices do not increase significantly, and domestic
prices for crude oil were reduced in line with international prices, our future calculations of estimated proved reserves would be based
on lower prices. This could result in our having to remove non-economic reserves from our proved reserves in future periods. Holding
all other factors constant, if commodity reference prices used in our year-end reserve estimates were decreased for crude oil to match
international prices of approximately U.S.$40 per barrel for WTI, and considering such prices since January 1, 2016, our total proved
reserves as of December 31, 2015 would decrease by approximately 39%. Holding all other factors constant, if commodity reference
prices used in our year-end reserve estimates were decreased for crude oil to match the current prices for crude oil in the domestic
market since January 1, 2016 of approximately U.S.$67.50 per barrel for WTI equivalent quality, and considering such prices since
January 1, 2016, our total proved reserves at December 31, 2015 would decrease by approximately 5%. In addition, as a result of the
prices used to calculate the present value of future net revenues from our proved reserves, in accordance with SEC rules, which are
similar to the calculation of proved reserves described above, the present value of future net revenues from our proved reserves will
not necessarily be the same as the current market value of our estimated crude oil and natural gas reserves. In particular, they may be
reduced due to the recent significant decline in commodity prices if such prices do not increase significantly and domestic prices were
reduced in line with international prices.
As a result of the foregoing, measures of reserves are not precise and are subject to revision. Any downward revision in our
estimated quantities of proved reserves could adversely impact our financial results by leading to increased depreciation, depletion
and amortization charges or impairment charges, which would reduce earnings and shareholders’ equity. See “—Oil and gas prices,
including the recent decline in global prices for oil and gas, could affect our business.”
Oil and gas activities are subject to significant economic, environmental and operational risks.
Oil and gas exploration and production activities are subject to particular economic and industry-specific operational risks, some
of which are beyond our control, such as production, equipment and transportation risks, as well as natural hazards and other
uncertainties, including those relating to the physical characteristics of onshore and offshore oil or natural gas fields. Our operations
may be curtailed, delayed or cancelled due to bad weather conditions, mechanical difficulties, shortages or delays in the delivery of
equipment, compliance with governmental requirements, fire, explosions, blow-outs, pipe failure, abnormally pressured formations,
and environmental hazards, such as oil spills, gas leaks, ruptures or discharges of toxic gases. In addition, we operate in politically
sensitive areas where the native population has interests that from time to time may conflict with our production objectives. If these
risks materialize, we may suffer substantial operational losses and disruptions to our operations and harm to our reputation. Drilling
may be unprofitable, not only with respect to dry wells, but also with respect to wells that are productive but do not produce sufficient
revenues to return a profit after drilling, operating and other costs are taken into account.
21
Our business plan includes future drilling activities for unconventional oil and gas reserves, such as shale oil and gas extraction,
and if we are unable to successfully acquire and use the necessary new technologies and other support as well as obtain financing
and venture partners, our business may be adversely affected.
Our ability to execute and carry out our business plan depends upon our ability to obtain financing at a reasonable cost and on
reasonable terms. We have identified drilling locations and prospects for future drilling opportunities of unconventional oil and gas
reserves, such as the shale oil and gas in the Vaca Muerta formation. These drilling locations and prospects represent a part of our
future drilling plans. Our ability to drill and develop these locations depends on a number of factors, including seasonal conditions,
regulatory approvals, negotiation of agreements with third parties, commodity prices, costs, access to and availability of equipment,
services and personnel and drilling results. In addition, as we do not have extensive experience in drilling and exploiting
unconventional oil and gas reserves, the drilling and exploitation of such unconventional oil and gas reserves depends on our ability
to acquire the necessary technology and hire personnel and other support needed for extraction or obtain financing and venture
partners to develop such activities. Furthermore, in order to implement our business plan, including the development of our oil and
natural gas exploration activities and the development of refining capacity sufficient to process increasing production volumes, we
will need to raise significant amounts of debt capital in the financial and capital markets. We cannot guarantee that we will be able to
obtain the necessary financing or obtain financing in the international or local financial markets at reasonable cost and on reasonable
terms to implement our new business plan or that we would be able to successfully develop our oil and natural gas reserves and
resources (mainly those related to our unconventional oil and gas business plan). Because of these uncertainties, we cannot give any
assurance as to the timing of these activities or that they will ultimately result in the realization of proved reserves or meet our
expectations for success, which could adversely affect our production levels, financial condition and results of operations.
We may not have sufficient insurance to cover all the operating hazards that we are subject to.
As discussed under “—Oil and gas activities are subject to significant economic, environmental and operational risks” and “—
We may incur significant costs and liabilities related to environmental, health and safety matters,” our exploration and production
operations are subject to extensive economic, operational, regulatory and legal risks. We maintain insurance covering us against
certain risks inherent in the oil and gas industry in line with industry practice, including loss of or damage to property and equipment,
control-of well incidents, loss of production or income incidents, removal of debris, sudden and accidental seepage pollution,
contamination and clean up and third-party liability claims, including personal injury and loss of life, among other business risks.
However, our insurance coverage is subject to deductibles and limits that in certain cases may be materially exceeded by our
liabilities. In addition, certain of our insurance policies contain exclusions that could leave us with limited coverage in certain events.
See “Item 4. Information on the Company—Insurance.” In addition, we may not be able to maintain adequate insurance at rates or on
terms that we consider reasonable or acceptable or be able to obtain insurance against certain risks that materialize in the future. If we
experience an incident against which we are not insured, or the costs of which materially exceed our coverage, it could have a
material adverse effect on our business, financial condition and results of operations.
Argentine oil and gas production concessions and exploration permits are subject to certain conditions and may be cancelled or
not renewed.
As modified by Law No. 27,007, the Hydrocarbons Law provides for oil and gas concessions to remain in effect for 25 years as
from the date of their award, 35 years for unconventional concessions and 30 years for offshore concessions. It further provides that
concession terms may be extended for periods of up to 10 years each. The authority to extend the terms of current and new permits,
concessions and contracts has been vested in the governments of the provinces in which the relevant area is located (and the federal
government in respect of offshore areas beyond 12 nautical miles). In order to be eligible for an extension of a concession, under the
modifications of Law No. 27,007, concessionaires must (i) have complied with their obligations, (ii) be producing hydrocarbons in
the concession under consideration and (iii) submit an investment plan for the development of such areas as requested by the
competent authorities up to a year prior to the termination of each term of the concession. Under the Hydrocarbons Law, non-
compliance with the obligations and standards set out therein may also result in the imposition of fines and in the case of material
breaches, following the expiration of applicable cure periods, the revocation of the concession or permit.
We cannot provide assurances that any of our concessions will be extended as a result of the consideration by the relevant
authorities of the investment plans the Company would submit in the future for the development of the areas as of the date of
requesting the extension periods for the relevant areas for the Company, or other requirements will not be imposed on us in order to
obtain extensions as of the date of expiration. Additional royalty payments of 3%, up to a maximum of 18%, are provided for in
extensions under Law No. 27,007. The termination of, or failure to obtain the extension of, a concession or permit, or its revocation,
could have a material adverse effect on our business and results of operations.
22
Our acquisition of exploratory acreage and crude oil and natural gas reserves is subject to heavy competition.
We face intense competition in bidding for crude oil and natural gas production areas, especially those areas with the most
attractive crude oil and natural gas reserves. As a result, the conditions under which we are able to access new exploratory or
productive areas could be adversely affected. In addition, fewer offerings of exploratory acreages available to be bid upon could
affect our future results.
We may incur significant costs and liabilities related to environmental, health and safety matters.
Our operations, like those of other companies in the oil and gas industry, are subject to a wide range of environmental, health
and safety laws and regulations in the countries in which we operate. These laws and regulations have a substantial impact on our
operations and those of our subsidiaries, and could result in material adverse effects on our financial position and results of operation.
In addition, YPF Holdings, a wholly-owned subsidiary of YPF, has certain environmental liabilities. See “Item 8. Financial
Information—Legal Proceedings —YPF Holdings.” A number of events related to environmental, health and safety matters,
including changes in applicable laws and regulations, adverse judicial or administrative interpretations of such laws and regulations,
changes in enforcement policy, the occurrence of new litigation or development of pending litigation, and the development of
information concerning these matters, could result in new or increased liabilities, capital expenditures, reserves, losses and other
impacts that could have a material adverse effect on our financial condition and results of operations. See “Item 8. Financial
Information—Legal Proceedings,” “Item 4. Information on the Company—Regulatory Framework and Relationship with the
Argentine Government—Argentine Environmental Regulations” and “Item 4. Information on the Company—Regulatory Framework
and Relationship with the Argentine Government—U.S. Environmental Regulations.”
Environmental, health and safety regulation and jurisprudence in Argentina is developing at a rapid pace and no assurance can
be provided that such developments will not increase our cost of doing business and liabilities, including with respect to drilling and
exploitation of our unconventional oil and gas reserves. In addition, due to concern over the risk of climate change, a number of
countries have adopted, or are considering the adoption of, new regulatory requirements to reduce greenhouse gas emissions, such as
carbon taxes, increased efficiency standards or the adoption of cap and trade regimes. If adopted in Argentina, these requirements
could make our products more expensive as well as shift hydrocarbon demand toward relatively lower-carbon sources such as
renewable energies.
We may incur significant costs and liabilities depending on the ultimate design and implementation of the remedial action
approved by the U.S. Environmental Protection Agency (“EPA”) regarding the Focused Feasibility Study for remedial action with
respect to environmental contamination of the lower eight miles of the Passaic River in New Jersey and any other action by the
EPA related to the Newark Bay Complex.
As previously mentioned, YPF Holdings, a wholly-owned subsidiary of YPF, is subject to certain environmental liabilities. In
particular, in June 2007, the EPA released a draft Focused Feasibility Study (“FFS”) that outlined several alternatives for remedial
action in the lower eight miles of the Passaic River. As a result of comments received, the EPA withdrew the FFS for revision and
further consideration in light of the comments. On November 14, 2013, the EPA described four alternatives it was considering in the
revised FFS, including: (i) no action, (ii) deep dredging with backfill of 9.7 million cubic yards over 12 years, which it estimated
would cost U.S.$1.4 billion to U.S.$3.5 billion, depending on whether the dredged sediment is disposed of in a confined aquatic
disposal facility (“CAD”) at the bottom of Newark Bay, at an off-site disposal facility or locally decontaminated and put to beneficial
use; (iii) capping with dredging of 4.3 million cubic yards over six years, which it estimated would cost U.S.$1.0 billion to U.S.$1.8
billion, depending on whether there is a CAD, off-site disposal or local decontamination and beneficial use; and (iv) one additional
alternative that it subsequently discarded.
On April 11, 2014, the EPA published the revised FFS for the lower eight miles of the Passaic River in final form. In the final
FFS, the EPA recommended as its preferred remedial action for this area removal of approximately 4.3 million cubic yards of
sediment through bank-to-bank dredging, which sediments would then be dehydrated locally and transported by train for their
incineration or disposal at an off-site disposal facility. An engineering cap (a physical barrier mainly consisting of sand and stone)
would then be placed over the bank-to-bank dredged area. In its final FFS, the EPA estimated the cost of the preferred remedy
(without CAD) for the lower eight miles of Passaic River to be U.S.$1,731 million (present value estimated with a 7% discount rate).
23
On August 20, 2014, Maxus and Tierra, on behalf of Occidental, submitted extensive comments on the final FFS to the EPA.
The main comments offered by Maxus, Tierra and Occidental on the final FFS were:
•
•
•
•
•
•
The FFS is not a process legally authorized to select the type and size of remediation proposed by the EPA for the
lower eight miles of the Passaic River;
The FFS is based on a flawed site design;
The FFS overstates the human health and ecological risk issues;
The proposed remediation plan is not executable or economically reasonable in terms of cost-benefit;
The processes of the EPA Region 2 have a lack of public transparency; and
The inclusion in the remediation plan of dredging for navigational purposes is not covered by the regulation.
In addition to the comments received from Maxus and Tierra, the EPA also received comments from approximately 400 other
companies, institutions, government agencies, non-governmental organizations and individuals, including the CPG, Amtrak (the
federal railway company), NJ Transit, the American Army Corps of Engineers, the Passaic Valley Sewerage Commission, yacht
clubs, public officials and others.
In addition to commenting on the final FFS, Maxus and Tierra have proposed a preliminary project called In-ECO, which is an
ecological and sustainable bio-remediation alternative, as a substitute for the remediation chosen by the EPA in its final FFS. Maxus
and Tierra presented In-ECO to the EPA in May 2014. The EPA provided comments in September 2014, and Maxus and Tierra
presented a revised version in November 2014. The EPA provided additional comments to the In-ECO Statement of Work in March
2015. Tierra subsequently developed responses to those comments and submitted them to the EPA. A meeting was held in September
2015 between Tierra, its experts and the EPA. During this meeting, certain issues were resolved, and laboratory studies are now
anticipated to begin sometime in early 2016.
In October 2015, the U.S. Government Accountability Office (the “GAO”) advised Maxus, Tierra and Occidental that it had
commenced a study on some “Superfund” sites with sediment contamination issues, including the Lower Section of the Passaic River,
at the request of the Committee of Environmental Matters and Public Works of the United States Senate. It is anticipated that the
GAO’s report will be made public in the third quarter of 2016.
On March 4, 2016, subsequent to the issuance of the accompanying Financial Statements, EPA released the Record of Decision
for the “Lower 8.3 Miles of the Lower Passaic River, Part of the Diamond Alkali Superfund Site—Essex and Hudson Counties, New
Jersey” (hereinafter, the “ROD”).
The ROD presented the selected remedy to address contaminated sediments found in the lower 8.3 miles of the Lower Passaic
River, a part of the Diamond Alkali Superfund Site. In this regard, the EPA selected Alternative 3 (capping with dredging for
flooding and navigation of 3.5 million cubic yard over 6 years term). This approach is consistent with the alternative selected in the
Second Draft FFS – 2014 but for the amount of sediment to be removed through bank-to-bank dredging (which was approximately
4.3 million cubic yards in the FFS 2014 draft and is approximately 3.5 million cubic yards in the ROD).
The ROD provides that the estimated total net present value costs to be US$ 1,382 million. This amount is consistent with the
amount provided in the FFS – 2014 Draft, taking in consideration a reduction of 0.8 million cubic yards to be removed between the
two reports. According to the EPA, a major source of dioxin in the river was discharges from the former Diamond Alkali facility in
Newark, where the production of Agent Orange and other pesticides during the 1960s generated dioxin that contaminated the land
and the river.
The EPA further stated that the selected alternative is the first of three remedies to be selected for the Lower Passaic/Newark
Bay waterway, highlighting that separate RI/FSs are being conducted for the full 17-mile Lower Passaic River Study Area and for the
Newark Bay Study Area. Accordingly, the EPA expects the three remedies to be integrated into a comprehensive response action.
In accordance with the issuance of the ROD, the EPA stated that now that the cleanup plan has been selected, the EPA will
immediately begin discussions with those responsible for the contamination to seek their performance of or payment for the cleanup
work. The EPA stated that once the legal process concludes, the design of the activities necessary to carry out the cleanup will be
outlined in a legally binding document. The EPA expects that the design will take three to four years to complete. In accordance with
the EPA, the dredging, dewatering and disposal of dredged materials and related construction work will follow and is expected to take
six years to complete.
24
At this time, there is significant uncertainty regarding the outcome of any allocation negotiation or mediation process to estimate
the percentage share to Occidental for which Maxus might be liable under the indemnity.
Based on (a) the uncertainties identified by the Company as of the date of this annual report, including but not limited to (i) the
extraordinary volume of sediment materials for which, to date, the sediment treatment technologies have neither been constructed nor
operated in the United States on a scale commensurate with the capacity that would be necessary for the remedial work this
remediation that this project would be requiring, (ii) the results of the studies and discoveries yet to be produced, (iii) the number and
diversity of contaminants of concern identified by the ROD (furans, PCB’s, mercury, copper, dieldrin, PAHs, lead, dioxins and
DDT), many of which have not been previously associated with the Lister Site and/or have been generated by other potentially
responsible parties, (iv) the number and diversity of potential responsible parties involved in the matter (EPA identified more than
one hundred potential responsible parties), and (v) the final allocation of the removal and remediation costs; (b) consultation with our
internal and external counsel; (c) the amounts previously incurred and recorded by YPF Holdings in remediation activities in the area
covered by the ROD; and (d) the limitation on responsibility that YPF may have as an indirect controlling shareholder of Maxus, no
additional liability has been accrued for this environmental matter as of the date of this annual report. Depending on the final outcome
of this matter, our financial condition and results of operation could be negatively affected. In addition, taking into account YPF
Holdings’ economic and financial situation, we cannot assure you that as a result of the final costs of the FFS, YPF Holdings would
not fail to make payments related thereto. See “Item 8. Financial Information—Legal Proceedings—YPF Holdings.”
We face risk relating to certain legal proceedings.
As described under “Item 8. Financial Information—Legal Proceedings,” we are party to a number of labor, commercial, civil,
tax, criminal, environmental and administrative proceedings that, either alone or in combination with other proceedings, could, if
resolved in whole or in part adversely to us, result in the imposition of material costs, fines, judgments or other losses. While we
believe that we have provisioned such risks appropriately based on the opinions and advice of our external legal advisors and in
accordance with applicable accounting rules, certain loss contingencies, particularly those relating to environmental matters, are
subject to change as new information develops and it is possible that losses resulting from such risks, if proceedings are decided in
whole or in part adversely to us, could significantly exceed any accruals we have provided.
In addition, we may be subject to undisclosed liabilities related to labor, commercial, civil, tax, criminal or environmental
contingencies incurred by businesses we acquire as part of our growth strategy, that we may not be able to identify or that may not be
adequately indemnified under our acquisition agreements with the sellers of such businesses, in which case our business, financial
condition and results of operation may negatively and adversely affected.
Our business depends to a significant extent on our production and refining facilities and logistics network.
Our oil and natural gas field facilities, refineries and logistics network are our principal production facilities and distribution
network on which a significant portion of our revenues depends. Although we insure our properties on terms we consider prudent and
have adopted and maintain safety measures, any significant damage to, accident or other production stoppage at our facilities or
network could materially and adversely affect our production capabilities, financial condition and results of operations.
For instance, on April 2, 2013 our facilities in the La Plata refinery were hit by a severe and unprecedented storm, recording
over 400 mm of rainfall. The rainfall set a new record for the area and disrupted refinery systems, causing a fire that affected the
Coke A and Topping C units in the refinery. This incident temporarily affected the crude processing capacity of the refinery, which
had to be stopped entirely. Seven days after the event, the processing capacity was restored to about 100 mbbl/d through the
commissioning of two distillation units (Topping IV and Topping D). By the end of May 2013, the Topping C unit resumed
operations at full nominal capacity. The Coke A unit has been shut down permanently since the storm, affecting the volume of crude
processed in the refinery, due to a reduction in conversion capacity. The storm resulted in a decrease in the volume of crude oil
processed. YPF has an insurance policy that provides coverage for the loss of income and property damage due to incidents like the
storm that affected the La Plata refinery. See Note 11.b to the Audited Consolidated Financial Statements for information regarding
the amount recognized in our result of operations in connection with our insurance coverage.
In addition, on March 21, 2014, a fire occurred at the Cerro Divisadero crude oil treatment plant, located 20 kilometers from the
town of Bardas Blancas in the province of Mendoza. The Cerro Divisadero plant, which has six tanks, four of which are for
processing and two are for dispatch of treated crude oil, concentrates the production of ten fields in the Malargue area. This
constitutes a daily production of approximately 9,200 barrels of oil as of the date of the incident. As of the date of this annual report,
the production of the affected fields has almost returned to previous levels, and the construction of the new oil treatment plant has
advanced as planned.
25
We could be subject to organized labor action.
Our operations have been affected by organized work disruptions and stoppages in the past and we cannot assure you that we
will not experience them in the future, which could adversely affect our business and revenues. Labor demands are commonplace in
Argentina’s energy sector and unionized workers have blocked access to and damaged our plants in the recent past. Our operations
were affected occasionally by labor strikes in recent years. See “—Oil and gas prices, including the recent decline in global prices for
oil and gas, could affect our business” and “Item 5. Operating and Financing Review and Prospects—Factors Affecting Our
Operations—Macroeconomic Conditions.”
We may not be able to pay, maintain or increase dividends.
On April 30, 2013, our shareholders approved a dividend of Ps. 326 million (Ps. 0.83 per share or ADS), which was paid during
August 2013. On April 30, 2014, our Shareholders approved a dividend of Ps. 464 million (Ps. 1.18 per share or ADS), which was
paid during July 2014. On April 30, 2015, our shareholders approved a dividend of Ps.503 million (Ps.1.28 per share or ADS), which
was paid during July 2015. On March 3, 2016, our Board of Directors agreed to propose at the shareholders’ meeting the allocation of
Ps. 889 million to a reserve for the payment of dividends, authorizing the Board to determine the opportunity for its distribution
within a period not exceeding the end of 2016. Notwithstanding the foregoing, our ability to pay, maintain or increase dividends is
based on many factors, including our net income, anticipated levels of capital expenditures and expected levels of growth. A change
in any such factor could affect our ability to pay, maintain or increase dividends, and the exact amount of any dividend paid may vary
from year to year.
Our performance is largely dependent on recruiting and retaining key personnel
Our current and future performance, the successful implementation of our strategy and the operation of our business are
dependent upon the contributions of our senior management and our highly skilled team of engineers and other employees. Our
ability to continue to rely on these key individuals is dependent on our success attracting, training, motivating and retaining key
management and commercial and technical personnel with the necessary skills and experience. There is no assurance that we will be
successful in retaining and attracting key personnel and the replacement of any key personnel who were to leave could be difficult
and time consuming.
On March 9, 2016, our current Chairman and CEO Miguel Galuccio announced that he will step down at the end of his term,
which ends at our next annual shareholders meeting, expected to be held in April 2016. See “Item 6. Directors, Senior Management
and Employees—Board of Directors.” The Expropriation Law provides that the National Executive Office, by itself or through an
appointed public entity, shall exercise all the political rights associated with the shares subject to expropriation until the transfer of
political and economic rights to the provinces that compose the National Organization of Hydrocarbon Producing States is completed.
Consequently, the Argentine government has the majority of votes which allows to appoint the majority of members of our board of
directors at the General Shareholder’s meeting. See “—The Argentine federal government will control the Company according to
domestic energy policies in accordance with the Expropriation Law” and “—Our business is largely dependent upon economic
conditions in Argentina.” The loss of the experience and services of key personnel or the inability to recruit suitable replacements or
additional staff could have a material adverse effect on our business, financial condition and our results of operations.
Our business has become increasingly dependent on digital technologies to conduct day-to-day operations, including oil, gas and
petrochemical operations.
As dependence on digital technologies has increased, cyber incidents, including deliberate attacks or unintentional events, have
also increased worldwide. Our technologies, systems, networks and those of our business associates have been and may continue to
be the target of cyberattacks or information security breaches, which could lead to disruptions in critical systems (such as SCADAs,
DCS systems), the unauthorized release of confidential or protected information, corruption of data or other disruptions of our
business operations. In addition, certain cyber incidents, such as surveillance, may remain undetected for an extended period. To our
knowledge, we have not experienced any material losses relating to cyberattacks. However, as cyberattacks continue to evolve, there
can be no assurance that we will not suffer any cyberattack in the future that may affect our operations or our financial condition.
Risks Relating to Our Class D Shares and ADSs
The market price for our shares and ADSs may be subject to significant volatility
The market price of our ordinary shares and ADSs may fluctuate significantly due to a number of factors, including, among
others, our actual or anticipated results of operations and financial condition; speculation over the impact of the Argentine
government as our controlling shareholder on our business and operations, investor perceptions of investments relating to Argentina
and political and regulatory developments affecting our industry or the Company. In addition, recent regulatory and policy
developments in Argentina, including the passage of the Expropriation Law, as well as the litigation of the Argentine government
with Holdout Bondholders (see “—Our business is largely dependent upon economic conditions in Argentina”), have led to
considerable volatility in the market price of our shares and ADSs. For example, the price of our ADSs has varied from
U.S.$54.58 on January 5, 2011 to U.S.$9.57 on November 16, 2012. The price hit a high closing price of U.S.$36.99 on July 1, 2014,
but subsequently fell to U.S.$12.83 on January 20, 2016. See “Item 9. The Offer and Listing.” We cannot assure you that concerns
about factors that could affect the market price of our ordinary shares as previously mentioned may have a material adverse effect on
the trading values of our securities.
26
Certain strategic transactions require the approval of the holder of our Class A shares or may entail a cash tender offer for all of
our outstanding capital stock.
Under our by-laws, the approval of the Argentine government, the sole holder of our Class A shares, is required to undertake
certain strategic transactions, including a merger, an acquisition that results in the purchaser holding 15% or more of our capital stock
or an acquisition that results in the purchaser holding a majority of our capital stock, requiring consequently the approval of the
National State (the holder of our Class A shares) for such decisions.
In addition, under our by-laws, an acquisition that results in the purchaser holding 15% or more of our capital stock would
require such purchaser to make a public cash tender offer for all of our outstanding shares and convertible securities, which could
discourage certain investors from acquiring significant stakes in our capital stock. See “Item 10. Additional Information—Certain
Provisions Relating to Acquisitions of Shares.”
Restrictions on the movement of capital out of Argentina may impair your ability to receive dividends and distributions on, and the
proceeds of any sale of, the Class D shares underlying the ADSs.
The government is empowered, for reasons of public emergency, as defined in Article 1 of Law No. 25,561, to establish the
system that will determine the exchange rate between the peso and foreign currency and to impose exchange regulations. Although
the transfer of funds abroad in order to pay dividends currently does not require Central Bank approval, restrictions on the movement
of capital to and from Argentina may, if imposed, impair or prevent the conversion of dividends, distributions, or the proceeds from
any sale of Class D shares, as the case may be, from pesos into U.S. dollars and the remittance of the U.S. dollars abroad.
Under the terms of our deposit agreement with the depositary for the ADSs, the depositary will convert any cash dividend or
other cash distribution we pay on the shares underlying the ADSs into U.S. dollars, if it can do so on a reasonable basis and can
transfer the U.S. dollars to the United States. If this conversion is not possible for any reason, including regulations of the type
described in the preceding paragraph, the deposit agreement allows the depositary to distribute the foreign currency only to those
ADR holders to whom it is possible to do so. If the exchange rate fluctuates significantly during a time when the depositary cannot
convert the foreign currency, you may lose some or all of the value of the dividend distribution.
Under Argentine law, shareholder rights may be different from other jurisdictions.
Our corporate affairs are governed by our by-laws and by Argentine corporate law, which differ from the legal principles that
would apply if we were incorporated in a jurisdiction in the United States or in other jurisdictions outside Argentina. In addition, rules
governing the Argentine securities markets are different and may be subject to different enforcement in Argentina than in other
jurisdictions.
Actual or anticipated sales of a substantial number of Class D shares could decrease the market prices of our Class D shares and
the ADSs.
Sales of a substantial number of Class D shares or ADSs by any present or future relevant shareholder could decrease the
trading price of our Class D shares and the ADSs.
You may be unable to exercise preemptive, accretion or other rights with respect to the Class D shares underlying your ADSs.
You may not be able to exercise the preemptive or accretion rights relating to the shares underlying your ADSs (see “Item 10.
Additional Information—Preemptive and Accretion Rights”) unless a registration statement under the U.S. Securities Act of 1933
(the “Securities Act”) is effective with respect to those rights or an exemption from the registration requirements of the Securities Act
is available. We are not obligated to file a registration statement with respect to the shares relating to these preemptive rights, and we
cannot assure you that we will file any such registration statement. Unless we file a registration statement or an exemption from
registration is available, you may receive only the net proceeds from the sale of your preemptive rights by the depositary or, if the
preemptive rights cannot be sold, they will be allowed to lapse. As a result, U.S. holders of Class D shares or ADSs may suffer
dilution of their interest in our company upon future capital increases.
27
In addition, under the Argentine Corporations Law, foreign companies that own shares in an Argentine corporation are required
to register with the Superintendency of Corporations (Inspección General de Justicia) (“IGJ”) in order to exercise certain shareholder
rights, including voting rights. If you own our Class D shares directly (rather than in the form of ADSs) and you are a non-Argentine
company and you fail to register with IGJ, your ability to exercise your rights as a holder of our Class D shares may be limited.
You may be unable to exercise voting rights with respect to the Class D shares underlying your ADSs at our shareholders’
meetings.
The depositary will be treated by us for all purposes as the shareholder with respect to the shares underlying your ADSs. As a
holder of ADRs representing the ADSs being held by the depositary in your name, you will not have direct shareholder rights and
may exercise voting rights with respect to the Class D shares represented by the ADSs only in accordance with the deposit agreement
relating to the ADSs. There are no provisions under Argentine law or under our by-laws that limit the exercise by ADS holders of
their voting rights through the depositary with respect to the underlying Class D shares. However, there are practical limitations on
the ability of ADS holders to exercise their voting rights due to the additional procedural steps involved in communicating with these
holders. For example, holders of our shares will receive notice of shareholders’ meetings through publication of a notice in an official
gazette in Argentina, an Argentine newspaper of general circulation and the bulletin of the Buenos Aires Stock Exchange, and will be
able to exercise their voting rights by either attending the meeting in person or voting by proxy. ADS holders, by comparison, will not
receive notice directly from us. Instead, in accordance with the deposit agreement, we will provide the notice to the depositary. If we
ask it to do so, the depositary will mail to holders of ADSs the notice of the meeting and a statement as to the manner in which
instructions may be given by holders. To exercise their voting rights, ADS holders must then instruct the depositary as to voting the
Class D shares represented by their ADSs. Due to these procedural steps involving the depositary, the process for exercising voting
rights may take longer for ADS holders than for holders of Class D shares, and Class D shares represented by ADSs may not be voted
as you desire. Class D shares represented by ADSs for which the depositary fails to receive timely voting instructions may, if
requested by us, be voted as we instruct at the corresponding meeting.
Shareholders outside of Argentina may face additional investment risk from currency exchange rate fluctuations in connection
with their holding of our Class D shares or the ADSs.
We are an Argentine company and any future payments of dividends on our Class D shares will be denominated in pesos. The
peso has historically and recently fluctuated significantly against many major world currencies, including the U.S. dollar. A
devaluation of the peso would likely adversely affect the U.S. dollar or other currency equivalent of any dividends paid on our Class
D shares and could result in a decline in the value of our Class D shares and the ADSs as measured in U.S. dollars.
ITEM 4. Information on the Company
History and Development of YPF
Overview
YPF is a corporation (sociedad anónima), incorporated under the laws of Argentina for a limited term. Our address is Macacha
Güemes 515, C1106BKK Ciudad Autónoma de Buenos Aires, Argentina and our telephone number is (011-54-11) 5441-2000. Our
legal name is YPF Sociedad Anónima and we conduct our business under the commercial name “YPF.”
We are Argentina’s leading energy company, operating a fully integrated oil and gas chain with leading market positions across
the domestic upstream and downstream segments. Our upstream operations consist of the exploration, development and production of
crude oil, natural gas and LPG. Our downstream operations include the refining, marketing, transportation and distribution of oil and
a wide range of petroleum products, petroleum derivatives, petrochemicals, LPG and bio-fuels. Additionally, we are active in the gas
separation and natural gas distribution sectors both directly and through our investments in several affiliated companies. In 2015, we
had consolidated revenues of Ps. 156,136 million and consolidated net income of Ps. 4,426 million. Due to decreased export volumes,
the portion of our revenues derived from exports has decreased steadily in recent years. Exports accounted for 7.9%, 17.1% and
13.3% of our consolidated net sales revenues in 2015, 2014 and 2013, respectively.
Until November 1992, most of our predecessors were state-owned companies with operations dating back to the 1920s. In
November 1992, the Argentine government enacted the Privatization Law (Law No. 24,145), which established the procedures for
our privatization. In accordance with the Privatization Law, in July 1993, we completed a worldwide offering of 160 million Class D
shares that had previously been owned by the Argentine government. As a result of that offering and other transactions, the Argentine
government’s ownership interest in our capital stock was reduced from 100% to approximately 20% by the end of 1993.
28
In 1999, Repsol acquired control of YPF and remained in control until the passage of the Expropriation Law. Repsol is an
integrated oil and gas company headquartered in Spain with global operations. Repsol YPF owned approximately 99% of our capital
stock from 2000 until 2008, when the Petersen Group purchased, in different stages, shares representing 15.46% of our capital stock
(the “Petersen Transaction”). In addition, Repsol granted certain affiliates of Petersen Energía S.A. (“Petersen Energía”) an option to
purchase up to an additional 10% of our outstanding capital stock, which was exercised in May 2011.
On May 3, 2012, the Argentine congress passed the Expropriation Law. Among other matters, the Expropriation Law provided
for the expropriation of 51% of the share capital of YPF represented by an identical stake of Class D shares owned, directly or
indirectly, by Repsol YPF and its controlled or controlling entities. The shares subject to expropriation, which have been declared of
public interest, will be assigned as follows: 51% to the federal government and 49% to the governments of the provinces that
compose the National Organization of Hydrocarbon Producing States. To ensure compliance with its objectives, the Expropriation
Law provides that the National Executive Office, by itself or through an appointed public entity, shall exercise all the political rights
associated with the shares subject to expropriation until the transfer of political and economic rights to the provinces that compose the
National Organization of Hydrocarbon Producing States is completed. See “Item 3. Key Information—Risk Factors—Risks Relating
to Argentina—The Argentine federal government will control the Company according to domestic energy policies in accordance with
the Expropriation Law,” “Risk Factors—Risks Relating to the Argentine Oil and Gas Business and Our Business—We face risk
relating to certain legal proceedings,” “—Regulatory Framework and Relationship with the Argentine Government—The
Expropriation Law” and “Item 7. Major Shareholders and Related Party Transactions.”
In addition, on February 25, 2014, the Republic of Argentina and Repsol reached an agreement (the “Repsol Agreement”) in
relation to compensation for the expropriation of 200,589,525 of YPF’s Class “D” shares pursuant to the Expropriation Law under the
Repsol Agreement. Repsol accepted U.S.$5.0 billion in sovereign bonds from the Republic of Argentina and withdrew judicial and
arbitral claims it had filed, including claims against YPF, and waived additional claims. YPF and Repsol also executed a separate
agreement (the “Repsol Arrangement”) on February 27, 2014, pursuant to which YPF and Repsol each withdrew, subject to certain
exclusions, all present and future actions and/or claims based on causes occurring prior to the date of execution of Repsol
Arrangement arising from the expropriation of the YPF shares owned by Repsol pursuant to the Expropriation Law, including the
intervention and temporary possession for public purposes of YPF’s shares. YPF and Repsol agreed to withdraw reciprocal actions
and claims with respect to third parties and/or pursued by them and to grant a series of mutual indemnities, which at the time were
subject to certain conditions precedent. The Repsol Arrangement entered into force the day after Repsol notified YPF that the Repsol
Agreement had entered into force. The Repsol Agreement was ratified on March 28, 2014 at a Repsol general shareholders’ meeting
and approved by the Argentine congress by Law No. 26,932 enacted by Decree No. 600/2014. On May 8, 2014, YPF was notified of
the entry into force of the Repsol Agreement. As of that date, the expropriation pursuant to the Expropriation Law was concluded,
and as a result the Republic of Argentina is definitively the owner of 51% of the capital stock of each of YPF S.A. and YPF GAS
S.A.
The financial data contained in this annual report as of and for the years ended December 31, 2015, 2014 and 2013 has been
derived from our Audited Consolidated Financial Statements included in this annual report. See Note 20 to the Audited Consolidated
Financial Statements. The financial data contained in this annual report as of December 31, 2012 and 2011 and for the years ended
December 31, 2012 and 2011 have been derived from our consolidated financial statements as of and for the years ended
December 31, 2013, 2012 and 2011 included in our 2013 20-F.
Upstream Operations
•
As of December 31, 2015, we held interests in 108 oil and gas fields in Argentina. According to the Argentine Secretariat
of Energy, in 2015 these assets accounted for approximately 48.6% of the country’s total production of crude oil,
excluding NGLs, and approximately 44.1% of its total natural gas production, including NGLs, in 2015, according to
information provided by the Argentine Secretariat of Energy.
•
We had proved reserves, as estimated as of December 31, 2015, of approximately 679 mmbbl of oil, including condensates
and NGLs, and approximately 3,072 bcf of gas, representing aggregate reserves of approximately 1,226 mmboe as of such
date, compared to approximately 674 mmbbl of oil, including condensates and NGLs, and approximately 3,016 bcf of gas,
representing aggregate reserves of approximately 1,212 mmboe as of December 31, 2014.
•
In 2015, we produced approximately 91 mmbbl of oil (approximately 250 mbbl/d), including condensates, approximately
18 mmbbl of NGLs (approximately 49 mbbl/d), and approximately 569 bcf of gas (approximately 1,560 mmcf/d),
representing a total production of approximately 210 mmboe (approximately 577 mboe/d), compared to approximately 89
mmbbl of oil (approximately 245 mbbl/d), including condensates, approximately 18 mmbbl of NGLs (approximately 49
mbbl/d), and approximately 547 bcf of gas (approximately 1,498 mmcf/d) representing a total production of approximately
204 mmboe (approximately 560 mboe/d) in 2014.
29
Downstream Operations
•
We are Argentina’s leading refiner with operations conducted at three wholly-owned refineries with combined annual
refining capacity of approximately 116 mmbbl (319.5 mbbl/d). See “—Downstream—Refining division.” We also own a
50% equity interest in Refinería del Norte, S.A. (“Refinor”), an entity jointly controlled with and operated by Petrobras
Energía S.A., which has a refining capacity of 26.1 mbbl/d.
•
•
Our retail distribution network for automotive petroleum products as of December 31, 2015 consisted of 1,538 YPF-
branded service stations, of which we own 112 directly and through our 100% subsidiary Operadora de Estaciones de
Servicios S.A. (“OPESSA”), and we estimate we held approximately 35% of all gasoline service stations in Argentina.
We are one of the leading petrochemical producers in Argentina and in the Southern Cone of Latin America, with
operations conducted through our Ensenada industrial complex (“CIE”) and Plaza Huincul site. In addition, Profertil S.A.
(“Profertil”), a company that we jointly control with Agrium Holdco Spain S.L. (“Agrium”), is one of the leading
producers of urea in the Southern Cone.
The following chart illustrates our organizational structure, including our principal subsidiaries, as of the date of this annual report.
(1)
Includes the directly and indirectly controlled companies of the Apache Group acquired on March 12, 2014.
See Note 11.c “—Investment Project Agreements” to the Audited Consolidated Financial Statements for a description of the
transaction we entered into with Chevron and the Apache Group.
30
The map below illustrates the location of our productive basins, refineries, storage facilities and crude oil and multi-product pipeline
networks as of December 31, 2015.
For a description of our principal capital expenditures and divestitures, see “Item 5. Operating and Financial Review and Prospects—
Liquidity and Capital Resources—Capital investments, expenditures and divestitures.”
The Argentine Market
Argentina is the second largest producer of natural gas and the fourth largest producer of crude oil in Central and South America, based
on 2014 production, according to the 2015 edition of the BP Statistical Review of World Energy, published in June 2015.
In response to the economic crisis of 2001 and 2002, the Argentine government, pursuant to the Public Emergency Law, established
export taxes on certain hydrocarbon products. In subsequent years, in order to satisfy growing domestic demand and abate inflationary
pressures, this policy was supplemented by constraints on domestic prices, temporary export restrictions and subsidies on imports of natural
gas and diesel. As a result, until 2008, local prices for oil and natural gas products had remained significantly below those prevalent in
neighboring countries and international commodity exchanges.
31
In 2012, Argentina’s GDP experienced a slowdown, with GDP increasing 1.9% on an annual basis compared to the preceding
year according to the methodology of calculation prevailing until March 2014. On March 27, 2014, the Argentine government
announced a new method of calculating GDP by reference to 2004 as the base year (as opposed to 1993, which was the base reference
year under the prior method of calculating GDP). As a result of the application of this new method, the estimated GDP growth rate
for 2013 was revised from 4.9% to 2.9%. As of the date of this annual report, the provisional figures of Argentina’s estimated GDP
for 2014 and the first half of 2015 published by INDEC is 0.5% and 2.2%, respectively. However, on January 7, 2016 through Decree
No. 55/2016, the new leadership of INDEC issued a report declaring a “national statistical emergency.” INDEC stated that its
administration since 2006 was irregular and it would reorganize. As a result, INDEC would not publish new information until at least
June 2016.
Driven by economic expansion and stable domestic prices, energy demand has increased significantly during the same period,
outpacing energy supply (which, in the case of oil, declined). As a result of a high number of power outages caused by the
consumption increase, the Ministry of Energy requested that the Executive Branch declare a National Electric System Emergency
through December 31, 2017. This decree instructs the Minister of Energy to develop and propose measures and to ensure adequate
power supplies. Also by Resolution No. 06/2016, published in January 2016, the Ministry of Energy and Mining established new
seasonal reference prices for power and energy in the Wholesale Electricity Market (“MEM”) for the period from February 1, 2016 to
April 30, 2016. See “—Regulatory Framework and Relationship with the Argentine Government—Resolution No. 06/2016.”
Argentine natural gas consumption grew at an average annual rate of approximately 5.0% during the period from 2003 to 2011,
according to the BP Statistical Review and the Argentine Secretariat of Energy. As a result of this increasing demand and actions
taken by the Argentine regulatory authorities to support domestic supply, exported volumes of hydrocarbon products, especially
natural gas, diesel and gasoline, declined steadily over this period. At the same time, Argentina has increased hydrocarbon imports,
becoming a net importer of certain products, such as diesel, and increased imports of gas (including NGL). In 2003, Argentina’s net
exports of diesel amounted to approximately 1,349 mcm, while in 2015 its net imports of diesel amounted to approximately 1,933
mcm, according to preliminary information provided by the Argentine Secretariat of Energy. Significant investments in the energy
sector are being carried out, and additional investments are expected to be required in order to support continued economic growth, as
the industry is currently operating near capacity.
Demand for diesel in Argentina exceeds domestic production. In addition, prior to the recent decline in international oil prices,
the import prices of refined products have been in general substantially higher than the average domestic sales prices of such
products, rendering the import and resale of such products less profitable. As a result, from time to time, service stations experience
temporary shortages and are required to suspend or curtail diesel sales. On May 3, 2012, the Expropriation Law was passed by the
Argentine congress. The Expropriation Law declared achieving self-sufficiency in the supply of hydrocarbons, as well as in the
exploitation, industrialization, transportation and sale of hydrocarbons, a national public interest and a priority for Argentina. In
addition, its stated goal is to guarantee socially equitable economic development, to create jobs, to increase the competitiveness of
various economic sectors and to promote the equitable and sustainable growth of Argentine provinces and regions. See “—Regulatory
Framework and Relationship with the Argentine Government—The Expropriation Law.”
History of YPF
Beginning in the 1920s and until 1990, both the upstream and downstream segments of the Argentine oil and gas industry were
effectively monopolies of the Argentine government. During this period, we and our predecessors were owned by the state, which
controlled the exploration and production of oil and natural gas, as well as the refining of crude oil and marketing of refined
petroleum products. In August 1989, Argentina enacted laws aimed at the deregulation of the economy and the privatization of
Argentina’s state-owned companies, including us. Following the enactment of these laws, a series of presidential decrees were
promulgated, which required, among other things, us to sell majority interests in our production rights to certain major producing
areas and to undertake an internal management and operational restructuring program.
In November 1992, the Privatization Law, which established the procedures by which we were to be privatized, was enacted. In
accordance with the Privatization Law, in July 1993, we completed a worldwide offering of 160 million Class D shares that had
previously been owned by the Argentine government.
As a result of that offering and other transactions, the Argentine government’s ownership percentage in our capital stock was
reduced from 100% to approximately 20% by the end of 1993.
In January 1999, Repsol YPF acquired 52,914,700 Class A shares in block (14.99% of our shares) which were converted to
Class D shares. Additionally, on April 30, 1999, Repsol YPF announced a tender offer to purchase all outstanding Class A, B, C and
D shares (the “Offer”). Pursuant to the Offer, in June 1999, Repsol YPF acquired an additional 82.47% of our outstanding capital
stock. Repsol YPF acquired additional stakes in us from minority shareholders and other transactions in 1999 and 2000.
32
On February 21, 2008, Petersen Energía (“PEISA”) purchased 58,603,606 of our ADSs, representing 14.9% of our capital stock,
from Repsol YPF for U.S.$2,235 million. In addition, Repsol YPF granted certain affiliates of Petersen Energía options to purchase
up to an additional 10.1% of our outstanding capital stock within four years. On May 20, 2008, PEISA exercised an option to
purchase shares representing 0.1% of our capital stock. Additionally, PEISA launched a tender offer to purchase all of the shares of
YPF that were not already owned by them at a price of U.S.$49.45 per share or ADS. Repsol YPF, pursuant to its first option
agreement with Petersen Energía, had stated that it would not tender YPF shares to PEISA. A total of 1,816,879 shares (including
Class D shares and ADSs), representing approximately 0.462% of our total shares outstanding, were tendered. On May 3, 2011,
PEISA exercised an option to acquire, from Repsol YPF, shares or ADSs representing 10.0% of our capital stock and on May 4,
2011, Repsol YPF acknowledged and accepted such exercise. See “—Regulatory Framework and Relationship with the Argentine
Government—The Expropriation Law” and “Item 7. Major Shareholders and Related Party Transactions,” for a detail of our current
major shareholders.
On May 3, 2012, the Argentine congress passed the Expropriation Law. Among other matters, the Expropriation Law provided
for the expropriation of 51% of the share capital of YPF represented by an identical stake of Class D shares owned, directly or
indirectly, by Repsol YPF and its controlled or controlling entities. The shares subject to expropriation, which have been declared of
public interest, will be assigned as follows: 51% to the federal government and 49% to the governments of the provinces that
compose the National Organization of Hydrocarbon Producing States. See “Item 3. Key Information—Risk Factors—Risks Relating
to Argentina—The Argentine federal government controls the Company according to domestic energy policies in accordance with
Law No. 26, 741 (“the Expropriation Law”).” As of the date of this annual report, the transfer of the shares subject expropriation
between the National Executive Office and the provinces that compose the National Organization of Hydrocarbon Producing States
was still pending. According to Article 8 of the Expropriation Law, the distribution of the shares among the provinces that accept
their transfer must be conducted in an equitable manner, considering their respective levels of hydrocarbon production and proved
reserves. To ensure compliance with its objectives, the Expropriation Law provides that the National Executive Office, by itself or
through an appointed public entity, shall exercise all the political rights associated with the shares subject to expropriation until the
transfer of political and economic rights to the provinces that compose the National Organization of Hydrocarbon Producing States is
completed. In addition, in accordance with Article 9 of the Expropriation Law, each of the Argentine provinces to which shares
subject to expropriation are allocated must enter into a shareholder’s agreement with the federal government that will provide for the
unified exercise of its rights as a shareholder. See “—Regulatory Framework and Relationship with the Argentine Government—The
Expropriation Law,” “Item 7. Major Shareholders and Related Party Transactions.” See “Item 3. Key Information—Risk Factors—
Risks Relating to the Argentine Oil and Gas Business and Our Business—We face risk relating to certain legal proceedings” for a
description of the Agreement between Repsol and the Argentine Republic relating to compensation for the expropriation of 51% of
the share capital of YPF owned, directly or indirectly, by Repsol.
For a discussion of the Repsol Agreement which concluded the expropriation of 51% of the capital stock of YPF S.A. and YPF
GAS S.A. pursuant to the Expropriate Law and the related Repsol Arrangement, see “—History and Development of YPF—
Overview.”
Our strategy intends to reaffirm our commitment to creating a new model of the Company in Argentina which aligns our
objectives, seeking profitable and sustainable growth that generates shareholder value, with those of the country, thereby positioning
YPF as an industry-leading company aiming at the reversal of the national energy imbalance and the achievement of hydrocarbon
self-sufficiency in the long term.
To achieve the goals set forth above, we intend to focus on (i) continuing to increase production, especially of natural gas;
(ii) improving efficiency and productivity to enable us to adapt to a scenario of a prolonged decline in international oil prices;
(iii) increasing exploration of mature areas; (iv) developing unconventional resources; (v) improving our capacity to refine in order to
accommodate the growth in demand for refined products; (vi) exploring conventional and unconventional resources and pushing the
limits of existing deposits and exploring new frontiers, including offshore; and (vii) maintaining a solid capital structure.
The investment plan related to our growth needs to be accompanied by an appropriate financial plan, whereby we intend to
reinvest earnings, search for strategic partners and raise debt financing at levels we consider prudent for companies in our industry.
Consequently, the financial viability of these investments and hydrocarbon recovery efforts will generally depend, among other
factors, on the prevailing economic and regulatory conditions in Argentina, the ability to obtain financing in satisfactory amounts at
competitive costs, as well as the market prices of hydrocarbon products. See “Item 3. Key Information—Risk Factors—Risks
Relating to Argentina.” and “Item 5. Factors Affecting Our Operations” for additional information regarding 2016 activity.
33
Business Organization
We currently conduct our business according to the following organization:
•
•
•
Upstream, which consists of our “Exploration and Production” segment;
Downstream, which consists of our “Refining and Marketing”, “Natural Gas Distribution and Electricity Generation” and
“Chemicals” segments; and
Corporate and other, which consists of our “Corporate and Other” segment.
The Exploration and Production segment’s sales to third parties in Argentina and abroad include sales of natural gas and
services fees (primarily for the transportation, storage and treatment of hydrocarbons and products). In addition, crude oil produced
by us in Argentina, or received from third parties in Argentina pursuant to service contracts, is mainly transferred from Exploration
and Production to Refining and Marketing at transfer prices established by us, which generally seek to approximate Argentine market
prices.
In 2013, we reorganized our reporting structure by grouping the “Chemical” and “Refining and Marketing” segments into a new
“Downstream” segment. We made this change primarily because of the common strategy shared by the former “Chemical” and
“Refining and Marketing” segments, in light of the synergies involved in their activities to maximize the volume and quality of fuel
offered to the market.
The Downstream segment purchases crude oil from the Exploration and Production segment and from third parties.
Downstream activities include crude oil refining and transportation, as well as the marketing and transportation of refined fuels,
lubricants, LPG, natural gas, petrochemical products and other refined petroleum products in the domestic wholesale and retail
markets and the export markets.
In addition, our activities related to power generation, which are not material for us, which we have developed through our
controlled company YPF Energía Electrica S.A., and our natural gas distribution activities, which we have developed through
Metrogas S.A., are also included in Downstream activities.
Additionally, we record certain assets, liabilities and costs under the Corporate and Other business segment, including corporate
administration costs and assets, environmental matters related to YPF Holdings, Inc. (“YPF Holdings”) and certain construction
activities, mainly related to the oil and gas industry, through our subsidiary A-Evangelista S.A. and its subsidiaries. See Note 4 to our
Audited Consolidated Financial Statements.
Substantially all of our operations, properties and customers are located in Argentina. However, we carry out exploration
activities in the United States, among other foreign jurisdictions, and hold an interest in a producing field in the United States and in
one exploratory area in Chile. See “—Exploration and Production Overview—Main properties.” Additionally, we market lubricants
and specialties in Brazil and Chile.
The following table sets forth revenues and operating income for each of our lines of business for the years ended December 31,
2015, 2014 and 2013:
Revenues (1)
Exploration and production
Revenues
Revenue from intersegment sales (3)
Total exploration and production
Downstream
Revenues
Revenue from intersegment sales
Total refining and marketing
Corporate and other
Revenues
Revenue from intersegment sales
Total corporate and other
Less inter-segment sales and fees
Total revenues
For the year ended December 31,
2014
2013
2015
(in millions of pesos)
16,044 8,853 3,851
64,243 61,844 38,846
80,287 70,697 42,697
138,962 132,254 85,624
1,535 1,489 1,147
140,497 133,743 86,771
835
638
1,130
6,182 5,212 2,285
7,312 6,047 2,923
(71,960) (68,545) (42,278)
156,136 141,942 90,113
Operating income (Loss) (2)
Exploration and production
Downstream
Corporate and other
Consolidation adjustments
Total operating income
7,535 12,353 6,324
8,446 10,978 6,721
(2,331) (3,343) (1,522)
(363)
2,938
16,588 19,742 11,160
(246)
(1) Revenues are net of payment of a fuel transfer tax and turnover tax. Customs duties on hydrocarbon exports are disclosed in
“Taxes, charges and contributions,” as indicated in Note 6.n to the Audited Consolidated Financial Statements. Royalties with
respect to our production are accounted for as a cost of production and are not deducted in determining revenues. See Note
1.b.15 to the Audited Consolidated Financial Statements.
Includes exploration costs in Argentina and the United States and production operations in Argentina and the United States.
Intersegment revenues of crude oil to Downstream are recorded at transfer prices that reflect our estimate of Argentine market
prices.
(2)
(3)
34
Exploration and Production Overview
Our portfolio includes more than 1,400 projects to develop proved, probable and possible reserves, in addition to contingent and
prospective resources related to future developments and exploration activity. Our business growth objectives, whereby we seek to
maximize the productivity and profitability of our portfolio, are based on the following key concepts: the rejuvenation of mature
fields, an ongoing focus on gas development and the intensive development of unconventional reservoirs. See “Item 3. Key
Information—Risk Factors.”
The projects selected to be pursued and their schedules for completion are periodically determined by a portfolio optimization
process, in accordance with our strategic guidelines.
Increased investments in Argentina have enabled us to maintain a high level of activity in projects that have contributed to
significant increases in the production and value of our fields. In 2015, our oil production in Argentina increased by 2.1% and our gas
production in Argentina increased by 4.2%, compared to our production in 2014. This increase reflects the intensive work we
performed in the conventional and unconventional fields we operate. See “Item 5. Operating and Financial Review and Prospects—
Factors Affecting Our Operations” for additional information regarding 2016 activity.
Meeting the challenge of the mature oil and gas fields
Most of our oil and gas producing fields in Argentina are mature, requiring strong commitments to overcome their decline.
We have significantly increased our activity and resources in mature areas that present profitable opportunities for increases in
the recovery factor by employing techniques including infill wells, and extension of secondary recovery and tertiary recovery testing.
We are focused on identifying new opportunities in both infill potential and improved sweep efficiency in our mature fields. These
efforts are guided by subsurface modeling conducted by in-house multidisciplinary teams. Furthermore, we place a strong emphasis
on surveillance and conformance activities to improve current mature water injection projects. Tertiary recovery is being pursued
with polymer and surfactant waterflooding in mature reservoirs in both the Golfo de San Jorge and Neuquén basins.
Continuous technical reviews of our oil and gas fields allow us to identify opportunities to rejuvenate mature fields and optimize
new field developments in Argentine basins in order to achieve similar recovery factors that mature fields have already reached in
other regions of the world, with the application of new technologies.
We have managed, through the extension of most of our concessions with relatively favorable terms and conditions, to continue
with the development of strategic waterflooding and improved oil recovery projects, improving our perspectives of production and
reserves.
Nevertheless, the financial viability of these investments and reserve recovery efforts will generally depend on prevailing
economic and regulatory conditions in Argentina, as well as the market prices of hydrocarbon products. See “Item 3. Key
Information—Risk Factors.” and “Item 5. Operating and Financial Review and Prospects—Factors Affecting Our Operations” for
additional information regarding 2016 activity.
35
Staying the Path of Unconventional Resources
During 2015, we continued extending our leadership in this area. We reaffirmed our commitment to the objective of growing
our production and reserves through the development of unconventional resources, which began in 2013. More than 400 wells were
drilled with Vaca Muerta shale as the target, mostly in the Loma Campana field, continuing the massive development we began in
2013. The remaining wells were targeted to continue the development phase in El Orejano block, in association with Dow Chemical,
the Narambuena project in association with Chevron, and the La Amarga Chica pilot in association with Petronas. The purpose of
these projects is to determine the potential of Vaca Muerta shale gas formation.
As we gathered more experience, drilling activity in Loma Campana migrated to horizontal wells of 1,500 meters in lateral
length and 18 frack stages, obtaining wells with a promising relation between expected Estimated Ultimate Recovery (“EURs”) and
well costs.
During 2014, we finalized the agreement with Petronas to jointly start a new three-year pilot project in the La Amarga Chica
concession, located northeast of Loma Campana. See “—Main properties.” At the end of 2015, three horizontal and one vertical well
had been drilled in the block.
Like the previous agreements with Chevron and Dow Chemical, the agreement with Petronas constitutes a significant step
towards the development of our vast unconventional resources, although this still represents only a fraction of our unconventional
acreage. See “—Main properties.”
The development of unconventional resources in the Vaca Muerta formation will demand a significant capital investment. As
we rapidly progress on our learning curve, we expect to continue yielding substantial savings due to operational optimizations
economies of scale and increasing well productivity through a better understanding of the subsurface.
Nevertheless, the financial viability of these investments and reserve recovery efforts will depend on the prevailing economic
and regulatory conditions, as well as the market prices of hydrocarbons in Argentina. See “Item 3. Key Information—Risk Factors.”
and “Item 5. Operating and Financial Review and Prospects—Factors Affecting Our Operations” for additional information regarding
2016 activity.
Tight sands also contributed to the increase of natural gas production and reserves in 2015, as was the case in the Mulichinco
formation in the Rincón del Mangrullo concession, where Pampa Energía SA acquired 50% of the working interest during 2015.
More than 87 wells were drilled in these marine tight sands, increasing gas production to 3 mmcm/d through a gas pipeline that
connects to Loma La Lata facilities. This pipeline may enable the development of other gas fields, like the recent shale gas discovery
La Ribera, where a successful well is already in production.
Recently we acquired land in the province of Chubut and Río Negro which can produce sand to be used as proppant in the
development of unconventional hydrocarbons. Additionally, a sand treatment plant is under construction in the province of Neuquén
and is expected to be operational by the first quarter of 2016. We expect to gradually replace the more expensive imported sand with
our domestic product, allowing for significant well cost reductions.
36
Vaca Muerta Formation
•
“Loma Campana” Area: On July 16, 2013, YPF and Chevron signed an investment project agreement for the joint exploitation of
unconventional hydrocarbons in the province of Neuquén. The agreement contemplated an outlay of U.S.$1,240 million by Chevron for
a first phase of work to develop about 20 km2 (“Pilot Project”) (4,942 acres) of the 395 km2 (97,607 acres) corresponding to the area
dedicated to the Pilot Project. This first Pilot Project included the drilling of more than 100 wells. Together with what has already been
invested by YPF in the area, the total investment is U.S.$1,500 million. In the second phase, which started during 2014 after completion
of the Pilot Project, both companies continued the development of the area, sharing investments equally. Drilling activity continued in
2015 with more than 10 rigs operating most of the year. In addition, 122 vertical wells and 30 horizontal wells were put into production
during the year. The plan for 2016 is to complete eight vertical wells and 54 horizontal wells. For additional information see “Note 11.c
–Investment Project Agreements” to the Audited Consolidated Financial Statements.
•
“El Orejano” Area: On September 23, 2013, YPF and Dow Europe Holding B.V. and PBB Polisur S.A. signed an agreement that
included a disbursement by both parties up to U.S.$188 million that will be directed towards the joint development of an unconventional
gas pilot project in the province of Neuquén. Of the U.S.$188 million to be disbursed, Dow will provide up to U.S.$120 million through
a convertible financing in their participation in the project. The agreement contemplated a first phase of work during which 16 wells
would be drilled. This first phase ended in June 2015, with all 16 wells hooked up and reaching production of 668 mcm/d of gas at the
end of this phase. On October 22, 2015, the companies signed an amendment to the original agreement whereby Dow Europe Holding
B.V. and PBB Polisur S.A. increased the original commitment by U.S.$60 million for the development of a second phase, which
includes the drilling of 18 new wells. On December 15, 2015, the parties executed all steps contemplated in the agreement so that PBB
Polisur S.A. became a partner in “El Orejano” Area on a 50/50 basis with YPF. During December 2015, the project had an average
production of 765 mcm/d, with 19 producing wells. The total YPF investment for 2015 was U.S.$228 million, including drilling,
completion and facilities.
37
•
“La Amarga Chica” Area: On December 10, 2014, YPF and PETRONAS E&P ARGENTINA S.A. (“PEPASA”), an affiliate of
PETRONAS E&P Overseas Ventures Sdn. Bhd (“PEPOV”) of Malaysia executed a Project Investment Agreement (the
“Investment Agreement”) aiming to perform joint exploitation of unconventional hydrocarbons in the La Amarga Chica area in
the province of Neuquén. The Investment Agreement provides for the joint development of a shale oil pilot project (the “Pilot
Plan”) in three annual phases with a total investment of U.S.$550 million plus VAT, of which PEPASA will provide U.S.$475
million and YPF will provide U.S.$75 million. YPF assigned 50% of the La Amarga Chica concession to PEPASA and is the
operator of the area. The concession rights will, in turn, be collaterally assigned by PEPASA in favor of YPF as security for, and
until PEPASA has complied with all its obligations under the Investment Agreement. Additionally, PEPOV has executed a
payment guaranty of certain of PEPASA’s financial obligations under the Investment Agreement. The Pilot Plan, comprising 30
wells in three years, started in May 2015, with the drilling of a first vertical well , which will be finished in 2016. By the end of
2015, one vertical and three horizontal wells were drilled. Completion of these four wells is scheduled for early 2016. This
drilling activity developed during 2015 implied an investment of U.S.$30 million, with an additional U.S.$6.5 million expended
on production facilities.
•
“Chihuido de la Sierra Negra Sudeste – Narambuena” Area: During April 2014, YPF and subsidiaries of Chevron Corporation
executed a new agreement with the objective of the joint exploration of unconventional hydrocarbons in the province of
Neuquén, within the area Chihuido de la Sierra Negra Sudeste – Narambuena. The investment will be undertaken exclusively
by, and at the sole risk of, Chevron. The agreement defined a first phase exploratory commitment during 2015 and 2016, which
includes the drilling and completion of four exploration wells (three vertical wells and one horizontal well) with a total
investment of U.S.$62.6 million. During 2015, this activity began, with two of the wells already drilled and completed and the
third well (horizontal) in the drilling phase. In October 2016, Chevron will declare whether the joint activity continues to a
second phase, during which five wells would be drilled and completed (during the pilot phase) during 2017 and 2018. If the
second phase takes place, then the farm-in decision deadline for Chevron will be in June 2019. See “—Main properties.”
Main properties
Our production is concentrated in Argentina and our domestic operations are subject to the risks. See “Item 3. Key
Information—Risk Factors.”
In 2015, we finalized agreements related to the acquisition and development of properties that are part of our core business:
•
On January 31, 2014, we acquired Petrobras Argentina S.A.’s 38.45% participation in the concession contract UTE Puesto
Hernández executed between both companies for the exploitation of the Puesto Hernández area. The Puesto Hernández area is
an exploitation concession located in the Provinces of Neuquén and Mendoza. YPF is the holder of the concession until 2027,
now owning 100% of the participation in the Puesto Hernández area and becoming the operator of the concession. As of
December 2015, Puesto Hernández produced over 9,100 barrels a day of light crude oil (Medanito quality). The transaction was
completed for the amount of U.S.$40.7 million. By becoming the operator of the Puesto Hernández area, we expect we will be
able to accelerate our investment plans to optimize the area’s production potential until 2027.
•
On February 7, 2014, we acquired Potasio Rio Colorado S.A.’s 50% interest in the joint operation contract “Segment 5 Loma La
Lata—Sierra Barrosa” (known as the “Lajas” formation) signed by YPF and Potasio Rio Colorado S.A. for the exploitation of
the Lajas formation concession area. The Lajas formation area is an exploitation concession, located in the province of
Neuquén. YPF is the holder of the concession, which expires in 2027. Exploitation of the Lajas formation area was conducted
under the aforementioned joint operation contract. The terms of the joint operation contract provided that it would expire upon
the earlier of the expiration of the concession or the early termination of any agreement or contract that granted the right to
continue exploiting the area. As a result of the termination of the joint operation contract, YPF owns 100% of the interest in the
Lajas formation area. The consideration for the transaction was U.S.$25 million.
38
•
On March 12, 2014, we acquired 100% of the interests of Apache Overseas lnc. and Apache International Finance II S.a.r.l.
(together with their affiliates, “Apache”) in certain foreign companies that control Argentine companies that are the owners of
assets located in Argentina, including 28 concessions (23 operated and 5 non-operated) in Neuquina basin (in the provinces of
Neuquén and Río Negro), 7 concessions in Tierra del Fuego, and a significant conventional resource base. Pursuant to this
transaction, YPF acquired control of all of the assets of the Apache Corporation in Argentina. The price paid for the transaction
includes U.S.$786 million in cash plus the assumption of approximately U.S.$31 million of bank debt relating to the companies
acquired. The primary assets included in this transaction, located in the provinces of Neuquén, Tierra del Fuego and Río Negro,
have an important infrastructure of pipelines and facilities. In addition, certain assets have potential for exploration and
development in the Vaca Muerta formation.
•
•
On March 12, 2014, YPF completed a transfer of assets transaction under an agreement with Pluspetrol S.A. (“Pluspetrol”)
whereby Pluspetrol transferred, in exchange for U.S.$217 million, an interest in certain assets related to those acquired from
Apache located in the province of Neuquén, with the objective of jointly exploring and developing the Vaca Muerta formation.
During April 2014, YPF and subsidiaries of Chevron Corporation executed a new agreement with the objective of the joint
exploration of unconventional hydrocarbons in the province of Neuquén, within the area Chihuido de la Sierra Negra Sudeste –
Narambuena. The investment will be undertaken exclusively by, and at the sole risk of, Chevron. For more information, see
Note 11.c) to the Audited Consolidated Financial Statements.
•
On December 5, 2014, YPF S.A., Yacimientos del Sur S.A. (“YSUR”) and the Province of Neuquén and Gas y Petroleo del
Neuquen S.A. signed a Memorandum of Investment Agreement (the “Memorandum Agreement”) pursuant to which the parties
have agreed to convert the joint ventures and respective joint operating agreements relating to La Amarga Chica and Bajada de
Añelo areas into unconventional hydrocarbon extraction concession agreements under Articles 27 and 35(b) of the
Hydrocarbons Law (as amended by Law No. 27,007). The Memorandum Agreement was also approved by the National
Executive Office and the Legislature of the Province of Neuquén.
As part of the conversion of these agreements to unconventional hydrocarbon extraction concession agreements, the Company agreed
to make a cash payment and assign all of its interests in the following areas: i) Puesto Cortadera, ii) Loma Negra NI, iii) Cutral Co
Sur, iv) Neuquén del Medio, v) Collon Cura Bloque I and vi) Bajo Baguales.
Under the Memorandum Agreement, the conditions for carrying out the pilot projects on the new La Amarga Chica and Bajada de
Añelo concessions are set forth, with a term of 36 and 42 months, respectively, as required by Article 35 (b) of the Hydrocarbons Law
as amended by Law No. 27,007. On December 19, 2014, the Company reported that the National Executive Office and the
Legislature of the Province of Neuquén approved the Investment Agreement contemplated by the Memorandum Agreement.
•
On December 10, 2014, YPF and PEPASA, an affiliate of PEPOV executed a Project Investment Agreement (the “Investment
Agreement”) aiming to perform joint exploitation of unconventional hydrocarbons in the La Amarga Chica area in the province
of Neuquén. The parties have signed the following supplementary agreements to the Investment Agreement (the “Supplemental
Agreements”): a) the Assignment Agreement for 50% of the concession for the La Amarga Chica area; b) a Joint Venture
Agreement; c) the Joint Operating Agreement (“Joint Operating Agreement”); d) the Guaranty Assignment Agreement; e) the
Right of First Offer Agreement for the sale of crude oil and f) an Assignment Agreement for hydrocarbons export rights. The
Investment Agreement provides for the joint development of a shale oil pilot project (the “Pilot Plan”) in three annual phases
with a total investment of U.S.$550 million plus VAT, of which PEPASA will provide U.S.$475 million and YPF will provide
U.S.$75 million. YPF will assign 50% of the La Amarga Chica concession to PEPASA and will be the operator of the area. The
concession rights will, in turn, be collaterally assigned by PEPASA in favor of YPF as security for, and until PEPASA has
complied with all its obligations under the Investment Agreement. Additionally, PEPOV has executed a payment guaranty of
certain of PEPASA’s financial obligations under the Investment Agreement. The Pilot Plan began in May 2015 once conditions
precedent to the effectiveness of the Investment Agreement and the Supplemental Agreements were fulfilled, which relate
primarily to the granting of the 35-year exploitation concession for the project area by the province of Neuquén and certain
provisions with respect to the project’s tax structure, including promotional, tax and royalty commitments in accordance with
Law No. 27,007 and the agreement executed with the province of Neuquén on December 5, 2014. When the full contributions to
each of the annual phases of the Pilot Plan have been made, PEPASA will have the option to withdraw from the plan by
transferring its participation in the concession and paying liabilities accrued prior to its withdrawal (without the right to 50% of
the value of net production from wells drilled prior to the exercise of its right to withdraw). After the parties’ total commitments
have been met during the Pilot Plan, each party will be responsible for and contribute 50% of the work program and budget to
develop the area as provided for by the Joint Operating Agreement. The Investment Agreement provides that over the three
phases of the Pilot Plan, the parties will be required to perform a 3D seismic acquisition and processing program covering the
entire concession area, drill 35 wells targeting the Vaca Muerta formation (including vertical and horizontal wells) and install
facilities to transport the hydrocarbon production from this area.
39
The following table sets forth information with regard to our developed and undeveloped acreage by geographic area as of
December 31, 2015:
South America
Argentina
Rest of South America (5)
North America (6)
Total
As of December 31, 2015
Developed (1)
Undeveloped (2)
Gross (3)
Net (4)
Gross (3)
Net (4)
(thousands of acres)
1,481 1,092
1,481 1,092
— —
0.2 —
1,481.2 1,092
32,990
32,405
585
—
32,990
16,833
16,531
302
—
16,833
(1) Developed acreage is spaced or assignable to productive wells.
(2) Undeveloped acreage encompasses those leased acres on which wells have not been drilled or completed to a point that would
permit the production of economic quantities of oil or gas regardless of whether such acreage contains proved reserves.
“Net” acreage equals gross acreage after deducting third-party interests.
(3) A “gross acre” is an acre in which we own a working interest.
(4)
(5) Relates to Colombia and Chile. In the case of Colombia, YPF has requested approval from the application authority (“ANH”),
for the farm-out of its total working interest in COR 12 block. YPF and its partners informed ANH of the decision to relinquish
COR 33 block. In Chile, YPF’s undeveloped surface acreage totaled 130,000 acres.
(6) Relates only to the United States’ Gulf of Mexico.
As of December 31, 2015, none of our exploratory undeveloped acreage was subject to exploration permits that will expire in
2016 in accordance with the Hydrocarbons Law and complementary provincial laws. In addition, according to Law No. 27,007 that
amended the Hydrocarbons Law, all national offshore permits and offshore hydrocarbon production concessions that did not have
association agreements with ENARSA as of the date of the new law reverted and were transferred to the Argentine Secretariat of
Energy. Permits and concessions granted prior to Law No. 25,943 will be exempt from this provision. In September 2015, the
National Executive Office and YPF began negotiating the conversion of association agreements signed with ENARSA. As of the date
of this annual report, the negotiations are ongoing. YPF currently participates in three offshore blocks in association with ENARSA,
which represent approximately 60% of the undeveloped acreage. We cannot guarantee that as a result of such negotiations we would
not decide to relinquish to the Argentine Secretariat of Energy part or all of the acreage included in our current association with
ENARSA. With the exception of the above, none of our exploration permits are regulated by Law No. 27,007. See “—Regulatory
Framework and Relationship with the Argentine Government—Law No. 27,007, amending the Hydrocarbons Law—Exploration and
Production.”
However, as a result of the expiration in 2016 of the first, second or third exploration terms of certain of our exploration permits
(according to the original terms of the Hydrocarbons Law, which applied to our existing exploration permits), we would be required
to relinquish a fixed portion of the acreage related to each such expiring permit, as set forth in the Hydrocarbons Law, as long as
exploitable quantities of oil or gas are not discovered in such areas (in which case we may seek to obtain a declaration of their
commercial viability from the relevant authorities, and the related areas would then be subject to exploitation concessions).
Additionally, and depending on the circumstances that could arise in each case (for instance, the state of exploratory activity in a
certain area), we could request an extension of the expiration of the exploration permit, which would be subject to the approval of the
respective governing authority. As a result, if no discoveries are made in 2016, we would be required to relinquish approximately
3,500 km2 of exploratory undeveloped acreage (approximately 9% of our 39,000 km2 of net exploratory undeveloped acreage as of
December 31, 2015) during 2016.
40
Additionally, based on information available as of the date of this annual report, if we fail to make any discoveries or to engage
in new activity that could extend the expirations of the exploration permits, we could be required or could decide to relinquish a
maximum of approximately 600 km2 of exploratory undeveloped acreage (approximately 2% of our 39,000 km2 of net exploratory
undeveloped acreage as of December 31, 2015) during 2017 and 2018.
According to the Hydrocarbons Law, we are entitled to decide, according to our best interest, which acreage related to each
exploration permit to keep if we remain within the required relinquishment percentage. Therefore, the areas to be relinquished consist
usually of acreage where drilling has not been successful and are considered non-core lease acreage.
Except as described above, we do not have any material undeveloped acreage related to our production concessions expiring in
the near term.
See “—Regulatory Framework and Relationship with the Argentine Government—Law No. 27,007, amending the
Hydrocarbons Law” for a description of new terms that apply to new production concessions or exploration permits, other than those
already governed by previous laws.
Argentine Exploration Permits and Exploitation Concessions
Argentina is the second largest gas and fourth largest oil-producing nation in Central and South America according to the 2015
edition of the BP Statistical Review of World Energy, published in June 2015. Oil has historically accounted for the majority of the
country’s hydrocarbon production and consumption, although the relative share of natural gas has increased rapidly in recent years.
As of the date of this annual report, a total of 24 sedimentary basins were re-evaluated in the country, in the line with (Plan
Exploratorio Argentina). The total surface area of the continent represents approximately 408 million acres and the total offshore
surface area includes 194 million acres on the South Atlantic shelf within the 200 meter line. Of the total 602 million acres of the
sedimentary basins, a significant part still needs to be evaluated through exploratory and study drilling.
The following table shows our gross and net interests in productive oil and gas wells in Argentina by basin, as of December 31,
2015:
Basin
Onshore
Neuquina
Golfo San Jorge
Cuyana
Noroeste
Austral
Offshore
Total
Wells(1)(2)
Oil
Gas
Gross
Net
Net
Gross
13,539 12,186 1,515 1,142
4,689 4,048 1,349 1,008
57
7,856 7,230
769 — —
8
20
131
57
10
— —
13,539 12,186 1,534 1,152
843
20
131
52
57
19
57
(1)
In addition to productive oil and gas wells located in Argentina, we have interests in oil wells located in the United States (seven
gross wells and approximately one net well, as of December 31, 2015).
(2) A “gross well” is a well in which we own a working interest. A “net well” is deemed to exist when the sum of fractional
ownership working interests in gross wells equals one. The number of net wells is the sum of the fractional working interests
owned in gross wells expressed as whole numbers and fractions of whole numbers. Gross and net wells include one oil well and
three gas wells with multiple completions.
As of December 31, 2015, we held 146 exploration permits and production concessions in Argentina. We directly operate 113 of
them, including 34 exploration permits and 79 production concessions.
•
Exploration permits. As of December 31, 2015, we held 38 exploration permits in Argentina, 34 of which were onshore
exploration permits and four of which were offshore exploration permits. We had 100% ownership of two onshore permits, and
our participating interests in the remainder varied between 30% and 90%. We had 100% ownership of one offshore permit, and
our participating interests in the remainder varied between 30% and 35%.
•
Production concessions. As of December 31, 2015, we had 108 production concessions in Argentina. We had a 100%
ownership interest in 69 production concessions, and our participating interests in the remaining 39 production concessions
varied between 7% and 98%.
41
In addition, we have 31 crude oil treatment plants and seven pumping plants where oil is processed and stored. The purpose of these plants
is to receive and treat oil from different fields prior to shipment to our refineries and/or commercialization to third parties, as applicable. See
“Item 3. Key Information—Risk Factors—Risks Relating to the Argentine Oil and Gas Business and Our Business—Our business depends to a
significant extent on our production and refining facilities and logistics network.”
The table below provides certain information with respect to our net working interests in our principal oil and gas fields in Argentina at
December 31, 2015, most of which are mature:
Areas (1)
Loma La Lata Central
Los Perales
Aguada Toledo - Sierra Barrosa
Estación Fernández Oro
Seco León
Lindero Atravesado (3)
Barranca Baya
Manantiales Behr
Loma La Lata Norte (4)
Tierra del Fuego - Fracción B
Chihuido Sierra Negra
Puesto Hernández
Magallanes (3)
San Roque (3)
Rincón del Mangrullo
El Portón
El Trébol
CNQ 7A (3)
Lomas del Cuy
Vizcacheras
Chihuido La Salina
Cañadón Yatel
Señal Picada
Desfiladero Bayo
Aguada Pichana (3)
La Ventana Central
Escalante
Acambuco (3)
Cerro Fortunoso
Interest (%)
Production 2015
Gas
(mmcf)
Oil (2)
(mmbbl)
Oil (2)
(mmbbl)
Proved Reserves as
of December 31,
2015
Gas
(mmcf)
BOE
(mmboe)
Basin / Location
Development
Stage of the area
38
97
99 12,036
100 4,232
100 5,787
100 7,388
1,016 29,296
809 26,449
1,125 40,322
6,484 34,798
61 5,690 18,524 22,610
804 27,929
100 8,198 114,236 36,633 617,212 146,555 Neuquina
100 5,497 13,758 63,204
72,650
100 1,963 74,505 10,289 358,519
922 20,719 17,887 271,798
25,015
4,722 44,017
822 246,072
6,619
22,534
87,285
4,642 158,253
7,415
6,107
3,925 127,520
7,452 101,494
5,332 103,577
82,423
7,997
5,701
1,037 21,513
4,165
1,270 21,733
7,845
1,374 19,565
1,789
241 18,529
55,891
8,470
53,226
6,641
1,756
255 15,253
316 14,957
1,978
64,359
3,427
2,018
165 12,734
982 11,453
6,178
62,664
1,285
0
0 11,993
Mature Field
76,142 Golfo San Jorge Mature Field
Mature Field
74,139 Neuquina
66,293 Neuquina
Mature Field
48,472 Golfo San Jorge Mature Field
44,646 Neuquina
Mature Field
41,501 Golfo San Jorge Mature Field
38,812 Golfo San Jorge Mature Field
Mature/New Field
38,155 Neuquina
Mature Field
32,826 Austral
Mature Field
30,617 Neuquina
Mature Field
27,536 Neuquina
Mature Field
26,635 Austral
Mature Field
25,528 Neuquina
New Field
23,778 Neuquina
22,676 Neuquina
Mature Field
22,529 Golfo San Jorge Mature Field
22,475 Neuquina
Mature Field
20,962 Golfo San Jorge Mature Field
Mature Field
18,847 Cuyana
18,424 Neuquina
Mature Field
16,121 Golfo San Jorge Mature Field
Mature Field
15,566 Neuquina
Mature Field
15,309 Neuquina
Mature Field
14,889 Neuquina
13,093 Cuyana
Mature Field
12,554 Golfo San Jorge Mature Field
Mature Field
12,445 Noroeste
Mature Field
11,993 Neuquina
100
100 4,346
100 3,400
50
811 14,022
34 1,528 20,828
767 12,597
50
100 2,877 32,986
100 2,490
50 4,422
100 2,702
100 2,682
100 3,020 26,785
100 1,940 12,412
100 2,165
99 2,221
27 1,534 25,048
70 1,278
100 1,387
100 1,317
237 10,321
23
(1) Exploitation areas.
(2) Includes condensate and NGL.
(3) Non-operated fields.
(4) Working interest is 100% in the Sierras Blancas formation (mature field) and 50% in the Vaca Muerta and Quintuco formations (new field).
Approximately 88% of our proved crude oil reserves in Argentina are concentrated in the Neuquina (47%) and Golfo San Jorge
(41%) basins, and approximately 86% of our proved gas reserves in Argentina are concentrated in the Neuquina (75%) and Austral (11%) basins.
Joint ventures and contractual arrangements in Argentina
As of December 31, 2015, we participated in 30 exploration and 32 production joint ventures and contractual arrangements (24 of which
were not operated by us) in Argentina. Our interests in these joint ventures and contractual arrangements ranged from 7% to 98%, and our
obligations to share exploration and development costs varied under these agreements. In addition, under the terms of some of these joint
ventures, we have agreed to indemnify our joint venture partners in the event that our rights with respect to such areas are restricted or affected in
such a way that the purpose of the joint venture cannot be achieved. For a list of the main exploration and production joint ventures in which we
participated as of December 31, 2015, see Annex II to the Audited Consolidated Financial Statements. We are also a party to a number of other
contractual arrangements that arose through the renegotiation of service contracts and risk contracts and their conversion in exploitation
concessions and exploration permits, respectively.
42
Oil and Gas Reserves
Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be
estimated with reasonable certainty to be economically producible (from a given date forward, from known reservoirs, and under
existing economic conditions, operating methods and government regulations) prior to the time at which contracts providing the right
to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic
methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be
reasonably certain that it will commence the project within reasonable time. In some cases, substantial investments in new wells and
related facilities may be required to recover proved reserves.
Information on net proved reserves as of December 31, 2015, 2014 and 2013 was calculated in accordance with the SEC rules
and Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 932, as amended. Accordingly,
crude oil prices used to determine reserves were calculated each month, for crude oils of different quality produced by the Company.
Consequently, for calculation of our net proved reserves as of December 31, 2015, the Company considered the realized prices for
crude oil in the domestic market (which are higher than those that had prevailed in the international market), taking into account the
unweighted average price for each month within the twelve-month period ended December 31, 2015. Additionally, since there are no
benchmark market natural gas prices available in Argentina, the Company used average realized gas prices during the year to
determine its gas reserves.
Notwithstanding the foregoing, commodity prices declined significantly since 2014. See “Item 3. Key Information—Risk
Factors—Risks Relating to the Argentine Oil and Gas Business and Our Business—Our oil and natural gas reserves are estimates.”
Net reserves are defined as that portion of the gross reserves attributable to the interest of YPF after deducting interests owned
by third parties. In determining net reserves, the Company excludes from its reported reserves royalties due to others, whether
payable in cash or in kind, where the royalty owner has a direct interest in the underlying production and is able to make lifting and
sales arrangements independently. By contrast, to the extent that royalty payments required to be made to a third party, whether
payable in cash or in kind, are a financial obligation, or are substantially equivalent to a production or severance tax, the related
reserves are not excluded from the reported reserves despite the fact that such payments are referred to as “royalties” under local
rules. The same methodology is followed in reporting our production amounts.
Gas reserves exclude the gaseous equivalent of liquids expected to be removed from the gas on concessions and leases, at field
facilities and at gas processing plants. These liquids are included in net proved reserves of NGLs.
Technology used in establishing proved reserves additions
YPF’s estimated proved reserves as of December 31, 2015 are based on estimates generated through the integration of available
and appropriate data, utilizing well-established technologies that have been demonstrated in the field to yield repeatable and
consistent results. Data used in these integrated assessments include information obtained directly from the subsurface via wellbore,
such as well logs, reservoir core samples, fluid samples, static and dynamic pressure information, production test data, and
surveillance and performance information. The data utilized also include subsurface information obtained through indirect
measurements, including high quality 2-D and 3-D seismic data, calibrated with available well control. Where applicable, geological
outcrop information was also utilized. The tools used to interpret and integrate all this data included both proprietary and commercial
software for reservoir modeling, simulation and data analysis. In some circumstances, where appropriate analog reservoir models are
available, reservoir parameters from these analog models were used to increase the reliability of our reserves estimates.
For further information on the estimation process of our proved reserves, see “—Internal controls on reserves and reserves
audits.”
43
Net Proved Developed and Undeveloped Reserves as of December 31, 2015
The following table sets forth our estimated net proved developed and undeveloped reserves of crude oil, NGLs and natural gas
at December 31, 2015.
Proved Developed Reserves
Consolidated entities
South America
Argentina
North America
United States
Total consolidated entities
Equity-accounted entities
South America
Argentina
North America
United States
Total equity-accounted entities
Total proved developed reserves
Proved Undeveloped Reserves
Consolidated entities
South America
Argentina
North America
United States
Total consolidated entities
Equity-accounted entities
South America
Argentina
North America
United States
Total equity-accounted entities
Total proved undeveloped reserves
Total Proved Reserves (2) (3)
Consolidated entities
Developed reserves
Undeveloped reserves
Total consolidated entities
Equity-accounted entities
Developed reserves
Undeveloped reserves
Total equity-accounted entities
Total proved reserves
Oil (1) (mmbbl)
NGL (mmbl)
Natural
Gas
(bcf)
Total (2)
(mmboe)
439
1
440
—
—
—
440
56
2,205
—
56
5
2,210
887
2
889
—
—
—
—
—
56
—
—
2,210
—
—
889
Oil (1) (mmbbl)
NGL (mmbbl)
Natural
Gas
(bcf)
Total (2)
(mmboe)
168
—
168
—
—
—
168
15
862
337
—
15
—
862
—
337
—
—
—
—
—
15
—
—
862
—
—
337
Oil (1) (mmbbl)
NGL (mmbbl)
440
168
608
—
—
—
608
56
15
71
—
—
—
71
Natural
Gas
(bcf)
2,210
862
3,072
—
—
—
3,072
Total (2)
(mmboe)
889
337
1,226
—
—
—
1,226
Includes crude oil (oil and condensate).
(1)
(2) Volumes of natural gas in the table above and elsewhere in this annual report have been converted to barrels of oil equivalent at
5,615 cubic feet per barrel.
(3) Proved crude oil and NGLs reserves of consolidated entities include an estimated approximately 88 mmbbl of crude oil and 14
mmbl of NGLs in respect of royalty payments which, as described above, are a financial obligation or are substantially
equivalent to a production or similar tax. Proved natural gas reserves of consolidated entities include an estimated approximately
329 bcf in respect of such payments. Equity-accounted entities reserves in respect of royalty payments that are a financial
obligation or are substantially equivalent to a production or similar tax are not material.
For information regarding changes in our estimated proved reserves during 2015, 2014 and 2013, see Note 20 to the Audited
Consolidated Financial Statements.
The paragraphs below explain in further detail the most significant changes in our proved undeveloped reserves during 2015,
2014 and 2013.
44
Changes in our proved undeveloped reserves during 2015
YPF had estimated a volume of net proved undeveloped reserves of 337 mmboe at December 31, 2015, which represented
approximately 27% of the 1,226 mmboe total reported proved reserves as of such date. This compares to estimated net proved
undeveloped reserves of 307 mmboe as of December 31, 2014 (approximately 25% of the 1,212 mmboe total reported proved
reserves as of such date).
The 10% total net increase in net proved undeveloped reserves in 2015 is mainly attributable to:
–
–
–
–
–
Extensions and discoveries, which added 93 mmboe (24.5 mmbbl of crude oil, 7.3 mmbbl of NGL and 341.8 bcf of
natural gas) of proved reserves mainly from Lindero Atravesado, Estación Fernandez Oro, Aguada Toledo—Sierra
Barrosa, Rincón del Mangrullo, Loma Campana and Loma La Lata Norte fields.
Ongoing successful development activities related to proved undeveloped reserves projects, which allowed a
transfer of approximately 77 mmboe (29 mmbbl of crude oil, 10.2 mmbbl of NGL and 212 bcf of natural gas) to
proved developed reserves. Main contributions are related to development wells (51 mmboe), gas compression
projects (15 mmboe) and improved recovery projects (8 mmboe).
New project studies and revision of gas and oil development projects, which added approximately 18 mmboe (7.5
mmbbl of crude oil, 0.9 mmbbl of NGL and 52.4 bcf of natural gas) of proved undeveloped reserves. The main
contributions came from Loma La Lata Central, Barranca Baya, Tierra del Fuego Fracción B, Seco León and Los
Perales fields.
New improved recovery projects, adding approximately 10 mmbbl of proved undeveloped secondary recovery
reserves of crude oil. The most important additions belong to Los Perales, CNQ7A, Chachahuen Sur, Punta Barda
and El Trebol fields.
A new joint venture agreement for Rincón del Mangrullo field resulted in an approximately 8 mmboe (0.3 mmbbl of
crude oil, 1.6 mmbbl of NGL and 34.7 bcf of natural gas) reserves reduction in proved undeveloped reserves, due to
a change in YPF’s working interest in this area.
YPF’s total capital expenditure to continue the development of reserves was approximately U.S.$4,592 million during 2015, of
which U.S.$ 1,557 million was allocated to projects related to proved undeveloped reserves.
As at December 31, 2015, we did not have material amounts of proved undeveloped reserves in individual fields or countries
that have remained undeveloped for five years or more after being disclosed as proved undeveloped reserves.
Changes in our proved undeveloped reserves during 2014
YPF had estimated a volume of net proved undeveloped reserves of 307 mmboe at December 31, 2014, which represented
approximately 25% of the 1,212 mmboe total reported proved reserves as of such date. This compares to estimated net proved
undeveloped reserves of 261 mmboe as of December 31, 2013 (approximately 24% of the 1,083 mmboe total reported proved
reserves as of such date).
The 18% total net increase in net proved undeveloped reserves in 2014 is mainly attributable to:
–
Ongoing successful development activities related to proved undeveloped reserves projects, which allowed a
transfer of approximately 88.1 mmboe (26.3 mmbbl of crude oil, 8.3 mmbbl of NGL and 300.6 bcf of natural gas) to
proved developed reserves. Main contributions are related to development wells (58 mmboe), gas compression
projects (14 mmboe) and improved recovery projects (10 mmboe).
–
–
Extensions and discoveries, which added 79.3 mmboe (19.6 mmbbl of crude oil, 9.6 mmbbl of NGL and 291.3 bcf
of natural gas) of proved reserves mainly from the Rincón del Mangrullo, Aguada Toledo-Sierra Barrosa, Loma La
Lata Norte, Manantiales Behr and Chachahuen fields.
Negotiation of the extension of exploitation concessions in the provinces of Tierra del Fuego and Río Negro which
added 15.5 mmboe (4.7 mmbbl of crude oil, 0.8 mmbbl of NGL and 56.3 bcf of natural gas) of proved undeveloped
reserves. See “Item 4. Information on the Company—Regulatory Framework and Relationship with the Argentine
Government Exploration and Production.
45
–
–
New project studies and revision of gas and oil development projects, which added approximately 28 mmboe (17.7
mmbbl of crude oil, a decrease of 1.3 mmbbl of NGL, and 64.8 bcf of natural gas) of proved undeveloped reserves.
The main contributions came from the Volcán Auca Mahuida, Aguada Toledo-Sierra Barrosa, Seco León and Los
Perales fields.
New improved recovery projects, which added approximately 10 mmbbl of proved undeveloped secondary recovery
reserves. The most important additions are related to the Manantiales Behr, El Trébol, Escalante, Barranca Baya and
Los Perales fields.
YPF’s total capital expenditure to advance the development of reserves was approximately U.S.$4,260 million during 2014, of
which U.S.$758 million was allocated to projects related to proved undeveloped reserves.
As of December 31, 2014, we estimate our proved undeveloped reserves related to gas wells and to primary and secondary oil
recovery projects, which account for approximately 96% of our proved undeveloped reserves, will be developed within five years
from their initial booking date.
Low pressure gas compression projects in Loma La Lata Central and Loma La Lata Norte Fields, which account for the
remaining approximately 4% of our proved undeveloped reserves as of December 31, 2014, continue their scheduled development.
We estimate that the last compression stage (representing approximately 1% of our proved reserves as of such date) will be developed
within approximately seven years from its booking date according to expected compression needs based on current (and consequently
expected) reservoir behavior.
Changes in our proved undeveloped reserves during 2013
YPF had estimated a volume of net proved undeveloped reserves of 261 mmboe at December 31, 2013, which represented
approximately 24% of the 1083 mmboe total reported proved reserves as of such date. This compares to estimated net proved
undeveloped reserves of 203 mmboe as of December 31, 2012 (approximately 21% of the 979 mmboe total reported proved reserves
as of such date).
The 28% total net increase in net proved undeveloped reserves in 2013 is mainly attributable to:
–
–
–
New project studies and extensions of natural gas and oil development projects, which added approximately 83
mmboe of proved undeveloped reserves, mainly from the Aguada Toledo–Sierra Barrosa (Lajas Tight Gas and
Lotena formations), Rincón del Mangrullo, Loma La Lata Central (Sierras Blancas formation), and Piedras Negras
fields.
Successful development activities related to proved undeveloped reserves projects, which allowed a transfer of
approximately 41 mmboe to proved developed reserves.
Negotiation of the extension of exploitation concessions in the province of Chubut (See “Item 4. Information on the
Company—Regulatory Framework and Relationship with the Argentine Government—Exploration and
Production”) which added 8 mmboe of proved undeveloped reserves, mainly due to scheduled proved undeveloped
projects and which will not require additional investment.
–
New improved recovery projects, which added approximately 8 mmboe of proved undeveloped secondary recovery
reserves.
YPF’s total capital expenditure to advance the development of reserves was approximately U.S.$3,631 million during 2013, of
which U.S.$628 million was allocated to projects related to proved undeveloped reserves.
As of December 31, 2013, we estimate our proved undeveloped reserves related to gas wells and to primary and secondary oil
recovery projects, which account for approximately 84% of our proved undeveloped reserves, will be developed within five years
from their initial booking date.
46
Low pressure gas compression projects in Loma La Lata, which account for the remaining approximately 16% of our proved
undeveloped reserves as of December 31, 2013, continue their scheduled development. We estimate that the first stage of these
projects will be developed within five years from their initial booking. We estimate that the last compression stage, which accounts
for approximately 6% of our proved undeveloped reserves as of December 31, 2013 (representing approximately 2% of our proved
reserves as of such date), will be developed within approximately seven years from its booking date according to expected
compression needs based on current (and consequently expected) reservoir behavior.
Internal controls on reserves and reserves audits
All of our oil and gas reserves held in consolidated companies have been estimated by our petroleum engineers. In order to meet
the high standard of “reasonable certainty,” reserves estimates are stated taking into consideration additional guidance as to reservoir
economic producibility requirements, acceptable proved area extensions, drive mechanisms and improved recovery methods,
marketability under existing economic and operating conditions and project maturity.
Where applicable, the volumetric method is used to determine the original quantities of petroleum in place. Estimates are made
by using various types of logs, core analysis and other available data. Formation tops, gross thickness and representative values for
net pay thickness, porosity and interstitial fluid saturations are used to prepare structural maps to delineate each reservoir and
isopachous maps to determine reservoir volume. Where adequate data is available and where circumstances are justified, material-
balance and other engineering methods are used to estimate the original hydrocarbon in place.
Estimates of ultimate recovery are obtained by applying recovery factors to the original quantities of petroleum in place. These
factors are based on the drive mechanisms inherent in the reservoir, analysis of the fluid and rock properties, the structural position of
the reservoir and its production history. In some instances, comparisons are made with similar production reservoirs in the areas
where more complete data is available.
Where adequate data is available and where circumstances are justified, material-balance and other engineering methods are
used to estimate ultimate recovery. In these instances, reservoir performance parameters such as cumulative production, production
rate, reservoir pressure, gas to oil ratio behavior and water production are considered in estimating ultimate recovery.
In certain cases where the above methods could not be used, proved reserves are estimated by analogy to similar reservoirs
where more complete data are available.
To control the quality of reserves booking, a process has been established that is integrated into the internal control system of
YPF. This process to manage reserves booking is centrally controlled and has the following components:
(a) The Reserves Audit (“RA”) is separate and independent from the Exploration and Production segment. RA’s activity is overseen
by YPF’s Audit Committee, which is also responsible for supervising the procedures and systems used in the recording of and
internal control over the Company’s hydrocarbon reserves. The primary objectives of the RA are to ensure that YPF’s proved
reserves estimates and disclosure are in compliance with the rules of the SEC, the FASB, and the Sarbanes-Oxley Act, and to
review annual changes in reserves estimates and the reporting of YPF’s proved reserves. The RA is responsible for preparing the
information to be publicly disclosed concerning YPF’s reported proved reserves of crude oil, NGLs, and natural gas. In addition,
the RA is also responsible for providing training to personnel involved in the reserves estimation and reporting process within
YPF. The RA is managed by and staffed with individuals that have an average of more than 20 years of technical experience in
the petroleum industry, including in the classification and categorization of reserves under the SEC guidelines. The RA staff
includes several individuals who hold advanced degrees in either engineering or geology, as well as individuals who hold
bachelor’s degrees in various technical studies. Several members of the RA are registered with or affiliated to the relevant
professional bodies in their fields of expertise.
(b) The Reserves Auditor, who has headed the RA since January 2013, is responsible for overseeing the preparation of the reserves
estimates and reserves audits conducted by third party engineers. The current director has over 19 years of experience in
geology and geophysics, reserves estimates, project development, finance and general accounting regulation. In the six years
prior to becoming the Reserves Auditor, he was Regional Director responsible for the operation and development of YPF’s
operated fields at the Cuyana and North of Neuquina basins, in western Argentina. He holds a degree in geology from the
National University of Tucumán, and postgraduate courses at IAE Austral University. Consistent with our internal control
system requirements, the Reserves Auditor’s compensation is not affected by changes in reported reserves.
(c) A quarterly internal review by the RA of changes in proved reserves submitted by the Exploration and Production business units
and associated with properties where technical, operational or commercial issues have arisen.
47
(d) A Quality Reserve Coordinator (“QRC”) is assigned to each Exploration and Production business unit of YPF to ensure that
there are effective controls in the proved reserves estimation and approval process of the estimates of YPF and the timely
reporting of the related financial impact of proved reserves changes. Our QRCs are responsible for reviewing proved reserves
estimates. The qualification of each QRC is made on a case-by-case basis with reference to the recognition and respect of such
QRC’s peers. YPF would normally consider a QRC to be qualified if such person (i) has a minimum of 5 years of practical
experience in petroleum engineering or petroleum production geology, with at least three years of such experience in charge of
the estimation and evaluation of reserves, and (ii) has either (A) obtained, from a college or university of recognized stature, a
bachelor’s or advanced degree in petroleum engineering, geology or other related discipline of engineering or physical science,
or (B) received, and is maintaining in good standing, a registered or certified professional engineer’s license or a registered or
certified professional geologist’s license, or the equivalent thereof, from an appropriate governmental authority or professional
organization.
(e) A formal review through technical review committees to ensure that both technical and commercial criteria are met prior to the
commitment of capital to projects.
(f) Our internal audit team examines the effectiveness of YPF’s financial controls, which are designed to ensure the reliability of
reporting and safeguarding of all the assets and examines YPF’s compliance with the law, regulations and internal standards.
(g) All volumes booked are submitted to a third party reserves audit on a periodic basis. The properties selected for a third party
reserves audit in any given year are selected on the following basis:
i.
ii.
all properties on a three year cycle; and
recently acquired properties not submitted to a third party reserves audit in the previous cycle and properties with respect
to which there is new information which could materially affect prior reserves estimates.
For those areas submitted to a third party reserves audit, YPF’s proved reserves figures have to be within 7% or 10 mmboe of
the third party reserves audit figures for YPF to declare that the volumes have been ratified by a third party reserves audit. In the
event that the difference is greater than the tolerance, YPF will re-estimate its proved reserves to achieve this tolerance level or should
disclose the third party figures. YPF has adopted the above-mentioned procedure by approving the corresponding internal policy.
In 2015, IHS Global Canada Limited audited certain YPF operated and non-operated areas in the Neuquina, Golfo San Jorge
and Cuyana basins in Argentina, and DeGolyer and MacNaughton audited Neptune, a non-operated area in the United States. These
audits were performed as of December 31, 2015, and the audited fields contain in aggregate, according to our estimates, 330.6
mmboe proved reserves (93.8 mmboe of which were proved undeveloped reserves) as of such date, which represented approximately
27.0% of our proved reserves and 27.8% of our proved undeveloped reserves as of December 31, 2015. Copies of the related reserves
audit reports are filed as an exhibit to this annual report.
We are required, in accordance with Resolution S.E. No. 324/06 of the Argentine Secretariat of Energy, to annually file by
March 31 details of our estimates of our oil and gas reserves and resources with the Argentine Secretariat of Energy, as defined in that
resolution and certified by an external auditor. The aforementioned certification and external audit only have the meaning established
by Resolution S.E. No. 324/06, and are not to be interpreted as a certification or external audit of oil and gas reserves under SEC
rules. We last filed such a report for the year ended December 31, 2014. Estimates of our oil and gas reserves filed with the Argentine
Secretariat of Energy are materially higher than the estimates of our proved oil and gas reserves contained in this annual report
mainly because: (i) information filed with the Argentine Secretariat of Energy includes all properties of which we are operators,
irrespective of the level of our ownership interests in such properties; (ii) information filed with the Argentine Secretariat of Energy
includes other categories of reserves and resources that are not included in this annual report, which are different from estimates of
proved reserves consistent with the SEC’s guidance contained in this annual report; and (iii) the definition of proved reserves under
Resolution S.E. No. 324/06 is different from the definition of “proved oil and gas reserves” established in Rule 4-10(a) of Regulation
S-X. Accordingly, all proved oil and gas reserve estimates included in this annual report reflect only proved oil and gas reserves
consistent with the rules and disclosure requirements of the SEC.
Oil and gas production, production prices and production costs
The following table shows our crude oil (including oil and condensate), NGL, and gas production on an as sold and annual basis
for the years indicated. In determining net production, we exclude royalties due to others, whether payable in cash or in kind, where
the royalty owner has a direct interest in such production and is able to make lifting and sales arrangements independently. By
contrast, to the extent that royalty payments required to be made to a third party, whether payable in cash or in kind, are a financial
obligation or are substantially equivalent to a production or severance tax, they are not excluded from our net production amounts
despite the fact that such payments are referred to as “royalties” under local rules. This is the case for our production in Argentina,
where royalty expense is accounted for as a production cost.
48
Oil and Condensate Production (1)
Consolidated entities
South America
Argentina
North America
United States
Total consolidated entities
Equity-accounted entities
South America
Argentina
North America
United States
Total equity-accounted entities
Total oil production(2)
NGL Production (1)
Consolidated entities
South America
Argentina
North America
United States
Total consolidated entities
Equity-accounted entities
South America
Argentina
North America
United States
Total equity-accounted entities
Total NGL production (3)
Natural Gas Production (1)
Consolidated entities
South America
Argentina
North America
United States
Total consolidated entities
Equity-accounted entities
South America
Argentina
North America
United States
Total equity-accounted entities
Total natural gas production (4) (5)
Oil Equivalent Production (1)(6)
Consolidated entities
Oil and condensate
NGL
Natural gas
Equity-accounted entities
Oil and condensate
NGL
Natural gas
Total oil equivalent production
2015
2014
(mmbbl)
2013
91
89
84
*
91
*
89
*
84
—
—
—
—
—
91
—
—
89
—
—
84
2015
2014
(mmbbl)
2013
18
18
18
—
18
—
18
—
18
—
—
*
—
—
18
—
—
18
—
*
18
2015
2014
(bcf)
2013
452
470
372
*
452
1
471
1
373
—
—
5
—
—
452
—
—
471
—
5
378
2015
2014
(mmboe)
2013
91
18
81
89
18
84
84
18
66
—
—
—
190
—
—
—
191
—
*
1
169
Not material (less than 1).
*
(1) Loma La Lata Central and Loma La Lata Norte (southern and northern parts of the Loma La Lata field) in Argentina contain
approximately 15% of our total proved reserves expressed on an oil equivalent barrel basis. Oil and condensate production in
these fields was approximately 6, 5, and 5 mmbbl for the years ended December 31, 2015, 2014 and 2013, respectively. NGL
production in these fields was approximately 8, 8 and 9 mmbbl for the years ended December 31, 2015, 2014 and 2013,
respectively. Natural gas production in the Loma La Lata field was 133, 138 and 110 bcf for the years ended December 31,
2015, 2014 and 2013, respectively.
(2) Crude oil production for the years ended in December 31, 2015, 2014 and 2013 includes an estimated approximately 13, 13 and
12 mmbbl, respectively, in respect of royalty payments which are a financial obligation or are substantially equivalent to a
production or similar tax. Equity-accounted entities production of crude oil in respect of royalty payments which are a financial
obligation, or are substantially equivalent to a production or similar tax is not material.
(3) NGL production for the years ended in December 31, 2015, 2014 and 2013 includes an estimated approximately 2, 2 and 3
mmbbl, respectively, in respect of royalty payments which are a financial obligation or are substantially equivalent to a
production or similar tax. Equity-accounted entities production of NGL in respect of royalty payments which are a financial
obligation or are substantially equivalent to a production or similar tax is not material.
(4) Natural gas production for the years December 31, 2015, 2014 and 2013 includes an estimated approximately 58, 60 and 47 bcf,
respectively, in respect of royalty payments which are a financial obligation or are substantially equivalent to a production or
similar tax. Equity-accounted entities production of natural gas in respect of royalty payments which are a financial obligation
or are substantially equivalent to a production or similar tax is not material.
(5) Does not include volumes consumed or flared in operations (whereas sale volumes shown in the reserves table included in
“Supplemental Information on Oil and Gas Exploration and Production Activities—Oil and Gas Reserves” include volumes
consumed in operations).
(6) Volumes of natural gas have been converted to barrels of oil equivalent at 5,615 cubic feet per barrel.
The composition of the crude oil produced by us in Argentina varies by geographic area. Almost all crude oil produced by us in
Argentina has very low or no sulfur content. We sell substantially all the crude oil we produce in Argentina to our Refining and
Marketing business segment. Most of the natural gas produced by us is of pipeline quality. All of our gas fields produce commercial
quantities of condensate, and substantially all of our oil fields produce associated gas.
49
The following table sets forth the average production costs and average sales price by geographic area for 2015, 2014 and 2013:
Production costs and sales price
Year ended December 31, 2015
Lifting costs
Local taxes and similar payments (1)
Transportation and other costs
Average production costs
Average oil sales price
Average NGL sales price
Average natural gas sales price (2)
Year ended December 31, 2014
Lifting costs
Local taxes and similar payments (1)
Transportation and other costs
Average production costs
Average oil sales price
Average NGL sales price
Average natural gas sales price (2)
Year ended December 31, 2013
Lifting costs
Local taxes and similar payments (1)
Transportation and other costs
Average production costs
Average oil sales price
Average NGL sales price
Average natural gas sales price(2)
Total
Argentina
(Ps./boe)
United States
152.00
4.82
14.95
171.77
620.77
133.92
249.71
122.44
11.43
15.06
148.93
594.02
188.87
204.02
88.02
5.55
19.89
113.46
393.62
114.05
129.86
151.85
4.83
14.91
171.59
621.85
133.59
249.75
122.26
11.44
15.03
148.74
593.34
187.70
204.01
88.02
5.58
19.88
113.48
392.77
112.90
129.87
240.76
—
41.09
281.85
392.86
175.25
129.73
235.99
—
31
266.99
724.77
364.23
192.58
88.52
—
21.96
110.48
541.74
252.27
108.12
(1) Does not include ad valorem and severance taxes, including the effect of royalty payments which are a financial obligation or
are substantially equivalent to such taxes, in an amount of approximately Ps. 60.39 per boe, Ps. 45.51 per boe and Ps. 32.77 per
boe for the years ended December 31, 2015, 2014 and 2013, respectively.
Includes revenues from the Gas Plan.
(2)
Drilling activity in Argentina
The following table shows the number of wells drilled by us or consortiums in which we had a working interest in Argentina
during the periods indicated.
Wells Drilled in Argentina
Gross wells drilled (1)
Exploratory productive
Oil
Gas
Dry
Total
Development productive
Oil
Gas
Dry
Total
Net wells drilled (2)
Exploratory productive
Oil
Gas
Dry
Total
Development productive
For the Year Ended December 31,
2015
2014
2013
35
24
11
5
40
962
766
196
10
972
27
22
6
4
31
766
35
20
15
8
43
861
725
136
4
865
30
17
13
5
35
708
38
30
8
3
41
728
664
64
2
730
29
25
4
3
32
679
Oil
Gas
Dry
Total
629
137
8
774
592
116
4
712
624
55
2
681
(1)
(2)
“Gross” wells include all wells in which we have an interest. In addition to wells drilled in Argentina, we participated in the
drilling of the following “gross” wells in North America: one development oil well in 2014 with positive result, which belongs
to the Neptune off shore project GOM (first oil January 2015).
“Net” wells equals gross wells after deducting third-party interests. In addition to wells drilled in Argentina, “net” wells were
not drilled in North America.
50
Exploration & Production Activity in Argentina
During 2015, our main exploratory and development activities in Argentina have had the following principal focus:
1. Operated areas - Exploratory activities
During 2015, our main exploratory activities in Argentina were principally focused on:
1.1 Onshore:
•
Unconventional activities:
The successful exploration results achieved in 2014 continued into 2015. We continued the regional exploration of the
Vaca Muerta formation to determine the productivity of the shale oil, wet gas and dry gas in different areas of the basin.
Having completed the exploration phase, we obtained 35-year exploitation permits for the Bandurria Sur block and
requested 35-year exploitation permits for the La Ribera I & II blocks.
•
Shale oil:
Neuquina basin: Exploration continued along the shale oil strip, in an attempt to define intermediate control points of
productivity.
We obtained positive results in wells drilled in the Bandurria, Chihuido de la Sierra Negra and Bajo del Toro blocks. These
wells confirmed the productivity of the Vaca Muerta formation at various points of the basin.
•
Shale gas:
Neuquina basin: During 2015, we focused on the regional definition of the shale gas strip area obtaining positive results in
the Bandurria and La Ribera I & II blocks. Discoveries will be evaluated further in order to establish their commercial
production potential. Studies to confirm results in Cerro Arena, Pampa de las Yeguas and Loma del Molle are still underway.
•
Conventional activities:
1. Neuquina basin:
Tight gas: Exploration of tight gas continued with the drilling of RDM.xp-38 in the Rincón de Mangrullo block. As of the date
of this annual report, this well is pending completion.
Positive results were obtained in eleven exploration wells targeting conventional reservoirs in the following blocks:
(cid:123) Los Caldenes (gas)
(cid:123) Paso de las Bardas (gas)
(cid:123) Payún Oeste (oil) (2 wells)
(cid:123) Altiplanicie del Payún (oil)
(cid:123) Las Tacanas (gas)
(cid:123) Loma la Lata - Sierra Barrosa (gas)
(cid:123) Octógono (oil)
(cid:123) Chachahuen Sur (oil)
(cid:123) El Manzano Este (oil)
(cid:123) Puntilla del Huicán (oil)
51
In the Cajón de los Caballos Oriental block one exploration well LoAl.x-1 was drilled in 2015, with the objective of the classic
rocks of Neuquén group and the fissured rocks of Mendoza group. As of December 2015, this well was awaiting completion
with a target date of March 2016.
2. Golfo San Jorge basin:
During 2015, we continued exploration activity targeting conventional oil and gas reservoirs in the Golfo San Jorge basin and
we are continuing exploration of deep objectives during 2016. We obtained positive results in three exploration wells in the
following blocks:
(cid:123) Restinga Alí (gas)
(cid:123) Los Perales-Las Mesetas (oil)
3. Cuyana basin:
We continued exploration activity targeting conventional oil in Cuyana basin, with results under evaluation in the following
blocks:
(cid:123) Barrancas
(cid:123) La Ventana
(cid:123) Ugarteche
(cid:123) Cuenca Cuyana y Bolsones 17/B (CCyB 17/B)
From the results obtained in the Payun Oeste block (Neuquen basin) and Cuenca Cuyana y Bolsones 17/B (Cuyana basin), we
have requested the province to allow commercial exploitation of the blocks, which opens new areas of development.
CCyB17/B Exploration block: Successful exploration of a well revealed a new mineralized area to be delineated and studied, in
the Río Blanco formation.
4. Bordering areas:
Los Tordillos Oeste block located in the province of Mendoza: We fulfilled our commitment to drill two exploratory wells.
Considering the results, we decided not to continue with the second exploratory period and, as a result, the block was
relinquished to the province of Mendoza.
•
Seismic activities:
A long-term 2D-3D seismic registration campaign was started in 2015 and will continue in 2016.
During 2015, 1,070 km2 of seismic 3D was registered in the following blocks:
(cid:123) Chachahuén (Mendoza province – Neuquina basin)
(cid:123) Zampal Norte (Mendoza province – Cuyana basin)
(cid:123) Cerro Piedra – Cerro Guadal Norte (Santa Cruz province - Golfo San Jorge basin)
Also, 350 km of seismic 2D was registered in the following blocks:
(cid:123) Cajón de los Caballos (Mendoza province – Neuquina basin)
(cid:123) Chachahuén (Mendoza province – Neuquina basin)
After the survey is performed, seismic data processing will be carried out for subsequent interpretation. The purpose of
acquiring and processing the seismic data is to identify new exploration opportunities.
52
2.2 Offshore:
According to the amendments to the Hydrocarbons Law adopted by Law No. 27,007, all exploration permits owned by
ENARSA will be transferred to the Secretariat of Energy. YPF currently participates in three offshore blocks in association with
ENARSA (E1 block: YPF 35%, E2 block: YPF 33% and E3 block: YPF 30%) with total acreage of 23,700 km2. In September
2015, the National Executive Office and YPF began negotiating the conversion of association agreements signed with
ENARSA. As of the date of this annual report, the negotiations are ongoing. As of December 31, 2015, we do not have
registered assets in these blocks. See “—Regulatory Framework and Relationship with the Argentine Government—Law
No. 27,007, amending the Hydrocarbons Law” for a description of new terms which apply to new production concessions or
exploitation permits.
Operated Areas - Development activities
During 2015, our development activities in Argentina were mainly focused on the following regions:
2.1 Neuquén—Río Negro
•
Neuquén concession:
1. Loma La Lata field:
The Sierras Blancas Infill project in the Southeast area continues its development with nine wells (four horizontal and five
directional) during 2015. Six of these are already in production, one is being completed and tested, and two are being drilled.
The four horizontal wells have had good pressure and production results. During 2016, we plan to drill eighteen wells.
In order to address the declining production of the field, we also continue improving production with plunger lift and wellhead
compression.
2. Aguada Toledo–Sierra Barrosa field:
(cid:123)
Tight gas (Lajas formation)
During 2015, the regular offset drilling was almost completed. Several wells were drilled in the outer area of the main structure.
The infill drilling started in 2015, achieving good results so far. We are conducting a horizontal drilling pilot in the deepest and
tightest sands of Lajas formation to define the potential of the formation in low levels of the structure.
(cid:123)
Waterflooding (Lotena formation)
In 2015 we completed the Aguada Toledo Waterflooding project. We achieved the injection flow capacity planned (21,000
cm/d). For that, facilities were built and refurbished, 17 wells were converted to injectors and several others were repaired. Also,
during 2016, studies will be carried out to extend waterflooding to Sierra Barrosa, an adjacent field, where there is an
anticipated potential oil recovery of 3 mmboe.
(cid:123)
Delineation of tight oil strata (Quintuco-Vaca Muerta formation)
As part of a regional study of Quintuco-Vaca Muerta Formation, seven workovers and three wells were completed, from which
rock and fluid data was taken. More studies and strategic evaluations are needed (such as horizontal wells) to confirm the
formation’s potential.
(cid:123)
Barrosa Norte tight gas field (Lajas formation)
During 2015, six wells were drilled in this field. Three of the wells are already in production and the others are being completed
and tested. In 2016, 15 wells will be drilled, with thirteen development wells and two appraisal wells in the west side of the
structure. The Precuyo and Molles formations will be evaluated to determine their potential for future development.
53
(cid:123)
El Cordón tight gas field
In this field, we are in the early stages of development. Three wells and a workover were performed in 2015, with results
meeting expectations, especially for the Lower Lajas formation, which is over-pressured and produces at expected rates. In
2016, new wells are planned in order to produce gas from the region ranging from Lower Lajas to the Sierras Blancas
formations. A new pipeline has allowed us to increase flow rate from this field from December 2015.
3. Octógono block:
Four development wells were completed targeting the Basamento formation. The results were as expected, with an average
production of 660 bbl/d by the end of December 2015. In addition to this, we completed two workovers targeting the same
formation, with an average production of 43 bbl/d by the end of December 2015.
We completed four other workovers targeting the Lajas formation, which confirmed its potential in the north of the
Octógono concession area, where good results were obtained. Regarding the secondary recovery pilot, we drilled and completed
one replacement well and did four workovers. In addition to drilling activities, we are building and refurbishing facilities to
reach a capacity of 1,500 cm/d of water injection, considering the first stage of the project.
4. Chihuido de la Sierra Negra field:
During 2015, we successfully completed a single well chemical tracer test, alkali surfactant polymer (“ASP”). This field
test validated the entire previous lab test. In order to start a pilot on the field, further tests are required to evaluate ASP
efficiency over longer time periods.
5. Volcán Auca Mahuida and Las Manadas blocks:
We continued with the appraisal and development of the Centenario and Mulichinco formations. Five new wells were
completed during 2015, all of which were productive with good results. Further appraisal and development wells are scheduled
to be drilled in 2016.
6. Cerro Hamaca Noroeste field:
The northwest area was discovered in late 2012. During 2015, we continued with the development campaign of the Rayoso
formation. Ten wells were completed in 2015. As of December 2015, the field average oil production was 900 bbl/d,
approximately 117% higher than the previous year, as of December 2014. Water injection is scheduled to begin in 2017.
7. Puesto Hernandez block:
During 2015, we reactivated the drilling activity in the area where new wells had not been added since 2008. This activity
contemplated the drilling of four production wells and two injection wells in the northwest and southeast of the field. As of
December 2015, this activity generated an incremental production of oil of 126 bbl/d.
8. Bardita Zapala field:
Four development wells were drilled targeting the Tordillo formation, three of them with average oil production of 8 bbl/d
in 2015. The results were lower than expected. The fourth well, BZ.a-10(d), had gas production of 14 mcm/d in 2015, meeting
expectations.
9. Portezuelos field:
Four workovers were performed targeting shallow gas in the Centenario formation with an average gas production in 2015
of 15 mcm/d. In addition, three workovers were performed in the Lajas formation with an average gas production in 2015 of 10
mcm/d. The results of these workovers did not meet expectations.
10. Portezuelos Oeste field:
Five workovers were performed to open gas-bearing intervals in the Grupo Cuyo Superior formation, with average gas
production for the PO-09 and PO-10 wells of 12 mcm/d in 2015. The expected production exceeds expectations.
54
11. Ranquil Co field:
Four development wells were drilled targeting the Precuyo formation, with average gas production of 47 mcm/d in 2015.
These results did not exceed the plan.
12. Guanaco field:
Two step-out wells were drilled during 2015 in the Guanaco Shallow area targeting the Lotena and Lajas formations. One
of them produces oil from Lotena with average production of 43 bbl/d in 2015. The results were lower than expected. To
confirm the shallow gas potential from the Lajas formation in this field, we executed two workovers, which had a combined
average production of 19 mcm/d in 2015.
13. Huincul field:
Two Lajas development wells with secondary exploratory targets of the Precuyo and Basamento formations were drilled
during 2015, with an average oil production of 8 bbl/d and average gas production of 1 mcm/d in 2015. The results exceed the
plan in oil but not in gas.
Neuquen YPF Concession
1 Aguada de Castro; 2 Aguada Pichana; 3 Aguada Villanueva; 4 Al Norte de La Dorsal; 5 Al Sur de La Dorsal I; 6 Al Sur de La
Dorsal II; 7 Al Sur de La Dorsal III; 8 Al Sur de La Dorsal IV; 9 Al Sur De La Dorsal V; 10 Al Sur De La Dorsal VI; 11 Al Sur de La
Dorsal VII; 12 Anticlinal Campamento; 13 Apon; 14 Bajada de Añelo; 15 Bajo Del Toro; 16 Bandurria Sur; 19 Cerro Arena; 20
Cerro Avispa; 21 Cerro Bandera; 22 Cerro Hamaca; 23 Cerro Las Minas; 24 Cerro Partido; 25 Chapua Este; 26 Chasquivil; 27
Chihuido de La Salina Sur; 28 Chihuido de La Sierra Negra; 29 Corralera; 30 Cortadera; 31 Cortadera; 32 Dadín—Lote I; 33
Dadín—Lote II; 34 Dadín—Lote III; 35 Don Ruíz; 36 Dos Hermanas; 37 El Orejano; 38 El Portón; 39 El Santiagueño; 40 Filo
Morado; 41 Huacalera; 42 La Amarga Chica; 43 La Banda; 44 La Calera; 45 La Ribera I; 46 La Ribera Ii; 47 Las Manadas (Calandria
Mora); 48 Las Tacanas; 49 Lindero Atravesado; 50 Loma Amarilla; 51 Loma Campana; 52 Loma del Mojón; 53 Loma Del Molle; 54
Loma La Lata—Sierra Barrosa; 55 Los Candeleros; 56 Mata Mora; 57 Meseta Buena Esperanza; 58 Narambuena; 59 Octogono; 60
Ojo De Agua; 61 Pampa de Las Yeguas I; 62 Pampa de Las Yeguas II; 63 Paso de Las Bardas Norte; 64 Puesto Hernandez; 65
Rincón Del Mangrullo; 66 Río Barrancas; 67 Salinas del Huitrin; 68 San Roque; 69 Santo Domingo I; 70 Santo Domingo II; 71 Señal
Cerro Bayo; 72 Señal—Punta Barda; 73 Volcán Auca Mahuida.
55
•
Río Negro Concession:
1. Los Caldenes block:
We drilled four wells and completed three wells in 2015. We also performed two workovers on existing wells. The oil is
produced from two layers, as we successfully tested production from Quintuco and Sierras Blancas. As a result of this activity,
oil production averaged 591 bbl/d as of December 31, 2015 (an increase of 389% compared to December 2014). Further drilling
and completion activity is scheduled for 2016 and a gas line is planned to produce gas from deeper formations.
2. Señal Picada-Punta Barda block:
During 2015, we continued optimizing the existing waterflooding projects in the 50-year-old Señal Picada area. We
completed 21 new wells and workovers in existing wells. Oil production decreased to 5,791 bbl/d (a decrease of 101 bbl/d or
2%) from December 2014 to December 2015. In the Punta Barda area, we continued with the appraisal campaign to extend the
proved reserves area. Two wells were drilled in the Loma Montosa formation. One of these wells was completed and
successfully tested for oil. The other well is scheduled to be completed in 2016. Three other wells were completed and ten
workovers were performed in 2015. Oil production increased to 1,208 bbl/d (an increase of 166 bbl/d or 16%) from December
2014 to December 2015.
3. Los Ramblones field:
Eleven oil wells were drilled during 2015, targeting primarily the Sierras Blancas formation. The best results were
achieved from eight wells drilled on the western end of the field on a faulted combined trap. The 2015 drilling campaign had an
average production with excellent results that restored the field’s production to its highest levels, reached in the 1980’s. It hit a
peak of 1,406 bbl/d in December 2015. The successful campaign has opened up new opportunities for drilling in the area, which
are currently under study.
4. Punta Rosada field:
Four workovers were performed targeting shallow gas in the Centenario formation. The successful campaign has created
new opportunities in the area, which are currently under study.
5. Estación Fernandez Oro block:
During 2015, we drilled 19 gas wells targeting the Lajas formation (13 development gas wells, five step-out gas wells and
one exploratory gas well) with results better than expected for the development wells, but poorer than expected for the rest of
the wells. The development of the gas field will continue during 2016, focusing on drilling activity. An expansion in the mid-
pressure compression and continuation of work on three drilling rigs are planned for 2016.
56
Río Negro YPF Concession
2.2 Mendoza
•
Mendoza Norte concession:
During 2015, our activities were focused on the development of new areas and performing primary recovery and waterflooding
in mature oilfields by workovers and drilling new wells. Key activities are described below:
1. Barrancas block:
(cid:123)
Barrancas area: Results obtained from the appraisal well B.a-508, drilled in 2014, helped revitalize this mature oilfield
as it opens a new opportunity in the area located at the northeast flank from the Barrancas Anticline. The drilling
activity plan involved drilling 15 development wells. The dynamic-static model shows opportunities along the eastern
flank of the structure and it is consistent with results from well B.a-507. Both support the expansion of the drilling
activity.
(cid:123) Ugarteche area: After 14 years, drilling activity has been revitalized with two development wells located in Ugarteche
Occidental field. The successful results allow the expansion of the productive area in the south portion of the field. These wells
produce from both the Barrancas and the Río Blanco formations.
(cid:123)
Estructura Cruz de Piedra area: The field development plan continued during 2015, including four workovers and five
new development wells. We obtained good results that support the proposed activity for 2016, which includes the
expansion of waterflooding to the ECP-Lunlunta area in the southern portion of the field.
2. La Ventana block:
After reaching a new Joint Operating Agreement with Sinopec, drilling activities were increased during 2014 and 2015. Four
exploration wells were drilled between June 2014 and December 2015. According to the field development plan (infill &
replacements wells), seven wells were drilled in 2014 and nine wells were drilled in 2015.This activity allowed us to incorporate
reserves and production in the block. We expect to continue with the development plan, increasing the recovery factor of this mature
field by drilling deep-objective appraisal wells, development wells, and workovers and optimizing the secondary recovery. In
addition, this block is included in regional studies in order to develop an ASP formulation (tertiary recovery), according to
temperature and salinity conditions of the reservoir-enhanced oil recovery (“EOR”) in the Barrancas Formation.
57
3. Vizcacheras block:
A new geological model of this mature field was created after seismic re-interpretation in 2012. This model enabled the
construction of a development plan (including 63 new wells to drill). During 2015, three wells were drilled in the Vizcacheras
Oeste field. We tested oil downdip in the Papagayos formation in the Vizcacheras field, Vi.a-1138 well. Three re-entry wells to
the Barrancas formation were drilled (with positive results in the northwest zone). We also drilled two infill wells in the Cañada
Dura field. In addition, this block is included in regional studies in order to develop EOR, in the Barrancas and Papagayos
formations.
4. Llancanelo block:
Six horizontal wells and two appraisal wells were drilled in 2015, targeting two geological formations. A total of 23 wells
have been drilled since 2010, with an oil production of 1,116 bbl/d, in line with expectations.
5. El Manzano block:
Positive results, which exceeded expectations, were obtained in the appraisal well LVo.a-9 drilled in 2014. This project
continued in 2015 with the drilling of appraisal well LVo.a-14, which is not complete.
6. Cerro Fortunoso block:
A water treatment plant was installed to treat a maximum rate of 4,500 cm/d of injection water. We continued the
waterflooding development plan in 2015, including drilling two injector wells, repairing one injector well and repairing one
water production well. The last of the injector wells from the 2015 plan was being drilled at the end of December 2015.
Mendoza Norte YPF Concession
58
Mendoza Sur YPF concession:
During 2015, we remained focused on the development of new areas and waterflooding in mature oil fields. Key activities
are described below:
1. Desfiladero Bayo area:
We drilled eight development wells and four appraisal wells in the Rayoso, Troncoso, Agrio, Mulichinco and Tordillo
formations, in keeping with the development plan, and focused on investigating deep formations. Water injection was started to
define the polymer baseline in the pilot area. We intend to begin the polymer injection pilot during the first half of 2016.
2. Chachahuen Sur block:
We drilled 52 development wells and 12 appraisal wells in the Rayoso formation with positive results. The expansion of
water injection in block 1 is ongoing.
3. Cañadón Amarillo block:
We drilled 17 development wells and six appraisal wells in shallow formations (La Tosca and Chorreado), and deep
formations (Grupo Cuyo, Barda Negra and Tordillo) to continue the development of the north area in the Cañadón Amarillo
block. We obtained results exceeding expectations from the development wells and good results from shallow appraisal wells.
4. Paso Bardas Norte block:
We drilled three development wells and one appraisal well in tight gas formations (Lotena and Grupo Cuyo). The results
were below expectations.
5. Puesto Molina block:
Three development and two injector wells were drilled, and workovers of producers and injector wells were perfomed to
extend and optimize waterflooding patterns. The results were better than expected.
6. El Portón block:
One appraisal well was drilled to investigate deep formations (Quintuco and Mulichinco) with positive results.
7. Chihuido de la Salina block:
One appraisal well was drilled to investigate deep formations (Quintuco and Mulichinco) with positive results.
59
Mendoza Sur YPF Concession
2.3 Chubut
The oil production of the blocks operated by YPF in the province of Chubut surpassed historic levels for the third
consecutive year, achieving a 1.8% increase in net oil production in 2015 compared to 2014. In addition, wellhead gas
production increased 12% in 2015 compared to 2014.
1. Manantiales Behr block:
We drilled 43 wells in 2015 among three main oil fields, La Carolina, El Alba and Grimbeek, with positive results.
Additionally, we completed 61 workovers also with positive results.
The assisted recovery project in Grimbeek began in 2013 with a focus on standard waterflooding. It is currently in an
advanced stage with good production results.
During the first quarter of 2015, the polymer injection phase began. Some evidence of water decreases in the central well
was recorded in 2015, which was the first positive result of the pilot phase. In the same field, the secondary recovery is
performing well. Its peak oil rate surpassed expectations.
60
During the second half of 2015, the extension of this project, known as Grimbeek Norte, was implemented. It is expected
to increase production in 2016.
The short-term focus on the Manantiales Behr block is to extend waterflooding projects along the field in order to sustain
production growth. Facilities developments to extend waterflooding projects will continue in 2016.
As a result of the activities described, the volume of oil production has remained at similar levels of production compared
to 2014.
Gas production increased by 10.9%, driven by the development of a new shallow low pressure target, the Glauconitic
formation.
Chubut YPF Concession
2. El Trébol – Escalante block:
As a result of the investments during 2015 in this mature block, oil production increased by approximately 7.1% compared
to 2014. We drilled 60 new wells and performed 58 workovers within waterflooding optimization projects, which, along with
the delineation of new, deeper structures, increased the accumulated production by 18.6% in the last two years.
A new structure and project was delineated and partially developed in Escalante oilfield, called G3, with excellent
production performance and geographic extension. We are employing an integrated primary and secondary development
strategy to be carried out over the next three years.
3. Zona Central – Cañadón Perdido block:
This block is located near the urban area of Comodoro Rivadavia. Production decreased by 10.2% compared to 2014. This
decrease was a consequence of delays in the extension of the Bella Vista Sur drilling project and a disruption at the HMO oil
treatment plant for the block. One of the plant tanks failed on August 18, 2015, and we were forced to suspend oil production
completely for two weeks. The problem was gradually remedied over three months.
61
4. Restinga Alí block:
Located on the coast between the urban area and the sea, this block was reactivated in 2013. Production increased to a peak
of 940 bbl/d in July 2015. Beginning mid-August, production significantly decreased following a disruption at the Km9 oil
plant. The block has been prevented from delivering oil to date. Production is expected to return to normal during the first
quarter of 2016.
2.4 Santa Cruz
During 2015, we implemented 31 integral development projects across five major development areas in the province of
Santa Cruz (Las Heras, El Guadal, Los Perales, Pico Truncado and Cañadon Seco), comprising a total portfolio of 40 projects.
The main projects include the following reserve areas: Cañadón Escondida, Cerro Grande, Seco León, Los Perales, Cañadon
Yatel and El Guadal, with 243 wells drilled (220 oil wells, 13 injectors and 10 advanced wells), 489 workovers and associated
facilities.
The main objectives of these integral projects are:
(cid:123) Comprehensively developing the areas through the drilling of new wells.
(cid:123) Acquiring the necessary information with electrical logs, rotated plugs and well testing.
(cid:123) Increasing the recovery factor with new enhanced oil recovery projects.
(cid:123) Increasing water injection to improve the sweep efficiency.
(cid:123) Extending horizontal and vertical limits with new appraisal and exploration wells. Drilling of new advanced
wells in Los Perales.
(cid:123) Providing development support through the appropriate surface facilities.
Santa Cruz YPF Concession
62
2.5 Tierra del Fuego
After five years with no activity, in June 2015 drilling activity in the area resumed with one rig. The 2015 campaign
focused on drilling of oil development wells.
1. Carmen Silva field:
In this partially developed field, one well was drilled during 2015 (CS-2003), targeting the Springhill formation classic
reservoir with average oil production of 20 bbl/d and an initial daily production of 113 bbl/d.
2. Cañadón Piedras field:
Two development wells were drilled in this mature oil field. The pressure ranges from 40% to 50% of the original well in
the Springhill formation. One of the wells, CP-2003(d), was a dry hole well. The other, CP-2004(d), was put on production with
average oil production of 19 bbl/d in 2015, below the expected production level.
A workover program consisting of six wells was executed, three of which obtained initial average daily production of 10.6
bbl/d (CP-69, CP96, CP50) and three of which did not produce (CP-73, CP109, RC-14). The results were lower than expected.
3. Cabo Nombre field:
Two development wells were drilled in this mature oil field, where a waterflooding project is ongoing, targeting primarily
Springhill formation. One of them, CN-2002, had average oil production of 79 bbl/d, and met the expected production. The
other well, CN-2001, began production in January 2016.
A workover program consisting of five wells was executed, four of which obtained initial average daily production of 7.5
bbl/d (CN-78, CN-1, CN17, CN-37). The other (CN-8) obtained initial production of 1.2 bbl/d. The results were lower than
expected.
4. San Sebastián field:
A workover program consisting of nine wells was executed in this very mature gas field. The program reversed the
declining output in the field.
During 2015, seismic reprocessing and 5D interpolation of 1,821 km2 in the Los Chorrillos and Uribe blocks was
performed. It will be applied to the development of the fields located in Los Chorrillos block and in the review of Uribe’s
exploratory prospects.
The 2016 campaign calls for drilling of gas development wells in the San Sebastián and Lago Fuego fields.
63
Tierra del Fuego YPF Concession
3.
Non-operated areas
•
Exploration activities:
We obtained positive results in exploration wells drilled in the Lindero Atravesado block, which is operated by Pan American
Energy, and CNQ7/A, which is operated by Pluspetrol.
•
Development activities:
1. El Tordillo and La Tapera-Puesto Quiroga blocks:
Beginning in January 2014, under an agreement between YPF and the province of Chubut related to the negotiation of an
extension of YPF concessions there, YPF transferred 41% of its working interest in the joint venture’s ET/LT-PQ to Petrominera
Chubut S.E. As a result, the participation of YPF in the joint venture is 7.196%.
During 2015, 19 wells were drilled. Of those, 17 were producing in line with our expectations and two were pending
completion as of December 2015.
2. Magallanes block:
On November 17, 2014, we agreed to extend the joint venture contract with ENAP Sipetrol Argentina S.A. in the Magallanes
block. The objective of this agreement was to extend the rights and obligations of ENAP in the original joint venture agreement and
confirm its role as operator, maintaining its 50% share until the end of the concession. On January 8, 2016, the Argentine
government approved a concession extension through November 17, 2027. See “Item 4. Information on the Company—Regulatory
Framework and Relationship with the Argentine Government—Extension of Exploitation Concessions in the Cuenca Marina
Austral.”
64
During 2015, an incremental production project began, known as “PIAM.” This project aims to increase the production
capacity of the area by approximately 1.6 mmcm/d of gas beginning mid-2017. Currently, a portion of the engineering tasks
have been in process. This project involves laying a marine pipeline, expanding compression capacity and reopening
approximately 24 wells that are currently shut-in. The total estimated value of the project is approximately U.S.$354 million and
its completion is expected during the second half of 2017.
3. Aguada Pichana block:
This block is operated by Total S.A. YPF holds a 27.2% working interest in this block.
Tight gas projects: during 2015, we continued tight gas development in different areas of the block and seven wells were
drilled. Six of them are in production or waiting to put into production. The last well, APO-25(h), is pending its producing line
to begin production.
Production improvements: during 2015, we continued our efforts to maintain or improve daily production. We continued
the campaign initiated during the first half of 2013, under which six velocity strings and five capillary strings were initiated,
three wells were refractured and three workovers were conducted.
Unconventional: we continued drilling the pilot wells for unconventional development, which consisted of six horizontal
wells. During the second half of 2015, the completion stage began, which consisted of ten fractures by well and treatment
facilities.
4. Lindero Atravesado block:
This block is operated by Pan American Energy LLC. YPF holds a 37.5% working interest in this block.
During 2015, a new non-conventional concession through 2060 was granted by the government of Neuquén, according to
the Hydrocarbons Law as amended by Law No. 27,007. This non-conventional concession is based on developing and drilling
the Lajas formation. The original scope of the concession includes 97 wells and three new gas plants, as well as the renovation
of two existing gas plants. The 2015 drilling campaign, consisted of 28 wells, all of which are in production. The project also
includes building the corresponding field facilities. Additionally, two wells were drilled in the Sierras Blancas formation.
5. Aguaragüe block:
This block is operated by Tecpetrol, and YPF holds a 53% working interest in this block. Two gas wells were drilled in the
Tupambi formation of the Campo Durán field, with better results than expected. One oil well was drilled in the Los Monos
formation of the Altos de Yariguarenda field, with results meeting expectations.
Properties and E&P activities in rest of the world
1. United States:
During 2015, Maxus relinquished a total of three blocks in the Green Canyon area and one in the Mississippi Canyon area.
As of December 31, 2015, we had mineral rights in 16 blocks in U.S. territorial waters in the Gulf of Mexico, comprised of 13
exploratory blocks, with a gross surface area of 303 km2 (128 km2 net to Maxus), and three development blocks, with a gross surface
area of 70 km2 (10.5 km2 net to Maxus). Our U.S. subsidiaries’ net proved reserves as of December 31, 2015 was 2.266 mmboe. Our
U.S. subsidiaries’ net hydrocarbon production for 2015, including in the GOM area and Crescendo (ORRIs), was 0.584 mmboe.
The Neptune field is located approximately 120 miles off the Louisiana coast in the deepwater region of the Central Gulf of
Mexico. The field is made up of the Atwater Valley 574, 575 and 618 blocks. Our indirect subsidiary, Maxus U.S. Exploration
Company, has a 15% working interest in the field. The other joint venture participants are BHP Billiton (35%), Marathon Oil Corp.
(30%) and W&T Offshore (20%). BHP Billiton is the operator of the Neptune field and the associated production facilities. The
Neptune reserves are being produced using a standalone, tension leg platform (“TLP”) located in the Green Canyon 613 block in
4,230 feet of water. The platform supports seven sub-sea development wells that are tied back to the TLP via a subsea gathering
system.
65
In addition, YPF Holdings entered into various operating agreements and capital commitments associated with the exploration
and development of its oil and gas properties. These contractual, financial and performance commitments are not material. Our
operations in the United States, through YPF Holdings, are subject to certain environmental claims. See “—Environmental Matters—
YPF Holdings—Operations in the United States.”
2.
Chile:
We were selected to operate in two exploratory blocks of the Magallanes basin: (i) San Sebastián, which we will operate and in
which we will hold a 40% working interest with Wintershall, which will hold a 10% working interest, and ENAP, which will hold a
50% working interest; and (ii) Marazzi/Lago Mercedes, which we will operate and in which we will hold a 50% working interest
along with ENAP, which will hold a 50% working interest.
Total commitments with respect to the awarded exploration blocks during the first exploratory period include the acquisition of
672 km2 of 3D seismic data and the drilling of eight exploratory wells. Between 2013 and 2014, 679 km2 of 3D seismic data were
registered. Exploratory wells were drilled during 2015. In 2015, YPF requested to access a second exploration period in the San
Sebastián block. However, Wintershall and ENAP have formally decided not to enter the second exploration period. Subsequently,
the Marazzi/Lago Mercedes block was relinquished.
3.
Colombia:
Blocks COR12 and COR33 are located in the Cordillera Oriental basin, which we operate pursuant to authorization by the
Colombian National Hydrocarbons Agency (Agencia Nacional de Hidrocarburos) (“ANH”). Our working interest in these blocks
ranges from 55% to 60%. The net acreage relating to our working interest in the blocks is 700 km2. As of the date of this annual
report, we have requested approval from the ANH to farm out our working interest in the COR 12 block. YPF and its partners
informed the ANH of their decision to relinquish the COR 33 block. As of the date of this annual report, no confirmation from the
ANH has been received.
4. Uruguay:
4.1 Deep Water Offshore — Punta del Este basin:
(cid:123) Area 3: We owned a 40% working interest in this area and acted as operator, in partnership with Shell, which
had a 40% working interest it took over from Petrobras Uruguay, and GALP, which had a 20% working
interest. The permit expired on October 6, 2014 and a 120-day extension application was submitted to the
authorities. The consortium declined to opt for a second exploration period.
5.
Ecuador
In October 2014, we signed a service contract with Petroamazonas, the national oil company of Ecuador, to optimize production
in Yuralpa field. The 15-year agreement contemplates drilling of at least ten wells, using technologies for enhanced oil recovery and
performing activities to increase oil production in this field, located in Block 21 in the Amazonian province of Napo.
During 2015, we opened an office in Quito and constituted its project team, composed of 16 members. A geological and
reservoir model of the Hollín reservoir was constructed, allowing YPF to design the field development strategy, and the first
workover operation was performed on the YRCA-012 well.
In October 2015, Petroamazonas EP requested that YPF suspend operations and immediately start renegotiating terms and
conditions of the contract noting the abrupt drop in crude oil prices.
66
Additional information on our present activities
The following table shows the number of wells in the process of being drilled as of December 31, 2015.
Number of wells in the process of being drilled
Argentina
Rest of South America
North America
Total
As of December 31, 2015
Net
Gross
57
—
—
57
50
—
—
50
Delivery commitments
We are committed to providing fixed and determinable quantities of crude oil and natural gas in the near future under a variety of contractual
arrangements.
With respect to crude oil, we sell substantially all of our Argentine production to our Refining and Marketing business segment to satisfy our
refining requirements. As of December 31, 2015, we were not contractually committed to deliver material quantities of crude oil to third parties in
the future.
As of December 31, 2015, we were contractually committed to deliver 12,806 mmcm (or 452 bcf) of natural gas in the future, without
considering interruptible export supply contracts, of which approximately 3,690 mmcm (or 130 bcf) will have to be delivered from 2016 through
2018. According to our estimates as of December 31, 2015, our contractual delivery commitments for the next three years could be met with our
own production and, if necessary, with purchases from third parties.
However, since 2004 the Argentine government has established regulations for both the export and domestic natural gas markets which have
affected Argentine producers’ ability to export natural gas. Consequently, since 2004 we have been forced in many instances to partially or fully
suspend natural gas export deliveries that are contemplated by our contracts with export customers. Charges to income totaling Ps. 31 million, Ps.
52 million and Ps. 174 million have been recorded in 2015, 2014 and 2013, respectively, in connection with our contractual commitments in the
natural gas export market.
Among the regulations adopted by the Argentine government, on June 14, 2007, the Argentine Secretariat of Energy passed Resolution
No. 599/07, compelling us to enter into an agreement with the Argentine government regarding the supply of natural gas to the domestic market
during the period 2007 through 2011 (the “Agreement 2007-2011”). On January 5, 2012, the Official Gazette published Resolution S.E. No. 172,
which temporarily extends the rules and criteria established by Resolution No. 599/07 until new legislation is passed replacing such rules and
criteria. On February 17, 2012, we filed a motion for reconsideration of Resolution S.E. No. 172 with the Argentine Secretariat of Energy.
As a consequence of such agreement, YPF has not entered into any contractual commitment to supply natural gas to distribution companies.
The purpose of Agreement 2007-2011 is to guarantee the supply of natural gas to the domestic market at the demand levels registered in 2006, plus
the growth in demand by residential and small commercial customers. See “—Regulatory Framework and Relationship with the Argentine
Government—Market Regulation” and “Item 3. Key Information—Risk Factors—Risks Relating to Argentina—We are subject to direct and
indirect export restrictions, which have affected our results of operations and caused us to declare force majeure under certain of our export
contracts.” According to our estimates as of December 31, 2015, supply requirements under Agreement 2007-2011 (which we were compelled to
enter into and which was approved by a resolution that has been challenged by us) could be met with our own production and, if necessary, with
purchases from third parties. Additionally, on October 4, 2010, the National Gas Regulatory Authority (“ENARGAS”) issued Resolution
No. 1410/2010, which approved the “Procedure for Applications, Confirmations and Control of Gas” setting new rules for natural gas dispatch
applicable to all participants in the gas industry and imposing new and more severe priority demand gas restrictions on producers. See “—
Regulatory Framework and Relationship with the Argentine Government—Market Regulation.”
We have appealed the validity of the aforementioned regulations and have invoked the occurrence of a force majeure event (government
action) under our export natural gas purchase and sale agreements, although certain counterparties to such agreements have rejected our position.
See “Item 8. Financial Information—Legal Proceedings—Argentina—Accrued, probable contingencies—Alleged defaults under natural gas
supply contracts.”
In addition, on May 3, 2012, the Expropriation Law was passed by the Argentine congress. The Expropriation Law declared achieving self-
sufficiency in the supply of hydrocarbons, as well as in the exploitation, industrialization, transportation and sale of hydrocarbons, a national
public interest and a priority for Argentina. In addition, its stated goal is to guarantee socially equitable economic development, the creation of
jobs, the increase of the competitiveness of various economic sectors and the equitable and sustainable growth of the Argentine provinces and
regions. After the takeover of the Company by the new shareholders in accordance with the Expropriation Law, our strategy intends to reaffirm our
commitment to creating a new model of the Company in Argentina that aligns our objectives, seeking profitable and sustainable growth that
generates shareholder value, with those of the country, thereby positioning YPF as an industry-leading company aiming at the reversal of the
national energy imbalance and the achievement of hydrocarbon self-sufficiency in the long term.
67
To achieve the goals set forth above, we intend to focus on (i) continuing to increase production, especially of natural gas;
(ii) improving efficiency and productivity to enable us to adapt to a scenario of a prolonged decline in international oil prices;
(iii) increasing exploration of mature areas; (iv) developing unconventional resources; (v) improving our capacity to refine in order to
accommodate the growth in demand for refined products; (vi) exploring conventional and unconventional resources and pushing the
limits of existing deposits and exploring new frontiers, including offshore; and (vii) maintaining a solid capital structure. These
initiatives have required and will continue to require organized and planned management of mining, logistic, human and financing
resources within the existing regulatory framework, with a long-term perspective.
The investment plan related to our growth needs to be accompanied by an appropriate financial plan, whereby we intend to
reinvest earnings, search for strategic partners and acquire debt financing at levels we consider prudent for companies in our industry.
Consequently, the financial viability of these investments and hydrocarbon recovery efforts will generally depend, among other
factors, on the prevailing economic and regulatory conditions in Argentina, the ability to obtain financing in satisfactory amounts at
competitive costs, as well as the market prices of hydrocarbon products. See “Item 3. Key Information—Risk Factors—Risks
Relating to Argentina.”
Natural gas supply contracts
The Argentine government has established regulations for both the international and domestic natural gas markets, which have
affected the ability of producers in Argentina to export natural gas YPF’s principal supply contracts are briefly described below.
We were committed to supply a daily quantity of 125 mmcf/d (or 4 mmcm/d) to the Methanex plant in Cabo Negro, Punta
Arenas, in Chile (under three agreements which expire between 2017 and 2025 (the “Agreements”)). Pursuant to instructions from the
Argentine government, deliveries have been interrupted since 2007. In connection with these contracts, the Company has renegotiated
them through 2018 and has agreed to make investments, export gas and temporarily import certain final products, subject to approval
by the relevant government authorities, which have been obtained. As of the date of this annual report, the Company has fulfilled the
agreed commitments mentioned above. As a result, current commitments under the Agreements amount to a daily quantity of 46
mmcf/d through 2019. To the extent that the Company does not comply with the Agreements, we could be subject to significant
claims, subject to the defenses that the Company might have.
We are currently engaged in a 15-year contract signed in 2003 with Gas Valpo, a natural gas distributor, to supply 35 mmcf/d
(or 1 mmcm/d) through the Gas Andes pipeline linking Mendoza, Argentina to Santiago, Chile, which has a transportation capacity of
353 mmcf/d (or 10 mmcf/d) (designed capacity with compression plants).
The contracts with Colbun and Gas Valpo were modified to become interruptible supply contracts.
We have a 21-year contract (entered into in 1999) to deliver 93 mmcf/d (or 2.63 mmcm/d) of natural gas to a Chilean
distribution company (Innergy) that distributes natural gas to residential and industrial clients through a natural gas pipeline (with a
capacity of 318 mmcf/d or 9 mmcm/d) connecting Loma La Lata in Neuquén, Argentina with Chile. The contract was modified
reducing its deliver or pay obligation to 7.1 mmcf/d (or 0.2 mmcm/d).
We have natural gas supply contracts with certain thermal power plants in northern Chile (Edelnor, Electroandina, Nopel and
Endesa) utilizing two natural gas pipelines (with a carrying capacity of 300 mmcf/d or 8.5 mmcm/d each) connecting Salta, Argentina
to Northern Chile (Región II). The contracts with Edelnor and Electroandina were modified to become interruptible supply contracts.
With respect to Brazil, we entered into a 20-year supply contract in 2000 to provide 99 mmcf/d (or 2.8 mmcm/d) of natural gas
to the thermal power plant of AES Uruguaiana Empreendimentos S.A. (“AESU”) through a pipeline linking Aldea Brasilera,
Argentina, to Uruguaiana, Brazil (with a capacity of 560 mmcf/d or 15.8 mmcm/d). In May 2009, AESU notified us of the
termination of the contract. We are currently in arbitration with AESU. See “Item 8. Financial Information—Legal Proceedings—
Argentina—Accrued, probable contingencies—Alleged defaults under natural gas supply contracts.”
Because of certain regulations implemented by the Argentine government, we could not meet our export commitments and were
forced to declare force majeure under our natural gas export sales agreements, although certain counterparties have rejected our
position. See “—The Argentine natural gas market” and “Item 8. Financial Information—Legal Proceedings.” As a result of actions
taken by the Argentine authorities, through measures described in greater detail under “—Regulatory Framework and Relationship
with the Argentine Government—Market Regulation—Natural gas,” during recent years we have been forced to reduce the export
volumes authorized to be provided under the relevant agreements and permits.
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The Argentine natural gas market
We estimate (based on preliminary reports of amounts delivered by gas transportation companies) that natural gas consumption
in Argentina totaled approximately 1,732 bcf (or 49.1 bcm) in 2015. We estimate that the number of users connected to distribution
systems throughout Argentina was approximately 8.5 million as of October 31, 2015.
In 2015, we sold approximately 40% of our natural gas to local residential distribution companies, approximately 9% to
compressed natural gas end users, approximately 44% to industrial users (including our affiliates, Mega and Profertil) and power
plants, less than 1% in exports to foreign markets (Chile) and 7% to YPF downstream operations. Sales were affected by increased
consumption by residential consumers during winter months (June to August). During 2015, approximately 85% of our natural gas
sales were produced in the Neuquina basin. In 2015, our domestic natural gas sales volumes were 2% higher than 2014.
The Argentine government has taken a number of steps aimed to satisfy domestic natural gas demand, including pricing, export
regulations, higher export taxes and domestic market injection requirements. These regulations were applied to all Argentine
producers, affecting natural gas production and exports from every producing basin. See “—Delivery commitments—Natural gas
supply contracts.” Argentine producers, such as YPF, complied with the Argentine government’s directions to curtail exports in order
to supply gas to the domestic market, whether such directions are issued pursuant to resolutions or otherwise. Resolutions adopted by
the Argentine government provide penalties for non-compliance. Rule SSC No. 27/2004 issued by the Undersecretary of Fuels (“Rule
27”), for example, punishes the violation of any order issued thereunder by suspending or revoking the production concession.
Resolutions No. 659 and No. 752 also provide that producers not complying with injection orders will have their concessions and
export permits suspended or revoked and state that pipeline operators are prohibited from shipping any natural gas injected by a non-
complying exporting producer.
The Argentine government began suspending natural gas export permits pursuant to Rule 27 in April 2004, and in June 2004 the
Argentine government began issuing injection orders to us under Resolution No. 659. Thereafter, the volumes of natural gas required
to be provided to the domestic market under the different mechanisms described above have continued to increase substantially. The
regulations pursuant to which the Argentine government has restricted natural gas export volumes in most cases do not have an
expiration date. We are unable to predict how long these measures will be in place, or whether such measures or any further measures
adopted will affect additional volumes of natural gas.
See “—Regulatory Framework and Relationship with the Argentine Government” for additional information on these and other
related regulations.
Argentine natural gas supplies
Most of our proved natural gas reserves in Argentina (approximately 75% as of December 31, 2015) are situated in the
Neuquina basin, which is strategically located in relation to the principal market of Buenos Aires and is supported by sufficient
pipeline capacity during most of the year. Accordingly, we believe that natural gas from this region has a competitive advantage
compared to natural gas from other regions. The capacity of the natural gas pipelines in Argentina has proven in the past to be
inadequate at times to meet peak-day winter demand, and there is no meaningful storage capacity in Argentina. Since privatization,
local pipeline companies have added capacity, improving their ability to satisfy peak-day winter demand, but no assurances can be
given that this additional capacity will be sufficient to meet demand.
In order to bridge the gap between supply and demand, especially with respect to peak-day winter demand, the Argentine
government has entered into gas import agreements.
YPF has provided regasification services to ENARSA since May 2008. In 2011, YPF executed an extension to the charter party
agreement and a regasification services agreement with Excelerate Energy to provide and operate a 151,000 cm (or 533,25 cf)
regasification vessel moored at the Bahía Blanca port facilities, which allowed for the supply of up to 17 mmcm/d of natural gas (or
600.34 mmcf/d). In December 2013, as a result of the first automatic extension of 36 additional months already included in this
charter party agreement, the expiration date of the agreement was extended to October 2018.
Since the beginning of its operations, the regasification vessel has converted 17.4 bcm (or 614.12 bcf) of LNG into natural gas,
which has been injected into a pipeline which feeds the Argentine national network. Most of this volume was supplied during the
peak winter demand period. In 2015, natural gas injected into the network amounted to approximately 3.1 bcm (or 109.0 bcf).
69
YPF is the operator of UTE Escobar (a joint venture formed by YPF and ENARSA), which operates an LNG Regasification
Terminal (“LNG Escobar”) located in the km 74.5 of the Paraná River. The LNG Escobar terminal has a floating, storage and
regasification unit permanently moored at the new port facilities, for which UTE Escobar has executed agreements with Excelerate
Energy to provide and operate a 151,000 cm (or 533,252 cf) regasification vessel moored at the LNG Escobar terminal with the
capacity to supply up to 17 mmcm/d (or 600 mmcf/d) of natural gas. Since the beginning of its operations, the total volume injected
into the network by this vessel was 10.02 bcm (or 353.9 bcf). In 2015 natural gas injected into the network amounted to
approximately 2.4 bcm (or 86.9 bcf).
Natural gas transportation and storage capacity
Natural gas is delivered by us through our own gathering systems to the five trunk lines operated by Transportadora de Gas del
Norte S.A and Transportadora de Gas del Sur S.A. from each of the major basins. The capacity of the natural gas transportation
pipelines in Argentina is mainly used by distribution companies. A major portion of the available capacity of the transportation
pipelines is booked by firm customers, mainly during the winter, leaving capacity available for interruptible customers to varying
extents throughout the rest of the year.
We have utilized natural underground structures located close to consuming markets as underground natural gas storage
facilities, with the objective of storing limited volumes of natural gas during periods of low demand and selling such natural gas
during periods of high demand. Our principal gas storage facility, “Diadema,” is located in the Patagonia region, near Comodoro
Rivadavia city. The injection of natural gas into the reservoir started in January 2001.
Downstream
During 2015, our Downstream activities included crude oil refining and transportation, and the marketing and transportation of
refined fuels, lubricants, LPG, compressed natural gas, and other refined petroleum products in the domestic wholesale and retail
markets and certain export markets and also power generation and natural gas distribution.
The Downstream segment is organized into the following divisions:
•
Refining and Logistic Division;
•
•
•
Refining Division;
Logistic Division;
Trading Division;
•
•
•
Domestic Marketing Division;
LPG General Division; and
Chemicals.
We market a wide range of refined petroleum products throughout Argentina through an extensive network of sales personnel,
YPF-owned and independent distributors, and a broad retail distribution system. In addition, we export refined products, mainly from
the port at La Plata. The refined petroleum products marketed by us include gasoline, diesel, jet fuel, kerosene, heavy fuel oil and
other crude oil products, such as motor oils, industrial lubricants, LPG and asphalts.
Refining division
We wholly own and operate three refineries in Argentina:
•
•
•
La Plata refinery, located in the province of Buenos Aires;
Luján de Cuyo refinery, located in the province of Mendoza; and
Plaza Huincul refinery, located in the province of Neuquén.
70
Our three wholly-owned refineries have an aggregate refining capacity of approximately 319,500 boe/d. The refineries are
strategically located along our crude oil pipeline and product pipeline distribution systems. In 2015, our crude oil production,
substantially all of which was destined to our refineries, represented approximately 82.8% of the total crude oil processed by our
refineries, while in 2014 it was 84.5%. Through our stake in Refinor, we also own a 50% interest in a 26,100 boe/d refinery located in
the province of Salta, known as Campo Durán.
The following table sets forth the throughputs and production yields for our three wholly-owned refineries for each of the three
years ended December 31, 2015, 2014 and 2013:
Throughput crude
Throughput feedstock
Throughput crude and feedstock
Production
Diesel
Motor gasoline
Petrochemical naphtha
Jet fuel
Base oils
Fuel oil
Coke
LPG
Asphalt
For the Year Ended December 31,
2014
2013
2015
(mmboe)
106.0
4.2
110.2
109.1
4.4
113.5
101.4
4.1
105.5
40.6
24.5
7.0
6.1
1.1
40.3
22.4
6.5
6.1
1.4
38.8
23.1
5.7
6.1
1.0
2015
For the Year Ended
December 31,
2014
(thousands of tons)
1,715
746
638
185
1,878
770
612
171
2013
1,338
803
607
198
During 2015, our global refinery utilization reached 93.6%, compared to 90.9% in 2014, both calculated over a nominal
capacity of 319.5 mboe/d.
The La Plata refinery is the largest refinery in Argentina, with a nominal capacity of 189,000 bbl/d. The refinery includes three
distillation units, two vacuum distillation units, two fluid catalytic cracking units, a coking unit, a coker naphtha hydrotreater unit, a
platforming unit, two diesel hydrofinishing units, a gasoline hydrotreater, an isomerization unit, an FCC (fluid cracking catalysts)
naphtha splitter and desulfuration unit and a lubricants complex, in addition to a petrochemical complex that generates MTBE,
TAME and aromatics compounds used for blending gasoline, and other chemical products for sale. The refinery is located at the port
in the city of La Plata, in the province of Buenos Aires, approximately 60 kilometers from the City of Buenos Aires. During 2015, the
refinery processed approximately 163.9 mbbl/d. The capacity utilization rate at the La Plata refinery for 2015 was 86.7%, slightly
above 163.3 mbbl/d processed in 2014, with a utilization rate of 86.4%. The crude oil processed at the La Plata refinery, 84.9 % of
which was YPF-produced in 2015, comes mainly from the Neuquina and San Jorge basins. Its crude oil supplies come from the
Neuquina basin by pipeline and from the San Jorge basin by vessel, in each case to Puerto Rosales, and then by pipeline from Puerto
Rosales to the refinery.
During 2015, a revamping in Vacuum B unit was successfully completed, which will permit us to increase our crude utilization
rate by 1.5%, with an increase in unit capacity of approximately between 14% and 20%, depending on the operation program.
In order to increase the conversion capacity, a new Coke A facility is under construction and is expected to be commissioned by
2016. The capacity of the new unit will be 1,160 bbl/h of fresh feed pumped from the bottoms of the Topping and Vacuum units,
providing the refinery with an increase in crude processing capacity utilization of 23.800 bbl/d, representing an increase of almost
12% in the capacity utilization rate. The production of the new facility will be a component for the blend to be used in the generation
of diesel, motor gasoline and coke.
71
The Luján de Cuyo refinery has a nominal capacity of 105,500 bbl/d, the third largest capacity among Argentine refineries. The
refinery includes two distillation units, a vacuum distillation unit, two coking units, one fluid catalytic cracking unit (FCCU), a
platforming unit, a MTBE unit, an isomerization unit, an alkylation unit, a naphtha splitter, a hydrocracking unit, a naphtha
hydrotreater unit and two gasoil hydrotreating units. During 2015, the refinery processed approximately 109.2 mbbl/d, with a capacity
utilization rate of more than 100%. In 2014, the refinery processed 103.2 mbbl/d with a capacity utilization rate of 97.8%. The lower
capacity utilization during 2014 was due to several planned maintenance shut-downs of units: Topping IV from March to April,
vacuum distillation from March to April, Coke II from March to April and fluid catalytic cracking from October to November, all of
which were executed successfully on time.
Due to its location in the western province of Mendoza and its proximity to significant distribution terminals we own, the Luján
de Cuyo refinery has become the primary facility responsible for providing to the central and northwest provinces of Argentina with
petroleum products for domestic consumption. The Luján de Cuyo refinery receives crude supplies from the Neuquina and Cuyana
basins by pipeline directly into the facility. Approximately 77.8% of the crude oil processed at the Luján de Cuyo refinery in 2015
(and 77.9% of the crude oil processed in this refinery in 2014) was produced by us. Most of the crude oil purchased from third parties
comes from oil fields located in the provinces of Neuquén or Mendoza.
The Plaza Huincul refinery, located in the province of Neuquén, has an installed capacity of 25,000 bbl/d. During 2015, the
refinery processed approximately 25.8 mbbl/d, with a capacity utilization rate of more than 100%, far from the 24.0 mbbl/d processed
in 2014 at a lower capacity utilization rate of 95.9%. The only products currently produced at the refinery are gasoline, diesel and jet
fuel, which are sold primarily in nearby areas and in the southern regions of Argentina. Heavier products, to the extent production
exceeds local demand, are blended with crude oil and transported by pipeline from the refinery to our facilities in La Plata for further
processing. The Plaza Huincul refinery receives its crude supplies from the Neuquina basin by pipeline. The crude supplies are
mostly produced by us. In 2015, 1.7% of the refinery’s crude supplies were purchased from other companies, while in 2014, such
purchases were 0.3% of the refinery’s crude supplies.
Since 1997 and 1998, each of our refineries (La Plata, Luján de Cuyo, and Plaza Huincul) have been certified under
International Organization for Standardization (“ISO”) 9001 (quality performance) and ISO 14001 (environmental performance). All
of them are also certified under the OHSAS 18001 (occupational health and safety performance) standard. Since 2009, inventories of
industrial greenhouse gases and savings of CO2 emissions equivalent (MDL projects) have been verified in accordance with ISO
14064 in both the La Plata and Lujan de Cuyo refineries. The refineries maintain their systems under continuous improvement and
revision by authorized organizations.
Logistics Division
Crude oil and products transportation and storage
We have available for our use a network of five major pipelines, two of which are wholly-owned by us. The crude oil
transportation network includes nearly 2,700 kilometers of crude oil pipelines with approximately 640,000 barrels of aggregate daily
transportation capacity of refined products. We have total crude oil tankage of approximately 7 mmbbl and maintain terminal
facilities at five Argentine ports.
Information with respect to YPF’s interests in its network of crude oil pipelines is set forth in the table below:
From
Puesto Hernández
Puerto Rosales
La Plata refinery
Brandsen
Puesto Hernández/ P. Huincul/Allen
Puesto Hernández
To
Luján de Cuyo refinery
La Plata refinery
Dock Sud
Campana
Puerto Rosales
Concepción (Chile)
YPF
Interest
100%
100%
100%
30%
37%
—(2)
Length (km)
528
585
52
168
888(1)
428
Daily
Capacity
(boe/d)
85,200
316,000
106,000
120,700
232,000
—(3)
(1)
Includes two parallel pipelines of 513 kilometers each from Allen to Puerto Rosales, with a combined daily throughput of
232,000 barrels.
(2) We hold a 36% interest in Oleoducto Transandino Argentina S.A., which operates the Argentine portion of the pipeline, and an
18% interest in Oleoducto Transandino Chile S.A., which operates the Chilean portion of the pipeline.
(3) This pipeline ceased operating on December 29, 2005.
72
We own two crude oil pipelines in Argentina. One connects Puesto Hernández to the Luján de Cuyo refinery (528 kilometers),
and the other connects Puerto Rosales to the La Plata refinery (585 kilometers) and extends to Shell’s refinery in Dock Sud at the
Buenos Aires port (another 52 kilometers). We also own a plant for the storage and distribution of crude oil in the northern province
of Formosa with an operating capacity of 19,000 cubic meters, and two tanks in the city of Berisso, in the province of Buenos Aires,
with 60,000 cubic meters of capacity. We own 37% of Oleoductos del Valle S.A., operator of an 888-kilometer pipeline network, its
main pipeline being a double 513 kilometer pipeline that connects the Neuquina basin and Puerto Rosales.
We hold, through Oleoducto Transandino Argentina S.A. and Oleoducto Transandino Chile S.A., an interest in the 428-
kilometer transandean pipeline, which transported crude oil from Argentina to Concepción in Chile. This pipeline ceased operating on
December 29, 2005, as a consequence of the interruption of oil exports resulting from decreased production in the north of the
province of Neuquén. The book value of the assets related to this pipeline was reduced to their recovery value.
We also own 33.15% of Terminales Marítimas Patagónicas S.A., operator of two storage and port facilities: Caleta Córdova
(province of Chubut), which has a capacity of 314,000 cubic meters, and Caleta Olivia (province of Santa Cruz), which has a capacity
of 246,000 cubic meters. We also have a 30% interest in Oiltanking Ebytem S.A., operator of the maritime terminal of Puerto
Rosales, which has a capacity of 480,000 cubic meters, and of the crude oil pipeline that connects Brandsen (60,000 cubic meters of
storage capacity) to the Axion Energy Argentina S.R.L. (previously ESSO, a former subsidiary of ExxonMobil which was acquired
by Bridas Corporation) refinery in Campana (168 km), in the province of Buenos Aires.
In Argentina, we also operate a network of multiple pipelines for the transportation of refined products with a total length of
1,801 kilometers. We also own seventeen plants for the storage and distribution of refined products and seven LPG plants with an
approximate aggregate capacity of 1,620,000 cubic meters. Three of our storage and distribution plants are annexed to the refineries
of Luján de Cuyo, La Plata and Plaza Huincul. Ten of our storage and distribution plants have maritime or river connections. We
operate 53 airplane refueling facilities (40 of which are wholly-owned) with a capacity of 22,500 mcm, and we also own 28 trucks,
123 manual fuel dispensers and 17 automatic fuel dispensers. These facilities provide a flexible countrywide distribution system and
allow us to facilitate exports to foreign markets, to the extent allowed pursuant to government regulations. Products are shipped
mainly by truck, ship or river barge.
YPF currently blends ethanol in the Luján de Cuyo, Monte Cristo, San Lorenzo, La Plata, Junín, Plaza Huincul, Barranqueras,
Concepción del Uruguay, Villa Mercedes and La Matanza storage plants.
In 1998, our logistics activities were certified under ISO 9001 (quality performance) and ISO 14001 (environmental
performance), and recertified in 2012 under ISO 9001:2008 and ISO 14001:2004. In 2010, logistics activities were also certified
under OHSAS 18001 (security performance) and recertified in 2013. In 2014, our trucking activities were certified under ISO 39001
(road traffic safety management system).
Trading Division
Our Trading Division sells refined products and crude oil to international customers and crude oil to domestic oil companies.
Exports may include crude oil, unleaded gasoline, diesel, fuel oil, LPG, light naphtha and virgin naphtha.
The division exports mainly to countries in South America, Africa and North America. Sales to international customers for 2015
and 2014 were Ps. 2,387 million and Ps. 4,081 million, respectively. In 2015, refined products accounted for 25% of total sales, up
from 8% in 2014. In 2015, 73% of total sales corresponded to marine fuels, down from 77% in 2014. In 2015 and 2014, sales
volumes to customers outside Argentina consisted of 1.6 mmbbl and 0.89 mmbbl of refined products, respectively, and 3.3 mmbbl
and 4.3 mmbbl of marine fuels, respectively.
For the domestic market, sales of crude oil totaled Ps. 712 million, or 1.1 mmbbl, in 2015 and Ps. 914 million, or 1.4 mmbbl, in
2014. Sales of marine fuels totaled Ps. 1,516 million, or 1.4 mmbbl, in 2015 and Ps. 1,352 million for the same volume in 2014. In
addition, imports of high and low sulfur diesel in 2015 totaled 7.3 mmbbl in 2015, a decrease of 7% compared with 2014.
73
Marketing Division
Our Marketing Division supplies gasoline, diesel, LPG and other petroleum products throughout the country and other countries in
the region. We supply several industries, including retail, transport and agriculture.
During 2015, YPF extended its leadership in Argentina, reaching a market share of 57.9% for liquefied fuels.
YPF sells two types of gasoline: Infinia, a premium 98 octane gasoline, and Super, a regular 95 octane gasoline.
During 2015, we continued to hold a leading position from sales of Infinia and Super gasolines, reaching a market share, according
to our estimates, of 62.0% and 55.1%, respectively, as of December 31, 2015, compared with 61.3% and 56.9%, respectively, in 2014.
Our sales volume for Infinia was 1,461 mcm in 2015 (26.0% higher than in 2014) and 3,392 mcm for Super in 2015 (3.3% less than in
2014).
After its launch in November 2014, sales of premium Infinia gasoline increased slightly as a percentage of our total gasoline sales to
30.1% in 2015, compared to 29.6% in December 2014. The marketing and communication activities carried out during 2015 for Infinia
gasoline resulted in an improvement in the product’s image. Results for the same poll carried out in 2014 and 2015 showed an increase in
“very good” responses from 48% in 2014 to 59% in 2015 (48% from December to March 2015 and 59% from August to October 2015).
The loyalty program Serviclub, which actively promotes tourism in Argentina among other things, reached more than 1.1 million
members in 2015.
With respect to diesel, according to our own estimates, as of December 2015 our market share was 58.5%, compared to 60.0% in
2014, with a decrease in our share of high sulphur content products. Along with D-Euro (10 ppm), for which sales volume was 1,271
mcm in 2015 compared to 1,015 mcm in 2014, our diesel (500 and 1500 ppm) reached a sales volume of 6,688 mcm compared to 6,928
mcm in 2014. Finally, market penetration for D-Euro and Diesel 500 reached 42% of total diesel sales volumes, up from 39.5% in 2014.
YPF markets lubricants through three segments of the domestic market: retail, agriculture and industry. Our three manufacturing
facilities, part of the CIE industrial complex, include lubricant, asphalt and paraffin production lines. Our line of automotive lubricants,
including mono-grade, multi-grade and oil, has received approval and recommendations from leading global automotive and engine
manufacturers, including Ford, Volkswagen, Renault, Audi, Deutz, Cummins, Volvo, MAN Truck, GM, Porsche, Scania, Detroit Diesel
and Caterpillar.
We are engaged in the LPG wholesale business, which encompasses LPG storage, logistics and commercialization to domestic and
foreign markets. We obtain LPG from our fractioning plants and refineries, as well as from third parties. In addition to butane and
propane, we also sell propellants, used in the aerosols manufacturing processes.
YPF also markets lubricants in Brazil and Chile, where we have subsidiary companies. Additionally, through a network of exclusive
resellers, we market lubricants in three bordering countries (Uruguay, Paraguay and Bolivia).
Retail Division
As of December 31, 2015, the Retail Division’s sales network in Argentina consisted of 1,538 retail service stations, compared to
1,534 as of December 31, 2014. Of these, 112 are owned by YPF. The remaining 1,426 service stations are associated service stations.
OPESSA, our wholly-owned subsidiary, actively operates 174 retail service stations of which 89 are owned by YPF, 27 are leased to the
Automóvil Club Argentino and 58 are leased to independent owners. Additionally, YPF owns 50% of Refinor, a company operating 69
service stations.
According to our estimates, as of December 31, 2015, we were the main fuel retailer in Argentina, with 35% of the country’s
gasoline service stations, followed by Shell, Axion, Petrobras and Oil with 14.1%, 11.4%, 6.1% and 6.3%, respectively. During 2015, our
market share in diesel and gasoline, marketed in all segments, decreased from 59.2% to 58.0%, from December 31, 2014 to December 31,
2015. This was due to increased market competition stemming primarily from an increase in the number of service stations of our
competitors and a smaller gap between our competitors’ prices and YPF’s during 2015.
The “Red XXI” program, released in October 1997, has significantly improved operational efficiency in service stations. This
program provides performance data for each active and on-line station, connecting most of our network. As of December 31, 2015, 1,283
service stations were linked to the Red XXI network system, unchanged from 2014.
Our convenience stores, YPF Full and YPF Full Express, are present in 391 and 100 points of sale, respectively, as of December 31,
2015. Additionally, a modern oil change service shop called YPF Boxes is present in 251 service stations across the country.
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During 2015, a service station operation manual was rolled out across the Retail Division sales network. The purpose of this
model is to promote self-management of our service stations.
In April 2015 we launched Opessa Leones, Argentina’s biggest service station, located on the highway between the cities of
Rosario and Cordoba. As the only rest area in the area, we expect 10,400 customers per day. With a footprint of 16,000 square
meters, it includes parking for 250 cars, a YPF full convenience store accommodating more than 170 people and 24 fuel supply
islands.
The project incorporates advanced fuel supply technology. Truck fueling is the fastest on the market, with a 30% performance
increase. The service station has six tanks equipped with a drive system with dual containment and sensors, giving more control and
the ability to detect potential leaks. The storage capacity of the service area exceeds 240,000 liters of fuel.
Agriculture Division
The Agriculture Division provides diesel, fertilizers, lubricants, agrochemicals, and ensiling bags (“silobolsa”), among other
products, directly or through a network of 105 wholesaler bases (nine owned by YPF), offering an extensive portfolio of products to
agricultural producers, including the delivery of products to the consumption site. Many of these wholesaler bases operate under a
“one stop shop” concept, with an audited operating system, offering a complete range of products under a unified brand image.
During 2015, YPF has launched several new products (mainly agrochemicals, fertilizers, biologic fertilizers and seeds), under our
own brand or through distribution agreements with leading local suppliers. At the option of the customer, we accept different types of
grains as payment (canje), mainly soybean, some of which is processed by third-party companies to obtain oil and other sub-products
that we generally export. In 2015, revenue from these exports was U.S.$398 million, a 6.8% increase compared to 2014. Although the
fall of international commodity prices affected local farmers, reducing overall sowing surface, we received approximately 1,348,000
tons of grains (oilseed and cereal), primarily soy, a 10.6% increase compared to 2014. In addition, the Agriculture Division provides
approximately 8% of YPF’s fatty acid methyl esters (“FAME”) needs (a natural product added to commercial grade diesel), which is
obtained from soybean oil.
Industry Division
This division supplies the national industry and transportation (ground and air) sectors’ needs, consisting of a broad portfolio of
products and services. The division develops specific solutions for the mining, oil & gas, aviation, transport, infrastructure and
construction sectors. We supply products such as fuels (diesel, gasoline, fuel oil, jet A-1), lubricants, coal, asphalts, paraffin and
derivatives (sulfur, CO2, decanted oil, aromatic extract), either directly from our refineries to the point of consumption (more than
5,000 direct customers) through our own ground and waterway network, or through a network of twelve distributors. Regarding the
37 distributors for 2014, twelve of them remain in the Industry Division and the remaining 25 were serviced by the Agriculture
Division.
The Industry Division’s mission is to promote efficiency in the value chains of the industries we serve through energy solutions,
supplies and services. In line with this, our strategy is based on the closeness and relationship with the client and the development of
innovative solutions focused on creating value for YPF and the region’s industry.
Lubricants and Specialties Division
During 2015, our lubricants and complementary products sales in the domestic market amounted to almost 127.7 mcm (an
increase of 2.6% compared to 2014) while exports decreased 14.1% from 20.0 mcm in 2014 to 17.2 mcm in 2015. Sales of asphalts
decreased 13% and paraffin increased 7% compared to 2014.
We export to two main markets. First, to our wholly-owned companies in Brazil and Chile. Sales volumes decreased 55% in
Brazil, due to market recession and increased 11% in Chile compared to 2014. In both countries, we produce lubricants locally.
However, local production in Chile has been replaced by Argentinean production due to lower tax withholdings in Argentina. On the
other hand, we export through our distribution network in Bolivia, Uruguay and Paraguay, in which sales volume increased 15%
compared to 2014. This increase was primarily due to a decrease in export taxes beginning in 2015, according to resolution S.E.
1077/14. Our Lubricants and Specialties Division has followed a strategy of differentiation, allowing it to achieve and maintain a
leading position in the Argentinean market. Our market share as of December 31, 2015 was 39.1% (a decrease of 2.2% compared to
2014) according to information provided by the Argentine Secretariat of Energy. As indicated above, our line of automotive
lubricants has received approvals and recommendations from leading global automotive and engine manufacturers (Ford,
Volkswagen, GM, Porsche and Scania).
75
With respect to lubricants, sales of the high-end light and heavy products, under the Elaion and Extravida brand names, were
43.7 mcm in 2015, compared to 43.6 mcm in 2014.
The Elaion brand reached sales volumes of 14.6 mcm in 2015, a 4% increase compared to 14.0 mcm in 2014. The Extravida
brand reached sales volumes of 29.1 mcm, remaining stable compared to 29.1 mcm in 2014.
Sales of the Elaion Moto lubricant, used for motorcycles, increased by 4% to 2.1 mcm from 2.0 mcm in 2014.
The Lubricants and Specialties Division has had an integrated management system since 1995. This division currently holds the
following certifications: ISO 9001:2008, ISO 14001:2004, OSHAS 18001:2007 ISO/TS 16949-third edition.
LPG Division
Through our LPG Division, we sell LPG to the foreign market, the domestic wholesale market and to distributors that supply the
domestic retail market. The LPG Division does not directly supply the retail market. It is supplied by YPF Gas S.A., which is not a
YPF-controlled company. During 2015, we sold approximately 40% of our LPG production to YPF Gas S.A. for the domestic
market.
We are the largest LPG producer in Argentina, with sales in 2015 reaching approximately 559 mtn, compared with 572 mtn in
2014. Of this, approximately 378 mtn were sold in the domestic market, compared to 414 mtn in 2014. Our main clients in the
domestic market are companies that sell LPG in cylinders or bulk packing to end-consumers, also providing LPG to households in
some regions. Additionally, exports in 2015 reached approximately 181 mtn, compared to 159 mtn in 2014. The main destinations
were Chile, Paraguay and Bolivia. Transportation of LPG to overseas customers is carried out by truck, pipeline and barges.
Total sales of LPG excluding LPG used as petrochemical feedstock were Ps. 1,415 million and Ps. 1,678 million in 2015 and
2014, respectively.
The LPG Division obtains LPG from natural gas processing plants and from our refineries and petrochemical plants. We
produced 447 mtn of LPG in 2015, not including LPG destined for petrochemical usage, and purchased LPG from third parties, as
detailed in the table below:
LPG from Natural Gas Processing Plants(1)
General Cerri
El Portón
San Sebastián
Total Upstream
LPG from Refineries and Petrochemical Plants
La Plata refinery
Luján de Cuyo refinery
CIE
Total refineries and petrochemical plants(2)
LPG purchased from joint ventures(3)
LPG purchased from unrelated parties
Total
Purchase (tons)
2015
12,569
108,479
0
121,048
182,514
110,255
33,072
325,841
25,684
62,997
535,569
(1) The San Sebastian plant is a joint venture in which we own a 30% interest; El Portón is 100% owned by us; General Cerri
belongs to a third party with which we have a processing agreement.
(2) This production does not include LPG used as petrochemical feedstock (olefins derivatives, polybutenes and maleic).
(3) Purchased from Refinor. We also have a 50% interest in Refinor, which produced 241 mtn of LPG in 2015.
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Chemicals Division
Petrochemicals are produced at our petrochemical facilities in Ensenada and Plaza Huincul. Additionally, we also own a 50%
interest in Profertil, a company that has a petrochemical complex in Bahía Blanca, as mentioned below.
Petrochemical production operations in the Complejo Industrial Ensenada (“CIE”) are closely integrated to the refining
activities at the La Plata refinery, allowing a flexible supply of feedstock, the efficient use of by-products, such as hydrogen, and the
supply of aromatics to increase gasoline octane levels.
The main petrochemical products and production capacities per year are as follows:
CIE
BTX (Benzene, Toluene, Mixed Xylenes)
Paraxylene
Orthoxylene
Cyclohexane
Solvents
MTBE
Butene I
Oxoalcohols
TAME
LAB
LAS
PIB
Maleic Anhydride
Plaza Huincul
Methanol
Capacity
(tons per year)
526,000
38,000
25,000
95,000
66,100
60,000
25,000
35,000
105,000
52,000
32,000
26,000
17,500
411,000
During 2015, the LAS plant was revamped increasing its capacity from 25,000 to 32,000 tons/year.
Natural gas, the raw material for methanol, is supplied by our Exploration and Production business segment. The use of natural
gas as a raw material allows us to monetize reserves, demonstrating the integration between the Chemical and the Upstream divisions.
We also use high carbon dioxide-content natural gas for methanol production, which allows us to keep the methanol plant
working at 50% of its production capacity during winter periods.
Raw materials for petrochemical production in the CIE, including virgin naphtha, propane, butane and kerosene, are supplied
mainly by the La Plata refinery.
In 2015 and 2014, 72% and 73%, respectively, of our petrochemicals sales (including propylene), were made in the domestic
market, while we export to Mercosur countries, the rest of Latin America, Europe and the United States.
77
We also participate in the fertilizer business, directly and through Profertil, a 50%-owned subsidiary. Profertil is a joint venture
with Agrium, a worldwide leader in fertilizers, which initiated operations in 2001. Profertil has a production facility in Bahía Blanca
which produces 1.1 million tons of urea and 750,000 tons of ammonia per year. In addition, Profertil markets other nutrients and
special blends of prepared land to optimize soil performance.
The CIE was certified under ISO 9001 in 1996 and recertified in 2013 (2008 version). The La Plata petrochemical plant was
certified under ISO 14001 in 2001 and recertified in 2013. The plant was also certified under OHSAS 18001 in 2005 and recertified
in 2013. Since 2008, the plant verified the inventory of CO2 emissions under ISO 14064: 1 and, in 2011, inventories of CH4 and
N2O emissions were verified as well. The Ensenada petrochemical complex laboratory was certified under ISO 17025, in 2005 and
recertified in 2013.
The CIE has recently attained ISO 50001 certification (version 2011), covering the following processes: production of complex
aromatics, olefins, maleic, polybutenes and the energy generation facilities that operate within the La Plata petrochemical complex.
The methanol plant was certified under ISO 9001 in December 2001 and recertified in August 2012. The methanol plant was
also certified under ISO 14001 in July 1998 together with the Plaza Huincul refinery, and recertified in August 2012. In addition, the
plant was also certified under OHSAS 18001 in December 2008, and the last date of recertification was August 2012.
The certification of our petrochemical business covers the following processes:
•
•
refining process of crude oil and production of gas and liquid fuels, base stocks for lubricants and paraffin, petroleum coke
(green coke) and petrochemical products in the units of refining, conversion, lubricants, aromatics, olefins PIB / Maleic
and LAB / LAS, methanol production and storage.
management and development of the petrochemical business of the Company, planning and economical and commercial
control, marketing and post-sale service of petrochemical products.
Other investments and activities
NGLs
We participated in the development of our affiliate Mega to increase its ability to separate liquid petroleum products from
natural gas. Through the fractionation of gas liquids, Mega increased production at the Loma La Lata gas field by approximately 5.0
mmcm/d (or 176.5 mmcf/d) in 2001 with the assistance of YPF.
We own 38% of Mega, while Petrobras and Dow Chemical have stakes of 34% and 28%, respectively.
Mega operates:
•
•
•
•
A separation plant, which is located in the Loma La Lata, in the province of Neuquén.
A NGL fractionation plant, which produces ethane, propane, butane and natural gasoline and is located in the city of Bahía
Blanca in the province of Buenos Aires.
A pipeline that links both plants and that transports NGLs.
Transportation, storage and port facilities in the proximity of the fractionation plant.
Mega’s maximum annual production capacity is 1.4 million tons of natural gasoline, LPG and ethane. YPF is Mega’s main
supplier of natural gas. The production of the fractionation plant is used mainly in the petrochemical operations of PBBPolisur S.A.
(“PBB”), owned by Dow Chemical Company, and is also exported by tanker to Petrobras’ facilities in Brazil.
Pursuant to Decree No. 2067/08 and Resolutions No. 1982/2011 and 1991/2011 of ENARGAS, since December 1, 2011, Mega
is required to pay, on a monthly basis, a fee of Ps.0.405 per cubic meter of natural gas it purchases. This requirement has a significant
impact on the operations of Mega and has been challenged in the Argentine federal courts. On October 27, 2015, the Argentine
Supreme Court ruled on the appeal filed by Mega covering the period up to the issuance of Law No. 26784. It ruled that Decree
2067/08 was unconstitutional and did not apply to Mega.
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Electricity market—generation
The Argentine Electricity Market
Argentina’s overall power generation was 4.6% higher in 2015 than 2014 according to Compañía Administradora del Mercado
Mayorista Eléctrico S.A. (“CAMMESA”). In 2015, 63% of Argentina’s power generation came from thermal power plants, 30%
from hydroelectric power plants, 5% from nuclear power plants, 1% from spot imports from Uruguay and Paraguay and the balance
from unconventional sources such as wind and solar power.
Thermal power plants consumed 2,237,761 cm of diesel oil, a 24.7% increase compared to 2014, 3.1 million tons of fuel oil, a
13.4% increase compared to 2014, and 14.4 billion cm of natural gas, a 0.2% increase compared to 2014.
The average electricity price was Ps. 490.90/MWh, a 26% increase compared to 2014, while the annual average marginal cost of
production was Ps.1,567/MWh, an 8.8% increase compared to 2014.
In 2014, Resolution No. 95/2013 of the Secretariat of Energy changed the procedures and increased rates of remuneration that
power generation plants receive, giving incentives to increase power plant reliability. In 2014, this rule was updated with Resolution
No. 529/14 of the Secretariat of Energy, increasing the remuneration to be received by 75%. In 2015, the same rule was updated with
Resolution No. 482/15 of the Secretariat of Energy, increasing the remuneration to be received by 25% and adding some new
concepts.
YPF in Power Generation
We participate in three power generation plants with an aggregate installed capacity of 1,622 MW:
•
•
•
a 100% interest in Central Térmica Tucumán (410 MW combined cycle) through YPF Energía Eléctrica S.A (“YPF EE”);
a 100% interest in Central Térmica San Miguel de Tucumán (370 MW combined cycle) through YPF EE in which we have
100% interest; and
a 40% interest in Central Dock Sud (775 MW combined cycle and 67 MW gas turbines), directly and through Inversora
Dock Sud S.A.
On August 1, 2013, as a result of the spinoff of the assets of PlusPetrol Energy S.A., YPF EE was created to continue the power
generation operations and businesses of Central Térmica Tucumán and Central Térmica San Miguel de Tucumán.
In 2015, YPF EE generated 5,276 GWh with its two combined cycles. Central Térmica Tucuman’s production was 3,071 GWh,
and Central Térmica San Miguel de Tucumán’s production was 2,205 Gwh. Additionally, Central Dock Sud generated 3,799 GWh.
The energy produced by YPF EE and Central Dock Sud (9,075 GWh in total) represented 6.6% of Argentina’s electricity generation
in 2015.
Energy produced by both combined cycles in Tucumán was 1.4% higher in 2015 compared to 2014, despite major overhauls on
units SMTUTV01 and SMTUTG02 in May and September 2015, respectively.
In August 2013, after taking over the power plants, YPF EE accepted Resolution No. 95/2013 issued by the Secretariat of
Energy, which allowed the company to increase rates of remuneration it received for spot electricity sales.
Energy produced by Central Dock Sud in 2015 decreased by 20.6% compared to 2014 because of a major overhaul and a serious
failure in the electrical connection.
Additionally, we own assets that are part of Filo Morado Partnership, which has an installed capacity of 63 MW. However the
relevant facilities have not been in operation since November 2008.
In addition to YPF EE, we also own and operate power plants supplied with natural gas produced by YPF, which produce power
to supply our upstream and downstream activities:
•
Los Perales power plant (74 MW), which is located in the Los Perales natural gas field;
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•
•
Chihuido de la Sierra Negra power plant (40 MW); and
the power plant located at the Plaza Huincul refinery (40 MW).
During 2015, YPF EE developed an important new generation project. A new thermal power generation plant will be located in
Añelo, Neuquén. This additional generation plant was designed in order to supply YPF energy demand all over the country. The
project will be financed with those additional revenues from CAMMESA, which were recovered after the takeover, and others.
Finally, as a consequence of new legislation about renewable energy, YPF EE has commenced design of a renewable generation
project near Comodoro Rivadavia, Chubut, in order to supply a percentage of YPF total demand with clean generation.
Natural gas distribution
We currently hold through our subsidiary YPF Inversora Energética S.A. (“YPF Inversora Energética”) a 100% stake in Gas
Argentino S.A. (“GASA”), which in turn holds a 70% stake in Metrogas S.A. (“Metrogas”), a natural gas distribution company in the
capital region and southern suburbs of Buenos Aires, and one of the main distributors in Argentina. During 2015, Metrogas
distributed approximately 19.5 mmcm (or 688 mmcf) of natural gas per day to 2.3 million customers in comparison to approximately
19.2 mmcm (678 mmcf) of natural gas per day to 2.3 million customers in 2014. During May 2013, the Company, through its
subsidiary YPF Inversora Energética gained 100% ownership of GASA, the controlling company of Metrogas, by acquiring shares
representing the remaining 54.7% interest in GASA. Prior to this acquisition, the Company through its interest in YPF Inversora
Energética S.A. owned 45.3% of the capital of GASA. See Note 13 to the Audited Consolidated Financial Statements.
GASA’s debt restructuring.
On May 11, 2009, GASA was notified of a bankruptcy petition brought by an alleged GASA creditor, and on May 19, 2009,
GASA filed a voluntary reorganization petition (concurso preventivo), which was approved on June 8, 2009. On February 10, 2012,
GASA presented a draft debt restructuring proposal addressed to verified unsecured creditors who have been declared admissible. On
August 6, 2012, GASA filed with the court an amended debt restructuring proposal. The final proposal includes a debt reduction of
61.4% of the claims admitted by the court and the issuance of new debt securities, with a maturity date of December 31, 2015, an
option to extend to December 31, 2016 in case all accrued interest is paid on December 31, 2015, and an interest rate of 8.875%.
In compliance with the reorganization proceeding, on March 15, 2013, GASA issued new notes which were delivered in
exchange for outstanding claims to financial creditors and non-financial creditors who were admitted and declared acceptable.
On December 14, 2015, YPF SA informed GASA that it acquired 100% of GASA’s outstanding securities, and it intends to
cancel them in light of GASA’s planned merger with YPF. YPF irrevocably waived compliance by GASA with any of its obligations
under the indenture as of March 15, 2013.
On March 3, 2016, the Board of Directors of the Company approved the merger of YPF Invesora Energética S.A. and GASA,
whereby the former will absorb the latter. GASA will be dissolved without liquidation.
Metrogas debt reorganization.
Given the adverse business conditions, Metrogas decided to file a voluntary reorganization petition in June 2010. On the same
date, Metrogas was notified of Resolution No. I-1260 issued by ENARGAS, which provided for the judicial intervention of the
company. The resolution based the intervention decision on the filing of a voluntary reorganization petition by Metrogas, and stated
that the intervention would control administration and disposition of Metrogas’ activities that may in any manner affect its normal gas
distribution. On July 15, 2010, the judge approved the commencement of Metrogas’s voluntary reorganization proceedings. On July
2011, Metrogas filed with the court a debt restructuring proposal, which was subsequently amended. The final proposal included a
debt reduction of 46.8% of the claims admitted by the court and the issuance of new debt securities, with a maturity date of
December 31, 2018 and an interest rate of 8.875%. In June 2012, a noteholders’ meeting was held within the framework of the Article
45 bis of Argentina’s bankruptcy law, where the company’s proposal was unanimously approved. On July 13, 2012, Metrogas
informed the Judge that it considered that the legal majorities established in the Article 45 of the Bankruptcy Law had been obtained
to approve the proposal.
On September 6, 2012, the intervening court ratified the Metrogas’s debt reorganization agreement. It also stipulated the
creation of the final creditors’ committee, which will act as controlling agent to determine compliance with the agreement under the
terms of Articles 59 and 260 of the Bankruptcy Law.
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Under the terms of the debt restructuring proposal, Metrogas was required to deliver new notes in exchange for outstanding
claims. The proposal consists of the issuance of two new classes of notes: Class A (for the equivalent of 38.6% of existing notes), and
Class B (contingent notes, for the equivalent of 61.4% of existing notes). The new Class B Notes would become due and payable only
if the New Class A Notes were accelerated as a result of the occurrence of an event of default on or before December 2015. If an
event of default had occured prior to December 2015, the new Class B Notes would have been automatically cancelled.
In compliance with the reorganization, on January 11, 2013, Metrogas issued new notes which were delivered in exchange for
outstanding claims to financial creditors and non-financial creditors who were admitted and declared acceptable.
•
In exchange for existing notes, classified as reorganization liabilities originated on financial debt:
•
•
Series A-L for an amount of U.S.$163,003,452
Series B-L for an amount of U.S.$122,000,000
•
In exchange for non-financial debt:
•
•
Series A-U for an amount of U.S.$16,518,450
Series B-U for an amount of U.S.$13,031,550
On February 1 and February 13, 2013, Metrogas submitted to the intervening court the documentation evidencing compliance
with the debt exchange and the issuance of the new notes in order to obtain the removal of all general inhibitions and the formal
declaration of completion of the reorganization proceedings, in accordance with the terms and conditions of Section 59 of the
Bankruptcy Law.
On March 26, 2013, the Metrogas Board of Directors decided by a majority of votes to capitalize 100% of the portion subject to
capitalization of accrued interest payable on June 30, 2013 and to issue additional negotiable obligations to effect the capitalization.
Furthermore, the Board also decided to issue new negotiable obligations for the new unsecured creditors, as long as their claims have
been verified in the relevant court in the reorganization proceedings.
On July 25, 2013, Metrogas issued:
•
Negotiable Obligations of Late Verification:
Series A-U: U.S.$5,087,459
Series B-U: U.S.$4,013,541
•
Negotiable Obligations of Capitalization:
Additional Series A-L: U.S.$6,756,665
Additional Series A-U: U.S.$704,581
On May 31, 2013, ENARGAS published Resolution ENRG I-2,587/13 providing for the termination of the ENARGAS
intervention in Metrogas.
On September 9, 2013, Metrogas made a formal presentation in connection with the reorganization proceedings requesting that
the court formally declare the completion of the proceedings.
On October 9, 2013, the Metrogas Board of Directors decided by a majority of votes to capitalize 50% of the portion subject to
capitalization of accrued interest payable on December 31, 2013 and to issue additional negotiable obligations to effect the
capitalization.
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On November 18, 2013 Metrogas received a notice from the National Commercial Court of First Instance No. 26, Clerk’s Office
No. 51, on the file entitled Metrogas S.A. about Reorganization Proceedings (filed on 10/17/2010 Court “D”). This notice, dated
November 8, 2013, sets forth the court’s decision to terminate the reorganization proceedings following Metrogas’s compliance with
the terms of Section 59 of the Argentine bankruptcy law.
On January 29, 2014, Metrogas issued:
•
Negotiable Obligations of Capitalization:
•
•
Additional Series A-L: U.S.$3,516,500
Additional Series A-U: U.S.$371,456
On April 28, 2014, the Board of Directors of Metrogas decided by a majority of votes to pay in cash interest for up to
U.S.$4,750,000, capitalize the remaining amount of the portion subject to capitalization of interest due on June 30, 2014 and issue
additional negotiable obligations for said capitalization.
On July 17, 2014, Metrogas issued:
•
Negotiable obligations of capitalization
•
•
Additional Series A-L June 2014: U.S.$3,516,500
Additional Series A-U June 2014: U.S.$371,044
Given the fact that no event of default has occurred prior to June 30, 2014, the Class B Notes were cancelled without any further
obligation.
No event of default has occurred as of December 31, 2015. During the present fiscal year Metrogas has complied with the terms
and covenants established under the offering circular.
Metrogas tariff issues: In January 2002, pursuant to the Public Emergency Law, the tariffs that Metrogas charges to its
customers were converted from their original dollar values to pesos at a rate of Ps.1.00 to U.S.$1.00. Thus the company’s tariffs were
frozen since indexation of any kind is not permitted under the Public Emergency Law.
The Public Emergency Law also provides that the Argentine government should renegotiate public utility services agreements
affected by the change to Argentine peso prices.
The Public Emergency Law, which was originally scheduled to be terminated in December 2003, has been extended until
December 31, 2017. As a consequence, the renegotiation terms for licenses and concessions of utility services were also extended.
Metrogas and the UNIREN signed a temporary agreement in September 2008. In November 2012, ENARGAS published
Resolution No. 2,407/12 that authorizes Metrogas, following the terms of the temporary agreement discussed above, to apply a fixed
amount in each customer’s bill, differentiating by type of customer according to the terms of the Resolution and following the
application of the methodology to be determined by the regulating agency.
Metrogas has been invoicing this new tariff charge since December 3, 2012.
Resolution ENRG 2851/2014 issued by ENARGAS on April 7, 2014 approved new applicable tariffs effective April 1,
2014, June 1, 2014 and August 1, 2014 under a price scheme whereby customers that register a decrease in consumption of over 20%
will continue with the same tariff level as that which was in effect until March 31, 2014, while customers that achieve a reduction of
between 5% and 20% will be charged a tariff approximately 50% lower in relation with the actual price variation, which will be
applied to customers unable to reduce their consumption or whose reduction is below 5%.
Temporary Economic Assistance
On June 8, 2015, the Official Gazette published ES Resolution No. 263/2015 whereby the Argentine Energy Secretariat
approved the allocation of funds as temporary economic assistance to be paid in ten consecutive installments for Metrogas and other
natural gas distributors effective from March 2015. The compensation was intended to cover expenditures and investments related to
the regular operation of the natural gas public service and in advance for the Comprehensive Tariff Revision to be carried out in the
future.
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This resolution establishes that the beneficiaries will assign a portion of the funds received by each of the monthly installments
to cancel unpaid past due debt as of December 31, 2014 with natural gas producers, and moreover, that distributor shall not take more
debt resulting from the purchase of natural gas after the above-mentioned Resolution has taken effect.
In the case of Metrogas, ENARGAS established a need for funds for 2015 to be disbursable monthly according to the schedule
between March and December. ENARGAS also established that the company will assign a portion of the temporary economic
assistance to pay debts to producers from December 31, 2014 in 36 monthly installments, plus interest, as from January 2015,
calculated using the current “Average Active Rate of Banco Nación for Commercial Discount Operations” (2.05% monthly), and will
begin to pay the installments in March 2015.
ENARGAS stated that distributors will proceed to pay gas purchase invoices due in 2015, estimating payments within 30, 60
and 90 days in line with the receipt of invoices by clients.
At the date of this annual report, Metrogas has received seven of the ten installments provided as a temporary economic
assistance, amounting to Ps. 561.7 million from a total of Ps. 711 million. Metrogas has also entered into payment agreements with
the majority of producers in terms of ES Resolution No. 263/15, this subject to availability of the amounts committed.
Funds from a letter of understanding executed on November 21, 2012 with ENARGAS, a provisional agreement executed on
March 26, 2014 with the UNIREN and collections from the temporary economic assistance program have been insufficient so far to
restore the financial condition of Metrogas.
Seasonality
For a description of the seasonality of our business, see “Item 5. Operating and Financial Review and Prospects—Factors
Affecting Our Operations—Seasonality.”
Research and Development
At the end of 2013, YPF created YPF Tecnología S.A (“Y-TEC”), a highly specialized company focusing on research and
development activities. YPF holds an equity stake of 51% and CONICET, a state-owned research and development organization,
holds an equity stake of 49%.
The lines of R&D carried out by Y-TEC are mainly aligned with the needs of YPF. The Board of Directors of Y-TEC consists
of three directors appointed by YPF and two directors appointed by CONICET. Additionally, the chairman and the general manager
of Y-TEC are appointed by YPF.
For the operations of Y-TEC, five hectares on the farm belonging to the National University of La Plata (“UNLP”) were
acquired and a 12,000 m2 building consisting of 48 labs and 12 experimental plants is under construction. Completion of the work is
expected in 2016. We expect that about 320 professionals will work in the new building, and their main goal is to create innovative
solutions for the energy sector. The R&D will be supported by a staff of over 6,000 researchers of different scientific backgrounds,
available to the CONICET through agreements with different universities and institutes of research and development.
As of December 2015, we managed a R&D portfolio consisting of 122 projects, 37 of which are short-term, high impact “quick
wins,” and more than 150 technical assistance and specialized service projects.
In 2015, U.S.$29.7 million was allocated to R&D activities, and U.S.$22.7 million (related to YPF´s working interest in
projects) was invested in a new laboratory building and equipment.
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R&D projects are related to the entire energy value chain, including exploration of new sources of oil or gas, extraction and
conditioning for transportation, transformation and manufacturing of products at industrial facilities and their distribution to the end
customer, renewable energies and environmental solutions.
R&D efforts are focused on the design, development and application of very specific technologies for the exploration and
exploitation of unconventional resources. Our most important challenges include the design and development of simulation and
modelling tools, specific software, measuring devices, proppants, fluids and materials for optimizing perforation, hydraulic
stimulation and production operations in our oilfields.
To optimize production from mature fields, we focused on the development of enhanced oil recovery technologies and the
development of new processes and materials to reduce the operational costs of our facilities.
Regarding refining and marketing of petroleum products, we applied our technological knowledge to optimize refinery
operations and improve product quality, with a strong focus on achieving energy efficiency and environmental improvements. In the
petrochemical business, R&D activities are mainly focused on the development of new products with higher added value, such as
special solvents, fertilizers and several agricultural products.
Renewable energy is a strategic R&D area. Energy storage, bioenergy and energy efficiency are among the larger challenges.
Competition
In our Exploration and Production business, we encounter competition from major international oil companies and other
domestic oil companies in acquiring exploration permits and production concessions. Our Exploration and Production business may
also encounter competition from oil and gas companies created and owned by certain Argentine provinces, including La Pampa,
Neuquén, Santa Cruz and Chubut. See “—Regulatory Framework and Relationship with the Argentine Government—Overview” and
“—Regulatory Framework and Relationship with the Argentine Government—Law No. 26,197.” However, recent changes
introduced in the Hydrocarbons Law through Law No. 27,007 limit the ability of provincial companies to possess future exclusive
rights over permits and concessions, which creates competition, driven by investment and technical capacities, in the Argentine oil
and gas industry. See “Regulatory Framework and Relationship with the Argentine Government—Law No. 27,007, amending the
Hydrocarbons Law.”
Over the past few years, several measures to promote the development of the industry occurred. The Argentine government
established a program to encourage additional production of natural gas which provides participating companies with a natural gas
price of U.S.$7.50/mmBtu for such additional production. Initially, larger producers with diversified portfolios joined the program.
Later on, the program was adapted to include mid and small sized oil and gas companies with less diversified portfolios, so as to
further promote the development of indigenous natural gas resources. Currently, more than 90% of natural gas production in
Argentina is included into this program. Still another measure to promote the oil and gas industry was the creation of the “Investment
Promotion Scheme for the Exploitation of Hydrocarbons” in Argentina set forth in in Decree 929/13. The decree creates an allowance
to export, free of export taxes, up to 20% of hydrocarbons produced from projects requiring an investment in excess of U.S.$1 billion.
Companies accessing the allowance can also retain dollars from their exports abroad. Both the natural gas pricing program and the
investment promotion scheme were recently incorporated into the Hydrocarbons Law, as amended by Law No. 27,007, reinforcing
their position as an instrumental part of the energy policy in Argentina. Furthermore, the investment threshold for investments funded
with dollars brought to Argentina’s financial market has been reduced to U.S.$250 million. At the same time, exploration and
development programs of different play types are allowed different, progressive benefits, according to their anticipated level of
complexity and investment intensity. YPF believes that the new measures further help attract strategic partners for the development of
its unconventional resource base. Following Chevron and Dow Chemical, YPF was able to create development projects with Pampa
Energía and more recently Petronas. At the same time, other companies were able to advance their exploration projects, in some
instances with new partners, including YPF as a non-operating party to some existing JVs where YPF is used to participating. We
believe that increasing the number of participants in the market causes the industry to become more dynamic in the long term and that
with additional critical mass it will become more efficient as well.
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In our Refining and Marketing businesses, we face competition from several major international oil companies, such as Axion
(previously ESSO, a former subsidiary of ExxonMobil acquired by Bridas Corporation), Shell and Petrobras, as well as several
domestic oil companies. In our export markets, we compete with numerous oil companies and trading companies in global markets.
In Argentina, we operate in a competitive oil and gas industry with a dynamic market. Crude oil and most refined products
prices are subject to international supply and demand and, in certain cases, to Argentine regulations. Although the Argentine market
has its own dynamics and fundamentals, changes in the domestic and international prices of crude oil and refined products have some
direct effect on our results of operations and on our levels of capital expenditures. See “Item 3. Key Information—Risk Factors—
Risks Relating to the Argentine Oil and Gas Business and Our Business—Oil and gas prices, including the recent decline in global
prices for oil and gas, could affect our business.”
On May 3, 2012, the Expropriation Law was passed by the Argentine congress, by which the government regained control of
51% of the capital structure of YPF. The Expropriation Law also declared that achieving energy self-sufficiency was of public
interest, and that the exploitation, industrialization, transportation and sale of hydrocarbons are priorities for Argentina. In addition,
its stated goal is to guarantee socially equitable economic development, the creation of jobs, the increase of the competitiveness of
various economic sectors and the equitable and sustainable growth of the Argentine provinces and regions. See “—Regulatory
Framework and Relationship with the Argentine Government—The Expropriation Law.” Despite all these overarching objectives, the
Law maintained YPF as a commercial corporation with the focus on keeping competitiveness in the market. That competitive drive,
along with the Company’s widely recognized professionalism, has driven its decision-making and will continue to do so.
During 2015, the Argentine government continued promoting the industry which, along with the competitive responses of
different market participants throughout the year, further strengthened the competitive nature of our industry and fostered a positive
business environment. In October 2014, the Argentine congress passed Law No. 27,007 which amended the Hydrocarbons Law and
introduced very important changes in order to have a more modern framework that recognizes specific considerations for new
petroleum companies, such as those working in unconventional resources, offshore and in enhanced oil recovery. The changes further
strengthen synergies, promote investments and seek uniformity. Besides recognizing the benefits of the gas pricing scheme and the
promotional regime for investments, Law No. 27,007 reflects new terms and conditions for permits and concessions according to the
types of exploration projects. The 35-year concession term for unconventional exploitation is a distinctive, key feature for the
development of the unconventional resources in Argentina. See “—Regulatory Framework and Relationship with the Argentine
Government—Law No. 27,007, amending the Hydrocarbons Law.”
Finally, on a daily basis our business manages competitive factors that are in turn influenced by international and local
variables, such as international and local crude oil and refining products pricing, inflation, foreign exchange rates and employment
rates. YPF continually adjusts its product offerings and the costs of its operations in order to adapt to these variables. One such
change relates to the agreement among industry participants and the Argentine government to address the steep decline in
international crude oil prices that occurred at the end of 2014, prices that continued at a relelatively low level during 2015. As of
December 30, 2014, the National Executive Office decided to reduce taxes on the sale of fuels, which partially compensated for the
decrease in the price of domestic fuels. Subsequently, the National Executive Office also reduced export taxes to the minimum
allowed by law, so that exporting producers of crude oil with no use in local refining could also partially compensate the decrease in
the price of international hydrocarbon products. These two measures were part of a comprehensive plan set forth by the Argentine
government, producers and the refiners. The principal Argentine producers and refiners privately negotiated an approximately U.S.$7
reduction to the domestic crude oil price per barrel as a function of the decline in international prices in order to continue developing
local production as well as to secure certain refining margins. In addition, on February 4, 2015 the Commission issued Resolution
14/2015 creating the Crude Oil Production Stimulus Program (Programa de Estímulo a la Producción de Petróleo Crudo) which was
in place from January 1, 2015 through December 31, 2015 and through which the Argentine federal government, subject to certain
requirements, paid an export stimulus or a production stimulus for companies registered under that program. The plan is intended to
offset the potential impact international crude oil prices could have had on the local industry which, in turn, created a comparatively
more attractive oil and gas market for Argentina during 2015. As of the beginning of 2016, the National Executive Office, which took
office on December 10, 2015, along with producers and refiners agreed to a reduction of the local price of crude oil beginning
January 2016, setting a new price for Medanito of U.S.$67.50/bbl and U.S.$54.90/bbl for Escalante. At the same time, and further to
the efforts initiated in 2015, producers and refiners continue working closely to encourage contractors and unions to acknowledge the
fundamental changes in the industry worldwide by significantly reducing costs and increasing productivity, thus making 2016 an
opportunity to further improve the competitiveness of the industry as a whole towards international standards. See “Item 3. Key
Information—Risk Factors” for a description main risks and uncertainties we face.
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Environmental Matters
YPF-Argentine operations
Our operations are subject to a wide range of laws and regulations relating to the general impact of industrial operations on the
environment, including air emissions and waste water, the disposal or remediation of soil or water contaminated with hazardous or toxic
waste, fuel specifications to address air emissions and the effect of the environment on health and safety. We have made and will continue to
make expenditures to comply with these laws and regulations. In Argentina, local, provincial and national authorities are moving towards
more stringent enforcement of applicable laws. In addition, since 1997, Argentina has been implementing regulations that require our
operations to meet stricter environmental standards that are comparable in many respects to those in effect in the United States and in
countries within the European Community. These regulations establish the general framework for environmental protection requirements,
including the establishment of fines and criminal penalties for their violation. We have undertaken measures to achieve compliance with these
standards and are undertaking various abatement and remediation projects, the more significant of which are discussed below. We cannot
predict what environmental legislation or regulation will be enacted in the future or how existing or future laws will be administered or
enforced. Compliance with more stringent laws or regulations, as well as more vigorous enforcement policies of regulatory agencies, could
require additional expenditures in the future by us, including the installation and operation of systems and equipment for remedial measures,
and could affect our operations generally. In addition, violations of these laws and regulations may result in the imposition of administrative
or criminal fines or penalties and may lead to personal injury claims or other liabilities.
We continued making investments in order to comply with new Argentine fuel specifications, pursuant to Resolution No. 1283/06
(amended by Resolution No. 478/2009) of the Argentine Secretariat of Energy (which replaces Resolution No. 398/03) relating to, among
other things, the purity of diesels. In the La Plata refinery, a new ultra-low sulfur diesel desulfurization plant was started up during 2012. In
Luján de Cuyo refinery, new HDS III (diesel desulfurization) and HTN II (gasoline desulfurization) plants were started up in 2013.
Additionally, we are increasing the tankage capacity of several of our terminals in order to optimize fuel distribution logistics. During 2013,
new diesel tanks were implemented in Luján de Cuyo refinery and Montecristo terminal. In 2014, a diesel tank was completed at Terminal
Villa Mercedes (“TVM”), and engineering projects advanced at the Luján de Cuyo and La Plata refineries.
First stage projects related to biofuels, such as the addition of bioethanol to gasoline and FAME to diesel, were accomplished by the end
of 2009 and were operational by the beginning of 2010. During 2010 and 2011, additional bioethanol facilities at several terminals were
installed and became ready to operate. Also, during this period, further investments were made in several terminals in order to allow the
increased addition of FAME to diesel and to improve the related biofuel logistics. A new facility for FAME blending was started up in 2013 in
the Montecristo terminal. In 2014, a 3,000 cm FAME tank at Terminal Dock Sud (“TDS”) and a 3,000 cm FAME tank at TVM were built.
Also, two 200 cm ethanol tanks at Concepción del Uruguay were built. These projects are expected to enable YPF to comply with
governmental requirements and to enter into the renewable energy sources market.
At each of our refineries during 2015, we continued with the initiatives relating to remedial investigations, feasibility studies and
pollution abatement projects, which are designed to address potentially contaminated sites and air emissions. In addition, we have
implemented an environmental management system to assist our efforts to collect and analyze environmental data in our upstream and
downstream operations.
Also, as part of our commitment to satisfying domestic demand for fuels and meeting high environmental standards, during 2013 we
started up a new Continuous Catalyst Regeneration (“CCR”) unit which involved an investment of U.S.$453 million. The plant uses the latest
worldwide technology to perform chemical processes and improvements in productivity, safety and environmental standards. Additionally,
the plant produces aromatics that can be used as octane enhancers for gasoline and automotive applications, as well as increases hydrogen
production to feed the fuel hydrogenation processes to increase fuel quality and reduce sulfur content, further reducing the environmental
impact of internal combustion engines
We also continue construction of a new coke unit at La Plata refinery, which will involve an aggregate investment of approximately
U.S.$1,015 million (the total amount disbursed as of December 31, 2015 was U.S.$869 million), replacing the one that was severely damaged
in the incident that occurred on April 2, 2013. The new unit design is expected to optimize energy efficiency and minimize particulate matter
emissions. We expect that this project will be completed during 2016.
In addition to the projects mentioned above, we have begun to implement a broad range of environmental projects in the domestic
Exploration and Production and Refining and Marketing and Chemicals segments, such as a new flare in the Luján de Cuyo refinery,
wastewater treatment and fire protection facilities, new flare in CIPH, improvement of fireproofing in existing facilities and implementation of
bottom loading systems in terminals.
We and several other industrial companies operating in the La Plata area have entered into a community emergency response agreement
with three municipalities and local hospitals, firefighters and other health and safety service providers to implement an emergency response
program. This program is intended to prevent damages and losses resulting from accidents and emergencies, including environmental
emergencies. Similar projects and agreements were developed at other refineries and harbor terminals as well.
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In 1991, we entered into an agreement with certain other oil and gas companies to implement a plan to reduce and assess
environmental damage resulting from oil spills in Argentine surface waters to reduce the environmental impact of potential oil spills
offshore. This agreement involves consultation on technological matters and mutual assistance in the event of any oil spills in rivers
or at sea due to accidents involving tankers or offshore exploration and production. During 1997 and 1998, each of our refineries (La
Plata, Luján de Cuyo, and Plaza Huincul) were certified under the ISO (International Organization for Standardization) 9001 (quality
performance) and ISO 14001 (environmental performance). All of them are also certified under the OHSAS 18001 (occupational
health and safety performance) standard. In addition, since 2008, the La Plata and Luján de Cuyo complexes have been verified in
accordance with ISO 14064 for the inventories of industrial greenhouse gases. The refineries maintain their systems under continuous
improvement and revision by accredited organizations.
With respect to climate change, YPF has:
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committed to active promotion of identification and pursuit of opportunities to reduce greenhouse gas emissions in our
operations;
a new internal corporate commitment on climate change and energy efficiency which was developed in June 2015. This
document obligates the company to work on reducing greenhouse gas emissions, contributing to mitigation activities while
promoting sustainable development and preserving natural resources;
intensified the execution of internal projects to obtain credits under the relevant clean development mechanisms through
the efficient use of resources, contributing to the transfer of technology and to the sustainable development of Argentina;
obtained the approval of the United Nations in December 2010 for an industrial project developed by YPF in Argentina
defined as a Clean Development Mechanism (“CDM”) project, the first of its kind in the world. The project in the La Plata
refinery reduces the emissions of greenhouse waste gases from fossil fuels used for process heating by replacing these
fuels with recovered waste gases that were previously burned in flares. The project increases energy efficiency by reducing
the demand for fuel oil and natural gas, allowing an annual emission reduction of approximately 200,000 tons of carbon
dioxide. During 2015 the La Plata project reduced carbon dioxide emissions by 111,115 tons;
obtained the approval of the United Nations in December 2011 for an industrial project developed by YPF in Argentina
defined as a CDM at the Luján de Cuyo refinery. During 2015 the project reduced carbon dioxide emissions by 24,521
tons;
secured the approval of the CDM project. YPF developed a new methodology which was approved by the United Nations
in 2007 under the name of AM0055 “Baseline and Monitoring Methodology for the recovery and utilization of waste gas
in refinery facilities.” Currently, five CDM projects are being developed around the world (Argentina, China, and Egypt)
applying this methodology designed by YPF;
undertook and verified third-party greenhouse gas emission inventories for refining and chemical operations in accordance
with the ISO 14064 standard. The inventory at CIE has been verified since 2008. In June 2015, the inventory verification
process of greenhouse gases in the La Plata complex and the Luján de Cuyo refinery was completed. A 2016 inventory
check, ending in the first half of 2016, is planned in all the refineries;
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estimated the contribution that its forestry projects located in the province of Neuquén had with respect to climate change.
These projects constitute approximately 6,500 hectares of trees forested under a long-term work program. Using the
afforestation methodologies and tools available at the United Nations Framework Convention on Climate Change
(“UNFCCC”) Clean Development Mechanism web site, it was possible to arrive to a conservative estimated amount of
approximately 760,000 tons of carbon dioxide equivalents that were captured by the afforestation project activities from
1984 (when the first afforestation activity occurred) through 2013; and
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strengthened the relationship established with the Argentinean Environmental Authority (Secretaria de Ambiente y
Desarrollo Sustentable de la Nación), in particular with its Climate Change Unit (Dirección de Cambio Climático) in order
to collaborate with the development of the Third National Communication on Climate Change to the UNFCCC.
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Our estimated capital expenditures are based on currently available information and on current laws. Any future information or
future changes in laws or technology could cause a revision of such estimates. Moreover, while we do not expect environmental
expenditures to have a significant impact on our future results of operations, changes in management’s business plans or in Argentine
laws and regulations may cause expenditures to become material to our financial position, and may affect results of operations in any
given year.
Unconventional oil and gas efforts led by YPF
Organically rich shale gas and oil accumulations are drawing increasing attention worldwide as sources of significant natural
gas and oil reserves.
Since 2008, YPF has led various exploration and development projects related to unconventional resources in Argentina, the
most important being in the Vaca Muerta formation within Neuquina basin.
The Vaca Muerta formation is found between 2,500 and 4,000 meters of depth, more than 2,000 meters below the water table,
which is usually located at depths of 300-500 meters. See “Item 3. Key Information—Risk Factors—Risks Relating to the Argentine
Oil and Gas Business and Our Business—Our domestic operations are subject to extensive regulation” and “—Oil and gas activities
are subject to significant economic, environmental and operational risks.”
Hydraulic stimulation, a long time proven technology, allows these resources to be extracted in an efficient and
environmentally-friendly way. Hydraulic stimulation consists of injecting high pressure fluids and sand into the wellbore to crack the
rock and enable the trapped hydrocarbons in the formation to flow to the surface like in any conventional well.
Generally, this technique uses water and sand (99.5% of the water can be recycled) and additives (0.5%). These additives are the
same as those used in products for household and commercial applications, such as sodium chloride (used in table salt), borate salts
(used in cosmetics), potassium carbonate (used in detergents), guar gum (used in ice cream) and isopropyl alcohol (used in
deodorants).
The water used for the development of these reservoirs is acquired from bodies of running water and it represents only a small
percentage of the total flow, which involves much lower volumes than those used for agricultural and human consumption in the
province of Neuquén.
From the beginning of unconventional operations, YPF has considered the environmental protection as one of the values of its
quality, health, safety and environment policy.
In accordance with law Disposition No. 112/2011 of the Environmental Subsecretary of Neuquén, the project has an
Environmental Baseline Study (“EBS”). The EBS includes the current description and environmental characterization of the
concession areas and specifically environmental components that may be affected significantly by the projects and activities.
YPF is currently developing a water management framework, which focuses on three key areas of water use: water resources
(sustainability factors, measures that consider the needs of other local water users, and the net environmental effect); water use and
efficiency (controls of replacing water use, reducing water consumption, and the reuse and recycling to consider the net
environmental effect); and wastewater management (consider similar sustainability factors and the net environmental effect as
outlined for water resources).
In addition, YPF commissioned the following studies: (i) a hydrogeological study of confined and semi-confined aquifers of
Neuquén and Rayoso Groups and hydrogeological study of the unconfined aquifer of the alluvial plain of the Neuquén River in the
Loma Campana area beginning in December 2014, (ii) an air quality and noise study in the Loma Campana area beginning 2016 and
(iii) aquatic and terrestrial environmental studies in the Loma Campana, El Mangrullo and El Orejano areas beginning 2016 to 2017.
YPF Holdings-Operations in the United States
Laws and regulations relating to health and environmental quality in the United States affect the operations of YPF Holdings, a
100% owned subsidiary of YPF. See “—Regulatory Framework and Relationship with the Argentine Government—U.S.
Environmental Regulations.”
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In 1995, YPF acquired Maxus Energy Corporation (“Maxus”), a U.S. corporation headquartered in Dallas, Texas. In connection
with the sale by Maxus of Diamond Shamrock Chemicals Company (“Chemicals Company”) to a subsidiary of Occidental Petroleum
Corporation (“Occidental”) in 1986, Maxus had agreed to indemnify Chemicals Company and Occidental from and against certain
liabilities relating to the business and activities of Chemicals Company prior to the September 4, 1986 closing date (the “Closing
Date”), including certain environmental liabilities relating to certain chemical plants and waste disposal sites used by Chemicals
Company prior to the Closing Date.
In addition, under the agreement pursuant to which Maxus sold Chemicals Company to Occidental (the “1986 Stock Purchase
Agreement”), Maxus is obligated to indemnify Chemicals Company and Occidental for certain environmental costs incurred on
projects involving remedial activities relating to chemical plant sites or other property used to conduct Chemicals Company’s
business as of the Closing Date and for any period of time following the Closing Date which relate to, result from or arise out of
conditions, events or circumstances discovered by Chemicals Company and as to which Chemicals Company provided written notice
prior to September 4, 1996, irrespective of when Chemicals Company incurs and gives notice of such costs.
Tierra Solutions Inc. (“Tierra”), a subsidiary of YPF Holdings, was formed to deal with the results of the alleged obligations of
Maxus, as described above, resulting from actions or facts that occurred primarily between the 1940s and 1970s while Chemicals
Company was controlled by other companies.
See “Item 8. Financial Information—Legal Proceedings—YPF Holdings” for a description of environmental matters in
connection with YPF Holdings.
Offshore Operations
All the offshore blocks in which we have a working interest are included in a Health, Safety and Environmental (“HSE”)
Management system to address risks and environmental impacts during each phase of the offshore activities.
Neptune
Under the Neptune Joint Operating Agreement, the operator of the field is required to maintain an HSE management plan based
on health and safety rules agreed upon between the operator and the non-operators. As a non-operator, we are entitled to review the
operator’s safety and environmental management systems for compliance with the HSE management plan, but we do not have direct
control over the measures taken by the field operator to remedy any particular spill or leak. The operator of the field is required to
notify all non-operators, including us, in writing of any spill greater than 50 barrels, among other incidents.
The HSE management plan for Neptune, which is maintained by the operator of the field, includes the following critical
elements and procedures:
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emergency shutdown (“ESD”) system
fire detection system
combustible gas detection system
ventilation systems (mechanical)
spill/leak containment systems
vent/flare system
subsea well control system
temporary refuge
escape water craft
critical power systems (including electric, pneumatic, hydraulic)
emergency communication systems
hull ballast systems
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hull tendons
riser hang-off components
design HSE case critical procedures
ESD procedures
evacuation procedures
dire fighting procedures
helideck operations procedures
emergency response procedures
Additionally, the operator’s emergency, preparedness and response procedures include teams that generally are on call 24 hours a day, 7
days a week and are summoned based on the severity level of the emergency (1-low up to 7-extreme) through a third party London based
emergency dispatcher. The operator’s teams include the following:
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Fire and Safety Team (“FAST”) site response (level 1 to 2 severity): Provides initial on-scene response and incident containment
in the operator’s tower building including evacuation, first aid, CPR, search and rescue.
Incident Management Team (“IMT”)—asset/local response (level 2 to 5 severity): Provides tactical, operational, HSE, planning,
logistical and regulatory notification support and other technical expertise. An incident management center is established for the
IMT in one room of the operator building in Houston. The IMT is also supported by a drilling-specific team from the World Wide
Drilling group for any incidents during drilling and completions activities.
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Emergency Management Team (“EMT”)—petroleum/asset response (level 3 to 5 severity): Provides support to the IMT with
emphasis on strategic issues affecting the asset and petroleum including internal and external stakeholder management, financial,
legal, and communication support. An emergency management room for the EMT is established in one room of the operator’s
building in Houston.
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Crisis Management Team (“CMT”)—operator response (level 5 to 7 severity): Provides support to the EMT with emphasis on
strategic issues affecting the operator including communications with stakeholders at senior levels.
External Response Organizations: Summoned for any severity level based on needs assessed by the IMT, EMT or CMT. Includes
government response groups and external oil spill response organizations and emergency management consultants.
The HSE management plan is administered by a leading oil field services company contracted by the operator and includes a plan of
action in the event of a spill or leak.
Property, Plant and Equipment
Most of our property, which comprises investments in assets which allow us to explore or exploit crude oil and natural gas reserves, as
well as refineries, storage, manufacturing and transportation facilities and service stations, is located in Argentina. As of December 31, 2015,
more than 99% of our proved reserves were located in Argentina. We also own property outside Argentina, mainly in the United States. See
“—Exploration and Production Overview—Main Properties.”
Our petroleum exploration and production rights are in general based on sovereign grants of concession. Upon the expiration of the
concession, our exploration and production assets associated with the particular property subject to the relevant concession revert to the
government. In addition, as of December 31, 2015, we leased 85 service stations to third parties and also had activities with service stations
that are owned by third parties and operated by them under a supply contract with us for the distribution of our products.
Insurance
The scope and coverage of the insurance policies and indemnification obligations discussed below are subject to change, and such
policies are subject to cancellation in certain circumstances. In addition, the indemnification provisions of certain of our drilling, maintenance
and other service contracts may be subject to differing interpretations, and enforcement of those provisions may be limited by public policy
and other considerations. We may also be subject to potential liabilities for which we are not insured or in excess of our insurance coverage,
including liabilities discussed in “Item 3. Key Information—Risk Factors—Risks Relating to the Argentine Oil and Gas Business and Our
Business—We may not have sufficient insurance to cover all the operating hazards that we are subject to,” “Item 3. Key Information—Risk
Factors—Risks Relating to the Argentine Oil and Gas Business and Our Business—The oil and gas industry is subject to particular economic
and operational risks” and “Item 3. Key Information—Risk Factors—Risks Relating to the Argentine Oil and Gas Business and Our
Business—We may incur significant costs and liabilities related to environmental, health and safety matters.”
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Argentine operations
We insure our operations against risks inherent in the oil and gas industry, including loss of or damage to property and our
equipment, control-of-well incidents, loss of production or profits incidents, removal of debris, sudden and accidental pollution,
damage and clean up and third-party claims, including personal injury and loss of life, among other business risks. Our insurance
policies are typically renewable annually and generally contain policy limits, exclusions and deductibles.
Our insurance policy covering our Argentine operations provides third party liability coverage up to U.S.$400 million per
incident, with a deductible of U.S.$2 million, in each and every loss. Certain types of incidents, such as intentional pollution and
gradual and progressive pollution are excluded from the policy’s coverage. The policy’s coverage extends to control-of-well
incidents, defined as an unintended flow of drilling fluid, oil, gas or water from the well that cannot be contained by equipment on
site, by increasing the weight of drilling fluid or by diverting the fluids safely into production. Our policy provides coverage for third-
party liability claims relating to pollution from a control-of-well event ranging from U.S.$75 million for certain onshore losses and a
maximum combined single limit of U.S.$250 million for offshore losses.
Our insurance policy also covers physical loss or damage in respect of, but not limited to, onshore and offshore property of any
kind and description (whether upstream or downstream), up to U.S.$2 billion per incident combined for downstream and upstream
operations, with varying deductibles of between U.S.$1 million and U.S.$10 million, including loss of production or profits with
deductibles of 90 days for downstream operations and 60 days with a minimum deductible of U.S.$20 million for upstream
operations.
Argentine regulations require us to purchase from specialized insurance companies (Aseguradoras de Riesgos de Trabajo)
insurance covering the risk of personal injury and loss of life of our employees. Our insurance policies cover medical expenses, lost
wages and loss of life, in the amounts set forth in the applicable regulations. These regulatory requirements also apply to all of our
contractors.
We have adopted a position in agreements entered into with contractors that provide drilling services, well services or other
services to our exploration and production operations (“E&P Services Agreements”), whereby contractors are generally responsible
for indemnifying us to varying degrees for certain damages caused by their personnel and property above the drilling surface.
Similarly, we are generally responsible under our drilling contracts to indemnify our contractors for any damages caused by our
personnel and property above the drilling surface.
In connection with losses or liabilities resulting from damages caused below the surface, we have agreed with some contractors
that YPF assumes responsibility for indemnifying our contractors provided that such damages below the surface have not been caused
by the negligence of the contractor in which case the contractor shall be liable up to a limited amount agreed by the parties in the
E&P Services Agreements. However, we have also agreed with a number of contractors that YPF shall be responsible and shall
indemnify contractors for damages or liabilities caused below the surface, unless such damages or liabilities result from the gross
negligence or willful misconduct of contractors, in which case contractor shall be liable in full or, in certain cases, up to a limited
amount.
E&P Services Agreements usually establish that contractors are responsible for pollution or contamination including clean-up
costs and third party damages caused above the surface by the spill of substances under their control, provided that the damage has
been caused by the negligence or willful misconduct of the contractor. In the event of pollution or contamination produced below the
surface, contractors shall also typically be liable for damages caused due to the contractor’s negligence or willful misconduct.
However, in this last case the damages are also usually limited to an amount agreed upon by the parties in the E&P Services
Agreement.
We are also partners in several joint ventures and projects that are not operated by us. Contractual provisions, as well as our
obligations arising from each agreement, can vary. In certain cases, insurance coverage is provided by the insurance policy entered
into by the operator, while in others, our risks are covered by our insurance policy covering our Argentine operations. In addition, in
certain cases we may contract insurance covering specific incidents or damages that are not provided for in the operator’s insurance
policy. We also retain the risk for liability not indemnified by the field or rig operator in excess of our insurance coverage.
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With respect to downstream servicing contracts, contractors are usually responsible for damages to their own personnel and
caused by them to third parties and they typically indemnify us for damages to equipment. A mutual hold-harmless provision for
indirect damages such as those resulting from loss of use or loss of profits is normally included.
Gulf of Mexico operations
Our operations in the Gulf of Mexico currently include only our 15% working interest, through Maxus U.S. Exploration
Company (a YPF Holdings subsidiary) in the Neptune field, which is operated by BHP Billiton.
Our Gulf of Mexico operations insurance policy provides coverage for property damage, operator’s extra expenses, loss of
production and third party liability, subject to certain customary exclusions such as property damage resulting from wear and tear and
gradual deterioration. The following limits and deductibles are applicable to our insurance coverage:
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Physical loss or damage to owned property and equipment is limited to U.S.$772 million (100% coverage), with
deductibles ranging from U.S.$0.75 million (100% coverage) to U.S.$1.25 million (100% coverage).
Coverage for operator’s extra expenses is subject to a limit of U.S.$250 million (100% coverage) per incident, with a
U.S.$1 million deductible (100% coverage). Our control-of-well insurance mainly covers expenses incurred on account of
bringing or attempting to bring under control a well that is out of control or extinguishing a well fire, including but not
limited to the value of materials and supplies consumed in the operation, rental of equipment, fees of individuals, firms or
corporations specializing in firefighting and/or the control of wells, deliberate well firing, and cost of drilling direction
relief well(s) necessary to bring the well(s) under control or to extinguish the fire and excludes bodily injury, damage to
property of others and loss of hole (except in respect of certain costs incurred in re-drilling and/or recompletion as a result
of an occurrence). For the purpose of this insurance, a well shall be deemed to be out of control only when there is an
unintended flow from the well of drilling fluid, oil, gas or water (1) which flow cannot promptly be (a) stopped by use of
the equipment on site and/or the blowout preventer, storm chokes or other equipment; or (b) stopped by increasing the
weight by volume of drilling fluid or by use of the other conditioning materials in the well; or (c) safely diverted into
production; or (2) which flow is deemed to be out of control by the appropriate regulatory authority.
Loss of production following damage to insured property or extra expenses paid by the operator arising from an incident is
covered up to a limit of U.S.$29.1 million (15% coverage) with a waiting time of 60 days.
Gulf of Mexico windstorm coverage is subject to a limit of U.S.$20 million (for the insured’s interest) with respect to each
and every occurrence and in the aggregate in respect of a named Gulf of Mexico windstorm (this limit applies across
property, OEE and loss of production); which is excess of a retention of U.S.$10 million (100% coverage) each and every
occurrence plus 90 days waiting time in respect of loss of production.
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Coverage for third party liability arising from personal injury or loss of life, which extends to our employees, contractors
and unaffiliated third party individuals, is subject to a limit of U.S.$333.33 million (100% coverage) per incident, without a
deductible.
According to the procedures applicable to the Neptune field consortium, its operator shall use its best efforts to require
contractors to carry insurance coverage for worker compensation, employers liability, commercial general liability and automobile
liability. To our knowledge, based solely on inquiries made to the operator, this policy is applicable to all contracts and a majority of
contractors carry such insurance. Contractors providing aircraft and watercraft are required to provide further insurance cover
relevant to this activity. In addition, our own insurance policy covers risks of physical loss or damage incurred as a result of
negligence by any contractor to supplies and equipment of every kind and description incidental to our operations, including, among
others, materials, equipment, machinery, outfit and consumables, in each case as defined in our insurance contract and with the
deductibles and exclusions specified therein. The consortium or operator, as applicable, is responsible for indemnifying a contractor
for damages caused by its personnel and property. The operator or consortium, as applicable, is also responsible for indemnifying
contractors for certain losses and liabilities resulting from pollution or contamination.
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Regulatory Framework and Relationship with the Argentine Government
Overview
The Argentine oil and gas industry is regulated by Law No. 17,319, referred to as the “Hydrocarbons Law,” which was enacted
in 1967 and amended by Law No. 26,197 enacted in 2007 and Law No. 27,007 enacted in 2014, which established the general legal
framework for the exploration and production of oil and gas, and Law No. 24,076, referred to as the “Natural Gas Law,” enacted in
1992, which established the basis for deregulation of natural gas transportation and distribution industries. See “—Law No. 27,007,
amending the Hydrocarbons Law.”
The National Executive Office issues the regulations to complement these laws. The regulatory framework of the Hydrocarbons
Law was established on the assumption that the reservoirs of hydrocarbons would be national properties and Yacimientos Petrolíferos
Fiscales Sociedad del Estado, our predecessor, would lead the oil and gas industry and operate under a different framework than
private companies. In 1992, the “Privatization Law” privatized YPF and provided for transfer of hydrocarbon reservoirs from the
Argentine government to the provinces, subject to the existing rights of the holders of exploration permits and production
concessions.
The Privatization Law granted us 24 exploration permits covering approximately 132,735 km2 and 50 production concessions
covering approximately 32,560 km2. Limits under the Hydrocarbons Law on the number of concessions for transportation that may
be held by any one entity, and the total area of exploration permits that may be granted to a single entity, were eliminated by Law
No. 27,007. As a consequence of the transfer of ownership of certain hydrocarbons areas to the provinces, we participate in
competitive bidding rounds organized since the year 2000 by several provincial governments for the award of contracts for the
exploration of hydrocarbons.
In October 2004, the Argentine congress enacted Law No. 25,943 creating a new state-owned energy company, ENARSA. The
corporate purpose of ENARSA is the exploration and exploitation of solid, liquid and gaseous hydrocarbons, the transport, storage,
distribution, commercialization and industrialization of these products, as well as the transportation and distribution of natural gas,
and the generation, transportation, distribution and sale of electricity. Moreover, Law No. 25,943 granted to ENARSA all exploration
concessions in respect to offshore areas located beyond 12 nautical miles from the coast line up to the outer boundary of the
continental shelf that were vacant at the time of the effectiveness of this law (i.e., November 3, 2004). Law No. 25,943 has been
modified by Law No. 27,007, as described below, eliminating all permits and hydrocarbon production concessions where association
agreements with ENARSA have not been signed and reverting them to the Argentine Secretariat of Energy (except for permits and
concessions granted prior to Law No. 25,943). Additionally, Law No. 27,007 provides for a six month negotiating period to convert
association agreements with ENARSA into permits or concessions. In September 2015, the National Executive Office and YPF began
negotiating the conversion of association agreements executed with ENARSA. As of the date of this annual report, these negotiations
are ongoing.
Decree No. 13/15 modified article 1 of the Law of Ministries No. 22,520 and created the Ministry of Energy and Mining,
absorbing the functions of the Secretariat of Energy.
In addition, in October 2006, Law No. 26,154 created a regime of tax incentives aimed at encouraging hydrocarbon exploration
and which apply to new exploration permits awarded in respect of the offshore areas granted to ENARSA and those over which no
rights have been granted to third parties under the Hydrocarbons Law, provided the provinces in which the hydrocarbon reservoirs are
located adhere to this regime. Association with ENARSA is a precondition to qualifying for the benefits provided by the regime
created by Law No. 26,154. The benefits include: early reimbursement of the value added tax for investments made and expenses
incurred during the exploration period and for investments made within the production period; accelerated amortization of
investments made in the exploration period and the accelerated recognition of expenses in connection with production over a period
of three years rather than over the duration of production; and exemptions to the payment of import duties for capital assets not
manufactured within Argentina. As of the date of this annual report, we have not used the tax incentives previously mentioned.
Ownership of hydrocarbons reserves was transferred to the provinces through the enactment of the following legal provisions
that effectively amended the Hydrocarbons Law:
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In 1992, the Privatization Law approved the transfer of the ownership of hydrocarbons reserves to the provinces where
they are located. However, this law provided that the transfer was conditioned on the enactment of a law amending the
Hydrocarbons Law to contemplate the privatization of Yacimientos Petrolíferos Fiscales Sociedad del Estado.
In October 1994, the Argentine National Constitution was amended and pursuant to Article 124 thereof, provinces were
granted the primary control of natural resources within their territories.
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In August 2003, Executive Decree No. 546/03 transferred to the provinces the right to grant exploration permits,
hydrocarbons exploitation and transportation concessions in certain locations designated as “transfer areas,” as well as in
other areas designated by the competent provincial authorities.
In January 2007, Law No. 26,197 acknowledged the provinces’ ownership of the hydrocarbon reservoirs in accordance
with Article 124 of the National Constitution (including reservoirs to which concessions were granted prior to 1994) and
granted provinces the right to administer such reservoirs.
The Expropriation Law
On May 3, 2012, the Expropriation Law (Law No. 26,741) was passed by the Argentine congress and, on May 7, 2012, it was
published in the Official Gazette of the Republic of Argentina. The Expropriation Law declared achieving self-sufficiency in the
supply of hydrocarbons, as well as in the exploitation, industrialization, transportation and sale of hydrocarbons, a national public
interest and a priority for Argentina. In addition, its stated goal is to guarantee socially equitable economic development, the creation
of jobs, the increase of the competitiveness of various economic sectors and the equitable and sustainable growth of the Argentine
provinces and regions.
Article 3 of the Expropriation Law provides that the principles of the hydrocarbon policy of the Republic of Argentina are the
following:
(a) Promote the use of hydrocarbons and their derivatives to promote development, and as a mechanism to increase the
competitiveness of the various economic sectors and that of the provinces and regions of Argentina;
(b) Convert hydrocarbon resources to proved reserves and their exploitation and the restoration of reserves;
(c)
Integrate public and private capital, both national and international, into strategic alliances dedicated to the exploration and
exploitation of conventional and unconventional hydrocarbons;
(d) Maximize the investments and the resources employed for the achievement of self-sufficiency in hydrocarbons in the short,
medium and long term;
(e)
Incorporate new technologies and categories of management that contribute to the improvement of hydrocarbon
exploration and exploitation activities and the advancement of technological development in the Republic of Argentina in
this regard;
(f)
Promote the industrialization and sale of hydrocarbons with a high added-value;
(g) Protect the interests of consumers with respect to the price, quality and availability of hydrocarbon derivatives; and
(h) Export hydrocarbons produced in excess of local demand, in order to improve the trade balance, ensuring a rational
exploitation of the resources and the sustainability of its exploitation for use by future generations.
According to Article 2 of the Expropriation Law, the National Executive Office will be responsible for setting forth this policy
and shall introduce the measures necessary to accomplish the purpose of the Expropriation Law with the participation of the
Argentine provinces and public and private capital, both national and international.
Creation of Federal Council of Hydrocarbons
Article 4 of the Expropriation Law provides for the creation of a Federal Council of Hydrocarbons which shall include the
participation of (a) the Ministry of Economy, the Ministry of Federal Planning, the Ministry of Labor and the Ministry of Industry,
through their respective representatives; and (b) the provinces of Argentina and the City of Buenos Aires, through the representatives
that each may appoint. According to Article 5 of the Expropriation Law, the responsibilities of the Federal Council of Hydrocarbons
will be the following: (a) promote the coordinated action of the national and provincial governments, with the purpose of ensuring the
fulfillment of the objectives of the Expropriation Law; and (b) adopt decisions regarding all questions related to the accomplishment
of the objectives of the Expropriation Law and the establishment of the hydrocarbons policy of the Republic of Argentina that the
National Executive Office may submit for consideration.
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Expropriation of shares held by Repsol YPF
For purposes of ensuring the fulfillment of its objectives, the Expropriation Law provided for the expropriation of 51% of the
share capital of YPF represented by an identical stake of Class D shares owned, directly or indirectly, by Repsol YPF S.A. and its
controlled or controlling entities. According to the Expropriation Law, the shares subject to expropriation, which have been declared
of public interest and were transferred to the Republic of Argentina, will be assigned as follows: 51% to the federal government and
49% to the governments of the provinces that compose the National Organization of Hydrocarbon Producing States. In addition, the
Expropriation Law provided for the expropriation of 51% of the share capital of the company Repsol YPF GAS S.A. represented by
60% of the Class A shares of such company owned, directly or indirectly, by Repsol Butano S.A. and its controlled or controlling
entities.
As of the date of this annual report, the transfer of the shares subject to expropriation between the National Executive Office and
the provinces that compose the National Organization of Hydrocarbon Producing States was still pending. According to Article 8 of
the Expropriation Law, the distribution of the shares among the provinces that accept their transfer must be conducted in an equitable
manner, considering their respective levels of hydrocarbon production and proved reserves.
To ensure compliance with its objectives, the Expropriation Law provides that the National Executive Office, by itself or
through an appointed public entity, shall exercise all the political rights associated with the shares subject to expropriation until the
transfer of political and economic rights to the provinces that compose the National Organization of Hydrocarbon Producing States is
completed. In addition, in accordance with Article 9 of the Expropriation Law, each of the Argentine provinces to which shares
subject to expropriation are allocated must enter into a shareholder’s agreement with the federal government that will provide for the
unified exercise of its rights as a shareholder.
Any future transfer of the shares subject to expropriation is prohibited without the permission of the Argentine congress by a
vote of two-thirds of its members.
In accordance with Article 9 of the Expropriation Law, the appointment of YPF S.A. Directors representing the expropriated
shares shall be made proportionately considering the holdings of the Argentine federal government and provincial governments, and
one Director shall represent the employees of the Company.
In accordance with Article 16 of the Expropriation Law, the federal government and the provinces must exercise their rights
pursuant to the following principles: (a) the strategic contribution of YPF to the achievement of the objectives set forth in the
Expropriation Law; (b) the administration of YPF pursuant to the industry’s best practices and corporate governance, safeguarding
shareholders’ interests and generating value on their behalf; and (c) the professional management of YPF.
See “—Law No. 26,932” for descriptions of the agreement between Repsol and the Argentine Republic relating to
compensation for the expropriation of 51% of the share capital of YPF owned, directly or indirectly, by Repsol, and the arrangement
between Repsol and YPF for the withdrawal of certain claims and actions relating to such expropriation.
Legal nature of the Company
YPF will continue to operate as a publicly traded corporation pursuant to Chapter II, Section V of Law No. 19,550 and its
corresponding regulations, and will not be subject to any legislation or regulation applicable to the management or control of
companies or entities owned by the federal government or provincial governments.
In accordance with Article 17 of the Expropriation Law, YPF will resort to internal and external sources of funding, strategic
alliances, joint ventures, transitory business unions, and cooperation partnerships whether public, private or mixed companies,
domestic and foreign.
You can find a copy of an English translation of the Expropriation Law in the report on Form 6-K furnished by the Company to
the SEC on May 9, 2012.
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Law No. 26,932
On February 25, 2014, the Republic of Argentina and Repsol reached an agreement (the “Repsol Agreement”) in relation to
compensation for the expropriation of 200,589,525 of YPF’s Class “D” shares pursuant to the Expropriation Law under the Repsol
Agreement. Repsol accepted U.S.$5.0 billion in sovereign bonds from the Republic of Argentina and withdrew judicial and arbitral
claims it had filed, including claims against YPF, and waived additional claims. YPF and Repsol executed a separate agreement (“the
Repsol Arrangement”) on February 27, 2014, pursuant to which YPF and Repsol each withdrew, subject to certain exclusions, all
present and future actions and/or claims based on causes occurring prior to the date of execution of Repsol Arrangement arising from
the expropriation of the YPF shares owned by Repsol pursuant to the Expropriation Law, including the intervention and temporary
possession for public purposes of YPF’s shares. YPF and Repsol agreed to withdraw reciprocal actions and claims with respect to
third parties and/or pursued by them and to grant a series of mutual indemnities, which at the time were subject to certain conditions
precedent. The Repsol Arrangement entered into force the day after Repsol notified YPF that the Repsol Agreement had entered into
force. The Repsol Agreement was ratified on March 28, 2014 at a Repsol general shareholders meeting and approved by the
Argentine congress by Law No. 26,932 enacted Decree No. 600/2014. On May 8, 2014, YPF was notified of the entrance into force
of the Repsol Agreement. As of that date, the expropriation pursuant to the Expropriation Law has been concluded, and as a result the
Republic of Argentina is definitively the owner of 51% of capital stock of each of YPF S.A. and YPF GAS S.A.
Law No. 26,197
Law No. 26,197, which amended the Hydrocarbons Law, transferred to the provinces and the City of Buenos Aires the
ownership over all hydrocarbon reservoirs located within their territories and in the adjacent seas up to 12 nautical miles from the
coast. Law No. 26,197 also provides that the hydrocarbon reservoirs located beyond 12 nautical miles from the coast to the outer limit
of the continental shelf shall remain within the ownership of the federal government.
Pursuant to Law No. 26,197, the Argentine congress shall continue to enact laws and regulations to develop oil and gas
resources existing within all of the Argentine territory (including its sea), but the governments of the provinces where the
hydrocarbon reservoirs are located shall be responsible for the enforcement of these laws and regulations, the administration of the
hydrocarbon fields and shall act as granting authorities for the exploration permits and production concessions. However, the
administrative powers granted to the provinces shall be exercised within the framework of the Hydrocarbons Law and the regulations
that complement this law.
Consequently, even though Law No. 26,197 established that the provinces shall be responsible for administering the
hydrocarbon fields, the Argentine congress retained its power to issue rules and regulations regarding the oil and gas legal
framework. Additionally, the Argentine federal government retained the power to determine the national energy policy.
It is expressly stated that the transfer will not affect the rights and obligations of exploration permit and production concession
holders, or the basis for the calculation of royalties, which shall be calculated in accordance with the concession title and paid to the
province where the reservoirs are located.
Law No. 26,197 provides that the Argentine federal government shall retain the authority to grant transportation concessions
for: (i) transportation concessions located within two or more provinces territory and (ii) transportation concessions directly
connected to export pipelines for export purposes. Consequently, transportation concessions which are located within the territory of
only one province and which are not connected to export facilities shall be transferred to the provinces.
Finally, Law No. 26,197 grants the following powers to the provinces: (i) the exercise in a complete and independent manner of
all activities related to the supervision and control of the exploration permits and production concessions transferred by Law
No. 26,197; (ii) the enforcement of all applicable legal and/or contractual obligations regarding investments, rational production and
information and surface fee and royalties payment; (iii) the extension of legal and/or contractual terms; (iv) the application of
sanctions provided in the Hydrocarbons Law; and (v) all the other faculties related to the granting power of the Hydrocarbons Law.
Decree No. 1277/2012
Decree No. 1277/12 derogated main previsions about free availability of hydrocarbons which were specifically contained in
section 5 subsection d) and section 13, 14 and 15 of Decree No. 1055/89, sections 1, 6 and 9 of Decree No. 1212/89 and sections 3
and 5 of Decree No. 1589/89. Decree No. 1277/12 enacted the “Hydrocarbons Sovereignty Regime Rules”, regulating the
Expropriation Law.
This regulation created a commission, that was later dissolved by Decree No. 272/2015, the Commission for Planning and
Strategic Coordination of the National Plan of Hydrocarbons Investments (the “Commission”). This Commission was entrusted with
annually making the National Plan for Hydrocarbons Investments.
Decree No. 1277/12 required every company that performs activities of exploration, exploitation, refining, transport and
commercialization of hydrocarbons to supply the Commission with all technical information required. The Commission was also
responsible for a National Hydrocarbons Investments Registry for all companies performing the activities of exploration, exploitation,
refining, transport and commercialization. All these companies were required to file an annual plan of investments before the
Commission.
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With respect to the refining industry, Decree No. 1277/12 gave the Commission the power to regulate the minimum utilization
rates for primary or secondary refining. It also had the ability to enact measures of promotion and coordination, aimed to guarantee
the development of the local processing capacity according with the goals established by the National Plan of Hydrocarbons
Investments.
With respect to commercialization, the Commission was entitled to publish reference prices of every component of the costs and
sales prices of hydrocarbons and fuels, which should enable the recovery of production costs plus a reasonable profit margin. The
Commission also had to periodically audit the reasonability of the informed costs and the respective sales prices, being entitled to
adopt necessary measures to prevent or correct distortive practices that might affect the interests of consumers.
Decree No. 13/2015
On December 11, 2015, Decree No. 13/2015 was published in the Official Gazette of the Republic of Argentina, modifying the
Ministries Law No. 22,520. Among other changes, it created the Ministry of Energy and Mining, which absorbs the functions of the
Secretaries of Energy and Mining and decentralized entities, from the Ministry of Federal Planning, Public Investment and Services.
The responsibilities of the Ministry of Energy and Mining include participating “in the management of the State’s shareholdings in
the corporations and companies operating in the area of its competence.”
Decree No. 272/2015
On January 4, 2016, Decree No. 272/2015 was published in the Official Gazette of the Republic of Argentina, which modified
Decree No. 1277/12. Among other changes, it dissolved the Commission, derogated certain responsibilities of the Commission and
stated that the tasks assigned to the Commission will be performed by the Ministry of Energy and Mining.
Furthermore, the decree established that the rights derived from the shares owned by the Argentine National State in YPF S.A.
and YPF GAS S.A., with the exception of the shares that belong to the Sustainability Guarantee of the Public Securities Regime
Fund, created by Decree No. 897/07, will be exercised by the Ministry of Energy and Mining, as of its publication date.
In addition, the decree established that the Ministry of Energy and Mining will conduct a comprehensive review and
reorganization regarding the creation of records and information duties in the hydrocarbon industry, which remain in force as long as
they are not derogated by the dispositions of the decree or addressed by the re-organization plan to be determined by the Ministry of
Energy and Mining.
Law No. 27,007, amending the Hydrocarbons Law
On October 31, 2014, Law No. 27,007 amending the Hydrocarbons Law was published in the Official Gazette of the Republic
of Argentina. The Hydrocarbons Law would apply in certain aspects of some of the Company’s existing concessions as well as future
concessions. The most relevant modifications in that law are detailed below.
•
With respect to exploration permits, it distinguishes between those with conventional and unconventional objectives, and
those in which exploration is undertaken in the territorial sea and continental shelf. Law No. 27,007 modifies the basic
time periods governing such activities, from three to two periods and limiting the two basic periods to (i) three years each
for exploration with conventional objectives and (ii) four years each for exploration with unconventional objectives and
(iii) four years each for exploration in the territorial sea or on the continental shelf. In each of these cases, the extension
period of up to five years (already established in the Hydrocarbons Law) is maintained, although it is subject to the permit
holder having complied with its investment and other obligations. At the end of the first basic period and so long as the
permit holder has complied with its obligations under the permit, the permit holder may continue to hold the entire area.
After the second basic period ends, the permit holder may surrender the entire area or, if the holder decides to trigger the
extension period, 50% of the remaining area.
•
In relation to concessions, Law No. 27,007 provides for three types of concessions: conventional production,
unconventional production and production in the territorial sea or on the continental shelf. Each of these concessions will
last 25, 35, and 30 years, respectively. In addition, permit holders or production concessionaires may request
unconventional production concessions on the basis of the development of a pilot plan. So long as the concessionaires
(i) have complied with their obligations, (ii) are producing hydrocarbons in the areas under consideration and (iii) present
an investment plan for the development of such areas as requested by the competent authorities up to a year prior to the
termination of each term of the concession, they may request extension periods of ten years each.
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•
•
•
The amounts to be paid with respect to annual surface fee pursuant to Sections 57 and 58 of the Hydrocarbons Law for the
periods of exploration and production have been increased with the goal of incentivizing exploration and development of
these areas. Additionally, beginning with the second basic exploration period, these may be reduced partially in light of
investments actually carried out in the relevant areas. Restrictions on the number of exploration permits and/or production
concessions that an individual or legal entity may hold were eliminated.
The Hydrocarbons Law established a 35-year term for those concessions granted for the transportation of oil, gas and
petroleum products that holders of production concessions are entitled to receive. Law No. 27,007 modified the awarded
term for hydrocarbon transportation concessions, to be synchronized with the production concession periods.
In connection with exploration and production offerings, tenders may be made by Argentine and foreign companies, with
the goal of obtaining the highest number of tenders possible. In addition, the bidding documents must be prepared by the
competent authorities on the basis of the model bidding document which will be drafted jointly by the competent
authorities of the Provinces and the Argentine Secretariat of Energy. This model bidding document must be prepared
within 180 days of the entry into force of Law No. 27,007. Tenders will be awarded to offerors who present the most
relevant offer, in particular, the one proposing the highest amount of investments or exploratory activity.
•
Royalties have been set at a maximum of 12% on the results of liquid hydrocarbons or natural gas production. Royalties
may be reduced considering productivity of the area and the type of production. In cases of extension periods, an additional
royalty of 3% will be added for each extension, up to a maximum of 18%. In addition, in case of such extensions, the
competent authority may include the payment of an extension bond which maximum amount shall be equal to the result of
multiplying the remaining proved reserves at the end of the concession period to be extended by 2% of the average basin
price, for the two years period prior the moment when the extension is granted, applicable to the hydrocarbons at issue.
•
Law No. 27,007 also provides that the Argentine federal government and the provinces may not establish, in the future,
new areas reserved in favor of state-owned entities or companies with state participation. Further, with respect to existing
reserved areas that do not have association agreements with third parties as of the date of this new law, associative schemes
may be carried out so long as, during the development phase, the participation of state-owned entities or companies with
state participation is proportional to the effective investments promised and carried out by them.
•
Law No. 27,007 additionally incorporates into the Investment Promotion Regime for the Exploration of Hydrocarbons
(Decree 929/2013) projects, as authorized by the Commission, that imply direct investments in foreign currency greater
than U.S.$250 million to be invested during the first three years of the project. Also, it modifies the percentages of
hydrocarbons that, beginning with the third year, will be subject to the benefits of the regime. For conventional and
unconventional production concessions, as well as offshore concessions at depths less than or equal to 90 meters, the
percentage shall be 20%; for offshore concessions at depths greater than 90 meters, the percentage shall be 60%.
•
Within the framework of the Investment Promotion Regime for the Exploration of Hydrocarbons, Law No. 27,007
provides for contributions by companies to the provinces where the projects take place, which amount to 2.5% of the initial
investment amount of the project, to be directed to “Corporate Social Responsibility” contributions. In addition, an amount
to be determined by the Commission in light of the extent of the project, to finance infrastructure, have to be contributed
by the Argentine federal government.
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•
•
Law No. 27,007 establishes that capital goods and inputs that are essential to the execution of the investment plans of
companies registered in the National Registry of Hydrocarbon Investments shall pay import duties as indicated in Decree
927/13 (reduced rates). This list may be extended to other strategic products.
According to Law No. 27,007, the federal government and the provinces shall attempt to establish uniform environmental
legislation and the adoption of uniform fiscal treatment in this sector. The competent authorities, including the Argentine
Secretariat of Energy and the Commission, will promote unification of procedures and registries.
All national off shore permits and off shore hydrocarbon production concessions that had no association agreements with
ENARSA as of the date of the new law reverted and were transferred to the Argentine Secretariat of Energy. Permits and
concessions granted prior to Law No. 25,943 shall be exempted from this provision. The National Executive Office may
negotiate, for 180 days following the enactment of the new law, the conversion of association agreements signed with
ENARSA to permits or production concessions. In September 2015, the National Executive Office and YPF began
negotiating the conversion of association agreements executed with ENARSA. As of the date of this annual report, there
has been no agreement on the conversion.
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Resolution 14/2015
On February 4, 2015, the Commission issued Resolution 14/2015 that created the Crude Oil Production Stimulus Program
(Programa de Estímulo a la Producción de Petróleo Crudo) (the “Program”), which was in force from January 1, 2015 through
December 31, 2015. This Program provided for a payment in Argentine pesos to beneficiary companies, in an amount of up to U.S.
$3.00 per barrel when such company’s quarterly production of crude oil was equal to or greater than the base production level under
the Program, in addition to the compliance with certain other requirements related to the level of activity of the Company as set for
Resolution 33/2015. The base production level under the Program was the total production of crude oil of the beneficiary company
for the fourth quarter of 2014. Those beneficiary companies that had satisfied the demand of all of the domestic refineries operating
within Argentina may direct a portion of their production to the international market and receive an additional payment of U.S. $2.00
or U.S. $3.00 per barrel of crude oil exported, depending on the volume exported.
The payments would be made in Argentine pesos using the Reference Exchange Rate of BCRA Communication “A” 3500 of
the last business day prior to the presentation of the information of the corresponding quarter to the Commission. See “Item 5.
Operating and Financial Review and Prospects—Results of Operations—Revenues.”
Resolution 21/2016
On March 9, 2016, Resolution 21/2016 of the Ministry of Energy and Mining was published in the Official Gazette and
established an export stimulus program of crude oil surplus, after domestic demand for crude oil Escalante from the San Jorge Gulf
Basin is satisfied. The stimulus will be paid for each shipment and to the extent that the average price of Brent oil does not exceed
U.S.$.47 per barrel two days before and two days after the shipment. It is valid until December 31, 2016. The compensation to be
paid by the Argentine government will amount to U.S.$ 7.50 per barrel, as long as the criteria is met.
Public Emergency
On January 6, 2002, the Argentine congress enacted the Public Emergency Law which represented a profound change of the
economic model effective as of that date, and rescinded the Convertibility Law No. 23,928, which had been in effect since 1991 and
had pegged the peso to the dollar on a one-to-one basis. In addition, the Public Emergency Law granted to the National Executive
Office the authority to enact all necessary regulations in order to overcome the economic crisis that Argentina was then facing. The
situation of emergency declared by Law No. 25,561 has been extended until December 31, 2017 by Law No. 27,200. The National
Executive Office is authorized to execute the powers delegated by Law No. 25,561 until such date.
After the enactment of the Public Emergency Law, several other laws and regulations have been enacted to overcome the
economic crisis, including (1) the conversion into pesos of deposit, obligations and tariffs of public services, among others, (2) the
imposition of customs duties on the export of hydrocarbons with instructions to the National Executive Office to set the applicable
rate thereof. The application of these duties and the instruction to the National Executive Office have been extended until January
2017 by Law No. 26,732. See “—Taxation.”
Exploration and Production
The Hydrocarbons Law establishes the basic legal framework for the regulation of oil and gas exploration and production in
Argentina. The Hydrocarbons Law empowers the National Executive Office to establish a national policy for development of
Argentina’s hydrocarbon reserves, with the principal purpose of satisfying domestic demand.
Pursuant to the Hydrocarbons Law, exploration and production of oil and gas is carried out through exploration permits,
production concessions, exploitation contracts or partnership agreements. The Hydrocarbons Law also permits surface reconnaissance
of territory not covered by exploration permits or production concessions upon authorization of the Argentine Secretariat of Energy
and/or competent provincial authorities, as established by Law No. 26,197, and with permission of the private property owner.
Information obtained as a result of surface reconnaissance must be provided to the Argentine Secretariat of Energy and/or competent
provincial authorities, which may not disclose this information for two years without permission of the party who conducted the
reconnaissance, except in connection with the grant of exploration permits or production concessions.
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Under the Hydrocarbons Law, the federal and/or competent provincial authorities may grant exploration permits after submission of
competitive bids. Permits were granted to third parties in connection with the deregulation and demonopolization process and permits covering
areas in which our predecessor company, Yacimientos Petrolíferos Fiscales Sociedad del Estado, was operating at the date of the Privatization
Law were granted to us by such law. In 1991, the National Executive Office established a program under the Hydrocarbons Law (known as Plan
Argentina) pursuant to which exploration permits were auctioned. The holder of an exploration permit has the exclusive right to perform the
operations necessary or appropriate for the exploration of oil and gas within the area specified by the permit. Under the Hydrocarbons Law, each
exploration permit may cover only unproved areas not to exceed 10,000 km2 (15,000 km2 offshore), and may have a term of up to 14 years (17
years for offshore exploration). The 14-year term is divided into three basic terms and one extension term. The first basic term is up to four years,
the second basic term is up to three years, the third basic term is up to two years and the extension term is up to five years. At the expiration of
each of the first two basic terms, the acreage covered by the permit is reduced, at a minimum, to 50% of the remaining acreage covered by the
permit, with the permit holder deciding which portion of the acreage to keep. At the expiration of the three basic terms, the permit holder is
required to surrender all of the remaining acreage to the Argentine government, unless the holder requests an extension term, in which case such
grant is limited to 50% of the remaining acreage. Under Law No. 27,007, which will apply to future exploration permits, each exploration permit
may have a term of up to 11 years for conventional objectives and 13 years for unconventional objectives and offshore exploration. The terms are
divided into two basic terms and one extension term. The first and second basic terms are up to three years, for conventional objectives and up to
four years for unconventional objectives and offshore exploration, and the extension term is up to five years, so long as the permit holder has
complied with its investments and other obligations. At the expiration of the first basic term, the permit holder will have the right to continue
exploring the entire area for the second basic term so long as it has complied with all its obligations under the permit. At the expiration of the
second basic term, the permit holder is required to surrender all of the remaining acreage, unless the holder requests an extension term, in which
case such grant is limited to 50% of the remaining acreage.
If the holder of an exploration permit discovers commercially exploitable quantities of oil or gas, the holder has the right to obtain an
exclusive concession for the production and development of this oil and gas. The Hydrocarbons Law, as modified by Law No. 27,007, provides
that new conventional oil and gas production concessions shall remain in effect for 25 years from the date of the award of the production
concession, new unconventional oil and gas production concessions shall remain in effect for 35 years from that date, and new offshore oil and
gas production concessions shall remain in effect for 30 years from that date, in addition to any remaining exploration term at the date of such
award. The Hydrocarbons Law, as modified by Law No. 27,007, further provides for the concession term to be extended for periods of up to ten
additional years each, subject to terms and conditions approved by the grantor at the time of the extension. Such conditions may include the
payment of an extension bond with a maximum amount equal to the result of multiplying the remaining proved reserves at the end of the
concession period by 2% of the average basin price, for the period two years prior to the date the extension is granted, applicable to the
hydrocarbons at issue. Under Law No. 26,197, the authority to extend the terms of current and new permits and concessions has been vested in
the governments of the provinces in which the relevant block is located (and the Argentine government in respect of offshore blocks beyond
twelve nautical miles). In order to be entitled to the extension, a concessionaire, such as us, must have complied with all of its obligations under
the Hydrocarbons Law, including, without limitation, evidence of payment of taxes and royalties and compliance with environmental, investment
and development obligations, must be producing hydrocarbons in the area at issue and must present an investment plan to develop the
concession. A production concession also confers on the holder the right to conduct all activities necessary or appropriate for the production of
oil and gas, provided that such activities do not interfere with the activities of other holders of exploration permits and production concessions. A
production concession entitles the holder to obtain a transportation concession for the oil and gas produced. See “—Transportation of Liquid
Hydrocarbons.”
Exploration permits and production concessions require holders to carry out all necessary work to find or extract hydrocarbons, using
appropriate techniques, and to make specified investments. In addition, holders are required to:
•
•
•
avoid damage to oil fields and waste of hydrocarbons;
adopt adequate measures to avoid accidents and damage to agricultural activities, fishing industry, communications networks and the
water table; and
comply with all applicable federal, provincial and municipal laws and regulations.
According to the Hydrocarbons Law, holders of production concessions, including us, are also required to pay royalties to the province
where production occurs. As modified by Law No. 27,007, royalty rates are set at a maximum of 12% (though 3% will be added for each
extension up to a maximum of 18%). They are payable on the value at the wellhead (equal to the price upon delivery of the product, less
transportation, treatment costs and other deductions) of crude oil production and natural gas volumes sold. These royalty rates may be reduced
considering productivity and the type of production at issue. Notwithstanding the foregoing, in concessions extended prior to the entry into force
of Law No. 27,007, the previous conditions adopted remain in force. In some cases, an additional 3% royalty has been added. See “—Extension
of Exploitation Concessions in the province of Neuquén, —Mendoza, —Salta, —Santa Cruz, —Chubut and —Tierra del Fuego.” In the
extension of our concessions in Santa Cruz, we agreed to a 10% royalty (instead of 12%) for unconventional hydrocarbons. The value is
calculated based upon the volume and the sale price of the crude oil and gas produced, less the costs of transportation and storage. In addition,
pursuant to Resolution S.E. 435/04 issued by the Argentine Secretariat of Energy, if a concession holder allots crude oil production for further
industrialization processes at its plants, the concession holder is required to agree with the provincial authorities or the Argentine Secretariat of
Energy, as applicable, on the reference price to be used for purposes of calculating royalties.
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As a result of Resolution 394/07 of the Ministry of Economy, among other things, which increased duties on exports of certain
hydrocarbons, Argentine companies began to negotiate the price for crude oil in the domestic market, which would in turn be used as
the basis for calculation of royalties. In January 2013, the Ministry of Economy issued Resolution 1/13, modifying exhibit I of
Resolution 394/07 of the Ministry of Economy, thus setting a new reference price for crude oil (U.S.$70 per barrel) and certain
products. In October 2014, the Ministry of Economy issued Resolution 803/2014 incorporating exhibit III to Resolution 394/07 of the
Ministry of Economy, thus modifying the applicable percentages of duties of exports for certain products below certain prices.
However, on December 29, 2014 Resolution 1077/2014 repealed Resolution 394/07, as amended, and set forth a new
withholding program based on the international price of crude oil (the “International Price”). The International Price is calculated
based on the Brent value for the applicable month less U.S.$8 per barrel. The new program establishes a 1% general nominal
withholding applicable to all products covered by the resolution, including crude oil, diesel, gasoline and lubricants as well as other
petroleum products, to the extent that the International Price is below U.S.$71 per barrel. The resolution further provides an
increasing variable withholding rate for crude exports oil exports to the extent the International Price exceeds U.S.$71 per barrel. As a
result, the maximum a producer may charge is approximately U.S.$70 per barrel exported, depending on the quality of crude sold.
The resolution also sets forth increasing withholding rates for exports of diesel, gasoline, lubricants and other petroleum when the
International Price exceeds U.S.$71 per barrel at rates that allow the producer to receive a portion of the elevated price.
In addition to the above, the Public Emergency Law, which created the export withholdings, established that export
withholdings were not to be deducted from the export price for purposes of calculating the 12% royalties. The royalty expense
incurred in Argentina is accounted for as a production cost (as explained in “Exploration and Production—Oil and gas production,
production prices and production costs”). According to the Hydrocarbons Law, any oil and gas produced by the holder of an
exploration permit prior to the grant of a production concession is subject to the payment of a 15% royalty.
Furthermore, pursuant to Sections 57 and 58 of the Hydrocarbons Law, holders of exploration permits and production
concessions must pay an annual surface fee that is based on acreage of each block and that varies depending on the phase of the
operation, such as exploration or production, and in the case of the former, depending on the relevant period of the exploration
permit. These amounts were updated by Law No. 27,007 and may be partially adjusted as from the second basic exploration period in
light of investments actually carried out. Exploration permits and production or transportation concessions may be terminated upon
any of the following events:
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•
•
•
•
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•
failure to pay annual surface taxes within three months of the due date;
failure to pay royalties within three months of the due date;
substantial and unjustifiable failure to comply with specified production, conservation, investment, work or other
obligations;
repeated failure to provide information to, or facilitate inspection by, authorities or to utilize adequate technology in
operations;
in the case of exploration permits, failure to apply for a production concession within 30 days of determining the existence
of commercially exploitable quantities of hydrocarbons;
bankruptcy of the permit or concession holder;
death or end of legal existence of the permit or concession holder; or
failure to transport hydrocarbons for third parties on a non-discriminatory basis or repeated violation of the authorized
tariffs for such transportation.
The Hydrocarbons Law further provides that a cure period, of a duration to be determined by the Argentine Secretariat of
Energy and/or the competent provincial authorities, must be provided to the defaulting concessionaire prior to the termination.
When a production concession expires or terminates, all oil and gas wells, operating and maintenance equipment and facilities
automatically revert to the province where the reservoir is located or to the Argentine federal government in the case of reservoirs
under federal jurisdiction (for instance, located on the continental shelf or beyond 12 nautical miles offshore), without compensation
to the holder of the concession.
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Certain of our production concessions expire in 2017. See “Item 3. Key Information—Risk Factors—Risks Relating to the
Argentine Oil and Gas Business and Our Business—Argentine oil and gas production concessions and exploration permits are subject
to certain conditions and may be cancelled or not renewed.” The granting of an extension is an unregulated process and normally
involves lengthy negotiations between the applicant and the relevant government. Although the Hydrocarbons Law, as modified,
provides that applications must be submitted at least one year prior to the concession expiration date, it is industry practice to
commence the process far earlier, typically as soon as the technical and economic feasibility of new investment projects beyond the
concession term become apparent.
On March 16, 2006, the Argentine Secretariat of Energy issued Resolution S.E. No. 324/06 requiring that holders of exploration
permits and hydrocarbon concessions must file with such agency details of their proved reserves existing in each of their areas,
certified by an external reserves auditor, each year. Holders of hydrocarbon concessions that export hydrocarbons are obliged to
certify their oil and gas proved reserves. The aforementioned certification only has the meaning established by Resolution S.E.
No. 324/06, according to which it is not to be interpreted as a certification of oil and gas reserves under the SEC rules. See “—
Exploration and Production Overview—Oil and Gas Reserves.”
In March 2007, the Argentine Secretariat of Energy issued Resolution No 407/07 that approved new regulations concerning the
Oil and Gas Exploration and Production Companies Registry. According to Resolution No. 407/07, YPF, as a holder of production
concessions and exploration permits, is banned from hiring or in any way benefiting from any company or entity which is developing
or has developed oil and gas exploration activities within the Argentine continental platform without an authorization from the
relevant Argentine authorities.
Extension of Exploitation Concessions in the province of Neuquén
In addition to the extension in 2002 of the expiration date of the exploitation concession of the Loma La Lata field until 2027,
during the years 2008 and 2009, YPF entered into a number of agreements with the province of Neuquén, pursuant to which the
exploitation concession terms of several areas located within the province were extended for a 10-year term, which now expire
between 2026 and 2027. As a condition to the extension of the concession terms, YPF has undertaken to do the following under the
relevant agreements: (i) to make initial payments to the province of Neuquén in an aggregate amount of approximately U.S.$204
million; (ii) to pay the province of Neuquén an extraordinary production royalty of 3% of the production of the areas affected by this
extension (in addition, the parties agreed to make additional adjustments of up to an additional 3% in the event of extraordinary
income, as defined in each agreement); (iii) to carry out exploration activities in the remaining exploration areas and make certain
investments and expenditures until the expiration of the concessions in an aggregate amount of approximately U.S.$3,512 million;
and (iv) to make corporate social responsibility contributions to the province of Neuquén in an aggregate amount of approximately
U.S.$23 million.
Decree No. 1208/2013 of the province of Neuquén approves an agreement entered into between the province of Neuquén and
YPF dated July 24, 2013, that (i) separates from the Loma La Lata—Sierra Barrosa concession a surface area of 327.5 km2;
(ii) incorporates the separated surface area into the Loma Campana concession and (iii) extends the Loma Campana concession to
November 11, 2048, according to Decree 929/13.
Extension of Exploitation Concessions in the province of Mendoza
In April 2011, YPF entered into an agreement with the province of Mendoza to extend the term of the exploitation concessions
identified below, and the transportation concessions located within the province, which was ratified by a decree published in July
2011.
The agreement between YPF and the province of Mendoza provides, inter alia, the following:
•
•
Concessions involved: El Portón, Barrancas, Cerro Fortunoso, El Manzano, La Brea, Llancanelo, Llancanelo R, Puntilla de
Huincán, Río Tunuyan, Valle del Río Grande, Vizcacheras, Cañadón Amarillo, Altiplanicie del Payún, Chihuido de la
Sierra Negra, Puesto Hernández and La Ventana;
Exploitation concession terms, which were originally set to expire in 2017, were extended for a 10-year term to 2027; and
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YPF agreed:
(i) to make initial payments to the province of Mendoza in an aggregate amount of approximately U.S.$135 million; (ii) to
pay the province of Mendoza an extraordinary production royalty of 3% of the production of the areas included in the
agreement; (iii) a fee for extraordinary income based on 10%, 15% or 20% of the difference between the price actually
received by YPF and certain benchmarks set out in the agreement; (iii) to carry out exploration activities in the remaining
exploration areas and make certain investments and expenditures in a total amount of U.S.$4.1 billion until the expiration
of the extended term; (iv) to contribute U.S.$16.2 million to a social infrastructure investment fund to satisfy community
needs in the province of Mendoza; and (v) to make payments equal to 0.3% of the annual amount paid as extraordinary
production royalty in order to fund the purchase of equipment and finance training activities in certain government
agencies of the province of Mendoza.
Extension of Exploitation Concessions in the province of Santa Cruz
In November 2012, YPF entered into an agreement with the province of Santa Cruz to extend the term of the exploitation
concessions identified below, which was ratified by a provincial law published on November 2012.
The agreement between YPF and the province of Santa Cruz provides, inter alia, the following:
•
•
•
Concessions involved: Cerro Piedra-Cerro Guadal Norte; Cañadón de la Escondida-Las Heras; Cañadón León-Meseta
Espinosa; Los Monos; Pico Truncado-El Cordón; Los Perales-Las Mesetas; El Guadal-Lomas del Cuy; Cañadón Vasco;
Cañadón Yatel, Magallanes (portion located in Santa Cruz) and Barranca Yankowsky;
Exploitation concession terms, which were originally set to expire in 2017, were extended for a 25-year term to 2042; and
YPF has undertaken:
(i)
(ii)
(iii)
(iv)
(v)
to make initial payments to the province of Santa Cruz in an aggregate amount of approximately of U.S.$200
million;
to pay the province of Santa Cruz a Production Royalty of 12% plus an additional 3% on the production of
conventional hydrocarbons, and 10% on the production of unconventional hydrocarbons;
to carry out exploration activities in the remaining exploration areas and make certain investments and
expenditures on the exploitation concessions;
to contribute with infrastructure investments within the province of Santa Cruz in an amount equivalent to 20%
of the initial payment, and;
to contribute to an “Institutional Strengthening Fund” and to carry out a program for technical formation (YPF
y los Trabajadores) and a program for development of contractors (Sustenta) within the province of Santa
Cruz.
Negotiation of Extension of Concessions in the province of Tierra del Fuego
The Company has negotiated with the Executive Office of the province of Tierra del Fuego the terms in order to extend the
Tierra del Fuego and Chorrillos exploitation concessions which are jointly held by YPF (30%), Petrolera LF Company S.R.L. (35%),
and Petrolera TDF Company S.R.L. (35%). Petrolera LF Company S.R.L. and Petrolera TDF Company S.R.L. were subsidiaries of
Apache which we acquired in 2013. The final agreement was executed by the province of Tierra del Fuego, YPF, Petrolera LF
Company S.R.L. and Petrolera TDF Company S.R.L. on December 18, 2013. The agreement was ratified by the Parliament of the
province of Tierra del Fuego on October 10, 2014 through the enactment of Provincial Law No. 998. The agreement grants an
extension of the Tierra del Fuego concession until November 2027 and an extension of the Chorrillos concession until April 2026.
As of the date of this annual report, the Company had not filed the request to extend the portion of the Magallanes concession
located in the province of Tierra del Fuego.
Extension of Concessions in the province of Chubut
The Company has obtained the extension of the following concessions in the Province of Chubut:
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El Tordillo – La Tapera and Puesto Quiroga Exploitation Concessions: On October 2, 2013 the province of Chubut
published the Provincial law approving the agreement for the extension of the El Tordillo, La Tapera and Puesto Quiroga
concessions located in the province of Chubut. YPF holds a 12.196% interest in these concessions while Petrobras
Argentina S.A. holds a 35.67% interest and Tecpetrol S.A. holds the remaining 52.133%. The concessions were extended
for a period of 30 years from the original 2017 expiration. The following are the main terms and conditions of the
extension agreement entered into by and between the province of Chubut and the parties that hold interests in the
concessions:
(i)
(ii)
To make initial payments to the province of Chubut in an aggregate amount of U.S.$18 million.
To pay an “Extraordinary Production Royalty” of 4% of the production of the areas included in the extension.
(iii) To make disbursements and investments aimed at the conservation and protection of the environment.
(iv)
To maintain operational a minimum number of drilling and work-over rigs.
(v)
Upon expiration of the first ten years of the extension period, the Parties shall transfer and assign to
Petrominera S.E., the provincial oil company, a 10% interest in the areas covered by the extension agreement.
•
Restinga Alí, Sarmiento, Campamento Central – Cañadón Perdido, Manantiales Behr and El Trébol—Escalante –
Escalante Exploitation Concessions: On December 26, 2013 YPF executed an agreement with the province of Chubut for
the extension of the original term of duration of these concessions. YPF holds a 100% interest in all the concessions except
for the Campamento Central – Cañadón Perdido Concession where ENAP Sipetrol S.A. and YPF each hold a 50% interest.
The concessions were extended for a period of 30 years following the expiration of the original concession terms, which
would have expired in 2017 (Campamento Central – Cañadón Perdido and El Trébol – Escalante), 2015 (Restinga Alí) and
2016 (Manantiales Behr).
The following are the main terms and conditions agreed by and between YPF and the province of Chubut.
(i)
(ii)
To make initial payments to the province of Chubut in an aggregate amount of U.S.$30 million.
To pay an “Extraordinary Production Royalty” of 3% of the production of the areas included in the extension
agreement.
(iii) To comply with a minimum investment program.
(iv)
To maintain a minimum number of drilling and work-over rigs operational.
(v)
To assign to Petrominera S.E., 41% of YPF’s interest in the El Tordillo, La Tapera and Puesto Quiroga
exploitation concessions (equal to 5% of the total interest in the concessions).
ENAP Sipetrol S.A. has agreed to fulfill the obligations set forth in the extension agreement on a pro-rata basis relative to its
participation interest in the Campamento Central – Cañadon Perdido concession agreement.
Extension of Exploitation Concessions in the province of Salta
In October 2012, YPF entered into an agreement with the province of Salta to extend the original terms of the exploitation
concessions identified below, subject to the approval of the National Executive Office by decree.
The agreement was approved by Resolution No. 35/12 of Salta’s Secretariat of Energy on October 26, 2012 and Decree 3694/12
on December 6, 2012. The agreement was signed between YPF, Tecpetrol S.A., Petrobras Argentina S.A., Compañía General de
Combustibles S.A. and Ledesma S.A.A.I. and the province of Salta, and provides for the following:
•
•
Concessions involved: Sierras de Aguaragüe, Campo Durán-Madrejones, La Bolsa and Río Pescado.
Exploitation concession terms are extended for a 10-year term following the expiration of the original 25 year term, until
November 14, 2027.
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YPF has agreed:
(i)
(ii)
(iii)
to conduct in Aguaragüe, the following investments: a minimum level of activity in development plans,
involving the drilling of development wells (at least three) and expansion of production facilities and treatment
of hydrocarbons of U.S.$36 million,
to pay the province a special extraordinary contribution equal to 25% of the amount corresponding to royalties
of 12% referred to in Article 59 and 62 of the Hydrocarbons Law,
to pay the province an additional payment, when extraordinary income the sale of crude oil and natural gas
from the concessions, under conditions where prices exceed U.S.$90/bbl in the case of crude oil and the
equivalent of 70% of import prices in the case of natural gas,
(iv)
to pay the province, in aggregate, a one-time amount of U.S.$5 million as an extension bonus,
(v)
to make investments for a minimum amount of U.S.$30 million in aggregate in additional exploration work to
be implemented in the concessions, subject to certain conditions and
(vi)
to invest U.S.$1 million in aggregate in the implementation of social infrastructure projects in the province.
Extension of Exploitation Concessions in the province of Río Negro
In December 2014, YPF entered into an agreement with the province of Río Negro to extend the original terms of the
exploitation concessions identified below. Effectiveness of the agreement was subject to the ratification of its terms by the Parliament
of the province of Río Negro that was granted on December 30, 2014 through the enactment of Provincial Law No. 5027.
The agreement was signed between YPF, YSUR Energia Argentina S.R.L. (formerly named Apache Energia Argentina S.R.L.),
YSUR Petrolera Argentina S.A. (formerly named Apache Petrolera Argentina S.A.) and the province of Río Negro and provides the
following:
•
Concessions involved: (i) El Medanito, Barranca De Los Loros, Señal Picada-Punta Barda, Bajo Del Piche and Los
Caldenes, where YPF holds a 100% undivided interest; (ii) Estacion Fernandez Oro, where YSUR Energia Argentina
S.R.L. holds a 100% undivided interest; and (iii) El Santiagueño, where YSUR Petrolera Argentina S.A. holds a 100%
undivided interest.
•
Exploitation concession terms are extended for a 10-year term following the expiration of the original 25 year term, until
November 14, 2027, except for the exploitation concessions in (i) Los Caldenes which was extended until September 18,
2036, (ii) Estacion Fernández Oro which was extended until August 16, 2026 and (iii) El Santiagueño which was extended
until September 6, 2025.
•
YPF has agreed:
(i)
(ii)
to make an initial payment to the Province of Río Negro in an aggregate amount of U.S.$46 million;
to make contributions to social development and institutional strengthening within the province of Río Negro
in an amount equivalent to 20% of the initial payment;
(iii)
to pay an “Extraordinary Production Royalty” of 3% of the monthly production;
(iv)
to contribute annually to training, research and development, the amount depends on the volume of production;
(v)
to comply with a minimum investment program; and
(vi)
to make disbursements and investments aimed at the conservation and protection of the environment.
Extension of Exploitation Concessions in the Cuenca Marina Austral
The National Executive Office (Poder Ejecutivo Nacional), through Administrative Decision No. 1/2016 published January 8,
2016 in the Official Gazette of the Republic of Argentina, extended the term of the hydrocarbon exploitation concession in the
Magallanes area held by YPF in the Marina Austral basin, as of November 14, 2017, for ten years, in the section corresponding to the
jurisdiction granted by the Argentine federal government, pursuant to Article 35 of the Hydrocarbons Law No. 17,319.
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Additionally, Administrative Decision No. 1/2016 establishes the following terms and conditions, among others: (i) approval of
the investment and works plan for the above-referenced concession from 2017 to 2027, (ii) payment of U.S.$12.5 million as an
extension bonus with respect to the section corresponding to the jurisdiction granted by the Argentine federal government, and
(iii) payment to the Argentine Federal Government of 15% royalties on the production of hydrocarbons extracted from the section of
the Magallanes area under its jurisdiction, in accordance with Article 59, paragraph 2 of Law No. 27,007.
Security Zones Legislation
Argentine law restricts the ability of non-Argentine companies to own real estate, oil concessions or mineral rights located
within, or with respect to areas defined as, security zones (principally border areas).
Additionally, prior approval of the Argentine government is required:
•
•
for non-Argentine shareholders to acquire control of us; or
if and when the majority of our shares belong to non-Argentine shareholders, as was the case when we were controlled by
Repsol for any additional acquisition of real estate, mineral rights, oil or other Argentine government concessions located
within, or with respect to, security zones.
Natural Gas Transportation and Distribution
The gas transmission system is currently divided into two systems principally on a geographical basis (the northern and the
southern trunk pipeline systems), designed to give both systems access to gas sources and to the main centers of demand in and
around Buenos Aires. These systems are operated by two transportation companies. In addition, the distribution system is divided into
nine regional distribution companies, including two distribution companies serving the greater Buenos Aires area.
The regulatory structure for the natural gas industry creates an open-access system, under which gas producers, such as us, will
have open access to future available capacity on transmission and distribution systems on a non-discriminatory basis.
Cross-border gas pipelines were built to interconnect Argentina, Chile, Brazil and Uruguay, and producers such as us had been
exporting natural gas to the Chilean and Brazilian markets, to the extent permitted by the Argentine government. During the last
several years the Argentine authorities have adopted a number of measures restricting exports of natural gas from Argentina,
including issuing domestic supply instruction pursuant to Regulation No. 27/04 and Resolutions Nos. 265/04, 659/04 and 752/05
(which require exporters to supply natural gas to the Argentine domestic market), issuing express instructions to suspend exports,
suspending processing of natural gas and adopting restrictions on natural gas exports imposed through transportation companies
and/or emergency committees created to address crisis situations. See “—Market Regulation— Natural gas export administration and
domestic supply priorities.”
Transportation of Liquid Hydrocarbons
The Hydrocarbons Law No. 17,319 permits the National Executive Office to award 35-year concessions for the transportation of
oil, gas and petroleum products following submission of competitive bids. Pursuant to Law No. 26,197, the relevant provincial
governments have the same powers. Holders of production concessions are entitled to receive a transportation concession for the oil,
gas and petroleum products that they produce. The term of a transportation concession may be extended for an additional ten-year
term upon application to the National Executive Office.
The Hydrocarbons Law No. 27,007, which will apply to future concessions, other than those already governed by previous laws,
for the transportation of liquid hydrocarbons, permits the National Executive Office to award concessions for the transportation of oil,
gas and petroleum products for terms equivalent to those granted for production concessions linked to those transport concessions,
following submission of competitive bids. The term of a transportation concession may be extended for additional terms equivalent to
those of the associated production concession. The holder of a transportation concession has the right to:
•
•
transport oil, gas and petroleum products; and
construct and operate oil, gas and products pipelines, storage facilities, pump stations, compressor plants, roads, railways
and other facilities and equipment necessary for the efficient operation of a pipeline system.
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The holder of a transportation concession is obligated to transport hydrocarbons for third parties on a non-discriminatory basis
for a fee. This obligation, however, applies to producers of oil or gas only to the extent that the concession holder has surplus capacity
available and is expressly subordinated to the transportation requirements of the holder of the concession. Transportation tariffs are
subject to approval by the Argentine Secretariat of Energy for oil and petroleum pipelines and by ENARGAS for gas pipelines. Upon
expiration of a transportation concession, the pipelines and related facilities automatically revert to the Argentine government without
payment to the holder. The Privatization Law granted us a 35-year transportation concession with respect to the pipelines operated by
Yacimientos Petrolíferos Fiscales Sociedad del Estado at the time. Gas pipelines and distribution systems sold in connection with the
privatization of Gas del Estado are subject to a different regime as described above.
Additionally, pursuant to Law No. 26,197, all transportation concessions located entirely within a province’s jurisdiction and not
directly connected to any export pipeline are to be transferred to such province. The National Executive Office retains the power to
regulate and enforce all transportation concessions located within two or more provinces and all transportation concessions directly
connected to export pipelines.
Refining
Crude oil refining activities conducted by oil producers or others are subject to prior registration of oil companies in the registry
maintained by the Argentine Secretariat of Energy and compliance with safety and environmental regulations, as well as to provincial
environmental legislation and municipal health and safety inspections.
In January 2008, the Argentine Secretariat of Domestic Commerce issued Resolution No. 14/2008, whereby the refining
companies were instructed to optimize their production in order to obtain maximum volumes according to their capacity.
Executive Decree No. 2014/08 of November 25, 2008, created the “Refining Plus” program to encourage the production of
diesel and gasoline. The Argentine Secretariat of Energy, by Resolution S.E. No. 1312/08 of December 1, 2008, approved the
regulations of the program. Pursuant to this program, refining companies that undertook the construction of a new refinery or the
expansion of their refining and/or conversion capacity, and whose plans were approved by the Argentine Secretariat of Energy, were
entitled to receive export duty credits to be applied to exports of products within the scope of Resolution No. 394/07 and Resolution
No. 127/08 (Annex) issued by the Ministry of Economy. In February 2012, by Notes Nos. 707/12 and 800/12 (the “Notes”) of the
Argentine Secretariat of Energy, YPF was notified that the benefits granted under the “Refining Plus” program had been temporarily
suspended. The effects of the suspension extend to benefits accrued and not yet redeemed by YPF at the time of the issuance of the
Notes. The reasons alleged for such suspension were that the “Refining Plus” program had been created in a context where domestic
prices were lower than prevailing prices and that the objectives sought by the program had already been achieved. On March 16,
2012, YPF challenged this temporary suspension.
Market Regulation
Overview
Under the Hydrocarbons Law and the Oil Deregulation Decrees, holders of production concessions, such as us, have the right to
produce and own the oil and gas they extract and are allowed to sell such production in the domestic or export markets, in each case
subject to the conditions described below.
The Hydrocarbons Law authorizes the National Executive Office to regulate the Argentine oil and gas markets and prohibits the
export of crude oil during any period in which the National Executive Office finds domestic production to be insufficient to satisfy
domestic demand. If the National Executive Office restricts the export of crude oil and petroleum products or the sale of natural gas,
the Oil Deregulation Decrees provide that producers, refiners and exporters shall receive a price for the crude oil and petroleum
products, not lower than that of imported crude oil and petroleum products of similar quality.
Furthermore, the Oil Deregulation Decrees required the National Executive Office to give twelve months’ notice of any future
export restrictions. Notwithstanding the above provisions, certain subsequently-enacted resolutions (Resolution S.E. 1679/04,
Resolution S.E. 532/04 and Resolution of the Ministry of Economy 394/07) have modified the aforementioned price mechanism,
resulting, in certain cases, in prices to producers that are below the levels described above.
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In addition, in May 2012, the Expropriation Law was passed by the Argentine congress and became effective. The
Expropriation Law declared achieving self-sufficiency in the supply of hydrocarbons, as well as in the exploitation, industrialization,
transportation and sale of hydrocarbons, a national public interest and a priority for Argentina. In addition, its stated goal is to
guarantee socially equitable economic development, the creation of jobs, the increase of the competitiveness of various economic
sectors and the equitable and sustainable growth of the Argentine provinces and regions. Furthermore, Decree No. 1277/12 derogated
the main previsions about free availability of hydrocarbons which were specifically contained in section 5 subsection d) and section
13, 14 and 15 of Decree No. 1055/89, sections 1, 6 and 9 of Decree No. 1212/89 and sections 3 and 5 of Decree No. 1589/89 (the
“Oil Deregulation Decrees”). Decree No. 1277/12 enacted the “Hydrocarbons Sovereignty Regime Rules,” regulating Law
No. 26,741. This regulation created the Commission, which among other matters was entitled to publish reference prices of every
component of the costs and sales prices of hydrocarbons and fuels, which should permit recovery of production costs and obtaining a
reasonable profit margin. See “—The Expropriation Law” and “—Decree No. 1277/2012” and “—Decree No. 272/2015.”
On July 15, 2013, Decree No. 929/2013 was published in the Official Gazette and provides for the creation of an Investment
Promotion Regime for the Exploitation of Hydrocarbons (the “Promotion Regime”), both for conventional and unconventional
hydrocarbons to be applied across the Argentine territory. Applications to be included in this Promotion Regime may be filed by
subjects duly registered with the National Registry of Hydrocarbon Investments who are holders of exploration permits and/or
exploitation concessions and/or third parties associated with those holders and who submit an Investment Project for Hydrocarbon
Exploitation (the “Investment Project”) to the Commission of Strategic Planning and Coordination of the National Hydrocarbons
Investment Plan created by Decree No. 1,277/12, entailing a direct investment in foreign currency of at least U.S.$1 billion,
calculated at the time of submission of the Investment Project, and to be invested in the first five years of the Investment Project.
Beneficiaries of this Promotion Regime shall enjoy the following benefits, among others: i) they shall be entitled, under the terms of
the Hydrocarbons Law, from the fifth anniversary of the start-up of their respective Investment Project, to freely export 20% of the
production of liquid and gaseous hydrocarbons produced under such Investment Projects, at a 0% export tax rate, if applicable; ii)
they shall freely dispose of 100% of the proceeds derived from the export of the hydrocarbons mentioned in i) above, provided the
approved Investment Project would have generated an inflow of foreign currency into Argentina’s financial market equal to at least
U.S.$1 billion, following the requirements mentioned above; iii) if hydrocarbon production in Argentina is not enough to cover
domestic supply needs in accordance with section 6 of the Hydrocarbons Law, beneficiaries of the Promotion Regime, from the fifth
anniversary of the start-up of their respective Investment the Projects, shall be entitled to obtain, in relation to the aforementioned
exportable rate of liquid and gaseous hydrocarbons produced in the Investment Projects, a price not lower than the reference export
price calculated without deducting any export duties that would have been applicable. Law No. 27,007, as described above, has
incorporated into this regime projects submitted to the Commission of Strategic Planning and Coordination of the National
Hydrocarbons Investment Plan entailing a direct investment in foreign currency of at least U.S.$250 million, calculated at the time of
submission of the Investment Project, and to be invested in the first three years of the Investment Project. Further, Law 27,007
modifies the percentages of hydrocarbons to be benefitted under this regime to 20% of the production of conventional,
unconventional and offshore concessions at depths less than or equal to 90 meters and 60% of the production of offshore concessions
at depths greater than 90 meters. See “—Law 27,007, amending the Hydrocarbons Law” and “Decree No. 272/2015.”
Additionally, the decree discussed above created a new type of concession for the “Exploitation of Unconventional
Hydrocarbons,” which has been incorporated in the Hydrocarbons Law by Law No. 27,007, consisting of the extraction of liquid
and/or gaseous hydrocarbons through unconventional stimulation techniques applied to reservoirs located in geological formations of
schist and slates (shale gas or shale oil), tight sands (tight oil and tight gas), coal layers (coal bed methane) and, in general, from any
reservoir that presents low-permeability rock as its main feature. The Decree provides that holders of exploration permits and/or
exploitation concessions that are beneficiaries of the Promotion Regime shall be entitled to apply for a “Concession for
Unconventional Hydrocarbons Exploitation.” Likewise, holders of a Concession for Unconventional Hydrocarbons Exploitation who
are also holders of an adjacent and pre-existing concession may request the unification of both areas into a single unconventional
exploitation concession, provided the geological continuity of such areas is duly proven.
As noted above, Law No. 27,007 provides for contributions by companies to the provinces where the projects take place, which
amount to 2.5% of the initial investment amount of the project, to be directed to “Corporate Social Responsibility” contributions. In
addition, an amount to be determined by the Commission in light of the extent of the project, to finance infrastructure, have to be
contributed by the Argentine federal government. Finally, Law No. 27,007 establishes that capital goods and inputs that are essential
to the execution of the investment plans of companies registered in the National Registry of Hydrocarbon Investments shall pay
import duties indicated in Decree 927/13 (reduced rates). This list may be extended to other strategic products.
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Production of crude oil and reserves
Executive Decree No. 2014/08 of November 25, 2008, created the “Petroleum Plus” program to encourage the production of
crude oil and the increase of reserves through new investments in exploration and development. The Argentine Secretariat of Energy,
by Resolution S.E. No. 1312/08 of December 1, 2008, approved the regulations of the program. The program entitled production
companies which increased their production and reserves within the scope of the program, and whose plans were approved by the
Argentine Secretariat of Energy, to receive export duty credits to be applied to exports of products within the scope of Resolution No.
394/07 and Resolution No. 127/08 (Annex) issued by the Ministry of Economy. In February 2012, YPF was notified by the Argentine
Secretariat of Energy that the benefits granted under the “Petroleum Plus” program had been temporarily suspended. The effects of
the suspension extend to benefits accrued and not yet redeemed by YPF at the time of the issuance of the notice. The reasons stated
for the suspension were that the “Petroleum Plus” program had been created in a context where domestic prices were lower than
prevailing prices and that the objectives sought by the program had already been achieved. On March 16, 2012, YPF challenged this
temporary suspension. Executive Decree No. 1330/2015 of July 13, 2015 provided for the termination of the “Petroleum Plus”
program, establishing compensation in BONAR 2024 Argentine public bonds. As of the date of this report, YPF has not been
compensated for the benefits accrued and not yet redeemed by YPF.
Refined products
In April 2002, the Argentine government and the main oil companies in Argentina, including us, reached an agreement on a
subsidy provided by the Argentine government to public bus transportation companies. The Agreement on Stability of Supply of
Diesel was approved by Executive Decree No. 652/02 and assured the transportation companies their necessary supply of diesel at a
fixed price of Ps.0.75 per liter from April 22, 2002 to July 31, 2002. Additionally, it established that the oil companies are to be
compensated for the difference between this fixed price and the market price through export duty credits. Subsequent agreements
entered into between the Argentine government and the main oil companies in Argentina extended the subsidy scheme until
December 2009, while the aforementioned fixed price was revised from time to time.
In March 2009, Executive Decree No. 1390/09 empowered the Chief of Staff to sign annual agreements extending the diesel
subsidy to transportation companies for the fiscal year 2009 and until the end of the public emergency declared by the Public
Emergency Law and its amendments, and instructed such official to incorporate the necessary modifications in order to extend the
possibility to compensate with export duty credits on all hydrocarbon products currently exported, or with cash. As of the date of this
annual report, execution of the annual agreements for the fiscal years 2010 and 2011 is pending. Nevertheless, the subsidy scheme
has continued to be in place on the basis of the monthly communications issued by the Argentine Secretariat of Transport notifying
oil companies of the volumes to be delivered to each beneficiary of the scheme at the fixed price, and the Argentine government has
continued to compensate oil companies for deliveries of diesel made under the scheme.
In addition, on January 11, 2012, the Argentine Secretary of Transport filed with the National Antitrust Commission (“CNDC”)
a complaint against five oil companies (including YPF) for alleged abuse of a dominant position regarding bulk sales of diesel to
public bus transportation companies. The alleged conduct consists of selling bulk diesel to public bus transportation companies at
prices higher than the retail price charged in service stations. On January 26, 2012, the Argentine Secretariat of Domestic Commerce
issued Resolution No. 6/2012 whereby, effective from the date of the resolution, (i) each of these five oil companies was ordered to
sell diesel to public bus transportation companies at a price no higher than the retail price charged by its nearest service station, while
maintaining both historic volumes and delivery conditions; and (ii) created a price monitoring scheme for both the retail and the bulk
markets to be implemented by the CNDC. YPF challenged Resolution No. 6/2012 and requested a preliminary injunction against its
implementation. YPF’s preliminary injunction has been granted and the effects of Resolution No. 6/2012 have been temporarily
suspended. On December 9, 2014, the Federal Civil and Commercial Appeals Court issued a ruling stating that the case had become
moot and that there are no actual consequences for YPF arising from the challenged Resolution, since prices of diesel to public bus
transportation companies have suffered several variations since the date such Resolution entered into effect. See “Item 8. Financial
Information—Legal proceedings—Argentina—Non-accrued, possible contingencies—CNDC claims.”
On March 13, 2012, YPF was notified of Resolution No. 17/2012, issued by the Argentine Secretariat of Domestic Commerce,
pursuant to which YPF, Shell and Axion (previously Esso) were ordered to supply jet fuel for domestic and international air transport
at a price, net of taxes, not to exceed by 2.7% the price, net of taxes, of medium octane gasoline (not premium) offered at its closest
service station to the relevant airport, while maintaining its existing supply logistics and its usual supply quantities. The resolution
benefits companies that operate in the field of commercial passenger and/or cargo aviation which are registered under the Argentine
National Aircraft Registry. According to a later clarification from the Argentine Secretariat of Domestic Commerce, the beneficiaries
of the measure adopted by this resolution are the following companies: Aerolíneas Argentinas, S.A., Andes Líneas Aéreas S.A.,
Austral – Cielos del Sur, LAN Argentina, S.A. and Sol S.A. Líneas Aéreas. In addition, in said resolution, the Argentine Secretariat
of Domestic Commerce suggested the implementation of a price surveillance system by the CNDC. YPF appealed Resolution
No. 17/2012 and on May 15, 2012 it was notified that the Federal Civil and Commercial Court of Appeals accepted YPF’s
presentation and suspended the effectiveness of Resolution No. 17/2012 until the final judgment regarding its legality. On August 31,
2012, the Court of Appeals declared Resolution No. 17/2012 to be null, on the basis of lack of authority of the Argentine Secretariat
of Domestic Commerce. This decision was appealed by the Secretariat and a final judgment is pending. After several years, on
November 3, 2015, the Argentine Supreme Court finally accepted an extraordinary petition submitted by the Argentine
government and overruled the previous sentence issued by Federal Civil and Commercial Court of Appeals. As a consequence of this
ruling, Resolution No. 17/2012 became effective again. As part of the litigation process, the case is currently in the Federal Civil and
Commercial Court of Appeals, Chamber I, which will issue final judgment in accordance with the decision of the Argentine Supreme
Court, which, upheld the resolution.
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The Argentine Secretariat of Energy has issued a series of resolutions in order to provide the market with information about
liquid fuel prices and volumes. For example, Resolution S.E. No. 1,102/04 created the Registry of Liquid Fuels Supply Points, Self-
Consumption, Storage, Distributors and Bulk Sellers of Fuels and Hydrocarbons, and of Compressed Natural Gas; Resolution S.E.
No. 1,104/04 created a bulk sales price information module as an integral part of the federal fuel information system, as well as a
mechanism for communication of volumes sold. Resolution S.E. No. 1,834/05 compels service stations and/or supply point operators
and/or self-consumption of liquid fuels and hydrocarbons who have requested supply, and have not been supplied, to communicate
such situation to the Argentine Secretariat of Energy. Resolution S.E. No. 1,879/05 established that refining companies registered by
the Argentine Secretariat of Energy, who are parties to contracts that create any degree of exclusivity between the refining company
and the fuel seller, shall assure continuous, reliable, regular and non-discriminatory supply to its counterparties, giving the right to the
seller to obtain the product from a different source, and thereupon, charging any applicable cost overruns to the refining company.
Disposition S.S.C. No. 157/06 of the Undersecretariat of Fuels provides that fuel sellers who are parties to contracts that create
any degree of exclusivity between the refining company and the fuel seller, and which for any reason are seeking to terminate such
contract, shall report the termination in advance with the Undersecretariat of Fuels in order to inform the Argentine Secretariat of
Domestic Commerce of the situation. In that case, the Argentine Secretariat of Domestic Commerce is to: (i) issue a statement
regarding the validity of the termination of the contract and (ii) use all necessary means to allow the fuel seller terminating the
contract to execute another agreement with a refining company and/or fuel broker in order to guarantee its fuel supply. The
Disposition has not been imposed by the authorities in cases involving YPF.
Resolution S.E. No. 1679/04 reinstalled the registry of diesel and crude oil export transactions created by Executive Decree
No. 645/02, and mandated that producers, sellers, refining companies and any other market agent that wishes to export diesel or crude
oil to register such transaction and to demonstrate that domestic demand has been satisfied and that they have offered the product to
be exported to the domestic market. In addition, Resolution S.E. No. 1338/06 added other petroleum products to the registration
regime created by Executive Decree No. 645/02, including gasoline, fuel oil and its derivatives, aviation fuel, coke coal, asphalts,
certain petrochemicals and certain lubricants. Resolution No. 715/07 of the Argentine Secretariat of Energy empowered the National
Refining and Marketing Direction to determine the amounts of diesel to be imported by each company, in specific periods of the year,
to compensate exports of products included under the regime of Resolution No. 1679/04; the fulfillment of this obligation to import
diesel is necessary to obtain authorization to export the products included under Decree No. 645/02 (crude, fuel oil, diesel, coke coal
and gasoline, among others). In addition, Resolution No. 25/06 of the Argentine Secretariat of Domestic Commerce, issued within the
framework of Law No. 20,680, imposes on each Argentine refining company the obligation to supply all reasonable diesel demand,
by supplying certain minimum volumes (established pursuant to the resolution) to their usual customers, mainly service station
operators and distributors. YPF has duly fulfilled its obligation under this Resolution and has not received any type of sanction from
the authorities in this regard.
On August 17, 2010, the Argentine Secretariat of Domestic Commerce issued Resolution No. 295/10, imposing that the trade
price of liquid fuels should be rolled back to those prices prevailing on July 31, 2010. This resolution has been successfully
challenged by another company and a preliminary injunction was granted suspending the effectiveness of such Resolution. This
Resolution was later on repealed by Resolution No. 543/10 of the Argentine Secretariat of Domestic Commerce.
On February 2, 2011, the Argentine Secretariat of Domestic Commerce issued Resolution No. 13/11 stating that the retail price
of liquid fuels had to be rolled back to those prices prevailing on January 28, 2011. This resolution also required refineries and oil
companies to continue to supply amounts of fuel to the domestic market consistent with amounts supplied the prior year, as adjusted
for the positive correlation between the increase in the demand of fuel and gross domestic product. On March 29, 2011, however, the
Argentine Secretariat of Domestic Commerce issued Resolution No. 46/11, which repealed Resolution No. 13/11, alleging that
market conditions had changed since its issuance.
On April 10, 2013, Resolution 35/2013 of the Argentine Secretariat of Domestic Commerce, determined a price cap for fuel at
all service stations for period of six months, which shall not exceed the highest outstanding price as of April 9, 2013 in each of the
regions identified of the Annex of the Resolution.
The above resolutions affecting domestic prices expired on November 24, 2013 and are no longer in effect.
In addition, in May 2012, the Expropriation Law was enacted by the Argentine congress and became effective. See “—The
Expropriation Law” and “—Decree No. 1277/2012.”
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On December 30, 2013, the Commission approved, through Resolution No. 99/2013, the general rules for the grant of quotes of
liquid fuels volumes allowed to be imported by locally registered companies, including, among others, oil companies registered in the
relevant registries of the Secretariat of Energy. These rules regulate the requirements, grant of volumes to be imported and other
conditions to be complied with by the companies that wish to import liquid fuels free of the tax on liquid fuels (imposed by Law
No. 23,966) and the tax on diesel (imposed by Law No. 26,098), jointly with other fuels up to a maximum aggregate amount of
7 million cubic meters.
Agricultural Commodity Export Tax Changes
By Executive Decree No. 133/2015 published in the Official Gazette on December 17, 2015, the Argentine government reduced
the export tax on soybeans and soybean byproducts by 5 percentage points and eliminated the export taxes on all other commodities.
Agricultural commodities with a new zero percent export tax include meat products, grains, fruits, and vegetables, among other
products. Finally, by Joint Resolutions Nos. 4/2015, 7/2015 and 7/2015 of the Ministries of Agroindustry, Treasury and Public
Finance and Production published in the Official Gazette on December 29, 2015, the export permits known as “ROEs” were
eliminated and replaced by the registration of a Sworn Affidavit of Exports Sales, known as a “DJVE.”
Automatic and Non-Automatic Import Licenses
On December 23, 2015, the Ministry of Production published Resolution No. 5/2015, in the Official Gazette, which reinstated
the automatic and non-automatic import licenses (“LAI” and “LNA,” respectively), (“Resolution 5”). In 2013 the former Ministry of
Economy and Public Finance eliminated the LNA, stating it existed alongside the Prior Import Statement (Declaración Jurada
Anticipada de Importación) requirement implemented in February 2012 and recently also repealed by AFIP Resolution No. 3823.
Resolution 5 also established that importers of products included in the Mercosur Tariff Code must obtain a LAI prior to the
entrance of the product into Argentina.
Certain products which are listed in Annex II to XVII of Resolution 5 will be subject to an LNA. The LNA will be applicable to
a wide variety of products, including, but not limited to, textile, footwear, toys, domestic appliances, motorbikes, and automobile
parts.
In order to obtain the LNA, importers must submit certain information from the importer itself (name, tax identification number)
and the product (FOB value, type and quantity, commercial brand, model, country of origin and of shipping, etc.) through the Import
Monitoring System (Sistema Integral de Monitoreo de Importaciones) (“SIMI”) created by AFIP Resolution 3823. After submitting
this information, importers will have ten business days to complete certain additional information required by Resolution 5. If the ten-
day term expires, the SIMI declaration will be automatically cancelled.
Regarding the LNA, Resolution 5 establishes that, at any stage of the process, importers may be required to submit additional
information or documents of the product subject to the LNA and request verification of technical agencies, as applicable.
Import licenses will be valid for 90 calendar days, once approved by the SIMI.
The following imports are exempt from the import regime established by Resolution 5:
1. Donation regime.
2.
Sample regime.
3. Diplomatic exemption regime.
4.
5.
6.
7.
Import of products with duties and tax exemption.
Import of products from Special Custom Zone (Tierra del Fuego, Antártida and Islas del Atlántico Sur).
Import of products by the General Secretary of Executive Branch (Secretaria General de la Presidencia de la Nación).
Courier and mail delivery, only for importer private use or consumption.
Resolution 5 became effective on December 24, 2015 and the Secretary of Trade is the application authority.
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Resolution No. 06/2016
By Resolution No. 06/2016 published on January 2016, the Ministry of Energy and Mining established new seasonal reference
prices of power and energy in the Wholesale Electricity Market (MEM) for the period from February 1, 2016 to April 30, 2016.
Furthermore, the resolution also establishes a stimulus plan, with reference prices for that residential demand that reduces their
consumption over the same month in 2015, and a social tariff.
Natural gas
In January 2004, Executive Decree No. 180/04 (i) created the Electronic Gas Market (“MEG”) for the trade of daily spot sales
of gas and a secondary market of transportation and distribution services and (ii) established information obligations for buyers and
sellers of natural gas in relation to their respective commercial operations, required as a condition to be authorized to inject into and
transport through the transportation system any volume of natural gas (further regulated by Resolution No. 1,146/04 issued on
November 9, 2004 and Resolution No. 882/05 issued by the Argentine Secretariat of Energy). According to Executive Decree
No. 180/04, all daily spot sales of natural gas must be traded within the MEG.
In January 2004, Executive Decree No. 181/04 authorized the Argentine Secretariat of Energy to negotiate with natural gas
producers a pricing mechanism for natural gas supplied to industries and electric generation companies. Domestic market prices at the
retail market level were excluded from these negotiations.
On June 14, 2007, Resolution No. 599/07 of the Argentine Secretariat of Energy approved a proposed agreement with natural
gas producers regarding the supply of natural gas to the domestic market during the period 2007 through 2011 (“Agreement 2007-
2011”). We executed Agreement 2007-2011 taking into account that producers that did not enter into Agreement 2007-2011 would be
required to satisfy domestic demand before those who entered into the agreement 2007-2011. Producers are authorized to withdraw
from Agreement 2007-2011 and will be treated as any producer that has not entered into Agreement 2007-2011. On January 5, 2012,
the Official Gazette published Resolution S.E. No. 172, which temporarily extends the assignation rules and other criteria established
by Resolution No. 599/07 until new legislation is passed replacing such rules and criteria. On February 17, 2012, we filed a motion
for reconsideration of Resolution S.E. No. 172 with the Argentine Secretariat of Energy.
The purpose of Agreement 2007-2011 was to guarantee the supply of the domestic market demand at the levels registered in
2006, plus the growth in demand by residential and small commercial customers (the “Agreed Demand Levels”). Producers that have
entered into Agreement 2007-2011 would commit to supply a part of the Agreed Demand Levels according to certain shares
determined for each producer based upon its share of production for the 36 months prior to April 2004. For this period, our share of
production was approximately 36.5%, or 36.8 mmcm/d (or 1,300 mmcf/d). Agreement 2007-2011 also provides guidelines for the
terms of supply agreements for each market segment, and certain pricing limitations for each market segment of the Agreed Demand
Levels. In order to guarantee any domestic market demand of natural gas in excess of the Agreed Demand Levels, Resolution S.E.
No. 599/07 maintains the effectiveness of the resolutions that implemented the curtailment of natural gas export commitments and the
re-routing of such natural gas volumes to certain sectors of the domestic market. See “—Natural gas export administration and
domestic supply priorities.” Resolution S.E. No. 599/07 also states that Agreement 2007-2011 does not prevent the possible
suspension or termination of export permits.
We were compelled to execute Agreement 2007-2011, among other reasons, in order to mitigate our potential damages.
Producers failing to sign Agreement 2007-2011 could be penalized and subject to other unfavorable measures by regulatory
authorities. However, we expressly stated that the execution of Agreement 2007-2011 did not entail any recognition by us of the
validity of the terms and conditions of the various resolutions of the Argentine Secretariat of Energy establishing programs for the
curtailment or re-routing of exports to satisfy domestic demand. We challenged Resolution No. 599/07 and stated that we signed
Agreement 2007-2011 taking into account the potential consequences of not doing so.
The Argentine Secretariat of Energy created, by its Resolution No. 24/08 issued on March 13, 2008, a program named “Gas
Plus” to encourage natural gas production resulting from discoveries, new fields and tight gas, among other factors. The natural gas
produced under the Gas Plus program is not subject to Agreement 2007-2011 and the price conditions established under such
Agreement.
The Argentine Secretariat of Energy, through Resolution No. 1031/08 issued on September 12, 2008, modified Resolution
No. 24/08, establishing the specific conditions petitioners must meet in order to qualify for the Gas Plus program. Certain of such
conditions were modified by Resolution No. 695/09 of the Argentine Secretariat of Energy, which demands compliance with
commitments already assumed.
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The Argentine Secretariat of Energy, through Resolution No. 1070/08 issued on October 1, 2008, ratified the complementary
agreement entered into between Argentine natural gas producers and the Argentine Secretariat of Energy on September 19, 2008 (the
“Complementary Agreement”), which (i) modified gas prices at the wellhead and segmented the residential sector in terms of natural
gas demand, and (ii) established the requirement that natural gas producers contribute to the fiduciary fund created by Law
No. 26,020. The Complementary Agreement also contains certain requirements concerning the provision of LPG to the domestic
market. See “—Liquefied petroleum gas.” Through Resolution No. 1417/08, the Secretariat of Energy determined the basin prices for
the residential segment applicable to the producers that signed the Complementary Agreement. On January 13, 2010, the natural gas
producers signed an addendum to the Complementary Agreement which extended the commitment to contribute to the fiduciary
funds created by Law No. 26,020 until December 31, 2010. On January 25, 2011, the natural gas producers signed a second
addendum to the Complementary Agreement which extended such commitment until December 31, 2011.
On March 19, 2012, the Official Gazette published Resolution SE No. 55/2012 of the Secretariat of Energy, which extended the
Complementary Agreement for 2012 and established the following with respect to non-signing parties: (i) the natural gas price
increase established by the Complementary Agreement will not be applicable to natural gas injected into the gas system by non-
signing parties; (ii) natural gas injected by non-signing parties will be consumed first in the order of priority by residential users,
which has the lowest tariffs; and (iii) non-signing parties must fulfill all of the commitments undertaken by natural gas producers
under Agreement 2007-2011, which was extended by Resolution S.E. No. 172. On March 23, 2012, Resolution S.E. No. 55/2012 was
supplemented by Resolution ENARGAS No. 2087/2012, which sets forth, among others, the procedure that distribution companies
should follow to secure amounts to be deposited with the fiduciary fund created by Law No. 26,020. Additionally, according to this
resolution, producers which have not signed the 2012 extension of the Complementary Agreement are not allowed to charge the well-
head price increases for gas set forth in Resolutions S.E. No. 1070/2008 and 1417/2008 to consumers directly supplied by distribution
companies. Thus, such non-signing producers have to invoice the lower prices which were in effect prior to the adoption of these
resolutions for the gas supplied to the distribution companies.
Thereafter, on April 19, 2012, December 18, 2012 and, December 19, 2013, YPF signed the 2012, 2013 and 2014 extensions of
the Complementary Agreement, respectively.
Executive Decree No. 2067/08 of December 3, 2008, created a fiduciary fund to finance natural gas imports destined for
injection into the national pipeline system, when required to satisfy the internal demand. The fiduciary fund is funded through the
following mechanisms: (i) various tariff charges which are paid by users of regular transport and distribution services, gas consumers
that receive gas directly from producers and companies that process natural gas; (ii) special credit programs that may be arranged
with domestic or international organizations; and (iii) specific contributions assessed by the Argentine Secretariat of Energy on
participants in the natural gas industry. This decree has been subject to different judicial claims and judges throughout the country
have issued precautionary measures suspending its effects. On November 8, 2009, ENARGAS published Resolution No. 1982/11,
which supplements Decree No. 2067/08. This Resolution adjusts the tariff charges established by Executive Decree No. 2067/08 to be
paid by users in the residential segment and gas processing and electric power companies, among others, starting December 1, 2011.
On November 24, 2011, ENARGAS issued Resolution No. 1991/11, which extends the type of users that will be required to pay tariff
charges. YPF has challenged these Resolutions. On April 13, 2012, a precautionary measure was granted regarding the processing
plant El Porton, suspending the effects of these Resolutions with respect to such plant.
On November 5, 2012 the Official Gazette published Law No. 26,784 which approves the National Administration Budget for
2013. Article 54 of the Law established that the tariff charges and the fiduciary fund established by Executive Decree No. 2067/08
and all its supplementary acts shall be ruled by Law No. 26,095.
On July 17, 2009, the Ministry of Federal Planning and certain natural gas producers (including YPF) signed an agreement
which sets forth: (i) natural gas prices at the wellhead for the electric power generators segment from July to December 2009, and
(ii) amounts to be received by natural gas producers for volumes sold to the residential segment from August 2009 onwards. These
amounts are adjusted on a monthly basis so that they represent 50% of the amount collected by the fiduciary fund to finance natural
gas imports.
On October 4, 2010, the Official Gazette published ENARGAS Resolution No. 1410/10, which set forth new rules for natural
gas dispatch applicable to all participants in the gas industry and imposing the following new and more severe priority demand gas
restrictions on producers:
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•
•
•
•
Distributors remain able to solicit all the gas necessary to cover the priority demand despite such gas volumes’ exceeding
those that the Argentine Secretariat of Energy would have allocated by virtue of Agreement 2007-2011 ratified by the
Resolution No. 599/07. See “—Exploration and Production Overview—Delivery commitments.”
Producers are obligated to confirm all the natural gas requested by distributors in respect of the priority demand. The
producers’ portion of such volumes follows the allocation criterion established by the Resolution No. 599/07. We cannot
predict the amount of the estimated domestic demand that a producer may be required to satisfy regardless of whether such
producer signed Agreement 2007-2011.
Once the priority demand has been satisfied, the remaining demands are fulfilled with exports last in order of priority.
In the event a producer is unable to meet the requested demand, transporters are responsible for redirecting gas until a
distributor’s gas demand is met. The gas deficiency is either (i) deducted from the producer suffering the deficiency if it is
able to meet the demands of its other clients in the same basin or (ii) recuperated from the remainder of the gas producers
in the event the deficient producer is not able to serve any of its clients in the same basin.
As a result, this regime imposes a jointly liable supply obligation on all producers in the event any producer experiences a gas
supply deficiency. We have challenged the validity of the aforementioned regulation. On December 9, 2015 ENARGAS denied our
administrative appeal. YPF is currently analyzing possible courses of action against the denial.
On December 17, 2010 certain natural gas producers (including YPF) signed an agreement which set forth the percentage of
regasified LNG assigned to each natural gas producer for 2011. Amounts produced under this agreement were counted towards such
producers’ commitments to supply natural gas to distributors under Resolution No. 599/07. As of the date of this annual report,
similar agreements have not been entered into for years subsequent to 2011.
On August 27, 2012 the Official Gazette published Resolution SE No. 1445/2012 of the Secretariat of Energy, according to
considerations set by Decree No. 1,277/2012, which modified gas prices at the wellhead for compressed natural gas (CNG) which
represents an increase of approximately 369% of the prices realized by the Company for such segment product. On February 14, 2013
Resolution 1/2013 of the Commission was published in the Official Gazette. This Resolution creates the “Natural Gas Additional
Injection Stimulus Program.” Under this regulation, gas producing companies were invited to file with the Commission before
June 30, 2013 projects to increase natural gas injection, in order to receive a compensation up to U.S.$7.50 per mmBtu for all
additional natural gas injected. These projects shall comply with minimum requirements established in Resolution 1/2013, and will be
subject to consideration approval by the Commission, including a maximum term of five years, renewable at the request of the
beneficiary, upon decision of the Commission. If the beneficiary company in a given month does not reach the committed production
increase it will have to make up for such volumes not produced. In addition, the Commission may withdraw a previously approved
proposal to increase the total injection of natural gas if some of the following events occur: (i) any omission, inaccuracy or distortion
of information provided by a company participating in a project or during its execution; (ii) breach of the obligations set forth in
Decree No. 1,277 / 2012 and its regulations or supplementary acts; (iii) breach by a company of its obligations under the program
after notice of not less than 15 business days; (iv) if the import price is equal to or lower than the price of the additional natural gas
injected for at least 180 days or (v) if the value of a company’s supply contracts or invoices used in the monthly calculation
corresponding to each month covered by the program had weighted average price decreases or unjustified amounts. On May 23,
2013, the Commission approved the project submitted by YPF. A similar program was created under Resolution 60/2013 of the
Hydrocarbon Commission, as amended by Resolution 83/2013 of the Hydrocarbon Commission for gas producers that failed to file
their natural gas additional injection program filings before the expiration date established by Resolution 1/2013 of the Hydrocarbon
Commission. The compensation to be received under this new program varies from U.S.$4.00 per mmBtu to U.S.$7.50 per mmBtu,
depending on the production curve reached by the applicable company. Addionally, a third stimulus program entered into effect under
Resolution Commission No. 185/2015 for companies without any prior gas production in Argentina at the time of issuance of the
resolution. Similar to the Gas Plan, companies with an approved program under this new resolution will receive compensation for the
difference between the price obtained in the market for the sale of all their gas production and U.S.$7.50 per mmBtu. The gas
production subject to such compensation only applies to the production from areas acquired by companies with approved programs
under either Resolution 1/2013 or Resolution 60/2013, as long as such production was computed under these programs as “increased
injection” as opposed to “base injection.”
On April 4, 2014, Resolution SE No. 226/2014 of the Argentine Secretariat of Energy was published in the Official Gazette.
Under this resolution the Secretariat set new prices for residential, commercial consumers and compressed natural gas consumers.
Residential and commercial consumers that achieve certain consumption savings compared to prior years will be: (i) excluded from
the price increase or (ii) subject to a lower price increase. Industrial users and power generation plants are excluded from the price
increase. Consumers served by distributor Camuzzi Gas del Sur S.A., which is not an affiliate of YPF, or its sub-distributors are
excluded.
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On November 17, 2014, Resolution No. 231/2014 of the Commission was published in the Official Gazette. Under this
Resolution, the price of compressed natural gas in service stations will be raised by the same percentage as the weighted average price
within Argentina, excluding taxes, of “super” quality gasoline over 93 octane or of any product that replaces it in the future as
provided for under the resolution.
Natural gas export administration and domestic supply priorities
In March 2004, the Argentine Secretariat of Energy issued Resolution S.E. No. 265/04 adopting measures intended to ensure the
adequate supply of natural gas to the domestic market and regulate its consequences on electricity wholesale prices. Among the
measures adopted were:
•
•
•
•
the suspension of all exports of surplus natural gas;
the suspension of automatic approvals of requests to export natural gas;
the suspension of all applications for new authorizations to export natural gas, filed or to be filed before the Argentine
Secretariat of Energy; and
the authorization to the Undersecretariat of Fuels to create a rationalization plan of gas exports and transportation capacity.
In March 2004, the Undersecretariat of Fuels, pursuant to the authority given to it under Resolution S.E. No. 265/04, issued
Regulation S.S.C. No. 27/04 establishing a rationalization plan of gas exports and transportation capacity. Among other things,
Regulation S.S.C. No. 27/04 established a limit on natural gas export authorizations, which, absent an express authorization by the
Undersecretariat of Fuels, may not be executed for volumes exceeding exports registered during 2003.
In June 2004, the Argentine Secretariat of Energy issued Resolution S.E. No. 659/04, which established a new program to assure
natural gas supply to the domestic market (which substitutes for the program created by Regulation No. S.S.C. 27/04). Under
Resolution S.E. No. 659/04 (amended by Resolution S.E. No. 1,681/04), natural gas exports may be restricted due to shortages of
natural gas in the domestic market, because exporting producers may be required to supply additional volumes of natural gas to the
domestic market beyond those that they are contractually committed to supply. The export of natural gas under current export permits
is conditioned on the fulfillment of additional supply requirements imposed on exporting producers by governmental authorities.
This program was further amended and supplemented by Resolution S.E. No. 752/05 issued by the Argentine Secretariat of
Energy in May 2005, which further reduced the ability of producers to export natural gas, and created a mechanism under which the
Argentine Secretariat of Energy may require exporting producers to supply additional volumes to domestic consumers during a
seasonal period (“Permanent Additional Supply”), which volumes of natural gas are also not committed by the exporting producers.
Based on the provisions of Rule No. 27/04, Resolution S.E. No. 659/04 and Resolution S.E. No. 752/05, the Argentine Secretariat of
Energy and/or the Undersecretariat of Fuels have instructed us to re direct natural gas export volumes to the internal market, thereby
affecting natural gas export commitments. We have challenged the validity of the aforementioned regulations and resolutions, and
have invoked the occurrence of a force majeure event under the corresponding natural gas export purchase and sale agreements. The
counterparties to such agreements have rejected our position. See “Item 8. Financial Information—Legal Proceedings.”
Resolution S.E. No. 752/05 also establishes (i) a special market, open and anonymous, for compressed natural gas stations to
purchase natural gas under regulated commercial conditions, with the demand being ensured by the Argentine Secretariat of Energy
through Permanent Additional Supply required of exporting producers, and (ii) a mechanism of standardized irrevocable offers for
electric power generators and industrial and commercial consumers to obtain supply of natural gas, with the demand being ensured by
the Argentine Secretariat of Energy through the issuance of the Permanent Additional Supply mentioned above.
Pursuant to the standardized irrevocable offers procedure mentioned above, which operates at the MEG, any direct consumer
may bid for a term gas purchase at the export average gas price net of withholdings by basin. The volume necessary to satisfy the
standardized irrevocable offers which have not been satisfied will be required as a Permanent Additional Supply only until the end of
the seasonal period during which the unsatisfied requests should be made (October–April or May–September). Such Permanent
Additional Supply will be requested from the producers that export gas and that inject the natural gas from the basins that are able to
supply those unsatisfied irrevocable offers. Resolution of the Argentine Secretariat of Energy S.E. No. 1886/06, published on
January 4, 2007, extended the term of effectiveness of this mechanism of standardized irrevocable offers until 2016, and empowered
the Undersecretariat of Fuels to suspend its effectiveness subject to the satisfaction of internal demand of natural gas achieved by
means of regulations, agreements or due to the discovery of reserves.
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By means of Resolution S.E. No. 1329/06, later supplemented by Note SSC No. 1011/07, the Argentine Secretariat of Energy
forced producers to give first priority in their injections of natural gas into the gas pipelines to certain preferential consumers and
obligated transportation companies to guarantee these priorities through the allocation of transportation capacity. In general, these
regulations subordinate all exports of natural gas to the prior delivery of natural gas volumes that are sufficient to satisfy domestic
market demand.
Also, beginning during the severe Argentine winter in 2007 and continuing thereafter, we and most gas producers, as well as the
transportation companies in Argentina, received instructions from the government to decrease exports, except for certain volumes
addressed to satisfy Chilean residential consumptions and other specific consumptions.
Liquefied petroleum gas
Law No. 26,020 enacted on March 9, 2005 sets forth the regulatory framework for the industry and commercialization of LPG.
This law regulates the activities of production, bottling, transportation, storage, distribution, and commercialization of LPG in
Argentina and declares such activities to be of public interest. Among other things, the law:
•
•
•
•
•
•
creates the registry of LPG bottlers, obliging LPG bottlers to register the bottles of their property;
protects the trademarks of LPG bottlers;
creates a reference price system, pursuant to which, the Argentine Secretariat of Energy shall periodically publish
reference prices for LPG sold in bottles of 45 kilograms or less;
required the Argentine Secretariat of Energy to comply with the following tasks: (i) create LPG transfer mechanisms, in
order to guarantee access to the product to all the agents of the supply chain; (ii) establish mechanisms for the stabilization
of LPG prices charged to local LPG bottlers; and (iii) together with the CNDC, analyze the composition of the LPG market
and its behavior, in order to establish limitations on market concentration in each phase, or limitations to the vertical
integration throughout the chain of the LPG industry (such limitations apply to affiliates, subsidiaries and controlled
companies);
grants open access to LPG storage facilities; and
creates a fiduciary fund to finance bottled LPG consumption for low-income communities in Argentina and the extension
of the natural gas distribution network to new areas, where technically possible and economically feasible. The fiduciary
fund is funded through the following mechanisms: (i) penalties established by Law No. 26,020, (ii) assignments from the
General State Budget, (iii) funds from special credit programs that may be arranged with national or international
institutions, and (iv) funds that may be assessed by the Argentine Secretariat of Energy on participants in the LPG industry.
The Argentine Secretariat of Energy established, through several subsequent resolutions, reference prices applicable to sales of
LPG bottles of less than 45 kilograms, and to sales of bulk LPG exclusively to LPG bottlers. Also, the Argentine Secretariat of
Energy approved the method for calculating the LPG export parity to be updated monthly by the Undersecretariat of Fuels. In 2007,
the Argentine Secretariat of Energy increased the LPG volumes to be sold to bottlers at the reference prices set forth in the
unconventional above mentioned resolutions.
Disposition 168/05 of the Undersecretariat of Fuels requires companies intending to export LPG to first obtain an authorization
from the Argentine Secretariat of Energy. Companies seeking to export LPG must first demonstrate that the local demand is satisfied
or that an offer to sell LPG to local demand has been made and rejected.
On September 19, 2008, the Secretariat of Energy and Argentine LPG producers entered into the Complementary Agreement
which, among other objectives, seeks to stabilize the price of LPG in the domestic market. The Complementary Agreement applies
only to LPG sold to bottlers that declare their intention to bottle such LPG in LPG bottles of 10, 12 or 15 kilograms. The
Complementary Agreement requires LPG producers to supply LPG bottlers with the same volume of LPG supplied the prior year and
to accept the price per ton set forth in the Complementary Agreement. The Complementary Agreement was extended until
December 31, 2010, pursuant to an addendum entered into on October 23, 2009 by YPF and Repsol YPF Gas S.A., which required
LPG producers to supply LPG bottlers in 2010 with the same volume provided during 2009 plus an additional 5%.
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On December 29, 2010, LPG producers signed a second addendum to the Complementary Agreement which extended the
Complementary Agreement until December 31, 2011 and required LPG producers to supply LPG bottlers in 2011 with the same
volume provided during 2010.
On March 16, 2012, the Official Gazette published Resolution No. 77 of the Argentine Secretariat of Energy, which ratified the
execution of the extension of the Complementary Agreement for 2012 regarding the provision and price stability of LPG bottles of
10, 12 and 15 kilograms for residential users. This resolution also provides that all LPG producers, whether they are parties or not to
the Complementary Agreement, must provide the volumes of LPG to be determined by the Argentine Secretariat of Energy at the
reference prices established in the Complementary Agreement. The failure to comply with such obligations may result in the
application of the penalties established in the Resolution, including the prohibition to export LPG and the limitation of LPG sales in
the domestic market. On April 19, 2012, YPF signed the 2012 extension of the Complementary Agreement. On December 21, 2012
YPF signed the 2013 extension of the Complementary Agreement. On July 5, 2013, Resolution No. 429 of the Argentine Secretariat
of Energy was published in the Official Gazette, approving the extension of the Complementary Agreement for the provision of LPG
bottles of 10, 12 and 15 kilograms for residential users for year. Similar terms to those of the 2012 extension (Resolution No. 77 dated
March 16, 2012) were included in the 2013 extension.
Pursuant to Resolutions No. 37 and 532 of the Argentine Secretariat of Energy, published on February 21 and May 18, 2014,
respectively, the terms of the Complementary Agreement for the provision of LPG bottles of 10, 12 and 15 kilograms were extended
for 2014. Among other provisions, Resolution No. 532/2014 established that LPG producers must offer the volume sold for bottling
companies during 2013, plus 25,000 tons in 2014. Resolution No. 380/2014 dated December 29, 2014 and published on January 8,
2015, raised the value of the compensations to be paid to LPG producers under the Complementary Agreement. On January 28, 2015
the sixth amendment to the agreement was signed by YPF.
On April 7, 2015, Resolution No. 73 of the Argentine Secretariat of Energy terminated the fiduciary agreement to which YPF
was a party as a natural gas producer, contributing funds for the payment of compensation for LPG producers and bottlers. As a
result, natural gas producers that were parties to the Complementary Agreement are no longer required to contribute funds. At the
same time, a new program for the provision of bottled LPG at reference prices was established by Decree No. 470/2015 dated
March 31, 2015. This decree established that LPG producers and bottlers provide LPG at reference prices in the domestic market,
gradually increasing the volumes provided in 2014.
Argentine Environmental Regulations
The enactment of Articles 41 and 43 in the National Constitution, as amended in 1994, as well as new federal, provincial and
municipal legislation, has strengthened the legal framework dealing with damage to the environment. Legislative and government
agencies have become more vigilant in enforcing the laws and regulations regarding the environment, increasing sanctions for
environmental violations.
Under the amended Articles 41 and 43 of the National Constitution, all Argentine inhabitants have both the right to an
undamaged environment and a duty to protect it. The primary obligation of any person held liable for environmental damage is to
rectify such damage according to and within the scope of applicable law. The federal government sets forth the minimum standards
for the protection of the environment and the provinces and municipalities establish specific standards and implementing regulations.
Federal, provincial and municipal laws and regulations relating to environmental quality in Argentina affect our operations.
These laws and regulations set standards for certain aspects of environmental quality, provide for penalties and other liabilities for the
violation of such standards, and establish remedial obligations in certain circumstances.
In general, we are subject to the requirements of the following federal environmental regulations (including the regulations
issued thereunder):
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National Constitution (Articles 41 and 43);
Law No. 25,675 on National Environmental Policy;
Law No. 25,612 on Integrated Management of Industrial and Service Industry Waste;
Law No. 24,051 on Hazardous Waste;
Law No. 20,284 on Clean Air;
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Law No. 25,688 on Environmental Management of Waters;
Law No. 25,670 on the Management and Elimination of Polychlorinated Biphenyls;
Criminal Code; and
the Argentine Civil and Comercial Code, which sets forth the general rules of tort law.
These laws address environmental issues, including limits on the discharge of waste associated with oil and gas operations,
investigation and cleanup of hazardous substances, workplace safety and health, natural resource damages claims and toxic tort
liabilities. Furthermore, these laws typically require compliance with associated regulations and permits and provide for the
imposition of penalties in case of non-compliance.
In addition, we are subject to various other provincial and municipal regulations, including those relating to gas venting, oil
spills and well abandonment, among other matters.
By Resolution No. 404/94, the Argentine Secretariat of Energy amended Resolution No. 419/93, and created the Registry of
Independent Professionals and Safety Auditing Companies (Registro de Profesionales Independientes y Empresas Auditoras de
Seguridad), which may act with respect to areas of hydrocarbons storage, oil refineries, gas stations, fuel commercialization plants
and plants for fractionation of LPG in containers or cylinders. The Resolution provides that external audits of oil refineries, gas
stations and all fuel storage plants must be carried out by professionals registered in the Registry. Domestic fuel manufacturing
companies and companies that sell fuels are prohibited from supplying these products to any station failing to comply with its
obligations. Penalties for failure to perform the audits and remedial or safety tasks include the disqualification of plants or gas
stations. In addition, a set of obligations was established regarding underground fuel storage systems, including a mechanism for
instant notification in cases of loss or suspicion of loss from the storage facilities.
On July 19, 2001, the Secretariat of Environmental Policy of the province of Buenos Aires issued Resolution No. 1037/01
ordering us to clean up certain areas adjacent to the La Plata refinery. The Resolution was appealed through an administrative
procedure which has not yet been resolved. Nevertheless, we have commenced certain actions in order to identify potential technical
solutions for the treatment of the historical contamination, while reserving that the remediation must be made by the parties
responsible for the environmental damage. Under current law, the Argentine government has the obligation to indemnify us against
any liability and hold us harmless for events and claims arising prior to January 1, 1991, according to the Privatization Law.
During 2005, the Argentine Secretariat of Energy, by means of Resolution No. 785/05, created the National Program of
Hydrocarbons Warehousing Aerial Tank Loss Control, a measure aimed at reducing and correcting environmental pollution caused
by hydrocarbons warehousing-aerial tanks.
The description of the material Argentine environmental regulations is only a summary and does not purport to be a
comprehensive description of the Argentine environmental regulatory framework. The summary is based upon Argentine regulations
related to environmental issues as in effect on the date of this annual report, and such regulations are subject to change.
U.S. Environmental Regulations
Federal, state and local laws and regulations relating to health, safety and environmental quality in the United States, where YPF
Holdings operates, affect the operations of this subsidiary. YPF Holdings’ U.S. operations, conducted primarily through Maxus
Energy Corporation are subject to the requirements of the following U.S. environmental laws:
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•
•
•
•
Safe Drinking Water Act;
Clean Water Act;
Oil Pollution Act;
Clean Air Act;
Resource Conservation and Recovery Act;
National Environmental Policy Act;
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•
•
•
Occupational Safety and Health Act;
Comprehensive Environmental Response, Compensation and Liability Act; and
various other federal, state and local laws.
These laws and regulations set various standards for many aspects of health, safety and environmental quality (including limits
on discharges associated with oil and gas operations), provide for fines and criminal penalties and other consequences (including
limits on operations and loss of applicable permits) for the violation of such standards, establish procedures affecting location of
facilities and other operations, and in certain circumstances impose obligations concerning reporting, investigation and remediation,
as well as liability for natural resource damages and toxic tort claims.
Taxation
Holders of exploration permits and production concessions are subject to federal, provincial and municipal taxes and regular
customs duties on imports. The Hydrocarbons Law grants such holders a legal guarantee against new taxes and certain tax increases
at the provincial and municipal levels, except in the case of a general increase in taxes.
Pursuant to Sections 57 and 58 of the Hydrocarbons Law, holders of exploration permits and production concessions must pay
an annual surface fee that is based on acreage of each block and which varies depending on the phase of the operation, i.e.,
exploration or production, and in the case of the former, depending on the relevant period of the exploration permit. On October 17,
2007, the Official Gazette published Executive Decree No. 1,454/07, which significantly increased the amount of exploration and
production surface fees expressed in Argentine pesos that are payable to the different jurisdictions where the hydrocarbon fields are
located. Law No. 27,007 published in the Official Gazette on October 31, 2014 updated amounts that must be paid pursuant to
Sections 57 and 58 of the Hydrocarbons Law. See “—Exploration and Production.”
In addition, “net profit” (as defined in the Hydrocarbons Law) of holders of permits or concessions accruing from activity as
such holders might be subject to the application of a special 55% income tax. This tax has never been applied. Each permit or
concession granted to an entity other than us has provided that the holder thereof is subject instead to the general Argentine tax
regime, and a decree of the National Executive Office provides that we are also subject to the general Argentine tax regime.
Following the introduction of market prices for downstream petroleum products in connection with the deregulation of the
petroleum industry, Law No. 23,966 established a volume-based tax on transfers of certain types of fuel, replacing the prior regime,
which was based on the regulated price. Law No. 25,745, modified, effective as of August 2003, the mechanism for calculating the
tax, replacing the old fixed value per liter according to the type of fuel for a percentage to apply to the sales price, maintaining the old
fixed value as the minimum tax. By Laws 26,028 and 26,181 new taxes on diesel and gasolines sales have been established.
Reduction in tax rates for fuels
On December 30, 2014, Decree No. 2579/2014 set forth a reduction in fuel taxes established Law No. 23,966 and 26,181 with
respect to diesel and unleaded gasoline products higher than 92 octane. The reductions took effect on January 1, 2015.
Export taxes
In 2002, the Argentine government began to implement customs duties on the export of hydrocarbons. Export tax rates were
increased on crude oil to 20%, on butane, methane and LPG to 20% and gasoline and diesel oil to 5%. In May 2004, Resolution
No. 337/04 of the Ministry of Economy increased export duties on crude oil to 25%. These export tax rates were increased again in
2004, when the Ministry of Economy issued Resolution No. 532/04, establishing a progressive scheme of export duties for crude oil,
with rates ranging from 25% to 45%, depending on the quotation of the WTI reference price at the time of the exportation. In
addition, in May 2004, pursuant to Resolution No. 645/04 of the Ministry of Economy, an export duty on natural gas and NGLs was
established at a rate of 20%. The export duty on natural gas was increased again in July 2006, when the Ministry of Economy
increased the rate to 45% and instructed the Customs General Administration to apply the price fixed by the framework agreement
between Argentina and Bolivia as the base price to which to apply the new tax rate, irrespective of the actual sales price. In addition,
on October 10, 2006, the Ministry of Economy imposed prevalent export duties on exports from the Tierra del Fuego province, which
were previously exempted from taxes. Moreover, in May 2007 the Ministry of Economy increased to 25% the export duty on butane,
propane and LPG.
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Resolution No. 394/07 of the Ministry of Economy, effective as of November 16, 2007, increased export duties on Argentine oil
exports (as defined by the regulator) on crude oil and other crude derivatives products. The new regime provides that when the WTI
international price exceeds the reference price, which was fixed at U.S.$60.9/barrel, the producer should be allowed to collect at
U.S.$42/barrel, with the remainder being withheld by the Argentine government as an export tax. If the WTI international price is
under the reference price but over U.S.$45/barrel, a 45% withholding rate would apply. If such price was under U.S.$45/barrel, the
applicable export tax was to be determined by the Argentine government within a term of 90 business days. By Resolution
No. 1/2013 of the Ministry of Economy and Public Finances, Resolution No. 394/07 was amended, increasing cutoff values from 42
U.S.$/barrel to U.S.$70/barrel, and reference price from U.S.$60.9 to U.S.$80 for crude oil. This means that when the international
price of crude oil is over U.S.$80/barrel, the local producer shall be allowed to collect at U.S.$70/barrel, with the remainder being
withheld by the Argentine government.
However, on December 31, 2014 Resolution 1077/2014 was published in the Official Gazette and repealed Resolution 394/07,
as amended, setting forth a new withholding program based on the “International Price”. The International Price is calculated based
on the Brent value for the applicable month less U.S.$8 per barrel. The new program establishes a 1% general nominal withholding
applicable to all products covered by the resolution, including crude oil, diesel, gasoline and lubricants as well as other petroleum
products, to the extent that the International Price is below U.S.$71 per barrel. The resolution further provides an increasing variable
withholding rate on crude oil exports to the extent the International Price exceeds U.S.$71 per barrel. As a result, the maximum price
a producer may charge is approximately U.S.$70 per barrel exported, depending on the quality of crude sold. The resolution also sets
forth increasing withholding rates for exports of diesel, gasoline, lubricants and other petroleum derivatives when the International
Price exceeds U.S.$71 per barrel at rates that allow the producer to receive a portion of the price increase.
Resolution No. 127/08 of the Ministry of Economy increased export duties applicable to natural gas exports from 45% to 100%,
mandating a valuation basis for the calculation of the duty as the highest price established in any contract of any Argentine importer
for the import of gas (abandoning the previously applicable reference price set by the framework agreement between Argentina and
Bolivia mentioned above). Resolution No. 127/08 provides with respect to LPG products (including butane, propane and blends
thereof) that if the international price of the relevant LPG product, as notified daily by the Argentine Secretariat of Energy, is under
the reference price established for such product in the Resolution (U.S.$338/cm for propane, U.S.$393/cm for butane and
U.S.$363/cm for blends of the two), the applicable export duty for such product will be 45%. If the international price exceeds the
reference price, the producer shall be allowed to collect the maximum amount established by the Resolution for the relevant product
(U.S.$233/cm for propane, U.S.$ 271/cm for butane and U.S.$250/cm for blends of the two), with the remainder being withheld by
the Argentine government as an export tax.
We cannot give any assurances as to future levels of export taxes.
Repatriation of Foreign Currency
Executive Decree No. 1,589/89, relating to the deregulation of the upstream oil industry, allowed us and other companies
engaged in oil and gas production activities in Argentina to freely sell and dispose of the hydrocarbons we produce. Additionally,
under Decree No. 1,589/89, we and other oil producers were entitled to keep up to 70% of foreign currency proceeds we received
from crude oil and gas export sales outside of Argentina, but were required to repatriate the remaining 30% through the exchange
markets of Argentina.
Decree No. 1722/2011 of October 26, 2011 requires all oil and gas companies (including YPF), among other entities, to
repatriate 100% of their foreign currency export receivables.
ITEM 4A. Unresolved Staff Comments.
YPF does not have any unresolved Staff comments.
ITEM 5. Operating and Financial Review and Prospects
The following discussion should be read in conjunction with our Audited Consolidated Financial Statements included in this
annual report.
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Overview
We are Argentina’s leading energy company, operating a fully integrated oil and gas chain with leading market positions across the
domestic upstream and downstream segments. Our upstream operations consist of the exploration, development and production of crude oil,
natural gas and liquefied petroleum gas. Our downstream operations include the refining, marketing, transportation and distribution of oil
and a wide range of petroleum products, petroleum derivatives, petrochemicals, LPG and bio-fuels. Additionally, we are active in the gas
separation and natural gas distribution sectors both directly and through our investments in several affiliated companies. As of December 31,
2015, we had consolidated revenues of Ps. 156,136 million and consolidated net income of Ps. 4,426 million.
Presentation of Financial Information
Our Audited Consolidated Financial Statements are prepared in accordance with IFRS as issued by the IASB. Our Audited
Consolidated Financial Statements are fully compliant with IFRS.
We fully consolidate the results of subsidiaries in which we have a sufficient number of voting shares to control corporate decisions.
Interest in joint operations and other agreements which give the Company a percentage contractually established over such percentage in the
assets and obligations that emerge from the contract (“joint operations”), have been consolidated line by line on the basis of the assets,
liabilities, income and expenses related to each contract.
The financial data contained in this annual report as of December 31, 2015, 2014 and 2013 and for the years ended December 31,
2015, 2014 and 2013 has been derived from our Audited Consolidated Financial Statements included in this annual report, which were
approved at the Board of Directors’ meeting and authorized to be issued on March 3, 2016 and which include subsequent events until such
date.
Finally, certain oil and gas disclosures are included in Note 20 to the Audited Consolidated Financial Statements included in this
annual report under the heading “Supplemental information on oil and gas producing activities (unaudited).”
Segment Reporting
We report our business into the following segments: (i) exploration and production, which includes exploration and production
activities, natural gas and crude oil purchases, sales of natural gas, and to a lesser extent crude oil, to third parties and intersegment sales of
crude oil, natural gas and its byproducts (“Exploration and Production”); (ii) the refining, transport, purchase of crude oil and natural gas
from third parties and intersegment sales, and marketing of crude oil, natural gas, refined products, petrochemicals, electric power generation
and natural gas distribution (“Downstream”); and (iii) other activities not falling into the previously described categories (“Corporate and
Other”), which includes principally corporate administration costs and assets, environmental matters related to YPF Holdings and
construction activities. See Note 4 to our Audited Consolidated Financial Statements and “Item 4. Information on the Company—Business
Organization.”
Sales between business segments are made at internal transfer prices established by us, which generally seek to approximate market
prices.
Summarized Statement of Comprehensive Income
For the Year Ended December 31,
2014
2015
(in millions of pesos)
2013
Revenues
Cost of sales
Gross profit
Administrative expenses
Selling expenses
Exploration expenses
Other operating results, net
Operating income
Income on investments in companies
Financial income (expense) net
Net income before income tax
Income tax
Net income
Total other comprehensive income
Total comprehensive income
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(2,473)
(853)
(2,034)
(1,030)
156,136 141,942 90,113
(119,537) (104,492) (68,094)
36,599 37,450 22,019
(4,530) (2,686)
(5,586)
(11,099) (10,114) (7,571)
(829)
227
16,588 19,742 11,160
353
318
12,157
1,772 2,835
29,063 22,072 14,348
(24,637) (13,223) (9,269)
8,849 5,079
4,426
43,758 16,276 12,031
48,184 25,125 17,110
558
Factors Affecting Our Operations
Our operations are affected by a number of factors, including:
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•
•
•
•
•
•
•
•
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•
•
•
the volume of crude oil, oil byproducts and natural gas we produce and sell;
regulation of domestic pricing;
export administration by the Argentine government and domestic supply requirements;
international and domestic prices of crude oil and oil products;
our capital expenditures and financing availability;
cost increases;
domestic market demand for hydrocarbon products;
operational risks, labor strikes and other forms of public protest in Argentina;
taxes, including export taxes;
regulation of capital flows;
the Argentine peso/U.S. dollar exchange rate;
the revocation of our concessions in case of noncompliance with certain provisions as set by laws and agreements with
provinces in Argentina;
dependence on the infrastructure and logistics network used to deliver our products;
laws and regulations affecting our operations, such us import regulations; and
interest rates.
Our operating income in 2015 decreased by 16% compared to 2014. This decrease was attributable to, among other things, the
recognition of a loss in the value of assets at the time of completion of the evaluation of impairment of fixed assets and intangible
assets mainly driven by lower estimated future oil prices an increase in depreciation of fixed assets as a result of the higher
investment in fixed assets and asset remeasurement in pesos, as a result of devaluation of the Argentine peso against the U.S. dollar,
which is our functional currency. Other factors that contributed to this decrease in operating income include increased royalties,
driven mainly by higher crude oil prices at the wellhead and higher natural gas prices, higher costs of sales and general cost increases
(mainly preservation, repair and maintenance costs, salaries and social security costs and costs of services rendered by third parties).
This increase in costs is attributable mainly to our increased activity and price increases in Argentina. The above-mentioned negative
effects were partially offset by the increase in domestic prices and volumes of diesel, gasoline and natural gas and accruals mainly
due to the Crude Oil Production Stimulus Program (Resolution No. 14/2015). On April 2, 2013 our facilities in the La Plata refinery
were hit by a severe and unprecedented storm, recording over 400 mm of rainfall (which was the maximum ever recorded in the
area). The heavy rainfall during 2013 disrupted refinery systems and caused a fire that affected the Coke A and Topping C units in the
refinery. As of December 31, 2015, 2014 and 2013 we have recognized Ps. 523 million, Ps. 2,041 million and Ps. 1,956 million,
respectively, relating to insurance compensation for the Coke A unit damage and operational losses for 2015, 2014 and 2013. In
addition, on March 21, 2014, a fire occurred at the Cerro Divisadero crude oil treatment plant, located 20 kilometers from the town of
Bardas Blancas in the province of Mendoza. As of December 31, 2015, we have recognized Ps. 1,165 million for insurance
compensation for Cerro Divisadero crude oil treatment plant damage and production losses for 2015. See “Item 4. Information on the
Company—Insurance—Argentine operations.”
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Our business is inherently volatile due to the influence of external factors, such as internal demand, market prices, availability of
financial resources for our business plan and its corresponding costs and government regulations. Consequently, our past financial
condition, results of operations and the trends indicated by such results and financial condition may not be indicative of the financial
conditions, results of operations or trends in future periods. We will focus on increasing productivity in 2016. We believe that we
need to create a more efficient industry that is sustainable in a lower crude oil price environment. Therefore, we estimate that we will
not see meaningful production growth this year. We expect to cut capital expenditures approximately 20% to 25% in U.S. dollar
terms, which implies less activity mainly in our Upstream business unit. We already have several drilling and workover rigs in
standby mode, and it is likely that some of them will not return to operation soon.
Most of our shale oil production comes from the Loma Campana area through our joint venture with Chevron, which was the
first and largest farm-out. As we gathered more experience, drilling activity migrated to horizontal wells of 1,500 meters in lateral
length and 18 frack stages, obtaining wells with a promising relation between expected EURs and well costs. These horizontal wells
cost approximately U.S.$13 million each, which we expect to be closer to U.S.$10 million each by the end of 2016 as we push
forward several initiatives to improve efficiency and significantly reduce the well costs. Our strategy is to continue to invest and de-
risk, but at a slower pace than the last couple of years.
Crude oil prices in Argentina were recently renegotiated among market participants, which kept them at levels significantly
above current international oil prices with the goal of avoiding significant domestic industry disruptions, taking into account that
domestic prices and costs are decoupled from international prices. We expect diesel and gasoline prices to increase in peso terms
during 2016, primarily to at least partially counteract the effects of the recent significant devaluation of the peso against the U.S.
dollar.
Our cash position by the end of 2015 was U.S.$1.0 billion, which represents approximately 50% of our debt maturing in 2016.
However, we believe we will be able to refinance most of the debt maturing in 2016 and have a cash cushion ready to fund negative
free cash flow for the year. We intend to start to reverse this trend during 2016 to reach a neutral position, which we expect will
become positive by 2017. In addition, we expect to reduce the collection cycle of accounts receivable from government entities in
order to increase our cash flow from operations during 2016. See “Item 3. Key Information—Risk Factors—A significant percentage
of our cash flow from operations is derived from counterparties that are governmental entities.”
Notwithstanding the foregoing, there can be no assurance that our production, costs, prices or our estimates of future cash flows
from operations, among other items, could not be affected by factors beyond our control and, as such, differ from our estimates. See
“Item 3. Key Information—Risk Factors.”
Macroeconomic conditions
Substantially all of our revenues are derived from our operations in Argentina and are therefore subject to prevailing
macroeconomic conditions in Argentina. Changes in economic, political and regulatory conditions in Argentina and measures taken
by the Argentine government have had and are expected to continue to have a significant impact on us.
The Argentine economy has experienced significant volatility in past decades, characterized by periods of low or negative
growth and high variable levels of inflation. Inflation reached its peak in the late 1980s and early 1990s. Due to inflationary pressures
prior to the 1990s, the Argentine currency devalued repeatedly and macroeconomic instability led to broad fluctuations in the real
exchange rate of the Argentine currency relative to the U.S. dollar. To address these pressures, past Argentine governments
implemented various plans and utilized a number of exchange rate systems.
In the fourth quarter of 1998, adverse international financial conditions caused the Argentine economy to enter into a recession
and GDP to decrease between 1999 and 2001. By the end of 2001, Argentina suffered a profound deterioration in social and
economic conditions, accompanied by high political and economic instability. The restrictions on the withdrawal of bank deposits, the
imposition of exchange controls, the suspension of the payment of Argentina’s public debt and the abrogation of the peso’s one-to-
one peg to the dollar (with the consequent devaluation of the peso against the dollar) caused a decline in economic activity. Real GDP
declined by 10.9% in 2002, annual inflation rose to 41%, the exchange rate continued to be highly volatile, and the unemployment
rate rose to more than 20%. The political and economic instability not only curtailed commercial and financial activities in Argentina
but also severely restricted the country’s access to international financing.
Strong economic growth in the world’s developed economies, favorable raw material prices from 2003 through the first half of
2008 and the implementation of new macroeconomic policies paved the way for Argentina’s economic recovery. Real GDP grew at
an average cumulative rate of 8.5% between 2003 and 2008. As a result of the crisis in the global economy, Argentina’s real GDP
growth rate decelerated in 2009 to 0.9%, but recovered in 2010 and 2011 growing by approximately 9% each year.
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After the growth in 2010 and 2011, several factors led to a decrease in growth of the Argentine economy in 2012 and 2013. The
growth of the global economy was not as strong as expected following the easing of U.S. economic crisis that started in 2007, and
financial volatility continued at high levels. The decline in the price of Brent crude to below U.S.$50 per barrel, the negative trend in
prices of major agricultural commodities and the geopolitical tensions between the United States, Russia and Ukraine as well as
countries in the Middle East presents a complicated new international scenario that creates uncertainty about the future performance,
including potential downside risks, of developed and emerging economies, including Argentina.
Mauricio Macri was elected president of Argentina, and his administration took office on December 10, 2015. The new
administration faces challenges in respect of Argentina’s economy, such as reducing the rate of inflation and a further devaluation of
the Argentine peso, improving the competitiveness of the local industries and normalizing or adjusting prices of certain goods and
services, such as electricity and natural gas for certain residential consumers of Argentina. Some of the measures necessary to meet
these objectives could be unpopular and generate political and social opposition or unrest. As a result, it is difficult to predict the
impact of these measures on the Argentine economy as a whole and the energy sector in particular, including revisions and reforms to
pricing mechanisms for oil and gas and elimination of energy subsidies, as well as other policy changes that may affect the energy
sector. This includes decisions that the new administration has already taken, such as the elimination of exchange restrictions, or
future measures it may take to address inflation or changes to the exchange rate. Uncertainty regarding the measures to be taken by
the new administration on the economy could further lead to price volatility of Argentine companies, including in particular
companies like ours in the energy sector, given the high level of regulation. In addition, there can be no assurance that current
government programs and policies that apply to the oil and gas sector will continue to be in place in the future. See “—Limitations on
local pricing in Argentina may adversely affect our results of operations” and “—Oil and gas prices, including the recent decline in
global prices for oil and gas, could affect our business.”
According to the IMF’s estimates, global economic growth reached 3.1% in 2015, although the rate of growth or, in some cases,
contraction, varied significantly from region to region. On March 27, 2014, the Argentine government announced a new method of
calculating GDP by reference to 2004 as the base year as opposed to 1993, which was the base reference year under the prior method
of calculating Argentine GDP. As a result of the application of this new method, the estimated Argentine GDP growth rate for 2013
was revised from 4.9% to 2.9%. As of the date of this annual report, the provisional figures of Argentina’s estimated GDP for 2014
and the first half of 2015 published by the National Statistics Institute (Instituto Nacional de Estadística y Censos) (“INDEC”) are
0.5% and 2.2% respectively. As mentioned previously, on January 7, 2016 through Decree No. 55/2016, the new leadership of
INDEC issued a report declaring a “national statistical emergency.” INDEC stated that its administration since 2006 was irregular and
it would reorganize. As a result, INDEC would not publish new information until at least June 2016.
The official exchange rate of the Argentine peso to the U.S. dollar as of December 31, 2014 was Ps. 8.55 per U.S.$1.00, a
devaluation of approximately 31.1% compared to Ps. 6.52 per U.S.$1.00 as of December 31, 2013. In December 2015, the new
authorities of the national government decided to eliminate certain exchange controls imposed by the previous government. Due to
the above, as of December 31, 2015, the peso fell to Ps. 12.99 per U.S.$1.00, a devaluation of approximately 52% compared to the
rate as of the end of 2014 (approximately 40% devaluation from the exchange rate in place on December 16, 2015).
Argentina has confronted and continues to confront inflationary pressures. According to inflation data published by INDEC,
from 2008 to 2013, the Argentine consumer price index (“CPI”) increased 7.2%, 7.7%, 10.9%, 9.5%, 10.8% and 10.9%, respectively,
and the wholesale price index increased 8.8%, 10.3%, 14.5%, 12.7%, 13.1% and 14.7%, respectively. In 2014, the Argentine
government established a new consumer price index known as the IPCNU that more broadly reflects consumer prices by considering
price information from the 24 provinces of the country, divided into six regions. According to INDEC, the IPCNU increased 23.9% in
2014 and increased 10.7% from January 2015 to September 2015. The wholesale price index increased 28.3% in 2014 and increased
11.9% from January 2015 to October 2015. Before the new administration took office, certain private sector analysts believed that the
inflation was significantly higher than the rate published by INDEC. However, on January 7, 2016, through Decree No. 55/2016, the
new leadership of INDEC issued a report declaring a “national statistical emergency.” INDEC stated that its administration since
2006 was irregular and it would reorganize. As a result, INDEC would not publish new information until at least June 2016. There
can be no assurance of the potential impact these changes may have on our results of operations and financial condition. According to
a price index published by the government of the City of Buenos Aires, inflation in the city was 3.9%, 4.1% and 4.0% in December
2015, January 2016 and February 2016, respectively. Previously, from December 2014 to November 2015, inflation averaged less
than 2.0% per month. There can be no assurance that inflation rates will increase in the future. See “Item 3. Key Information—Risk
Factors-Risks Relating to Argentina—Our business is largely dependent upon economic conditions in Argentina.”
During 2015, Argentina’s trade balance was a deficit of approximately U.S.$3.0 billion according to preliminary estimates from
INDEC, with total exports of approximately U.S.$56.7 billion during 2015, representing a 16.9% decrease compared to the same
period in 2014. Total imports were approximately U.S.$59.8 billion, representing a decrease of 8.3% compared to the same period in
2014.
124
In Argentina, domestic fuel prices have increased over the past five years, but have not kept pace with either increases or
decreases in international market prices for petroleum products due to the market conditions and regulations affecting the Argentine
market.
The drop in the international price of Brent crude has affected and will likely continue to affect the oil industry’s expected
activities worldwide, particularly with respect to expected investments in the industry. In 2015, this decline resulted in an
approximately U.S.$7 reduction to the domestic price per barrel compared to the price in effect on December 31, 2014. This change
stemmed from negotiations between producers and refiners to reduce the domestic price of Medanito and Escalante crude during
January 2015 to U.S.$77 and U.S.$63 per barrel, respectively. These prices stood at U.S.$75 and U.S.$61, respectively, as of
November 30, 2015.
In 2016, following the continuous drop in the international price of Brent crude, a new reduction of approximately 10% in the
domestic crude oil price per barrel compared to the price in effect on December 31, 2015 was agreed upon. This change stemmed
from negotiations between producers, refiners and the Ministry of Energy and Mining, whereby it was agreed to reduce the domestic
price of Medanito crude and Escalante crude since January 2016 to U.S.$67.50 and U.S.$54.90 per barrel, respectively.
Energy consumption in Argentina has increased significantly since 2003. Continued growth in demand has led to fuel shortages
and power outages, prompting the Argentine government to take additional measures to assure domestic supply. As a result of this
increasing demand, declines in the production of certain products and companies in our industry, and actions taken by the Argentine
regulatory authorities to prioritize domestic supply the volumes of hydrocarbon product exports, especially natural gas, have declined
steadily during this period. At the same time, in recent years, Argentina has increased its imports of natural gas and refined products.
On December 17, 2015, as a result of Decree No. 134/2015, the new government declared an emergency of the national
electricity system until December 31, 2017 and instructed the Minister of Energy and Mining to develop and propose measures that
would ensure power supply under adequate technical conditions. In light of this circumstance, by Resolution No. 06/2016, published
January 2016, the Ministry of Energy and Mining established the new seasonal reference prices of power and energy in the MEM
from February 1, 2016 to April 30, 2016. The aforementioned resolution has among its objectives adapting the quality and security of
the electric supply and ensuring the provision of the public electric supply under adequate technical and economical conditions,
considering, among others, that: a) the remuneration systems established by the MEM from 2003 involved the gradual adoption of
regulatory decisions that did not meet the objectives set out in Law No. 24,065 in ensuring the supply and quality under the
conditions laid out at the minimum possible cost to the Argentine electricity system; b) the regulatory framework consisting of Laws
No. 15,336 and 24,065 prescribed that the price to be paid for the demand for electricity in the MEM must meet the economic cost to
supply it; c) the abandonment of economic criteria in the definition of prices in the MEM distorted economic signals, increasing the
cost of supply, discouraging risk private investment directed to efficiently increase the offer and subtracting savings incentives and
proper use of the energy resources by the consumers and users; and d) only a small proportion of the cost of supply was offset by the
electricity fees from demand, requiring the resources of the Argentine national treasury to cover a substantial portion of this cost,
which significantly contributed to progressively increased tax pressure. Based on the above, Resolution 06/2016 establishes increases
in seasonal reference prices of power and energy from January 1, 2016 to April 30, 2016, thereby substantially eliminating the
application of existing subsidies. The resulting percentage price increases depend on the prices and consumption prior to the
implementation of the resolution, but it is estimated that on average prices will increase by 500% or more. The increase indicated
above does not improve the operational situation for generation or distribution of energy (which is pending), since its main effect is
the partial removal of existing subsidies as mentioned previously. Notwithstanding the above increases, the resolution also establishes
a stimulus plan, which focuses primarily on efficient users (with reference prices for residential users that reduces consumption over
the same month of 2015) and a social tariff for users with basic needs and those that meet the criteria defined in Resolution 7/2016.
In 2005, Argentina restructured a substantial portion of its bond indebtedness with approximately 76% of its bondholders, and in
2006 it settled all of its debt with the IMF. In June 2010, Argentina restructured additional defaulted bond indebtedness that was not
swapped in 2005. As a result of the 2005 and 2010 debt swaps, over 92% of the bond indebtedness on which Argentina had defaulted
in 2002 has been restructured (“Exchange Bonds”).
Certain holders of bonds that were not swapped in the debt restructuring have sued Argentina for payment (“Holdout
Bondholders”). On December 7, 2011, the U.S. District Court for the Southern District of New York held that Argentina was required
by the pari passu clause in the 1994 Fiscal Agency Agreement governing the defaulted bonds to rank its payment obligations to the
Holdout Bondholders equally with those of its other debt, including the Exchange Bonds. On February 23, 2012, the District Court
enjoined Argentina from making payments on the Exchange Bonds without making ratable payments on the defaulted debt, and on
October 2012, the District Court’s injunction was affirmed by the U.S. Court of Appeals for the Second Circuit.
125
On November 21, 2012, the District Court issued an amended order requiring Argentina to pay 100% of the amounts due to the
Holdout Bondholders upon payment of the amounts due on the next maturity date to the Exchange Bondholders. Argentina appealed
the District Court’s November 21, 2012 order to the Second Circuit Court of Appeals, which granted Argentina’s request for a stay of
the order. On August 30, 2013, the Second Circuit Court of Appeals affirmed the District Court’s November 21, 2012 order, but
stayed its decision pending an appeal to the U.S. Supreme Court. On June 16, 2014, the U.S. Supreme Court denied Argentina’s
appeal, and with the appeal process exhausted, the Second Circuit Court of Appeals lifted its stay of the District Court’s order on
June 18, 2014.
On June 26, 2014, Argentina deposited U.S.$832 million due to the Exchange Bondholders for the payment of interest that
matured on June 30, 2014, of which U.S.$539 million was deposited in accounts of the Bank of New York Mellon (“BoNY”), as
indenture trustee, in the Central Bank of Argentina. On June 27, 2014, the District Court referred to such funds as an illegal payment.
On October 22, 2014, the Second Circuit Court of Appeals dismissed Argentina’s appeal of the District Court’s decision finding that
the payment on the Exchange Bonds was illegal and that BoNY, therefore, should retain such funds.
BoNY has invoked the decision of the District Court to not deliver the funds deposited by Argentina to the Exchange
Bondholders. Argentina has asserted that it has complied with its obligation to the Exchange Bondholders by making said deposit,
and that BoNY, as the indenture trustee, has the obligation to deliver those funds to their beneficiaries.
On September 11, 2014, Argentina promulgated Law No. 26,984, which provided for various mechanisms to pay 100% of the
amounts owed on the Exchange Bonds, authorizing for that purpose, among other things, the Minister of Economy and Public
Finance to replace BoNY as indenture trustee and appoint Nación Fideicomisos S.A. instead, and to deposit funds owed to the
Exchange Bondholders in an account created to that end, providing also the possibility for the bondholders to change the trustee, the
jurisdiction or the governing law of the bonds.
On September 29, 2014, the District Court declared Argentina in contempt of court but did not impose sanctions. On October 3,
2014, the District Court ordered Argentina to repair its relations with BoNY, remove Nación Fideicomisos as indenture trustee and
resolve the situation with the Holdout Bondholders.
On March 12, 2015, the District Court held that U.S. dollar-denominated bonds issued by Argentina under Argentine Law
constitute external indebtedness, and, therefore, are covered by the court’s amended injunction dated November 21, 2012.
On May 11, 2015, certain Holdout Bondholders moved to amend the complaint to add two claims: (i) a claim for a declaratory
judgment stating that the BONAR 2024 bonds issued by Argentina are considered foreign debt, and (ii) a claim for a pari passu order
stating that Argentina must make ratable payments to claimants each time the BONAR 2024 bonds or other amounts are paid on past
or future external debt. On July 16, 2015, the District Court accepted the amended complaint.
Other holders of bonds that were not exchanged in the 2005 and 2010 debt swaps have sought relief similar to that sought by the
Holdout Bondholder plaintiffs (“Me Too Plaintiffs”). On June 5, 2015, the District Court granted summary judgment in 36 of these
cases, declaring that Argentina was in breach of the pari passu clause contained in their bonds. By an order of October 22, 2014 the
District Court granted identical summary judgment in fifteen other Me too Plaintiffs actions. On August 14, 2015, certain Me Too
Plaintiffs submitted motions requesting a pari passu order similar to that previously obtained by other Holdout Bondholders. Those
Me too Plaintiffs were afterwards followed by many others, and on October 30, 2015, the District Court granted 49 such motions.
Since the pari passu injunction became effective, litigation has continued regarding Argentina’s efforts to make payments to
Exchange Bondholders. Payments by Argentina have been blocked from reaching the Exchange Bondholders by judicial orders, and
various Exchange Bondholders have sought release of such funds through litigation before the District Court and in various
jurisdictions.
In connection with the Holdout Bondholder litigation against Argentina, the Holdout Bondholders served subpoenas on various
financial institutions in New York seeking the production of documents concerning the accounts and transfers of hundreds of entities
allegedly owned or controlled, in whole or in part, by Argentina, including YPF. During a hearing on September 3, 2013, the District
Court ruled that such discovery could proceed as to, among others, YPF, in order for the Holdout Bondholders to determine if those
documents supported an argument that YPF is an alter ego of Argentina. YPF is not a recipient of any such subpoenas and, as such,
has no obligation to produce documents or otherwise participate in discovery.
126
On June 17, 2015, the plaintiff NML and other Holdout Bondholders submitted a motion to the District Court alleging Argentina did
not comply with the court’s discovery order dated September 25, 2013 and seeking sanctions, including precluding Argentina from
disputing the Holdout Bondholder’s alter ego allegations as to the Central Bank of Argentina, Energía Argentina Sociedad Anónima
(“ENARSA”), and YPF, and deeming that Argentina’s assets in United States were used for commercial purposes. During a hearing on
August 12, 2015, the District Court found that Argentina had not complied with the September 25, 2013 discovery order and ordered that
Argentina’s assets in the United States, except for diplomatic and military assets, be deemed to be used for commercial purposes. The
District Court made no determination as to sanctions, if any, with respect to the alter ego issues.
Notably, the District Court has previously held that BNA is not an alter ego of Argentina, and on August 31, 2015, the Second
Circuit Court of Appeals ruled that the Central Bank of Argentina is not an alter ego of Argentina and dismissed claims asserted against it
on that basis. On January 7, 2016, NML filed a writ of certiorari before the Supreme Court of the United States on appeal of this issue. In
addition, the U.S. District Court for the Northern District of California on December 1, 2015 affirmed a magistrate judge’s ruling that the
Holdout Bondholders’ assertion that YPF was an alter ego of Argentina was insufficient to support discovery concerning YPF. This
decision was appealed by NML on December 23, 2015.
In February 2016, Argentina negotiated and reached agreements in principle with respect to a substantial number of the Holdout
Bondholders. On February 5, 2016, Argentina published its proposal to other Holdout Bondholder plaintiffs. Argentina has indicated that
it estimates that the settlement payments for the Holdout Bondholders covered by the pari passu injunctions, if made, would total
approximately U.S.$6.5 billion in cash.
On February 19, 2016, the District Court issued an indicative ruling stating that in light of Argentina’s settlement proposal, and
upon remand of Argentina’s motion to vacate the pari passu injunctions in the Me Too Plaintiffs’ actions from the Court of Appeals, it
would grant a motion to vacate the injunctions in all cases upon the occurrence of two conditions: (1) Argentina’s repeal of the legislative
obstacles to settlement, and (2) Argentina’s payment to all Holdout Bondholders that entered into agreements in principle with Argentina
on or before February 29, 2016 in accordance with the terms of such agreements, and notification of such payment to the District Court.
On February 24, 2016, the Court of Appeals remanded the pari passu cases on appeal to the District Court, stating that the order
formalizing the indicative ruling was subject to a motion from Argentina, with notice to all parties and an opportunity to be heard, and
that any such order will be stayed for up to two weeks. Argentina submitted that motion, and the District Court held a hearing of oral
arguments on March 1, 2016. On March 2, 2016, the District Court vacated the injunctions on all actions upon the occurrence of the
conditions set forth in the indicative ruling. During the two week stay, plaintiffs filed appeals and consented to an extended stay. On
March 11, the Second Circuit entered an order staying enforcement of the District Court’s March 2 order pending resolution of the
appeals.
See “Item 3. Key Information—Risk Factors—Risks Relating to Argentina—Our business is largely dependent upon economic
conditions in Argentina” and “—Risks Relating to Argentina.”
The table below shows Argentina’s total sales, production, exports and imports of crude oil, diesel and gasoline products for the
periods indicated.
Crude Oil in Argentina
Production (mmbbl)
Exports (mmbbl)
Imports (mmbbl)
Diesel oil in Argentina
Sales (mcm) (1)
Production (mmbbl)
Exports (mcm)
Imports (mcm)
Gasoline in Argentina
Sales (mcm)(1)
Production (mmbbl)
Exports (mcm)
Imports (mcm)
(1)
Includes domestic market sales.
Source: Argentine Secretariat of Energy
127
Year Ended December 31,
2014
2015
2013
186.63
13.27
1.84
189.40
13.41
3.45
191.7
13.7
2.6
14,290.54
12,181.12
—
1,933.69
14,012.95
11,521.57
—
2,001.31
14,490.6
11,680.8
—
2,427.1
8,720.81
7,280.89
—
15.00
8,360.31
7,280.89
—
449.16
8,579.7
7,609.8
14.0
378.7
Policy and regulatory developments in Argentina, including the Expropriation Law
The Argentine oil and gas industry has been subject to certain governmental policies and regulations that have resulted in:
(i) domestic prices that do not keep pace with those prevailing in international markets (which usually resulted in lower local prices
compared to prevailing international market prices before the recent decrease in international oil prices); (ii) export and import
regulations; (iii) domestic supply requirements that oblige us from time to time to divert supplies from the export or industrial
markets in order to meet domestic consumer demand; (iv) increasingly higher export duties on the volumes of hydrocarbons allowed
to be exported, before the recent decrease in international oil prices and the related measures recently taken by the Argentine
government to incentivize domestic investment and production through the temporary reduction of export duties; (v) increasingly
higher investment and costs expenditure requirements in order to satisfy domestic demand and (vi) increasingly higher taxes,
although certain taxes have recently declined as a result of the incentives set by the Argentine government in response to the decrease
in international oil prices to promote domestic activity. See “Item 4. Information on the Company—Regulatory Framework and
Relationship with the Argentine Government.” These governmental pricing and export administration and tax policies have been
implemented in an effort to satisfy increasing domestic market demand and, recently, to incentivize domestic activity as a result of
recent decreases in international oil prices. As discussed in “Item 3. Key Information—Risk Factors” and elsewhere in this annual
report, actions by the Argentine government have had and will continue to have a significant effect on Argentine companies,
including us.
Policy and regulatory developments relating to the oil and gas industry in Argentina include, among others:
•
Price administration. In order to support economic growth, the Argentine government has sought a number of policies and
measures to limit increases in hydrocarbon prices which could directly affect final consumers. See “—Macroeconomic
conditions.” Notwithstanding the foregoing, the Argentine government has implemented from time to time certain price
and investment incentives for certain products which allowed companies to receive increased prices mainly in connection
with investments and certain sales. See “—Gas programs” and “—Refining Plus and Petroleum Plus programs.” In
addition, as a result of the decline in international oil prices, the Argentine government had established incentives to
domestic oil producers, aiming to promote domestic activity. For more information, see “Item 4. Information on the
Company—Regulatory Framework and Relationship with the Argentine Government—Resolution 14/2015.” As a result,
fluctuations in Argentina’s domestic hydrocarbon prices have not matched increases or decreases at the pace of
international and regional prices.
•
•
Export administration. Since 2004, the Argentine government has prioritized domestic demand and adopted policies and
regulations partially restricting the export of certain hydrocarbon products. These regulations have impacted our export
sales as described in “—Declining export volumes.”
Export duties. Since the economic crisis in 2002, the Argentine government has imposed export taxes on certain
hydrocarbon products. These taxes have substantially increased over time as international prices have surged. In addition,
the Argentine government launched a series of measures designed to sustain the activity and production in the domestic oil
industry, including reductions to withholding taxes applicable to exports of certain petroleum products. For more
information, see “Item 4. Information on the Company—Regulatory Framework and Relationship with the Argentine
Government—Taxation”. For a description of the most recent export duties on hydrocarbon exports, see “—International
oil and gas prices and Argentine export taxes.”
•
Domestic supply requirements. The Argentine government has at times issued regulatory orders requiring producers to
inject natural gas in excess of contractual commitments and supply other hydrocarbon products to the domestic market. As
a result, we have had to limit our exports. In addition, we have imported diesel in order to satisfy domestic demand, which
has increased our operating costs. See “—Cost of sales.”
128
•
•
•
•
Gas programs. (a) The Argentine Secretariat of Energy, by Resolution S.E. No. 24/2008 of March 13, 2008, created the
“Gas Plus” program to encourage the production of natural gas from newly discovered reserves, new fields and tight gas,
among other sources. Natural gas produced under the Gas Plus program is not subject to the prices set forth in Agreement
2007-2011. See “Item 4. Information on the Company—Regulatory Framework and Relationship with the Argentine
Government—Market Regulation—Natural Gas.” (b) On February 14, 2013, Resolution 1/2013 of the Commission was
published and formally created the Gas Plan. Under this regulation, gas producing companies were invited to file with the
Commission before June 30, 2013 projects to increase natural gas injection, in order to receive an increased price of
U.S.$7.50/mmBtu for all additional natural gas injected. These projects shall comply with minimum requirements
established in Resolution 1/2013, and will be subject to approval by the Commission. The projects will have a maximum
term of five years, renewable at the request of a company, upon decision of the Commission. If a company in a given
month does not reach the committed production increase, it will be required to make up for such volumes not produced. On
May 23, 2013, the Commission approved the project submitted by YPF. (c) On November 29, 2013, Resolution 60/2013 of
the Commission was published and formally created the “Natural Gas Additional Injection Stimulus Program for
Companies with Reduced Injection.” Under this regulation, gas- producing companies with a natural gas average injection
lower than 3,500,000 cubic meters per day during the six months preceding the issuance of Resolution 60/2013 may apply,
including those with no gas injection at all. Companies were invited to file with the Commission before March 31, 2014
projects to increase natural gas injection. Companies that currently participate in the “Natural Gas Additional Injection
Stimulus Program” and are eligible for the new program may withdraw from the original program and apply to the new
program. Projects may have a maximum term of four years, and participants may petition the Commission for a one-year
extension, granted at the Commission’s discretion. The program sets a range of guaranteed prices from U.S.$7.50/mmBtu
to U.S.$4.00/mmBtu, depending on the natural gas injection performance of each producer. (d) A similar program was
created under Resolution 60/2013 of the Hydrocarbon Commission, as amended by Resolution 83/2013 of the
Hydrocarbon Commission, for gas producers that failed to file their natural gas additional injection program filings before
the expiration date established by Resolution 1/2013 of the Hydrocarbon Commission. The compensation to be received
under this new program varies from U.S.$4.00 per mmBtu to U.S.$7.50 per mmBtu, depending on the production curve
reached by the applicable company. Additionally, a third stimulus program entered into effect under Commission
Resolution No. 185/2015 for companies without any prior gas production in Argentina at the time of issuance of the
resolution. Similar to the Gas Plan, companies with an approved program under this new Resolution will receive
compensation for the difference between the price obtained in the market for the sale of all their gas production and
U.S.$7.50/mmBtu. The gas production subject to such compensation will be only the production proceeding from areas
acquired by companies with approved programs under either Resolution 1/2013 or Resolution 60/2013 and as long as such
production was computed under these programs as “increase injection” as opposed to “base injection.”
Refining Plus and Petroleum Plus programs. Decree No. 2014/2008 of the Department of Federal Planning, Public
Investment and Services of November 25, 2008 created the “Refining Plus” and the “Petroleum Plus” programs to
encourage (a) the production of diesel and gasoline and (b) the production of crude oil and the increase of reserves through
new investments in exploration and operation. The Argentine Secretariat of Energy, by Resolution S.E. No. 1312/2008 of
December 1, 2008, approved the regulation of these programs. The programs entitle refining companies that undertake the
construction of a new refinery or the expansion of their refining and/or conversion capacity and production companies that
increase their production and reserves within the scope of the program to receive export duty credits to be applied to
exports of products within the scope of Resolution No. 394/2007 and Resolution No. 127/2008 (Annex) issued by the
Department of Economy and Production. In February 2012, by Notes Nos. 707/12 and 800/12 of the Argentine Secretariat
of Energy, YPF was notified that the benefits granted under the “Refining Plus” and the “Petroleum Plus” programs have
been temporarily suspended. The reasons alleged for such suspension are that the programs were created in a context
where domestic prices were lower than currently prevailing prices and that the objectives sought by the programs have
already been achieved. Executive Decree No. 1330/2015 of July 13, 2015 declared the termination of the “Petroleum Plus”
program, establishing compensation in public bonds (“BONAR 2024”). As of the date of this annual report, YPF has not
been compensated for the benefits accrued and not yet redeemed by YPF.
Sworn declaration regarding imports. On January 5, 2012, the Federal Administration of Public Revenue (“AFIP”) issued
Resolution No. 3252, which requires importers to submit a sworn declaration prior to the placing of a purchasing order for
all imports to Argentina, with effect from February 1, 2012. Depending on the nature of the goods to be imported as well
as other criteria, certain State agencies may have access to this declaration and can raise objections. The criteria for the
approval or rejection of the sworn declaration are not legally defined. On December 23, 2015, the Ministry of Production
published Resolution No. 5/2015, which reinstated the automatic and non-automatic import licenses. See “Item 4.
Information on the Company—Regulatory Framework and Relationship with the Argentine Government— Automatic and
Non-Automatic Import Licenses.”
Cross-border services information reporting. On February 9, 2012, the AFIP issued Resolution No. 3276, which requires
Argentine individuals and companies that employ the services of providers located outside of Argentina, where the fee for
such services is equal to or greater than U.S.$100,000, to submit a sworn declaration in respect of such services, with effect
from April 1, 2012.
The Expropriation Law declared achieving self-sufficiency in the supply of hydrocarbons, as well as in the exploitation,
industrialization, transportation and sale of hydrocarbons, a national public interest and a priority for Argentina. In addition, its stated
goal is to guarantee socially equitable economic development, the creation of jobs, the increase of the competitiveness of various
economic sectors and the equitable and sustainable growth of the Argentine provinces and regions. See “Item 4. Information on the
Company—Regulatory Framework and Relationship with the Argentine Government—The Expropriation Law.” Upon the passage of
the Expropriation Law, the Argentine government gained control over the Company. See “Item 3. Key Information—Risk Factors—
Risks Relating to Argentina—The Argentine federal government will control the Company according to domestic energy policies in
accordance with Law No. 26,741 (“the Expropriation Law”)”
129
Declining export volumes
The exported volumes of many of our hydrocarbon products have declined significantly in recent years, driven mainly by
increasing domestic demand and export administration, as well as by declines in production. This shift from exports to domestic sales
has impacted our results of operations as the prices for hydrocarbons in the domestic market have, due to price administration,
generally not kept pace with international and regional prices. Notwithstanding the foregoing, and as a result of export taxes affecting
hydrocarbon products (“Item 4. Information on the Company—Regulatory Framework and Relationship with the Argentine
Government— Exploration and Production.”), prices in the export market do not materially differ from those prevailing in the
domestic market.
The table below presents, for the periods indicated, the exported volumes of certain of our principal hydrocarbon products.
2015
Year Ended December 31,
2014
(units sold)
2013
Product
Natural gas (mmcm)
Gasoline (mcm)
Fuel oil (mtn)(1)
Petrochemicals (mtn)
2
90
462
301
9
72
607
254
27
74
567
281
(1)
Includes bunker oil sales of 462 mtn, 607 mtn and 567 mtn in 2015, 2014 and 2013, respectively.
Due to the decreased export product volumes indicated above, the portion of our revenues accounted for by exports decreased
steadily in recent years. Exports accounted for 7.9%, 17.1% and 13.3% of our consolidated revenues in 2015, 2014 and 2013,
respectively. Export duties are accounted for as tax expenses in our Audited Consolidated Financial Statements.
The Argentine government currently requires companies intending to export crude oil, diesel and LPG to obtain prior
authorization from the Argentine Secretariat of Energy by demonstrating that local demand for those products has been satisfied.
Since 2005, because domestic diesel oil production has generally not been sufficient to satisfy Argentine consumption needs, exports
of diesel oil have been substantially restricted.
International oil and gas prices and Argentine export taxes
Since the economic crisis in 2002, the Argentine government has imposed export taxes on certain hydrocarbon products. These
taxes have substantially increased over time as international prices surged, prior to significant price decreases since late 2014.
Notwithstanding the foregoing, the Argentine government launched a series of measures designed to sustain the activity and
production in the domestic oil industry, including reductions to withholding taxes applicable to exports of certain petroleum products.
For a description of these taxes, reference prices and prices allowed to producers, see “Item 4. Information on the Company—
Regulatory Framework and Relationship with the Argentine Government—Market Regulation” and “Item 4. Information on the
Company—Regulatory Framework and Relationship with the Argentine Government—Taxation.”
Export taxes have affected the profitability of hydrocarbon exportation. They have also contributed to a shift away from exports
and towards domestic sales and reduced the export parity prices. For more information, see “—Declining export volumes.”
Seasonality
Historically, our results have been subject to seasonal fluctuations during the year, particularly as a result of greater natural gas
sales during the winter. After the 2002 devaluation and as a consequence of the natural gas price freeze imposed by the Argentine
government, the use of this fuel has diversified, generating an increase in its long-term demand throughout the year. However, sales
of natural gas are still typically much higher in the winter to the residential sector of the Argentine domestic market, the prices for
which are significantly lower than in other sectors of the Argentine market. Notwithstanding the foregoing, under the Gas Plan, gas
producing companies were invited to file with the Commission before June 30, 2013 projects to increase natural gas injection, in
order to receive an increased price of U.S.$7.50/mmBtu for all additional natural gas injected. These projects shall comply with
minimum requirements established in the Gas Plan, and will be subject to approval by the Commission, including a maximum term of
five years, renewable at the request of the beneficiary, upon decision of the Commission. If the beneficiary company in a given month
does not reach the committed production increase it will have to make up for such volumes not produced. The natural gas pricing
program was recently incorporated into the Hydrocarbons Law, as modified by Law No. 27,007.
130
Critical Accounting Policies
Our accounting policies are described in Note 1 to the Audited Consolidated Financial Statements. IFRS requires us to make
estimates and assumptions that affect the reported amounts of assets and liabilities, revenues and expenses and disclosures of
contingent assets and liabilities in our financial statements. Actual results could differ from those estimates. We consider the
following policies or matters to be most critical in understanding the judgments that are involved in preparing our Audited
Consolidated Financial Statements and the uncertainties that could impact our results of operations, financial condition and cash
flows:
•
•
•
•
•
•
Functional and reporting currency. See Note 1.b.1) to the Audited Consolidated Financial Statements.
Impairment of long-lived assets. See Notes 1.b.8) and 1.b.9) to the Audited Consolidated Financial Statements.
Furthermore, for additional information regarding assumptions used for our impairment calculation as of
December 31, 2015, see Note 1.c to the Audited Consolidated Financial Statements.
Depreciation of oil and gas producing properties. See Note 1.b.6) to the Audited Consolidated Financial Statements.
Asset retirement obligations. See Note 1.b.6) to the Audited Consolidated Financial Statements.
Environmental liabilities, litigation and other contingencies. See Note 10 and 11 to the Audited Consolidated
Financial Statements.
Income tax and deferred tax. See Note 6.i) to the Audited Consolidated Financial Statements.
In addition, for information regarding our estimates of oil and gas reserves, see “Item 4. Information on the Company—
Exploration and Production—Oil and Gas reserves.”
It is difficult to predict with reasonable certainty the amount of expected future impairment losses given the many factors
impacting the asset base and the cash flows used in the prescribed ceiling test calculation. These factors include, but are not limited
to, future prices, operating costs and negotiated savings, foreign exchange rates, capital expenditures timing and negotiated savings,
production and its impact on depletion and cost base, upward or downward reserve revisions, reserve additions, and tax attributes.
According to the foregoing, and in connection with impairment of long-lived assets according to our estimation as of December 31,
2015, if the average of the oil prices used for impairment tests as of December 31, 2015 were reduced by U.S.$5 each year, holding
all other factors constant, our ceiling test limitation related to the net book value of our proved oil properties would be reduced by
approximately U.S.$2.2 billion. As a result of the estimated reduction in the ceiling test limitation, a negative charge of U.S.$1.4
billion would be recorded, net of the effect in the income tax. This hypothetical calculation was prepared assuming all other factors
remain constant to isolate the impact of commodity prices on our ceiling test limitation. Consequently, as noted above, actual cash
flows may be materially affected by other factors. There are numerous uncertainties inherent in the estimation present value of future
cash flow, so this hypothetical calculation should not be construed as indicative of our development plans or future results. For more
information on recent declines in the international Brent crude oil prices, domestic crude oil prices and domestic gasoline prices, see
“—Macroeconomic Conditions.”
For information regarding our domestic oil prices and reserves sensitivity analysis, See “Item 3. Key Information—Risk
Factors—Risks Relating to Argentina— Our oil and natural gas reserves are estimates.”
Principal Income Statement Line Items
The following is a brief description of the principal line items of our income statement.
Revenues
Revenues include primarily our consolidated sales of crude oil and natural gas and refined fuel and chemical products net of the
payment of applicable fuel transfer taxes and turnover taxes. Customs duties on exports are accounted as selling expenses in our
consolidated results of operations. Royalty payments required to be made to a third party, whether payable in cash or in kind, which
are a financial obligation, or are substantially equivalent to a production or similar tax, are accounted for as a cost of production and
are not deducted from revenues. See “Item 4. Information on the Company—Exploration and Production—Oil and gas production,
production prices and production costs” and Note 6.l to the Audited Consolidated Financial Statements.
131
Cost of sales
The following table presents, for each of the years indicated, a breakdown of our consolidated cost of sales by category:
Inventories at beginning of year
Purchases for the year
Production costs (1)
Translation effect
Inventories at end of year
Cost of sales
For the year ended December 31,
2014
2015
(in millions of pesos)
2013
9,881 6,922
13,001
33,886 35,951 25,846
85,550 68,840 42,980
2,821 2,227
6,358
(19,258) (13,001) (9,881)
119,537 104,492 68,094
(1) The table below presents, for each of the years indicated, a breakdown of our consolidated production costs by category:
Salaries and social security costs
Fees and compensation for services
Other personnel expenses
Taxes, charges and contributions
Royalties and easements
Insurance
Rental of real estate and equipment
Depreciation of fixed assets
Amortization of intangible assets
Industrial inputs, consumable material and supplies
Operational services and other service contracts
Preservation, repair and maintenance
Contractual commitments
Transportation, products and charges
Fuel, gas, energy and miscellaneous
Total
For the year ended December 31,
2014
2013
2015
(in millions of pesos)
7,566
775
2,303
1,144
11,932
831
3,360
25,706
185
3,801
6,261
14,231
31
4,796
2,628
85,550
5,341
554
1,622
2,260
9,503
705
2,630
19,201
140
3,415
5,297
11,322
52
3,874
2,924
68,840
4,211
393
1,108
1,123
5,845
520
1,747
10,766
95
1,992
2,540
7,673
167
2,582
2,218
42,980
Our cost of sales accounted for 76.6%, 73.6% and 75.6% of our consolidated revenues in 2015, 2014 and 2013, respectively.
Our cost of sales increased by 14.4%% from 2014 to 2015, mainly as a result of: (i) increased purchases of crude oil from third
parties driven by the increase in oil prices in pesos in the domestic market; (ii) increased royalties, driven mainly by higher crude oil
prices at the wellhead as a result of the foregoing and higher natural gas prices; (iii) higher labor costs; (iv) higher costs related to the
renegotiation of certain service contracts and (v) increased depreciation of fixed assets as a result of the higher investment in fixed
assets and asset remeasurement in pesos as a result of devaluation of the Argentine peso against the U.S. dollar, which is our
functional currency. All of this was partially offset by (i) decreased purchases of refined products, principally gasoline and diesel, in
the international market driven by lower volume and lower international prices and (ii) insurance compensation of Ps. 1,688 million
recorded in 2015, compared to Ps. 2,041 million in 2014, related to a fire that occurred at the La Plata refinery in April 2013 and a
fire that occurred at the Cerro Divisadero crude oil treatment plant in March 2014.
Other operating results, net
Other operating results, net principally include provisions for pending lawsuits and other claims, provisions for environmental
remediation and provisions for defined benefit pension plans and other post-retirement benefits.
132
The following items, among others, are also included as of December 31, 2015: (i) the recognition of a loss in the value of assets at
the time of completion of the evaluation of impairment of Fixed Assets and Intangible Assets driven mainly by a reduction in the
estimated future price of oil, (ii) the temporary economic assistance received by Metrogas in accordance with Resolution No. 263/2015
of the Argentine Ministry of Energy and (iii) the incentive for domestic manufacturers of capital goods received by A-Evangelista in
accordance with the provisions of the Decree No. 379/2001 of the Ministry of Economy. For more information on the Metrogas
temporary economic assistance, see Note 6.o to the Audited Consolidated Financial Statements as of December 31, 2015.
Financial income (expense), net
Financial income (expense), net consists of the net of gains and losses on interest paid and interest earned and foreign currency
exchange differences.
Taxes
The effective income tax rates for the periods discussed in this annual report differ from the statutory tax rate (35%) mainly
because: the registration of the deferred income tax as a result of the effect of applying the current tax rate (35%) on the difference
generated between the tax basis of fixed and intangible assets (for which any asset remeasurement from the original value in pesos is not
acceptable under income tax law) and their book value under IFRS, measured in its functional currency and converted into pesos, as
described in Note 1.b.1 to our Audited Consolidated Financial Statements. See Note 6.i to the Audited Consolidated Financial
Statements for a more detailed description of the difference between statutory income tax rate and effective income tax rate.
Results of Operations
Consolidated results of operations for the years ended December 31, 2015, 2014 and 2013
The following table sets forth certain financial information as a percentage of revenues for the years indicated.
Year Ended December 31,
2015
2014
2013
Revenues
Cost of sales
Gross profit
Administrative expenses
Selling expenses
Other operating results, net
Exploration expenses
Operating Income
(percentage of revenues)
100.0 100.0 100.0
(76.6) (73.6) (75.6)
23.4 26.4 24.4
(3.0)
(3.6) (3.2)
(8.4)
(7.1) (7.1)
0.3
(0.5) (0.7)
(1.6) (1.4)
(0.9)
10.6 14.0 12.4
The tables below present, for the years indicated, volume and price data with respect to our sales of our principal products in the
domestic and export markets, respectively. Due to the decreased export product volumes, the portion of our revenues accounted for by
exports decreased steadily in recent years. Exports accounted for 7.9%, 17.1% and 13.3% of our consolidated revenues in 2015, 2014
and 2013, respectively.
Domestic Market
Product
Units sold
2015
Average
Price per
unit(1)
(in pesos)
Year Ended December 31,
2014
Units sold
Average
Price per
unit(1)
(in pesos)
Units sold
2013
Average
Price
per unit(1)
(in pesos)
Natural gas
Diesel
Gasoline
Fuel oil
Petrochemicals
12,365 mmcm
8,134 mcm
4,894 mcm
1,387 mtn
587 mtn
1,620 /mcm
6,912 /cm
6,867 /cm
5,095 /ton
5,620 /ton
12,028 mmcm
8,166 mcm
4,723 mcm
1,129 mtn
643 mtn
1,315 /mcm
6,466 /cm
6,146 /cm
4,505 /ton
6,109 /ton
11,092 mmcm
817 /mcm
8,098 mcm
4,545 mcm
734 mtn
579 mtn
4,277 /cm
3,895 /cm
2,963 /ton
4,189 /ton
(1) Average prices shown are net of applicable domestic fuel transfer taxes payable by consumers.
133
Export Markets
Product
Units sold
2015
Average
Price per unit (1)
(in pesos)
Year Ended December 31,
2014
Units sold
Average
Price per unit (1)
(in pesos)
Units sold
2013
Average
Price per unit (1)
(in pesos)
Gasoline
Fuel oil
Petrochemicals
(2)
90 mcm
462 mtn
6,265 /cm
2,972 /ton
72 mcm
607 mtn
7,289 /cm
4,382 /ton
74 mcm
567 mtn
5,274 /cm
3,157 /ton
301 mtn
5,694 /ton
254 mtn
7,751 /ton
281 mtn
5,262 /ton
(1) Average prices shown are gross of applicable export withholding taxes payable by us.
(2)
Includes exports of refined paraffinic.
Revenues
Revenues in 2015 were Ps. 156,136 million, representing a 10.0% increase compared to Ps. 141,942 million in 2014. Among the
main factors contributing to the increase were:
•
•
•
•
•
•
•
Diesel revenues increased by Ps. 3,466 million, or 6.5%, as a result of an increase in the average price for diesel mix
of approximately 11.0% with a decrease in sales volumes of approximately 0.4%, reflecting a 24.6% increase in
sales volume of Eurodiesel, a premium diesel;
Gasoline revenues increased by Ps. 4,780 million, or 15.8%, primarily as a result of an increase in the average price
for gasoline mix of approximately 14.1% and an increase in sales volumes of approximately 3.6%, reflecting a
25.6% increase of sales volume for Infinia gasoline;
Fuel oil revenues increased by Ps. 697 million, or 9.0%, primarily as a result of an increase in the average price of
fuel oil of approximately 2.3% and an increase in sales volumes of 6.6%;
Natural gas revenues increased by Ps. 4,629 million, or 26.6%, primarily as a result of an increase in sales volumes
of approximately 3.5%, which was driven by increased production. The increase was further due to an increase of
22.4% in the average sale price obtained by YPF in Argentine peso terms (or an 7.2% increase in U.S. dollar terms).
This includes not only higher prices from third parties but also the Gas Plan, which increased the average prices
obtained by YPF as a result of increasing YPF’s natural gas production;
Crude oil revenues decreased by Ps. 826 million, or 31.4%, primarily due to a decrease in the average price for
crude oil of approximately 7.0% and a decrease in sales volumes of approximately 26.2%, mainly as a result of a
single significant export event in February 2014;
LPG and aviation fuel sales to foreign markets decreased by Ps. 1,434 million, or 27.2%, mainly due to a decrease
in international aviation fuel prices of approximately 31.9%, which was partially offset by an increase in sales
volumes of 6.9%;
Exports of flour, grain and oil increased by Ps. 570 million, or 18.6%, due to an increase in sales volumes of
approximately 35.6%, which was partially offset by a decrease in international prices of 12.5%.
In addition, in 2015, the Company recorded Ps. 1,988 million of revenue corresponding to the Crude Oil Production Stimulus
Program (Programa de Estímulo a la Producción de Petróleo Crudo) set forth under Resolution 14/2015 of the Hydrocarbon
Commission. See “Item 4. Information on the Company—Regulatory Framework and Relationship with the Argentine Government—
Market Regulation—Resolution No. 14/2015” in the 2015 20-F.
134
Revenues in 2014 were Ps. 141,942 million, representing a 57.5% increase compared to Ps. 90,113 million in 2013. Among the
main factors contributing to the increase were:
•
•
•
•
Diesel revenues increased by Ps. 18,165 million, or 52.4%, primarily as a result of an increase in the average price
for diesel mix of approximately 51.2% and an increase in sales volumes of approximately 0.8%;
Gasoline revenues increased by Ps. 11,325 million, or 64.0%, primarily as a result of an increase in the average
price for gasoline mix of approximately 57.8% and an increase in sales volumes of approximately 3.9%;
Fuel oil revenues increased by Ps. 3,777 million, or 95.3%, primarily as a result of an increase in the average price
for fuel oil of approximately 46.4% and an increase in sales volumes of 33.4% in 2014, which were directed
primarily to the domestic electricity generation market; and
Natural gas revenues in the domestic market increased by Ps. 8,317 million, or 91.5%, primarily as a result of an
increase in sales volumes of approximately 21.7%, which was driven by (i) increased production, (ii) the YSUR
acquisition, accounting for an increase of revenues of approximately Ps. 1,476 million and (iii) increased sales of
natural gas byYPF Energía Eléctrica, accounting for an increase in revenues of approximately Ps. 84 million. The
increase was further due to an increase of 57.4% in the average sale price obtained by YPF in Argentine peso terms
(or a 6% increase in U.S. dollar terms), which includes not only higher prices from third parties but also the Gas
Plan, which increased the average prices obtained by YPF as a result of increasing YPF’s natural gas production.
Cost of sales
Cost of sales in 2015 was Ps. 119,537 million, representing a 14.4% increase compared to Ps. 104,492 million in 2014. Among
the main factors contributing to this increase were:
•
•
•
•
•
•
•
•
Fixed asset depreciation costs increased by Ps. 6,505 million, or 33.9%, primarily as a result of (i) increased
investments in assets and (ii) overall increases in Argentine peso terms of the value of fixed assets, which was
related to the depreciation of the Argentine peso against the U.S. dollar, which is the functional currency of the
Company;
Total lifting costs increased by Ps. 5,994 million, or 26.2%, primarily as a result of an increase of the unit indicator,
expressed in pesos, of 22.9% and the previously mentioned increase of crude oil and natural gas production;
Refining costs increased by Ps. 912 million, or 17.8%. This increase was driven by inflation, wage increases and a
higher processing level of refineries as mentioned above;
Royalty payments increased by Ps. 1,535 million, or 15.5%, primarily as a result of increases of (i) Ps. 692 million
related to crude oil production and (ii) Ps. 843 million related to natural gas production;
Transportation costs increased by Ps. 922 million, or 23.8%, mainly due to increases in rates in 2015;
Imported gasoline, diesel, and jet fuel, especially “premium” and “ultradiesel,” decreased by Ps. 4,425 million, or
41.5%, primarily as a result of lower international prices of 40.6% and lower purchase volumes of 16.1%;
Purchases of crude oil from third parties increased by Ps. 1,175 million, or 11.5%, primarily as a result of an
increase in average prices charged by third parties in Argentine peso terms of approximately 6.6%, which was
mainly related to the devaluation of the Argentine peso and an increase in purchased volumes of approximately
4.6%. In comparison, there was a 7.0% decrease in average prices charged by third parties in U.S. dollar terms;
Purchases of biofuels increased by Ps. 803 million, or 11.6%, primarily as a result of an increase in volume
purchased of FAME and bioethanol of 7% and 30%, respectively, partially offset by an approximately 3.6%
decrease in the price of FAME and a 5.7% decrease in the price of bioethanol.
Additionally, insurance payments related to the losses suffered from an incident at our La Plata refinery in April 2013 were Ps.
615 million in 2015, compared to Ps. 2,117 million in 2014. This had a negative impact on cost of sales for the current period
compared to the same period last year. In addition, with respect to the incident that affected the facilities of our oil treatment plant in
Cerro Divisadero in Mendoza in March 2014, an insurance payment amount of Ps. 1,165 million was recorded in 2015, of which Ps.
794 million was recorded as a lower cost for purchases and Ps. 371 million as other operating income.
135
Cost of sales in 2014 was Ps. 104,492 million, representing a 53.5% increase compared to Ps. 68,094 million in 2013. Among
the main factors contributing to this increase were:
•
•
•
•
•
•
•
•
•
An increase in imported gasoline and diesel, especially “premium” and “ultradiesel,” of Ps. 2,745 million, or 42.4%,
primarily as a result of devaluation of the Argentine peso against the dollar (slightly lower in U.S. dollars), while
diesel imported volumes remained flat and gasoline imported volumes increased slightly;
A net increase in purchases of crude oil from third parties of approximately Ps. 2,267 million, or 28.6%, primarily as
a result of an increase in average prices charged by third parties in Argentine peso terms of approximately 55.3%,
which was mainly related to devaluation of the Argentine peso. In comparison, there was a 5% increase in average
prices charged by third parties in U.S. dollar terms. This increase was partially offset by (i) a 527,000 cm decrease
in purchased volumes, primarily as a result of higher than usual purchases of heavy crude oil during the first quarter
of 2013 to supply higher fuel oil production for electricity generation and (ii) the inclusion of crude oil production
of YSUR;
An increase in purchases of biofuels of Ps. 2,799 million, or 70.3%, primarily as a result of an approximately 37%
increase in the price of fatty acid methyl esters, known as FAME, and a 50% increase in the price of bioethanol. The
volumes purchased of FAME and bioethanol increased 5% and 49%, respectively;
An increase in fixed assets depreciation costs of Ps. 8,435 million, or 78.4%, primarily as a result of (i) increased
investments in assets, (ii) overall increases in Argentine peso terms of the value of fixed assets, which was related to
the devaluation of the Argentine peso against the U.S. dollar (which is the functional currency of the Company),
(iii) increases in production volumes with a consequential effect on depreciation rates and (iv) the depreciation of
additional assets incorporated as a result of the YSUR acquisition;
An increase in the costs of operational services and other repair and maintenance service contracts of Ps.
6,201 million, or 64.5%, primarily as a result of (i) increases in services provided in the Upstream business segment
related to oil and natural gas production increases, (ii) operational costs linked to YSUR’s operations since the
acquisition in early 2014 and (iii) an overall increase in prices;
An increase in royalty payments of Ps. 3,617 million, or 65.7%, primarily as a result of increases of (i) Ps.
2,586 million related to crude oil production of YPF S.A., (ii) Ps. 543 million related to natural gas production of
YPF S.A., (iii) Ps. 460 million related to crude oil and natural gas production of YSUR and (iv) Ps. 28 million
related to crude oil and natural gas production of YPF Energía Eléctrica S.A. These increases resulted from higher
production volumes and also from higher prices in Argentine peso terms, which were mainly related to the
devaluation of the Argentine peso against the U.S. dollar;
Increases in salaries and other personnel expenses of Ps. 1,644 million or 30.9%, mainly as a result of negotiations
and agreements with corresponding unions;
Increases in environmental provisions of Ps. 205 million, primarily as a result of developments related to
environmental liabilities in both the Exploration and Production and Downstream business segments; and
An increase in other production costs of Ps. 323 million, primarily as a result of the acquisition and incorporation of
YSUR in our consolidated financial statements.
These increases were partially offset by insurance compensation of Ps. 2,041 million recognized during 2014, which stemmed
from YPF’s insurance coverage related to the April 2013 La Plata refinery fire. This compensation was recorded primarily as lower
costs for purchases. In relation to this event, in 2013 we recorded compensation of Ps. 1,479 million under other operating results, net
by way of pecuniary damage compensation and Ps. 477 million in lost profits, which is reflected as lower costs for purchases. We
used a similar approach to record the compensation in 2014.
Administrative expenses
Administrative expenses in 2015 were Ps. 5,586 million, representing a 23.3% increase compared to Ps. 4,530 million in 2014,
primarily as a result of increases in personnel costs and IT service contracts.
Administrative expenses in 2014 were Ps. 4,530 million, representing a 68.7% increase compared to Ps. 2,686 million in 2013,
primarily as a result of increases in publicity and advertising expenses, personnel cost increases for wage increases, IT service
contracts and higher expenses due to the incorporation into the consolidation process as a result of the acquisitions of Metrogas since
the takeover of that company in May 2013 and YSUR, as discussed in Note 2 to the Audited Consolidated Financial Statements.
136
Selling expenses
Selling expenses in 2015 increased to Ps. 11,099 million, representing a 9.7% increase compared to Ps. 10,114 million in 2014,
primarily as a result of higher charges for product transportation, mainly related to increased rates of transportation fuels in the
domestic market and higher volumes transported and sold and higher personnel cost. This increase was partially offset by lower
export taxes, mainly due to the rate reduction established by Resolution No. 1077/2014, lower export volumes of crude oil and the fall
in prices for exports of LPG and petrochemicals, as well as lower charges related to recoveries of provisions for doubtful accounts in
the segment of natural gas distributors.
Selling expenses in 2014 increased to Ps. 10,114 million, representing a 33.6% increase compared to Ps. 7,571 million in 2013,
primarily as a result of higher bank transaction taxes as a consequence of our increased activity and increased transportation fees for
fuel products in the domestic market.
Exploration expenses
Exploration expenses in 2015 increased to Ps. 2,473 million, representing a 21.6% increase compared to the Ps. 2,034 million in
exploration expenses in 2014, primarily as a result of an increase in exploration activities in which the Company made investments.
Total investments in exploration increased to Ps. 503 million, representing a 22.2% increase compared to the total investment in
exploration in 2014. In addition, negative results from unproductive exploratory drilling in 2015 compared to 2014 increased by Ps.
160 million. Additionally, expenditures for the performance of geological and geophysical studies increased by Ps. 253 million,
mainly as a result of seismic survey studies in the Chachahuén and Zampal Norte areas in the province of Mendoza.
Exploration expenses in 2014 increased to Ps. 2,034 million, representing a 145.4% increase compared to Ps. 829 million in
2013, primarily as a result of an increase in the exploration activity in Argentina. In 2014, investments of exploration assets increased
to Ps. 2,259 million, representing an approximately 149% increase compared to the previous year.
Other operating results, net
Other operating results, net in 2015 decreased to a loss of Ps. 853 million, representing a 17.2% decrease compared to a loss of
Ps. 1,030 million in 2014. In 2015, while conducting an evaluation of impairment of fixed assets and intangible assets, the Company
recognized an impairment of Ps. 2,535 million, which was recorded as other operating results, net. This impacted field assets in
Argentina with reserves and production primarily of oil within the Upstream business segment by Ps. 2,361 million, driven mainly by
lower estimated future oil prices. Field assets with oil production and intangible assets in the U.S. decreased by Ps. 174 million due to
the decline in international crude oil prices.
In addition, our subsidiary Metrogas recorded additional revenues of Ps. 711 related to the temporary economic assistance
established by Resolution No. 263/2015 of the Ministry of Energy. Also, the provision for contingencies increased by Ps. 650 million
in connection with a ruling against YPF regarding a claim filed by the Union of Consumers and Users (Unión de Usuarios y
Consumidores) for claims from 1993 to 1997. The claim alleges that excess fees were charged to GLP consumers during that period.
In the fourth quarter of 2015, there was also a decrease in the provision for abandonment and dismantling obligations for wells of Ps.
524 million, mainly due to the agreement reached with our partner in the Magallanes area. In 2014, a provision of Ps. 1,227 million
was recorded by Maxus Energy Corporation, a subsidiary of YPF Holdings, linked to third party claims based on alleged breach of
contract. See Note 10 to the Consolidated Financial Statements.
Other operating results, net in 2014 decreased to a loss of Ps. 1,030 million, compared to income of Ps. 227 million in 2013, a
decrease of Ps. 1,257 million. The net loss recorded in 2014 was primarily as a result of (i) a provision of Ps. 1,227 million that was
recorded in 2014 by Maxus Energy Corporation, a subsidiary of YPF Holdings, which was related to third party claims based on
alleged contractual responsibilities, which it is contesting (see Note 10 to the Audited Consolidated Financial Statements);
(ii) revenues of Ps. 369 million recorded during 2014 from the sale of a 30% interest in the extension of the La Ventana concession
area in the province of Mendoza to Sinopec; and (iii) the income for the transfer of assets to Pluspetrol (primarily Cerro Arena) for
Ps. 188 million. The net income recorded in 2013 was primarily as a result of (i) expenses during the second quarter of 2013 related
to the AESU and Transportadora de Gas del Mercosur (“TGM”) arbitration based on a partial award rendered by the International
Chamber of Commerce Arbitration Tribunal; and (ii) revenue of Ps. 1,479 million recorded in 2013 corresponding to the accrual of
insurance for material damage of the Coke A unit and Topping C unit, both as a result of the previously-discussed April 2, 2013 fire
at the La Plata refinery.
137
Operating income
Operating income in 2015 was Ps. 16,588 million due to the factors discussed above, representing a 16.0% decrease compared to Ps.
19,742 million in 2014.
Operating income in 2014 was Ps. 19,742 million, representing a 76.9% increase compared to Ps. 11,160 million in 2013.
Financial results, net
In 2015, financial results, net were an income of Ps. 12,157 million, representing a 586.1% increase compared to income of Ps.
1,772 million in 2014. The Company registered a higher positive foreign exchange difference in net monetary liabilities in pesos due to
higher depreciation of the Argentine peso against the U.S. dollar in 2015 compared to the same period in 2014. The Company registered
higher interest expenses as a result of higher average indebtedness and higher interest rates in 2015 compared to the same period in 2014.
The average net debt in 2015 was Ps. 64,956 million, while the average net debt in 2014 was Ps. 30,362 million. The average net amount of
financial indebtedness was calculated as the linear average of current and non-current loans at the beginning and end of the corresponding
period, net of the linear average of cash and cash equivalents at the beginning and end of the corresponding period.
Financial results, net in 2014 were income of Ps. 1,772 million compared to income of Ps. 2,835 million in 2013, primarily as a result
of higher net financial interest expenses due to overall higher levels of indebtedness and higher interest rates in 2014, which was partially
offset by the effect of higher foreign exchange gains on net monetary liabilities in Argentine pesos related to the devaluation of the
Argentine peso against the U.S. dollar. The average net amount of financial indebtedness in 2014 was Ps. 30,362 million, compared to Ps.
16,767 million in 2013. The average net amount of financial indebtedness was calculated as the linear average of current and non-current
loans at the beginning and end of the corresponding period, net of the linear average of cash and cash equivalents at the beginning and end of
the corresponding period.
Income tax
Income tax in 2015 was Ps. 24,637 million, representing a 86.3% increase compared to Ps. 13,223 million in 2014. This increase was
due to higher deferred tax related to greater devaluation of the Argentine peso compared to 2014. This resulted in a deferred tax liability
substantially higher than last year. In addition, a lower current tax was recorded in 2015 because the devaluation of the Argentine peso
resulted in no current tax in 2015.
Income tax in 2014 was Ps. 13,223 million, representing a 42.7% increase compared to Ps. 9,269 million in 2013, primarily as a result
of (i) an increase in current income tax payable of Ps. 4,479 million as a result of increased taxable income for the reasons discussed above
and (ii) a decrease of deferred tax liabilities of Ps. 525 million.
Net income and other comprehensive income
Net income in 2015 was Ps. 4,426 million, representing a 50.0% decrease compared to Ps. 8,849 million in 2014.
Other comprehensive income in 2015 was Ps. 43,758 million, representing a 168.8% increase compared to Ps. 16,276 million in 2014.
This increase was mainly attributable to higher appreciation of fixed assets.
As a result of the foregoing, total comprehensive income in 2015 was Ps. 48,184 million, representing a 91.8% increase compared to
Ps. 25,125 million in 2014.
Net income in 2014 was Ps. 8,849 million, representing a 74.2% increase compared to Ps. 5,079 million in 2013.
Other comprehensive income in 2014 was Ps. 16,276 million, representing a 35.3% increase compared to Ps. 12,031 million in 2013,
primarily as a result of higher currency translation difference of fixed assets, taking into account that the U.S. dollar is the functional
currency of the Company and changes in the exchange rate.
As a result of the foregoing, total comprehensive income in 2014 was Ps. 25,125 million, representing an approximately 46.8%
increase compared to Ps. 17,110 million during the same period in 2013, as a result of the factors discussed above.
Consolidated results of operations by business segment for the years ended December 31, 2015, 2014 and 2013
In 2013, we reorganized our reporting structure by grouping the Chemical and Refining and Marketing business segments into a new
Downstream business segment. We made this change primarily because of the common strategy shared by the former Chemical and
Refining and Marketing segments, in light of the synergies involved in their activities to maximize the volume and quality of fuel offered to
the market.
138
The following table sets forth revenues and operating income for each of our business segments for the years ended
December 31, 2015, 2014 and 2013:
Revenues (1)
Exploration and production
Revenues
Revenue from intersegment sales (3)
Total exploration and production
Downstream
Revenues
Revenue from intersegment sales
Total refining and marketing
Corporate and other
Revenues
Revenue from intersegment sales
Total corporate and other
Less inter-segment sales and fees
Total revenues
Operating income (Loss) (2)
Exploration and production
Downstream
Corporate and other
Consolidation adjustments
Total operating income
For the year ended December 31,
2014
2013
2015
(in millions of pesos)
16,044 8,853 3,851
64,243 61,844 38,846
80,287 70,697 42,697
138,962 132,254 85,624
1,535 1,489 1,147
140,497 133,743 86,771
835
1,130
638
6,182 5,212 2,285
7,312 6,047 2,923
(71,960) (68,545) (42,278)
156,136 141,942 90,113
7,535 12,353 6,324
8,446 10,978 6,721
(2,331) (3,343) (1,522)
(363)
2,938
16,588 19,742 11,160
(246)
(1) Revenues are net of payment of a fuel transfer tax and turnover tax. Customs duties on hydrocarbon exports are disclosed in
“Taxes, charges and contributions,” as indicated in Note 6.n to the Audited Consolidated Financial Statements. Royalties with
respect to our production are accounted for as a cost of production and are not deducted in determining revenues. See Note
1.b.15 to the Audited Consolidated Financial Statements.
Includes exploration costs in Argentina and the United States and production operations in Argentina and the United States.
Intersegment revenues of crude oil to Downstream are recorded at transfer prices that reflect our estimate of Argentine market
prices.
(2)
(3)
Exploration and Production
Revenues from the Exploration and Production business segment in 2015 were Ps. 80,287 million, representing a 13.6%
increase compared to Ps. 70,697 million in 2014.
Operating income in 2015 for the Exploration and Production business segment was Ps. 7,535 million, a decrease of 39.0%
compared to Ps. 12,353 million in 2014. This decrease in operating income was principally due to the following factors:
•
The intersegment oil price measured in U.S. dollars decreased 8.4%, while increasing 4.5% in Argentine peso terms.
Oil production in respect of our operations in Argentina in 2015 reached 248,500 barrels per day, representing a
2.1% increase compared to 2014. This contributed to the increase of 0.2 million cm of crude oil, or 1.7%,
transferred from the Exploration and Production business segment to the Downstream business segment and a
decrease of 167,000 cm of crude oil, or 26.2%, in sales to third parties.
139
•
Natural gas production in respect of our operations in Argentina in 2015 reached 44.1 million cm per day,
representing a 4.2% increase compared to 2014. With the exception of the YSUR production, all natural gas
produced, net of internal consumption, is assigned to the Downstream segment for sale to third parties. Sales
volumes increased 3.5% in 2015 compared to 2014. The Exploration and Production business segment records the
average price obtained by YPF in such sales net of sales and marketing fees. The Exploration and Production
segment also includes revenues from the Gas Plan, which increases the average prices obtained by YPF as a result
of increasing YPF and YSUR’s natural gas production. The average natural gas revenue recorded by the Company
in 2015, including revenues from the Gas Plan, reached U.S.$4.62 per million BTU, a 7.2% increase compared to
U.S.$4.31 per million BTU in 2014.
•
•
In addition, in 2015, the Company recorded Ps. 1,988 million corresponding to the Crude Oil Production Stimulus
Program (Programa de Estímulo a la Producción de Petróleo Crudo) set forth by Resolution 14/2015 of the
Hydrocarbon Commission. “See “Item 4. Information on the Company—Regulatory Framework and Relationship
with the Argentine Government—Market Regulation —Resolution No. 14/2015.”
In addition, with respect to the incident that affected the facilities of our oil treatment plant in Cerro Divisadero in
Mendoza in March 2014, an insurance payment of Ps. 1,165 million was recorded in 2015. Of this amount, Ps.
794 million was recorded as a lower cost for purchases and Ps. 371 million as other operating income.
All of this was partially offset by:
•
Total operating costs in respect of our operations in Argentina in 2015 were Ps. 67,744 million (excluding
exploration costs and impairment charges), representing a 20.3% increase compared to Ps. 56,311 million in 2014.
Among the main factors contributing to the increase were:
(cid:123) Fixed asset depreciation costs increased by Ps. 5,895 million, or 34.3%, primarily as a result of overall
increases of the value of fixed assets in Argentine peso terms, which was related to the devaluation of the
Argentine peso against the U.S. dollar, as well as increased investments in fixed assets and increased
production;
(cid:123) Lifting costs increased by Ps. 5,994 million, or 26.2%, due to an increase of the unit indicator, expressed in
pesos, of 22.9% and the increase of crude oil and natural gas production discussed above;
(cid:123) Royalty payments increased by Ps. 1,535 million, or 15.5%, primarily as a result of increases of (i) Ps.
692 million related to crude oil production and (ii) Ps. 843 million related to natural gas production.
Exploration expenses in 2015 increased to Ps. 2,473 million, representing a 21.6% increase compared to the Ps. 2,034 million in
exploration expenses in 2014, primarily as a result of an increase in exploration activities in which the Company made investments.
Total investments in exploration increased to Ps. 503 million, representing a 22.2% increase compared to the total investment in
exploration in 2014. In addition, negative results from unproductive exploratory drilling in 2015 compared to 2014 increased by Ps.
160 million. Additionally, expenditures for the performance of geological and geophysical studies increased by Ps. 253 million,
mainly as a result of seismic survey studies in the Chachahuén and Zampal Norte areas in the province of Mendoza.
As discussed above, while conducting an evaluation of impairment of fixed assets and intangible assets, the Company
recognized an impairment of Ps. 2,535 million, which was recorded as other operating results, net. This impacted field assets in
Argentina with reserves and production primarily of oil within the Upstream business segment by Ps. 2,361 million, driven mainly by
estimated future lower oil prices. Field assets with oil production and intangible assets in the U.S. decreased by Ps. 174 million due to
the decline in international crude oil prices.
Revenues from the Exploration and Production business segment in 2014 were Ps. 70,697 million, representing a 65.6%
increase compared to Ps. 42,697 in 2013.
Operating income for the Exploration and Production business segment in 2014 was Ps. 12,353 million, representing a 95.3%
increase compared to Ps. 6,324 million in 2013. This increase in operating income was principally due to the following factors:
•
The intersegment oil price measured in U.S. dollars increased 2.2%, representing an approximately 51% increase in
Argentine peso terms, which was related primarily to the devaluation of the Argentine peso against the U.S. dollar.
Oil production in respect of our operations in Argentina in 2014 reached 235,700 barrels per day, representing a
2.0% increase, in addition to 7,800 barrels per day as a result of the YSUR acquisition. This contributed to the
increase of 1.2 million cm of crude oil, or 9.3%, transferred from the Exploration and Production business segment
to the Downstream business segment and a decrease of 212,000 cm of crude oil sales to third parties principally
outside Argentina.
140
•
Natural gas production in respect of our operations in Argentina in 2014 reached 37.6 million cm / day, representing
approximately an 11.1% increase, in addition to a 4.8 million cm per day increase as a result of the YSUR
acquisition. With the exception of the YSUR production, all natural gas produced, net of internal consumption, is
assigned to the Downstream segment for sale to third parties. The Exploration and Production business segment
records the average price obtained by YPF in such sales net of sales and marketing fees. The Exploration and
Production business segment also includes revenues from the Gas Plan, which increases the average prices obtained
by YPF as a result of increasing YPF and YSUR’s natural gas production. The average gas income per million BTU
recorded by the Company in 2014, including revenues from the Gas Plan, reached U.S.$4.31 representing a 6.5%
increase compared to U.S.$4.05 per million BTU in 2013.
•
Total operating costs in respect of our operations in Argentina in 2014 were Ps. 56,311 million, (excluding
exploration costs and impairment charges), representing a 58.4% increase compared to Ps. 35,544 million in 2013.
Among the main factors contributing to the increase were:
–
Fixed asset depreciation costs increased by Ps. 7,589 million, or 79.1%, primarily as a result of overall
increases of the value of fixed assets in Argentine peso terms, which was related to the depreciation of the
Argentine peso against the U.S. dollar, as well as increased investments in fixed assets and increased
production;
–
Operational services and other repair and maintenance service contract costs increased by Ps. 5,057 million, or
57.9%, primarily as a result of (i) increases in production activity, including crude oil and natural gas
production, (ii) an increase in rates charged due to a general increase in prices and (iii) an increase in prices as
a result of the depreciation of the Argentine peso;
–
–
Environmental expenditures and provisions increased by Ps. 282 million;
Royalty payments increased by Ps. 3,617 million, or 65.7%, principally due to increases of (i) Ps.
2,586 million relating to crude oil production of YPF S.A., (ii) Ps. 543 million relating to natural gas
production of YPF S.A., (iii) Ps. 460 million relating to the production of crude oil and natural gas of YSUR
and (iv) Ps. 28 million relating to the production of crude oil and natural gas of YPF Energía Eléctrica S.A.
These increases resulted from higher production volumes and higher prices in Argentine pesos, which was
principally due to depreciation of the Argentine peso against the U.S. dollar;
•
•
In 2014, we recorded revenues of Ps. 369 million for the sale of a 30% interest in the extension of the La Ventana
concession area in the province of Mendoza to Sinopec and Ps. 188 million for the transfer of assets to Pluspetrol
(primarily Cerro Arena). In 2013, expenses related to the AESU and TGM arbitration were recorded, based on a
partial award rendered by the International Chamber of Commerce Arbitration Tribunal.
Exploration expenses in 2014 were Ps. 2,034 million, representing a 145.4% increase compared to Ps. 829 million in
2013, primarily as a result of an increase in domestic exploration activity. In 2014, investment in exploration assets
increased to Ps. 2,259 million, representing an approximately 149% increase compared to the previous year.
Downstream
Revenues from the Downstream business segment in 2015 were Ps. 140.497 million, representing a 5.0% increase compared to
Ps. 133.743 in 2014.
Operating income for the Downstream business segment in 2015 was Ps. 8.446 million, representing a 23.1% decrease
compared to Ps. 10,978 million in 2014. This decrease in operating income is primarily due to the following factors:
•
•
The average volume of oil processed per day in YPF’s refineries increased 2.9% to 299,000 barrels of oil per day,
with diesel production increasing by 1.4%, gasoline by 7.6% and fuel oil by 10.4%;
Diesel revenues increased by Ps. 3,466 million, or 6.5%, as a result of an increase in the average price for diesel mix
of approximately 11.0% with a decrease in sales volumes of approximately 0.4%, reflecting a 24.6% increase in
sales volume of Eurodiesel, a premium diesel;
141
•
•
•
•
•
Gasoline revenues increased by Ps. 4,780 million, or 15.8%, primarily as a result of an increase in the average price
for gasoline mix of approximately 14.1% and an increase in sales volumes of approximately 3.6%, reflecting a
25.6% increase of sales volume for Infinia gasoline;
Fuel oil revenues increased by Ps. 697 million, or 9.0%, primarily as a result of an increase in the average price of
fuel oil of approximately 2.3% and an increase in sales volumes of 6.6%;
Petrochemical products revenues decreased by Ps. 879 million, or 14.9%, mainly due to the fall in prices in both the
domestic and international market;
LPG and aviation fuel sales to foreign markets decreased by Ps. 1,434 million, or 27.2%, mainly due to a decrease
of international aviation fuel prices of approximately 31.9% which was partially offset by an increase in sales
volumes of 6.9%;
Exports of flour, grain and oil increased by Ps. 570 million, or 18.6%, due to an increase in sales volumes of
approximately 35.6% which was partially offset by a decrease in international prices of 12.5%.
All of this was partially offset by:
•
Oil prices increased in Argentine peso terms as a result of the devaluation of the Argentine peso against the U.S.
dollar as well as higher volumes of crude oil transferred from the Exploration and Production business segment and
an increase in the volume of crude oil purchased from third parties of approximately 4.6% (about 117,000 cm). The
average purchase price in Argentine peso terms for crude oil transferred from the Exploration and Production
business segment increased approximately 4.5% compared to an increase for oil purchased from third parties of
approximately 6.6%. This variation in the percentage amounts is due to different mixes of grades of crude oil
purchased from third parties;
•
•
•
•
•
•
•
Imported gasoline, diesel and jet fuel, especially “premium” and “ultradiesel,” decreased by Ps. 4,425 million, or
41.5%, primarily as a result of lower international prices of 40.6% and lower purchase volumes of 16.1%;
Purchases of biofuels increased by Ps. 803 million, or 11.6%, primarily as a result of an increase in volume
purchased of FAME and bioethanol of 7% and 30%, respectively, partially offset by an approximately 3.6%
decrease in the price of FAME and a 5.7% decrease in the price of bioethanol;
Production costs related to refining costs increased by Ps. 912 million, or 17.8%. This increase was driven by
inflation wage increases, and also considering a higher processing level of refineries as mentioned above;
Fixed asset depreciation increased by Ps. 723 million, or 29.6%, primarily as a result of (i) increased investments in
assets and (ii) an overall increase in fixed assets values in Argentine pesos, which was related to the depreciation of
the Argentine peso against the U.S. dollar, which is the functional currency of the Company;
Selling expenses increased by Ps. 1,028 million, or 11.0%, primarily as a result of (i) higher product transportation
charges, mainly related to increased costs for transportation related to increased fuel prices in the domestic market
and (ii) higher volumes transported and sold. This increase was partially offset by lower withholdings over exports,
mainly due to the rate reduction established by Resolution No. 1077/2014, the fall of export prices of LPG and
petrochemicals and lower charges related to recoveries in provisions for indebtedness in the segment of natural gas
distributors; and
The provision for contingencies increased by Ps. 650 million in connection with a ruling against YPF regarding a
claim filed by the Union of Consumers and Users (Unión de Usuarios y Consumidores) for claims from 1993 to
1997. The claim alleges that excess fees were charged to GLP consumers during that period. See Note 10 to the
Consolidated Financial Statements.
Our subsidiary Metrogas recorded additional revenues of Ps. 711 million related to the temporary economic
assistance established by Resolution No. 263/2015 of the Ministry of Energy.
Revenues from the Downstream business segment in 2014 were Ps. 133,743 million, representing a 54.2% increase compared to
Ps. 86,771 million in 2013.
142
Operating income for the Downstream business segment in 2014 was Ps. 10,978 million, representing a 63.3% increase
compared to Ps. 6,721 million in 2013. This increase in operating income is primarily due to the following factors:
•
•
•
•
•
The average volume of oil processed per day in YPF’s refineries increased 4.6% to 290,000 barrels of oil per day,
primarily as a result of the restoration of the refining capacity at the La Plata refinery after the damage on April 2,
2013 and, to a lesser extent, the increased availability of light crude in 2014.
An increase in diesel revenues of Ps. 18,165 million, or 52.4%, primarily as a result of an increase in the average
price received for diesel mix of approximately 51.2% and an increase in sales volumes of approximately 0.8%;
An increase in gasoline revenues of Ps. 11,325 million, or 64.0%, primarily as a result of an increase in the average
prices received for gasoline mix of approximately 57.8% and an increase in sales volumes of approximately 3.9%;
An increase in fuel oil revenues of Ps. 3,777 million, or 95.3%, primarily as a result of an increase in the average
price received for fuel oil of 46.4% and an increase in sales volumes, mainly in the domestic market, of 33.4%;
An increase in petrochemical revenues of Ps. 1,989 million, or 50.9%, primarily in the local market as a result of an
increase in the average prices received for methanol and aromatics and an increase in sales volumes, which
increased revenues by Ps. 1,500 million. Exports increased by Ps. 489 million driven by higher sales volumes of
methanol and generally higher prices in Argentine peso terms, which was partially offset by lower overall export
volumes of solvents and light paraffinics; and
•
An increase in natural gas sales volumes and higher average prices received for sales to third parties, which
increases the average prices obtained by YPF when increasing natural gas production. Sales volumes of natural gas,
most of which are domestic, increased approximately 22%. This increase in natural gas sales had a positive effect on
the Downstream results as a consequence of increased marketing fees.
All of this was partially offset by:
•
•
•
•
An increase in costs to purchase crude oil from third parties and the Exploration and Production business segment of
Ps. 22,547 million, or 58.2%, primarily as a result of increases in crude oil prices in Argentine peso terms related to
the devaluation of the Argentine peso against the U.S. dollar as well as higher volumes of crude oil transferred from
the Exploration and Production business segment. This in turn was partially offset by a decrease in the volume of
crude oil purchased from third parties of approximately 17% (about 527,000 cm). The average purchase price in
Argentine peso terms for crude oil transferred from the Exploration and Production business segment increased
approximately 51% compared to an increase for oil purchased from third parties of approximately 55%. This
variation in the percentage amounts is due to different mixes of grades of crude oil purchased from third parties;
An increase in the cost of imported gasoline and diesel, especially “premium” and “ultradiesel,” of Ps.
2,745 million, or 42.4%, primarily as a result of the effect of the devaluation of the Argentine peso (slightly lower in
U.S. dollars), while diesel imported volumes remained flat and gasoline imported volumes increased slightly;
An increase in purchases of biofuels of Ps. 2,799 million or 70.3%, primarily as a result of an approximately 37%
increase in the price of FAME and a 50% increase in the price of bioethanol. The volumes purchased of FAME and
bioethanol increased 5% and 49%, respectively; and
An increase in production costs of Ps. 1,895 million, representing a 51.5% increase, primarily as a result of
increases in (i) freight costs for transporting crude oil and raw material, (ii) fees for use of port facilities,
(iii) contracted services rates for refinery repair and maintenance and (iv) insurance policies. These increases were
driven by different factors, including general price increases in the economy and wage increases. Decreased costs
were also recorded with respect to provisions for environmental liabilities of Ps. 77 million. As a result of these cost
increases as well as increased refining activities, refining costs increased 45% in Argentine peso terms during 2014.
These increases to costs were partially offset by insurance compensation of Ps. 2,041 million recorded during 2014, which
stemmed from YPF’s insurance coverage related to the April 2013 La Plata refinery fire. This compensation was registered primarily
as lower costs for purchases. In relation to this event, in 2013 we had recorded a gain of Ps. 1,479 million under Other (expense)
income, net by way of pecuniary damage compensation and Ps. 477 million in lost profits, which is reflected as lower costs for
purchases. We used with a similar approach to recording the income in 2014.
143
Corporate and other
The operating loss for the Corporate and Other business segment in 2015 was a loss of Ps. 2,331 million, representing a 30.3%
decrease compared to a loss of Ps. 3,343 million in 2014. The results in 2014 were affected mainly by a provision of Ps. 1,227 million
recorded by our subsidiary Maxus Energy Corporation linked to third party claims based on alleged breach of contract. See Note 10
to the Consolidated Financial Statements. In addition, in 2015 higher costs from increased wages, social contributions and higher IT
services costs were recorded.
The operating loss for the Corporate and Other business segment in 2014 was Ps. 3,343 million, representing a 120% increase
compared to a loss of Ps. 1,522 million in 2013, primarily as a result of (i) a provision of Ps. 1,227 million, recorded in 2014 by
Maxus Energy Corporation, a subsidiary of YPF Holdings, which was related to third party claims based on alleged contractual
responsibilities, which it is contesting (see Note 10 to the Audited Consolidated Financial Statements); (ii) increased wages and social
contributions; and (iii) higher fees for services and publicity and advertising, all of which was partially offset by improved results
from our subsidiary A-Evangelista S.A.
Liquidity and Capital Resources
Financial condition
Total loans outstanding as of December 31, 2015, 2014 and 2013 were Ps. 105,751 million, Ps. 49,305 million and Ps.
31,890 million, respectively, consisting of (i) current loans (including the current portion of non-current loans) of Ps. 27,817 million
and non-current loans of Ps. 77,934 million as of December 31, 2015, (ii) current loans of Ps. 13,275 million (including the current
portion of non-current loans) and non-current loans of Ps. 36,030 million as of December 31, 2014 and (iii) current loans of Ps.
8,814 million (including the current portion of non-current loans) and non-current loans of Ps. 23,076 million as of December 31,
2013. As of December 31, 2015, 2014 and 2013, 74%, 66%, and 60% of our loans were denominated in U.S. dollars, respectively.
In the past we have repurchased certain of our publicly-traded bonds in open market transactions on an arms-length basis. As of
December 31, 2015, we had repurchased U.S.$41.9 million of our outstanding bonds. We may, from time to time, make additional
purchases of, or effect other transactions relating to, our publicly-traded bonds if, in our own judgment, the market conditions are
attractive.
The following tables set forth our consolidated cash flow information for the periods indicated.
Net cash flows provided by operating activities
Net cash flows used in investing activities
Net cash flows provided by financing activities
Translation differences generated by cash and equivalents
Net (decrease) increase in cash and equivalents
Cash and equivalents at the beginning of period
Cash and equivalents at the end of period
For the year ended December 31,
2013
2014
2015
(in millions of pesos)
41,404
(64,049)
23,665
46,154
(53,405)
4,986
20,964
(22,201)
6,979
4,609
5,629
9,758
15,387
1,310
(955)
10,713
9,758
224
5,966
4,747
10,713
Net cash flows provided by operating activities were Ps. 41,404 million in 2015 compared to Ps. 46,154 million in 2014. This
10% decrease was primarily attributable to the increase in working capital in 2015, related to the accrual of accounts receivable,
including the Crude Oil Production Stimulus Program and the Gas Plan and higher income tax, which was partially offset by higher
operating income of the Company, without considering depreciation of fixed assets and increased non-cash provisions, which did not
involve expenditures. We believe that, given the high level of cash flow provided by operating activities, including our expectation of
reducing accounts receivable from transactions with government entities (see “Item 3. Key Information—Risk Factors—A significant
percentage of our cash flow from operations is derived from counterparties that are governmental entities”), our working capital is
reasonable for the current requirements of the Company.
Net cash flows provided by operating activities were Ps. 46,154 million in 2014, compared to Ps. 20,964 million in 2013. This
120% increase was primarily attributable to better operating results, without considering depreciation of fixed assets and increased
non-cash provisions. See Note 10 to the Audited Consolidated Financial Statements. In addition, in 2014 we collected Ps.
1,689 million in insurance payments for lost profits in connection with the La Plata refinery fire in April 2013.
144
Cash flows used in investing activities were Ps. 64,049 million in 2015, compared to Ps. 53,405 million in 2014, representing a
19.9% increase compared with 2014, which related mainly to investments made by our Exploration and Production business segment
and investment in our refineries. This was partially offset by the fact in 2014 we registered the acquisitions of YSUR and the
additional interests in the Puesto Hernández, Lajas, La Amarga Chica and Bajada de Añelo areas as well as the collection of
insurance payments for material damages related to the incident suffered by our La Plata refinery in April 2013.
Cash flows used in investing activities were Ps. 53,405 million in 2014, compared to Ps. 22,201 million in 2013, representing a
140.6% increase, which related mainly to investments made by our Exploration and Production segment and investment in our
refineries, and also considering the contributions of capital investments in companies, for a total of Ps. 29,731 million, including the
acquisitions of YSUR, and additional interests in the Puesto Hernández, Lajas, La Amarga Chica and Bajada de Añelo areas.
Moreover, there was also a lower collection from sale of fixed assets and intangible assets of Ps. 3,291 million, based on 2014
revenues from the sale of assets to Pluspetrol and partial sales extensions concessions of La Ventana and Magallanes concessions,
which in 2013 included the collection from the investment agreement with Chevron in the Loma Campana area. There is also the
collection in 2014 of Ps. 1,818 million in property damage insurance, related to the loss suffered by our La Plata refinery in 2013.
Net cash flows provided by financing activities in 2015 were Ps. 23,665 million, which came primarily from the issuance of
notes in the local market and international markets, net of repayments of principal and interest, including issuance of notes in the
international debt capital markets for an aggregate principal amount of U.S.$2.1 billion.
Net cash flows provided by financing activities in 2014 were Ps. 4,986 million, which came primarily from the issuance of notes
in the local market and international markets, net of repayments of principal and interest, including issuance of notes in the
international debt capital markets for an aggregate principal amount of U.S.$1.06 billion, which was the largest made by an Argentine
company in history.
In 2015, at the shareholders’ ordinary and extraordinary general meeting held on April 30, 2015, a dividend of Ps. 503 million
(Ps. 1.28 per share or ADS) was authorized for payment in 2015. In 2014, at the shareholders’ general ordinary and extraordinary
meeting held on April 30, 2014, and its continuation on May 21, 2014, a dividend of Ps. 464 million (Ps. 1.18 per share or ADS) was
authorized for payment in 2014. In 2013, at the ordinary and extraordinary general shareholders’ meeting held on April 30, 2013 and
its continuation on May 30, 2013, a dividend of Ps. 326 million (Ps. 0.83 per share or ADS) was authorized for payment in 2013.
A Global Medium-Term Notes Program was approved at a shareholders’ meeting held on January 8, 2008 for an amount up to
U.S.$1.0 billion. On September 13, 2012 and on April 30, the shareholders’ meeting approved the increase of the amount of the
program, mentioned above, for an amount of U.S.$2.0 billion each time, resulting in a maximum nominal amount in circulation at any
time under the program of U.S.$5.0 billion, or its equivalent in other currencies, and providing the use of the proceeds to cover all
alternatives contemplated by Article 36 of Law No. 23,576 of Negotiable Obligations and Supplementary rules. On February 5, 2015,
the shareholders’ meeting resolved by a majority of computable votes to approve the increase of the amount of the Company’s Global
Medium-Term Notes Program of U.S.$5.0 billion or its equivalent in other currencies by U.S.$3.0 billion, resulting in the total
maximum nominal amount outstanding under the program at any time becoming U.S.$8.0 billion, or its equivalent in other
currencies, or a lower amount as may be determined by the Board of Directors.
Under the Global Medium-Term Notes Program, the Company issued several series of notes in the local and international
markets at different interest rates. All such securities are authorized to be traded on the Buenos Aires Stock Exchange (Bolsa de
Comercio de Buenos Aires) and the Electronic Open Market (Mercado Abierto Electrónico) in Argentina. In addition, in 2013 we
acquired the control of GASA, including our controlled company Metrogas S.A., which has outstanding notes for an amount of Ps.
2,091 million as of December 31, 2015. For additional information about the outstanding notes of YPF S.A. and our controlled
companies as of December 31, 2015, see Note 2 and 6.j to the Audited Consolidated Financial Statements.
The following table sets forth our commitments for the periods indicated below with regard to the principal amount of our debt,
as of December 31, 2015, plus accrued but unpaid interest as of that date:
Loans
Expected Maturity Date
Less
than 1
year
Total
1 – 2
Years
2 – 3
Years
3 – 4
Years
4 – 5
Years
More
than 5
years
(in millions of pesos)
105,751 27,817 6,888 21,928 3,892 5,914 39,312
145
For detailed information regarding our indebtedness, see Note 2.i to the Audited Consolidated Financial Statements.
Contractual obligations
The following table sets forth information with regard to our commitments, expressed in U.S. dollars, under commercial
contracts for the periods indicated below, as of December 31, 2015:
Contractual Obligations
Debt (1)
Operating lease obligations
Purchase obligations (2)
Purchases of services
Purchases of goods
LPG
Electricity
Gas
Steam
Others
Other liabilities (3)(6)
Total (3)(4)
Total
Less than 1
year
1 – 3
Years
3 – 5
Years
More than 5
years
11,983
864
2,857
1,955
903
2
18
6
14
863
9,755
25,459
(in millions of U.S.$) (5)
2,792 3,567 1,560
284 352 196
1,952 682 198
1,088 643 198
0
38
0
0
7 —
0
0
9 —
22 —
3,990 1,420 1,459
9,018 6,021 3,413
864
2
11
5
5
841
4,064
31
26
26
0
0
—
0
—
—
2,886
7,008
(1) These projected amounts include interest due during all the periods presented. Interest on variable rate instruments is calculated
(2)
using the rate as of December 31, 2015 for all periods. See additionally “Item 5 Operating and Financial Review and
Prospects—Liquidity and Capital Resources—Covenants in our indebtedness.”
Includes purchase commitments under commercial agreements that do not provide for a total fixed amount, which have been
valued using our best estimates. Accordingly, our actual purchase obligations may differ from the estimated amounts shown in
the table.
(3) Provisions for contingent liabilities under commercial contracts, which amounted to U.S.$810 million as of December 31, 2015,
are not included in the table above since we cannot, based on available evidence, reasonably estimate the settlement dates of
such contingencies.
In addition to the contractual obligations detailed in the preceding table, we are also committed to carry out exploration
activities in certain exploration areas and to make certain investments and expenditures until the expiration of some of our
concessions. These commitments amounted to U.S.$22.1 million as of December 31, 2015.
(4)
(5) The table is presented in U.S.$, which is the Company’s functional currency, and not in its reporting currency, as the majority of
(6)
the Company’s contractual obligations are originally denominated in U.S.$.
Includes accounts payable, salaries and social security, taxes payable, provisions for pensions, provisions for environmental
liabilities and provisions for hydrocarbon wells abandonment obligations as set forth in our audited consolidated financial
statements included as of December 31, 2015.
We have additional commitments under guarantees. For a discussion of these additional commitments see “—Guarantees
provided.”
Covenants in our indebtedness
Our financial debt generally contains customary covenants. With respect to a significant portion of our loans totaling Ps.
105,751 million, including accrued interest (current and non-current debt) as of December 31, 2015, we have agreed, among other
things and subject to certain exceptions, not to establish liens or charges on our assets. In addition, approximately 51.5% of our loans
outstanding as of December 31, 2015 were subject to financial covenants related to our leverage ratio and debt service coverage ratio.
Regarding our outstanding notes amounting to Ps. 83,962 million as of December 31, 2015, the holders of such notes may, upon
an event of default, declare due and immediately payable the principal and accrued interest on amounts owed to them.
Almost all of our total outstanding financial debt is subject to cross-default provisions. As a result of these cross-default
provisions, a default on our part or, in certain cases, the part of any of our consolidated subsidiaries covered by such provisions, could
result in a substantial portion of our debt being declared in default or accelerated.
146
As of the date of this annual report, none of our debt is under any event of default that could trigger an acceleration provision.
As of December 31, 2015, we were in compliance with all covenants in connection with our indebtedness.
Guarantees provided
As of December 31, 2015, we have issued letters of credit in an aggregate total amount of U.S.$27 million to guarantee certain
environmental obligations and guarantees in an aggregate amount of U.S.$199 million in relation with the performance of contracts of
certain of our controlled companies.
In addition, see Note 11.c to the Audited Consolidated Financial Statements for a description of the transaction we entered into
with Chevron.
Capital investments, expenditures and divestitures
Capital investments and expenditures
Capital investments in 2015 totaled Ps. 62,209 million. The table below sets forth our capital expenditures and investments by
activity for each of the years ended 2015, 2014 and 2013.
Capital expenditures and investments(1) Exploration and Production
Downstream
Corporate and Other
Total
2015
(in
millions of
pesos)
50,927
9,343
1,939
(%)
82
15
3
62,209 100%
2014
(in
millions of
pesos)
(%)
42,408 81
8,392 16
1,408
52,208 100%
3
2013
(in
millions of
pesos)
24,807
4,903
453
(%)
82
16
2
30,163 100%
(1)
Includes acquisitions of fixed assets and exploration expenses, net of unproductive drilling expenses and well abandonment
costs.
Our strategy intends to reaffirm our commitment to creating a new model of the Company in Argentina which aligns our
objectives, seeking profitable and sustainable growth that generates shareholder value, with those of the country, thereby positioning
YPF as an industry-leading company aiming at the reversal of the national energy imbalance and the achievement of hydrocarbon
self-sufficiency in the long term.
To achieve the goals set forth above, we intend to focus on (i) continuing to increase production, especially of natural gas;
(ii) improving efficiency and productivity to enable us to adapt to a scenario of a prolonged decline in international oil prices;
(iii) increasing exploration of mature areas; (iv) developing unconventional resources; (v) improving our capacity to refine in order to
accommodate the growth in demand for refined products; (vi) exploring conventional and unconventional resources and pushing the
limits of existing deposits and exploring new frontiers, including offshore, and (vii) maintaining a solid capital structure. The
investment plan related to our growth needs to be accompanied by an appropriate financial plan, whereby we intend to reinvest
earnings, search for strategic partners and acquire debt financing at levels we consider prudent for companies in our industry.
Consequently, the financial viability of these investments and hydrocarbon recovery efforts will generally depend, among other
factors, on the prevailing economic and regulatory conditions in Argentina, the ability to obtain financing in satisfactory amounts at
competitive costs, as well as the market prices of hydrocarbon products. See “Item 3. Key Information—Risk Factors—Risks
Relating to Argentina” and “Item 5. Operating and Financial Review and Prospects—Factors Affecting Our Operations” for
additional information regarding 2016 activity.
Capital divestitures
We have not made any significant divestitures in the past three years.
Quantitative and Qualitative Disclosures about Market Risk
For a description of our exposure to market risk, see “Item 11. Quantitative and Qualitative Disclosures about Market Risk.”
147
Off-Balance Sheet Arrangements
We do not have any material off-balance sheet agreements. Our off-balance sheet agreements are described in “—Liquidity and
Capital Resources—Guarantees provided.”
Research and Development, Patents and Licenses, etc.
For a description of our research and development policies, see “Item 4. Information on the Company—Research and
Development.”
ITEM 6. Directors, Senior Management and Employees
Management of the Company
On May 3, 2012, the Argentine congress enacted the Expropriation Law. Among other matters, the Expropriation Law provided
for the expropriation of 51% of the share capital of YPF represented by an identical stake of Class D shares owned, directly or
indirectly, by Repsol and its controlled or controlling entities. The shares subject to expropriation, which have been declared of public
interest, will be assigned as follows: 51% to the federal government and 49% to the governments of the provinces that compose the
National Organization of Hydrocarbon Producing States. To ensure compliance with its objectives, the Expropriation Law provides
that the National Executive Office, by itself or through an appointed public entity, shall exercise all the political rights associated with
the shares subject to expropriation until the transfer of political and economic rights to the provinces that compose the National
Organization of Hydrocarbon Producing States is completed.
The Expropriation Law states that YPF shall continue as a publicly traded corporation and the management of the shares subject
to expropriation shall be carried out according to the following principles: (i) strategic contribution of the Company to the aims
established in the Expropriation Law; (ii) the management of the Company in accordance with the best industry and corporate
governance practices, preserving the interests of the Company’s shareholders and creating value for them; and (iii) the professional
management of the Company.
The information provided below describes the composition and responsibilities of our Board of Directors and committees as of
the date of this annual report.
Board of Directors
Composition of our Board of Directors
Our business and affairs are managed by the Board of Directors in accordance with our by-laws and the Argentine Corporations
Law). Our by-laws provide for a Board of Directors of eleven to 21 members, and up to an equal number of alternates. Alternates are
those elected by the shareholders or the Supervisory Committee, when applicable, to replace directors who are absent from meetings
or who are unable to exercise their duties, when and for whatever period appointed to do so by the Board of Directors. Alternates
have the responsibilities, duties and powers of directors only if and to the extent they are called upon to attend board meetings and as
long as they perform the duties of a director.
Directors shall hold office from one to three years, as determined by the shareholders’ meetings.
Since the Board of Directors’ Meeting held on December 22, 2015, our Board of Directors is composed of 15 directors and
seven alternates.
In accordance with our by-laws, the Argentine government, as the sole holder of Class A shares, is entitled to elect one director
and one alternate.
Under the Argentine Corporations Law, a majority of our directors must be residents of Argentina. All directors must establish a
legal domicile in Argentina for service of notices in connection with their duties.
Our by-laws require the Board of Directors to meet at least once every quarter in person or by video conference, and a majority
of directors is required in order to constitute a quorum. If a quorum is not met one hour after the start time set for the meeting, the
President or his substitute may invite alternates of the same class as that of the absent directors to join the meeting, or call a meeting
for another day. Resolutions must be adopted by a majority of the directors present (including those connected by video conference),
and the President or his substitute is entitled to cast the deciding vote in the event of a tie.
148
The current members of our Board of Directors, the year in which they were appointed and the year their term of appointment
expires is as follows:
Name
Miguel Galuccio (6)(7)
Jorge Marcelo Soloaga (6)
Gustavo Alejandro Nagel (6)
Néstor José Di Pierro (1)
Juan Franco Donnini (1)
Enrique Andrés Vaquié (1)
Nicolás Alfredo Trotta (2)
Carlos Alberto Felices (3)
Miguel Ángel Gutiérrez (3)
Daniel Gustavo Montamat (3)
Fabián Jorge Rodríguez Simón (3)
Fernando Dasso (6)
Daniel Cristian González Casartelli (6)
Carlos Alberto Alfonsi (6)
Emilio José Apud (4)
Sergio Affronti (6)
Omar Gutiérrez
Luis Gustavo Villegas (5)
Lucio Mario Tamburo (5)
Pedro Martín Kerchner Tomba (5)
Fernando Pablo Giliberti (6)
Jesús Guillermo Grande (6)
Position
Chairman, Chief Executive Officer
(CEO) and Director
Director
Director
Director
Director
Director
Director
Director
Director
Director
Director
Director and Human Resources Vice
President
Director
Director and Downstream Executive
Vice President
Director
Alternate Director and Shared Services
Vice President
Alternate Director
Alternate Director
Alternate Director
Alternate Director
Alternate Director and Strategy and
Business Development Vice President
Alternate Director and Upstream
Executive Vice President
Age
47
Director
Since
2015
58
48
60
32
51
40
70
57
61
57
50
2015
2015
2015
2015
2015
2015
2015
2015
2015
2015
2015
Term
Expiration
2016
2016
2016
2016
2016
2016
2016
2016
2016
2016
2016
2016
46
2015
2016
55
70
2015
2015
46
48
43
55
41
49
2015
2015
2015
2015
2015
2015
2016
2016
2016
2016
2016
2016
2016
2016
47
2015
2016
(1) Messrs Di Pierro, Donnini and Vaquié were designated by the Supervisory Committee and assumed the position of Directors at
the Board of Directors’ meeting held on December 22, 2015, replacing Messrs. Jorge Manuel Gil, Ignacio Perincioli and Omar
Chafí Félix, respectively, who resigned.
(2) Designated by the Supervisory Committee and assumed the position of Director at the Board of Directors’ meeting held on
November 5, 2015, replacing Mrs. Andrea Mariana Confini, who resigned.
(3) Designated by the Supervisory Committee and assumed the position of Director at the Board of Directors’ meeting held on
December, 22, 2015, replacing Messrs. Rodrigo Cuesta, Nicolás Marcelo Arceo, Patricia María Charvay and Juan Franco
Donnini, who resigned.
(4) Representing our Class A shares.
(5) Messrs Villegas, Tamburo and Kerchner Tomba were designated by the Supervisory Committee and assumed the position of
Alternate Directors at the Board of Directors’ meeting held on December 22, 2015, replacing Messrs. Oscar Alfredo Cretini,
Edgardo Raúl Valfré and Francisco Ernesto García Ibáñez, respectively, who resigned.
(6) As of March 8, 2016, the person owns less than one percent of our Class D shares.
(7) On March 9, 2016 our Chairman and CEO Miguel Galuccio announced that he will step down at the end of his term, which ends
at our next annual shareholders meeting, expected to be held in April 2016.
149
The Chairman of the Board of Directors, who, according to our by-laws, must be a Class D director, was elected by the Board of
Directors in the meeting held on April 30, 2015. All other officers serve at the discretion of the Board of Directors and may be
terminated at any time without notice.
Pursuant to the information published by the Ministry of Energy and Mining, Mr. Miguel Ángel Gutiérrez will be proposed as
President of YPF once the term of Mr. Miguel Galuccio ends, as discussed above. Furthermore, the Ministry of Energy and Mining
has stated that the Argentine government will propose to separate the positions of President and CEO. To fill this position, a national
and international search process has commenced. See “Item 3. Key Information—Risk Factors— Our performance is largely
dependent on recruiting and retaining key personnel.”
Outside business interests and experience of the members of our Board of Directors
Miguel Galuccio
Mr. Galuccio holds a degree in oil engineering from the Technological Institute of Buenos Aires. Until April 16, 2012,
Mr. Galuccio was part of the management team of Schlumberger in London. He has more than 20 years of international experience in
the oil and gas industry. During his career at Schlumberger, he held the positions of Real Time Reservoir Manager, Mexico and
Central America General Manager, President of Integrated Project Management – IPM and President of Production Management. In
2011, he created the strategic “Schlumberger Production Management” division, based in London, which he led until joining YPF.
Throughout his career at Schlumberger, Mr. Galuccio led companies and working teams in the United States, Middle East, Asia,
Europe, Latin America, Russia and China. Prior to joining Schlumberger, he worked at YPF where he participated in the Company’s
internationalization process as Manager within Maxus Energy. During his career at YPF, he held among others the positions of
Development Manager – YPF Division South, Asset Manager Advisor at Maxus – YPF International and Business Unit Manager at
Maxus – YPF International. On May 7, 2012, through Decree No. 676/2012 of the National Executive Office, Mr. Galuccio was
appointed General Manager of the Company during the Intervention period and was appointed Chairman of the Company by the
General Shareholders Meeting held in June 4, 2012 and was appointed CEO of the Company by the Board of Directors meeting held
on June 4, 2012. Currently he has been the Chairman of the Board and CEO since June 2012.
On March 9, 2016 our Chairman and CEO Miguel Galuccio announced that he will step down at the end of his term, which ends
at our next annual shareholders meeting, expected to be held in April 2016. He has committed to supporting the Board of Directors to
ensure an orderly transition and cooperating in the search for his replacement.
Jorge Marcelo Soloaga
Mr. Soloaga graduated from the Industrial School in Caleta Olivia as a chemical technician. Currently, he is an employee of the
Company and is Chairman of the commune of Cañadón Seco since 2015. Since 1993, he has acted as General Secretary of the Oil
and Hydrocarbon Union (Sindicato Unido Petroleros e Hidrocarburíferos), in Santa Cruz. Among other offices, he served as a
member of congress in the low chamber of the province of Santa Cruz for the period between 1985 and 1989.
Gustavo Alejandro Nagel
Mr. Nagel graduated as an industrial engineer with a major in mechanics from the National University of the Comahue in
Neuquén, and was awarded a master’s degree in business administration from the International School of Business. He has served at
Skanska as the head of Teams and Maintenance (southwest affiliate), as Service and Operations team leader in Venezuela, as business
area manager in Neuquén, Mendoza and Rosario), as Oil and Gas manager for Argentina and Bolivia and country manager for the
Andean Region, among other positions. He was the Undersecretary of Planning and Public Services in the province of Neuquén.
Currently, he is the Director Representative for the Province of Neuquén at Hidroelectrica Piedra del Águila.
Néstor José Di Pierro
Mr. Di Pierro served among other positions, as Deputy in the Legislature of the Province of Chubut between 1991 and 1995, as
Secretary of Social Welfare of the Municipality of Comodoro Rivadavia, Province of Chubut, between 1995 and 1999 and as
Councilman in the Deliberative Council of Comodoro Rivadavia between 1999 and 2001. He was appointed Controller of
Petrominera Chubut S.E. between 2003 and 2009. Additionally, he was President of Correo Oficial de Argentina S.A. between 2009
and 2011. He served as Mayor of the Municipality of Comodoro Rivadavia from 2011 to December 2015.
150
Juan Franco Donnini
Mr. Donnini earned an economics degree from the Argentine University of Business (“UADE”). He has completed a specialization
in economy of oil and natural gas at the Technological Institute of Buenos Aires and earned a master’s degree in finance from CEMA
University. Among other positions, he served as Advisor in the Mining, Energy and Combustible Commission at the Senate in 2012 and
as Advisor at the Undersecretary of Economic Policy and Development Planning at the National Ministry of Economy and Public
Finance in 2013. Additionally, he worked as Administrative Secretary of the Planning and Strategic Coordination of the National Plan of
Hydrocarbon Investments Commission and was Undersecretary of Economic Policy at the National Ministry of Economy and Finance.
He is currently Minister of Economy and Public Works for the Province of Santa Cruz.
Enrique Andrés Vaquié
Mr. Vaquié obtained an economics degree from the National University of Cuyo and has a master’s degree in public policy from
the Torcuato Di Tella Institute. He served as Undersecretary of Finance of the Province of Mendoza, Minister of Finance of the Province
of Mendoza, from 1999 to 2001 and provincial Senator, from 2003 to 2007. He worked as an economic consultant from 2008 to 2011. In
addition, he was Advisor of the National Vice-Presidency from 2009 to 2011. He was elected National Deputy for the Province of
Mendoza from 2011 to 2015. Currently, he is the Minister of Economics, Infrastructure and Energy of the Province of Mendoza.
Nicolás Alfredo Trotta
Mr. Trotta earned a law degree from the Belgrano University and is a doctoral candidate in education at the Philosophy and Arts
School at the University of Buenos Aires (“UBA”). He is also a professor at the Belgrano University. Among other positions, he served
in several public functions in the Chief Cabinet of Ministers and also in the Autonomous City of Buenos Aires. Currently, he is Dean of
the University for Education and Work and President of the UMETEC Foundation.
Carlos Felices
Mr. Felices holds a bachelor’s degree in business administration from UBA and postgraduate studies in the U.S. He worked in
various capacities at Pfizer Inc. He served in Argentina as Treasurer, in Brazil as CFO and in the U.S. as Director of Administration for
Latin America. From 1993 to 2002, he worked for YPF, eventually serving as CFO. He was later appointed CEO of Telecom Argentina
S.A. until 2007 and Chairman of the Board of Directors of Telecom Argentina S.A. until April 2008.
Daniel Gustavo Montamat
Mr. Montamat holds a degree in Economics, Certified Public Accountant and Law. He has two doctoral degrees in Economic
Sciences and in Law and Social Sciences, both from the Catholic University of Córdoba. He obtained a master’s degree in Economy
from Michigan State University in the U.S. Among other positions, he was Director of Gas del Estado, Director and President of YPF
S.E. and Secretary of Energy of Argentina. In 1991, he founded Montamat & Asociados in the Autonomous City of Buenos Aires,
where he is the Executive Director. Currently, he is a consultant at the World Bank and the Inter-American Development Bank. He is a
postgraduate professor of the Energetic Regulation Study Centre of UBA.
Miguel Ángel Gutiérrez
Mr. Gutiérrez is a founding partner of The Rohatyn Group, where he is in charge of private investments, real estate, infrastructure
and renewable energy activities. From 1980 to 2001, he held various positions at J.P. Morgan, where he became Managing Director
responsible for Global Emerging Markets and a member of the Management Committee for Global Markets. In addition, he served as
Chairman of the Board of Directors of Autopistas de Oeste S.A. and he was the President and CEO of Grupo Telefonica de Argentina
S.A. Currently, he is a member of the Consultative Council of CIPPEC, the Economic and Social Council of the University Torcuato Di
Tella, the International Advisory Board of the IAE Business School and the Council of the Fundación Cruzada Argentina.
Fabián Jorge Rodríguez Simón
Mr. Rodríguez Simón earned a law degree from UBA and completed coursework at Harvard Law School. Among other positions,
he served as Advisor to the Mayor of the Autonomous City of Buenos Aires, as Chief of Staff of the Ministry of Environment and
Public Space of the Autonomous City of Buenos Aires between 2007 and 2009, and President of the Commission Act 1840 “Zero
Waste.” He was a founding partner of Llerena & Abogados and was Director of its Executive Committee. He is a member of the
Governing Council of the Instituto de Empresa (Madrid) and is President of the Fundación Pericles (Buenos Aires). Currently, he is
senior partner of AlfaLegalGroup.
151
Fernando Dasso
Mr. Dasso earned a degree in labor relations from UBA and completed a management development program at IAE in 1993
company. He has held various positions within the Company. In 2006, he was appointed Director of Human Resources of Argentina,
Bolivia and Brazil of the Exploration and Production business. He has been our Human Resources Vice President since July 2007.
Daniel Cristian González Casartelli
Mr. Gonzalez is the President of the Disclosure Committee. Daniel Gonzalez holds a degree in business administration from the
Argentine Catholic University. He served for 14 years in the investment bank Merrill Lynch & Co in Buenos Aires and New York,
holding the positions of Head of Mergers and Acquisitions for Latin America and President for the Southern Cone (Argentina, Chile,
Peru and Uruguay), among others. While at Merrill Lynch, Mr. Gonzalez played a leading role in several of the most important
investment banking transactions in the region and was an active member of the firm’s global fairness opinion committee. He
remained a consultant to Bank of America Merrill Lynch after his departure from the bank. Previously, he was Head of Financial
Planning and Investor Relations in Transportadora de Gas del Sur SA. He currently is also member of the Board of Directors of
Adecoagro S.A. Mr. Gonzalez has been our Chief Financial Officer since July 2012.
Carlos Alberto Alfonsi
Mr. Alfonsi graduated with a degree in chemistry from the Technological University of Mendoza. Additionally, he has a degree
in IMD Managing Corporate Resources from Lausanne University and has studied at the Massachusetts Institute of Technology.
Since 1987, he has held various positions at the Company, serving as an operations manager, Director of the La Plata refinery,
Operation Planning Director, Director of Commerce and Transportation for Latin America, Director of Refinery and Marketing in
Peru, Country Manager for Peru and R&M for Peru, Chile, Ecuador and Brazil. Mr. Alfonsi has been our Downstream Executive
Vice President since June 2010.
José Emilio Apud
Mr. Apud graduated as an industrial engineer from the Engineering School of UBA. He completed postgraduate degrees in
Energy Economics and Management Control of Large Projects at the Engineering School of UBA, in Regional Economic Analysis at
the Institute for Economic and Social Development Di Tella Institute; and obtained a postgraduate specialization in Energy
Conservation at Dupont WL, in the U.S. Among other positions, he served as Director of CAMMESA and Secretary of Energy and
Mining of Argentina, in 2001. He was Founder and Vice President of IAE, Energy Institute G. Mosconi, between 1983 and 1989. He
has owned Apud & Associates, a consulting firm in energy and the environment, since 2005. He serves as partner and director of
AMPAR, a Paraguayan consulting firm and of Ecoriental, an Uruguayan consulting firm. In addition, he serves as Chairman of BAE
S.A., a builder and developer, as Counselor at the Fundación Libertad y Progreso and as member of Fundación Pensar.
Sergio P. Affronti
Mr. Affronti earned a certified public accountant degree and a degree in business administration from the Argentine Catholic
University, and a degree from the Management and Engineering Program of the University of Texas, Austin. He has more than 20
years of experience in the oil and gas industry in Latin America, Europe and North Africa. Among other positions, he was Strategic
Planning Manager for YPF Upstream Latin America, Country and General Manager for Repsol in Ecuador, Director for Corporate
Development for Repsol Upstream, Director of Procurement for Repsol Upstream, Director of Planning and Control for Europe, Asia
and Africa for Repsol Upstream and Technical Planning Director for Algeria projects. He has been our Shared Services Vice
President since June 2012.
Omar Gutiérrez
Mr. Gutiérrez obtained a certified public accountant degree from National University of the Comahue in Neuquén. He served as
General Director of Administration from 1992 to 2004 and, during 1995, General Director of Coordination, both within the Ministry
of Government of the province of Neuquén. He was administrative prosecretary from 1999 to 2001 and Secretary in the Legislature
of the province, from 2002 to 2003. He was the President of the Board of Directors of the Banco Provincia del Neuquén from 2005 to
2011. He was a member of the Deliberate Council of the city of Neuquén’s Municipality and President of the Committee on Finance
and Budget. He served as Minister of Economy and Public Work of the province of Neuquén. Currently, he serves as Governor of the
Province of Neuquén.
152
Luis Gustavo Villegas
Mr. Villegas has worked in several positions in the oil industry since 1990. Currently, he serves as Undersecretary of the Union
of Senior Staff and Professionals of Southern Patagonian Oil and Gas Private Sector and as a senior staff member of the Oil Tankers
Mutual Commission.
Lucio Mario Tamburo
Mr. Tamburo graduated as a civil engineer from the National University of the South, Bahía Blanca. Among other positions, he
served as Inspection assistant of the Provincial Roads Direction of the Province of Río Negro and as sanitation consultant in the
National Undersecretary of Water Resources. He was the Engineering and Construction Manager and Service and Maintenance Chief
of Bahía Blanca at Azurix Buenos Aires SA. He also served as Administrator of the National Entity of Water Works of Sanitation
ENOHSA until December 2015.
Pedro Martín Kerchner Tomba
Mr. Kerchner Tomba obtained a degree as a certified public accountant from the Economic School of the Argentine Catholic
University. He completed postgraduate degrees in financial strategy at the National University of Cuyo and in Taxation at the
University of Tres de Febrero with a specialization in local taxation. Among other positions, he served as Administration Director of
Justice and Security Minister of the Province of Mendoza, as Secretary of Finance of the Municipality of Godoy Cruz, Province of
Mendoza and he was elected as provincial Deputy for the third electoral district of the Province of Mendoza. Currently, Mr. Kerchner
Tomba is Minister of Finance of the Province of Mendoza.
Fernando Pablo Giliberti
Mr. Giliberti earned a certified public accountant degree from the Argentine Catholic University, an MBA from the Argentine
University of the Enterprise, a postgraduate diploma in Management and Economics of Natural Gas from the College of Petroleum
Studies, Oxford University, and master’s degree in the Science of Management, from the Sloan Program at Stanford University.
Among other positions, he previously served at YPF as Head of Accounting and Finance at our headquarters in Mendoza, as South
Division Business Support Manager, as Asset Manager of the El Guadal-Lomas del Cuyo, as Business Development Manager and
Exploration and Production Business Development Director. In San Antonio, he was Vice President of Business Development and
Vice President of the Latin America Division of Pride International. He later served as Vice President of Business Development at
Pioneer Natural Resources of Argentina. In 2006, he founded Oper-Pro Services S.A. He has been our Strategy and Business
Development Vice President since June 2012.
Jesús Guillermo Grande
Mr. Grande graduated with honors from the National University of Tucumán with an engineering degree. He worked in
Schlumberger from 1993 to 2012. Over those 20 years, he held operational, managerial and staff positions in Kuwait, Argentina,
Brazil, Angola, France and the United States. In his last five years, he served as Director of Human Resources and President of
Testing Services. His specialty is management and operations optimization. Mr. Grande has been our Upstream Executive Vice
President since January 2013.
Board practices
The information provided below describes the composition and responsibilities of our Board of Directors.
Board practices of our Board of Directors
In accordance with the Argentine Corporations Law, directors have an obligation to perform their duties with loyalty and with
the diligence of a prudent business person. Directors are jointly and severally liable to us, our shareholders and to third parties for the
improper performance of their duties, for violating the law or our by-laws or regulations, and for any damage caused by fraud, abuse
of authority or gross negligence. Specific duties may be assigned to a director by the by-laws, applicable regulations, or by resolution
of the shareholders’ meeting. In such cases, a director’s liability will be determined by reference to the performance of such duties as
long as the director’s appointment and the determination of duties approved by a shareholders’ meeting is registered with the
Superintendency of Corporations.
153
Only shareholders, through a shareholders’ meeting, may authorize directors to engage in activities in competition with us.
Transactions or contracts between directors and us in connection with our activities are permitted to the extent they are performed
under fair market conditions. Transactions that do not comply with the above requirements may only be carried out with prior
approval of the Board of Directors or, in the case of an absence of a quorum in a Board of Directors meeting, the Supervisory
Committee. In addition, these transactions must be subsequently approved by the shareholders at a general meeting. If our
shareholders do not approve the relevant transaction, the directors and members of the Supervisory Committee who approved such
transactions are jointly and severally liable for any damages caused to us.
Any director whose personal interests are adverse to ours with respect to any matter shall notify the Board of Directors and the
Supervisory Committee and abstain from voting on such matters. Otherwise, such director may be held liable to us.
A director will not be liable if, notwithstanding his presence at the meeting at which a resolution was adopted or his knowledge
of such resolution, a written record exists of his opposition to such resolution and he reports his opposition to the Supervisory
Committee before any complaint against him is brought before the Board of Directors, the Supervisory Committee, the shareholders’
meeting, the appropriate governmental agency or the courts. Any liability of a director to us terminates upon approval of the
director’s actions by the shareholders at a general meeting, provided that shareholders representing at least 5% of our capital stock do
not object and provided further that such liability does not result from a violation of the law, our by-laws or other regulations.
Senior Management
Our current senior management as of the date of this annual report consists of:
Name
Miguel Galuccio (2)
Daniel González
Germán Fernández Lahore (1)
Jesús Grande
Carlos Alfonsi
Fernando Giliberti
Vacant
Fernando Dasso
Sergio Affronti
Daniel Palomeque (1)
Position
Chairman, Chief Executive Officer and
Director
Chief Financial Officer
Legal Affairs Corporate Vice President
Upstream Executive Vice President
Downstream Executive Vice President
Strategy and Business Development Vice
President
Communication and Institutional Relations
Vice President
Human Resources Vice President
Shared Services Vice President
Quality, Environment, Security and Health
Vice President
(1) Owns less than one percent of our Class D shares as of March 8, 2016.
(2) On March 9, 2016 our Chairman and CEO Miguel Galuccio announced that he will step down at the end of his term, which ends
at our next annual shareholders meeting, expected to be held in April 2016. See “––Board of Directors” above.
In addition to the above, the Company recently announced the creation of a new Gas and Energy Vice-President position for our
gas and energy activities. Mr. Marcos Browne has been appointed to this position. Mr. Browne obtained his degree in industrial
engineering from the Buenos Aires Institute of Technology (“IBTA”). He holds an MBA from Henley Management College in the
U.K. and a degree in natural gas management and economics from the College of Petroleum and Energy Studies at the University of
Oxford in the U.K. He also holds a specialization in economics of petroleum and natural gas from ITBA and a Management
Development Program Certification from IAE Business School. He has held different positions at YPF, including the Head of Supply
and Processing of Natural Gas between February 1994 and May 2000. He was the Head of Gas and Liquid Gas Processing business at
TGS S.A., a company at which he held various positions between June 2000 and March 2004. He is a founding partner of Endriven
S.A. and served as a Director until March 14, 2016. He also served as General Manager of Gas Meridional S.A., General Manager of
C3Plus S.A. and President of Fuels Meridional S.A.
In addition to the members of our senior management for whom outside business interests and experience were described above,
we include the following:
Germán Fernandez Lahore
Mr. Fernández Lahore joined the Oil Affairs Management of YPF in February 2002. Prior to that, he worked as an attorney at
Beccar Varela and as a foreign associate at Haynes and Boone, LLP in Dallas, Texas. He earned his law degree from UBA and
participated in the Academy for American and International Law. As a Chevening scholar, he earned a master’s degree in Natural
Resources Law and Policy from the University of Dundee, Scotland, United Kingdom. He obtained a postgraduate degree in tax
law from the Austral University, Argentina. He completed the management development program at IAE. He is a member of the
Academic Council of Argentine Journal of Energy, Hydrocarbons and Mining Law (Revista Argentina de Derecho de la Energía,
Hidrocarburos y Minería). His areas of expertise include Oil, Natural Gas and Mining Law and Natural Resource Taxation and
Financing. Among other positions held, he served as YPF Upstream Legal Affairs Manager. He currently serves as our Legal Affairs
Corporate Vice President.
Daniel Palomeque
Mr. Palomeque graduated with a degree in Chemical Engineering from UNLP and obtained a master degree in Environmental
Engineering from the Technological University of La Plata (“UTN”). He has also studied at the Massachusetts Institute of
Technology. He began his career at YPF in 1980 in the area of lubricants at the La Plata refinery in various positions until his
appointment as Planning Manager in 1998 and Latin America. Planning Director in 2000. He was promoted as Director of the Lujan
Industrial Complex Cuyo in 2002 and in 2005 was appointed Director of the Industrial Complex in La Plata. He was also our
Executive Manager Refining, and he is Chairman of the Argentine Institute of Oil and Gas of La Plata and professor at the UTN and
UNLP. He has been our Quality, Environment, Security and Health Vice President since June 2014.
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The Audit Committee
The information provided below describes the composition and responsibilities of our Audit Committee.
Composition and responsibilities of our Audit Committee
The Stock Market Law as defined in “Item 9. The Offer and Listing Argentine Securities Market” and Resolution No. 622/2013
of the Argentina National Securities Commission (Comision Nacional de Valores)(“the CNV”), require that Argentine public
companies appoint an audit committee (comité de auditoría) composed of at least three members of the Board of Directors. The by-
laws must set forth the composition and regulations for the operation of the Audit Committee. A majority of the members of the
Audit Committee must be independent directors. See “—Independence of the Members of our Board of Directors and Audit
Committee.”
The Board of Directors of the Company, at its meeting held on December, 22, 2015, appointed, the current members of the
Audit Committee, who as of the date of this filing are: president Carlos Felices, members Miguel Angel Gutiérrez and Daniel
Gustavo Montamat. Additionally, Mr. Felices was determined by our Board of Directors to be an “Audit Committee Financial
Expert” pursuant to the rules and regulations of the SEC.
Executive directors may not sit on the Audit Committee.
Our Audit Committee, among other things:
•
•
•
•
•
•
•
periodically inspects the preparation of our financial and economic information;
reviews and opines with respect to the Board of Directors’ proposals regarding the designation of the external auditors and
the renewal, termination and conditions of their appointment;
evaluates internal and external audit work, monitors our relationship with the external auditors, and assures their
independence;
provides appropriate disclosure regarding operations in which there exists a conflict of interest with members of the
corporate committees or controlling shareholders;
opines on the reasonability of the proposals by the Board of Directors for fees and stock option plans of the directors and
administrators;
verifies compliance with applicable national or international regulations in matters related to behavior in the stock markets;
and
ensures that the internal Code of Ethics complies with normative demands and is adequate.
Activities of the Audit Committee
The Audit Committee, which pursuant to its regulations shall meet as many times as needed and at least once every quarter, held
twelve meetings between March 2015 and March 2016.
Performing its basic function of supporting the Board of Directors in its oversight duties, the Audit Committee periodically
reviews economic and financial information relating to us, supervises the internal financial control systems and oversees the
independence of the external auditors.
Economic and financial information
With the assessment of the CFO and considering the work performed by our external and internal auditors, the Audit Committee
analyzes the consolidated annual and quarterly financial statements before they are submitted to the Board of Directors. The Audit
Committee reviewed our consolidated financial statements as of and for the year ended December 31, 2015, and comparative
information, included in our report on Form 6-K submitted to the SEC on March 11, 2016.
155
Oversight of the internal control system
To supervise the internal financial control systems and ensure that they are sufficient, appropriate and efficient, the Audit
Committee oversees the progress of the annual internal audit, which is aimed at identifying our critical risks.
Throughout each year, the Audit Committee is informed by our internal audit department of the most relevant facts and
recommendations arising out of its work, and the status of the recommendations issued in prior years.
Our internal control system for financial reporting was aligned with the requirements established by Section 404 of the
Sarbanes-Oxley Act, a process supervised by the Audit Committee. These regulations require that, along with the annual audit, a
report must be presented from our management relating to the design, maintenance and periodic evaluation of the internal control
system for financial reporting, accompanied by a report from our external auditor. Several of our departments are involved in this
activity, including the internal audit department.
Relations with the external auditors
The Audit Committee maintains a close relationship with the external auditors, allowing it to make a detailed analysis of the
relevant aspects of the audit of financial statements and to obtain detailed information on the planning and progress of the work.
The Audit Committee also evaluates the services provided by our external auditors, determines whether the condition of
independence of the external auditors, as required by applicable law, is met and monitors the performance of external auditors to
ensure that it is satisfactory.
As of the date of this annual report, and pursuant to the evaluation process described in the paragraph above, the Audit
Committee had no objections to the designation of Deloitte & Co. S.A. as our external auditors of the financial statements for the year
ended December 31, 2015. In addition, the Audit Committee at its meeting in March 2016, as a result of the evaluation process
outlined in the preceding paragraph, had no objections to the designation of Deloitte & Co. S.A. as our external auditors for the year
ended December 31, 2016, which will be treated in a general shareholders’ meeting to be held this year.
Independence of the Members of our Board of Directors and Audit Committee
Pursuant to CNV regulations, a director is not considered independent when such director (i) owns at least a 15% equity interest
in a company, or a lesser interest if the director has the right to appoint one or more directors of the company, which we refer to as a
“Significant Participation,” or has a Significant Participation in another company that in turn has a Significant Participation in the
company or a significant influence on the company (“significant influence” as defined by Argentine GAAP); (ii) is a member of the
board of directors of, or depends on, or is otherwise related to shareholders, who have a Significant Participation in the company or
another company in which these shareholders have a direct or indirect Significant Participation or significant influence; (iii) is or has
been in the previous three years an employee of the company; (iv) has a professional relationship with, or is a member of a company
that maintains professional relationships with, or receives remuneration (other than that received in consideration of his performance
as a director) from the company or any of its shareholders who has a direct or indirect Significant Participation in or significant
influence on the company, or with a third-party company that has a direct or indirect Significant Participation or a significant
influence; (v) directly or indirectly sells or provides goods or services to the company or to any of its shareholders who has a direct or
indirect Significant Participation in or significant influence on the company for an amount exceeding his remuneration as a member
of the Board of Directors or audit committee; or (vi) is the spouse or parent (up to second grade of affinity or up to fourth grade of
consanguinity) of persons who, if they were members of the Board of Directors or Audit Committee, would not be independent,
according to the above-listed rules.
As of the date of this annual report, Directors Gustavo Alejandro Nagel, Néstor José Di Pierro, Juan Franco Donnini, Enrique
Andrés Vaquié, Nicolás Alfredo Trotta, Carlos Felices, Miguel Ángel Gutiérrez, Daniel Gustavo Montamat, Fabián Rodriguez Simón
and Emilio José Apud, and Alternate Directors Luis Gustavo Villegas, Lucio Mario Tamburo and Pedro Martín Kerchner Tomba
qualified as independent members of our Board of Directors under the above-described criteria.
156
Disclosure Committee
Composition and responsibilities of our Disclosure Committee
In February 2003, we created a Disclosure Committee to:
•
•
•
•
•
•
monitor overall compliance with regulations and principles of conduct of voluntary application, especially in relation to
listed companies and their corporate governance;
direct, establish and maintain procedures for the preparation of accounting and financial information to be approved and
filed by us or which is generally released to the markets;
direct, establish and maintain internal control systems that are adequate and efficient to ensure that our financial statements
included in annual and quarterly reports, as well as any accounting and financial information to be approved and filed by
us, are accurate, reliable and clear;
identify significant risks to our businesses and activities that may affect the accounting and financial information to be
approved and filed;
assume the activities that, according to U.S. laws and SEC regulations, are applicable to us and may be assumed by
disclosure committees or other internal committees of a similar nature, especially those activities relating to the SEC
regulations dated August 29, 2002 (“Certification of Disclosure in Companies’ Quarterly and Prospectus” —SEC Release
number 33-8124), in relation to the support for the certifications by our Chief Executive Officer and Chief Financial
Officer as to the existence and maintenance by us of adequate procedures and controls for the generation of the information
to be included in our annual reports on Form 20-F, and other information of a financial nature;
take on activities similar to those stipulated in SEC regulations for a disclosure committee with respect to the existence and
maintenance by us of adequate procedures and controls for the preparation and content of the information to be included in
the annual financial statements, and any accounting or financial information to be filed with the CNV and other regulators
of the stock markets on which our stock is traded; and
•
formulate proposals for an internal code of conduct on the stock markets that follow applicable rules and regulations or any
other standards deemed appropriate.
In addition, the Disclosure Committee reviews and supervises our procedures for the preparation and filing of:
•
•
•
•
•
official notices to the SEC, the Argentine stock market authorities and other regulators of the stock markets on which our
stock is traded;
interim financial reports;
press releases containing financial data on results, earnings, large acquisitions, divestitures or any other information
relevant to the shareholders;
general communications to the shareholders; and
presentations to analysts, investors, rating agencies and lending institutions.
As of the date of this annual report, the Disclosure Committee was composed of the following persons:
Name
Miguel Galuccio (1)
Daniel González
Germán Fernández Lahore
Jesús Grande
Daniel Palomeque
Carlos Alfonsi
Fernando Giliberti
Vacant
Fernando Dasso
Javier Fevre
Position
Chairman, Chief Executive Officer and
Director
Chief Financial Officer and President of the
Disclosure Committee
Legal Affairs Corporate Vice President and
Secretary of the Disclosure Committee
Upstream Executive Vice President
Quality, Environment, Security and Health
Vice President
Downstream Executive Vice President
Strategy and Business Development Vice
President
Communication and Institutional Relations
Vice President
Human Resources Vice President
Internal Auditor
Javier Sanagua
Reserves Auditor
(1) On March 9, 2016 our Chairman and CEO Miguel Galuccio announced that he will step down at the end of his term, which ends
at our next annual shareholders meeting, expected to be held in April 2016. See “––Board of Directors” above.
Recently, the Company announced the creation of a new Gas and Energy Vice-President position for our gas and energy
activities. Mr. Marcos Browne has been appointed to this position. See “––Senior Management” above.
157
In addition to the members of our senior management for whom outside business interests and experience were described above,
we include the following:
Javier Sanagua
Mr. Sanagua obtained a degree in geology from the National University of Tucumán with postgraduate studies at the
management executive development program from the IAE at Austral University. Following positions as a university teacher and
researcher. He joined YPF in 1996. Over 18 years of experience, he held positions in different areas such as Reservoir, Development,
Exploration and Production. Also, he was District Chief, Manager of the Los Perales area, Manager of the Economic Unit from
Cañadón Seco, province of Chubut, and after that, Director of Business Unit in Mendoza. He has been our Reserves Auditor since
February 2013.
Javier Fevre
Mr. Fèvre obtained a certified public accountant degree from UADE. He has served as Auditor at the General Auditor Office,
and as Advisor to the Deputy General Syndic at the Argentine Office of the General Comptroller. He was also Assistant Internal
Auditor at the Ministry of Foreign Affairs, International Trade and Worship and General Coordinator of Internal Audit at Aerolíneas
Argentinas S.A. He has been our Internal Auditor since September 2012.
Compliance with New York Stock Exchange Listing Standards on Corporate Governance
In accordance with the NYSE corporate governance rules, as of July 31, 2005, all members of the Audit Committee were
required to be independent. Independence is determined in accordance with highly detailed rules promulgated by the NYSE and SEC.
Each of the members of our Audit Committee was determined to be independent in accordance with the applicable NYSE and SEC
rules.
Significant differences between our corporate governance practices and those required by NYSE listing standards
Non-U.S. NYSE-listed companies may, in general, follow their home country corporate governance practices in lieu of most of
the NYSE corporate governance requirements. The NYSE rules, however, require that non-U.S. companies disclose any significant
ways in which their specific corporate governance practices differ from U.S. companies under the NYSE listing standards.
The following is a summary of the significant differences between our corporate governance practices and those applicable to
U.S. companies under the NYSE listing standards.
Independence of the directors on the Board of Directors
In accordance with the NYSE corporate governance rules, a majority of the board of directors of U.S. companies listed on the
NYSE must be composed of independent directors, whose independence is determined in accordance with highly detailed rules
promulgated by the NYSE. The relevant Argentine rules for determining director independence are described under “—Independence
of the Members of our Board of Directors and Audit Committee” above.
Compensation and nomination committees
In accordance with the NYSE corporate governance rules, all U.S. companies listed on the NYSE must have a compensation
committee and a nomination committee and all members of such committees must be independent in accordance with highly detailed
rules promulgated by the NYSE. Under Argentine law, these committees are not required as mandatory, but are recommended by the
CNV under CNV’s General Resolution No. 622/13. The Company follows the CNV’s recommendation and has a Compensation
Committee, established by the Board of Directors under the option provided in Article 17 clause (xii) of the Company’s by-laws,
which currently is composed of Directors Miguel Galuccio, Carlos Alberto Felices, Miguel Ángel Gutiérrez, Fabián Jorge Rodríguez
Simón and Fernando Dasso. Miguel Galuccio and Fernando Dasso are not independent. As a result of the foregoing, most of the
members of the Compensation Committee are independent.
158
Shareholder approval of equity compensation plans
The NYSE rules require that, with limited exemptions, all equity compensation plans must be subject to a shareholder vote. Under
Argentine law, the approval of equity compensation plans is within the authority of the board of directors.
Separate meetings for non-management directors
In accordance with the NYSE corporate governance rules, independent directors must meet periodically outside of the presence of the
executive directors. Under Argentine law, this practice is not required and as such, the independent directors on our Board of Directors do
not meet outside of the presence of the other directors, except for the meetings of the Audit Committee, which members are independent
directors.
Compensation of members of our Board of Directors and Supervisory Committee
Argentine law provides that the aggregate annual compensation paid to the members of the Board of Directors (including those
directors acting in an executive capacity) and the Supervisory Committee with respect to a fiscal year may not exceed 5% of net income for
such year if YPF is not paying dividends in respect of such net income, which percentage is increased up to 25% of net income based on the
amount of dividends, if any, are paid. The compensation of the Chairman and other directors acting in an executive capacity, together with
the compensation of all other directors and members of the Supervisory Committee, requires the ratification of an ordinary general
shareholders’ meeting as provided by Argentine law. When the exercise of special commissions or technical administrative functions by one
or more directors and the reduced or lack of profits imposed the need to exceed the limits, such remunerations may only be paid in excess if
expressly agreed by the shareholders’ meeting, for which the matter should be included as one of the agenda points.
For the year ended December 31, 2015 the aggregate compensation accrued to the members of the Board of Directors and YPF’s
executive officers for services in all capacities was Ps. 208.9 million, without including social security payments made by the Company as
required by law, including Ps. 45.7 million in the form of an equity compensation plan, pension, retirement or similar benefits that YPF
provides to members of its Board of Directors and executive officers and including Ps. 2.7 million in compensation paid to the members of
the Supervisory Committee. During 2015, YPF’s performance-based compensation programs included a performance bonus program for
approximately 6,700 non-unionized YPF employees and 9,000 unionized YPF employees. This bonus program is intended to motivate and
reward individuals for annual achievement of business objectives. The program provided for cash to be paid to its participants based on a
measurable and specific set of objectives under YPF’s Management by Objectives program and the results of the review of individual
performance. The participation of each eligible employee in the bonus plan ranged from 6% to 50% of such employee’s annual base salary.
In 2015, our Shareholders’ Meeting, as proposed by our Board of Directors, approved the creation of a voluntary reserve of Ps.
120 million to be set aside to fulfill our long-term incentive plan which contemplates compensation in shares for certain employees. To that
end, the Company purchased its own shares in accordance with Section 64 et seq. of Law No. 26,831. For additional information see Note
1.b.10.iii to our Audited Consolidated Financial Statements. The share-based benefit plan: (i) encourages the alignment of performance of
key personnel with the objectives of the strategic plan of the company, (ii) generates a clear and direct link between the creation of
shareholder value and compensation of key personnel, rewarding them for achieving long-term results reflected in share price and
(iii) assists in the retention of key personnel in the organization.
YPF’s directors do not have any service contracts with YPF involving the payment of compensation other than those previously
mentioned and the performance of their duties in the Company.
Supervisory Committee
The Supervisory Committee is responsible for overseeing compliance by the management and the Board of Directors with the
Argentine Corporations Law, the by-laws and regulations (if any), and shareholders’ resolutions. The functions of the Supervisory
Committee include, among others, attending all meetings of the Board of Directors, preparing a report of the financial statements for our
shareholders, attending shareholders’ meetings and providing information upon request to holders of at least 2% of our capital stock.
The by-laws provide for a Supervisory Committee consisting of three to five members and three to five alternate members, elected to
one-year terms. The Class A shares are entitled to elect one member and one alternate member of the Committee so long as one share of
such class remains outstanding. The holders of Class D shares elect up to four members and up to four alternates. Under the by-laws,
meetings of the Supervisory Committee may be called by any member. The meeting requires the presence of all members, and a majority
vote of the members in order to make a decision. The members and alternate members of the Supervisory Committee are not members of our
Board of Directors. The role of our Supervisory Committee is distinct from that of the Audit Committee. See “—The Audit Committee.” In
2015, the aggregate compensation paid to the members of the Supervisory Committee was Ps. 2.7 million.
159
The current members of the Supervisory Committee, the year in which they were appointed and the year their current term
expires are as follows:
Name
Gustavo Adolfo Mazzoni
Guillermo Cadirola
Enrique A. Fila
Raquel Inés Orozco (alternate member)
Cecilia Carabelli (alternate member)
Class of
Shares
Represented
A
D
D
A
D
Age
64
40
56
60
45
Member
Since
2015
2015
2015
2015
2015
Term
Expires
2016(*)
2016(*)
2016(*)
2016(*)
2016(*)
(*) Members of our Supervisory Committee are appointed in connection with a fiscal year. Our shareholders, in the ordinary and
extraordinary general shareholders’ meeting held on April 30, 2015 appointed the members of our Supervisory Committee for
fiscal year 2015.
Gustavo Adolfo Mazzoni
Mr. Mazzoni earned a certified public accountant degree and a postgraduate degree in finance from UBA. He also earned a
degree in social psychology from the Pichon Riviere School of Psychology. Among other positions, he previously worked as a senior
auditor for Price Waterhouse & Co., and the Argentine National Office of the Comptroller General, supervising private companies
and different national ministries, including Justice, Labor, Health and Social Development, among others. He is currently the
statutory auditor of several companies such as Aerolíneas Argentinas S.A., Austral S.A., Optar S.A., Centro de Ensayos de Alta
Tecnología S.A., among others.
Guillermo Leandro Cadirola
Mr. Cadirola earned his degree as a certified public accountant from UBA, and has a master’s degree in Economics and
Business Administration from the IESE Business School in Barcelona, Spain. Currently, he is a member of the Argentine National
Office of the Comptroller General, performing duties as statutory auditor at Administración General de Puertos S.E., ADIF S.E., All
Central S.A. and All Mesopotámica S.A., among other public companies. He has extensive experience with the management of
different multinational companies in the areas of operations, purchasing and finance.
Enrique Alfredo Fila
Mr. Fila earned a certified public accountant degree from the University of La Plata. Among other positions, previously he was
a councilor in the City of La Plata, an advisor to the mayor of La Plata, and a consultant to the Argentine National Ministry of Social
Development between 2008 and 2009. Currently, he is member of the Supervisory Committee of Tandanor S.A.I.C. y N.,
Aeropuertos Argentina 2000 S.A., Distribuidora de Gas Cuyana S.A., Radio y Television Argentina S.E., Veng S.A. and YPF Gas
S.A., and alternate member of the Supervisory Committee of Nación A.F.J.P. S.A., Servicios de Radio y Televisión de la Universidad
Nacional de Córdoba S.A., Empresa de Transporte de Energía Eléctrica Por Distribución Troncal de la Provincia de Buenos Aires
S.A., Compañía de Transporte de Energía Eléctrica S.A., Compañía Inversora de Trasmisión Eléctrica S.A., Telam S.E., and
Sociedad del Estado Casa de Moneda.
Raquel Inés Orozco
Ms. Orozco obtained a law degree from UBA. Currently, she is member of the Supervisory Committee at the following
companies: Central Térmica Guemes S.A., Telam S.E., Ubatec S.A., Inder S.E. (e.I), Foncap S.A., LT10 Radio Universidad del
Litoral S.A., and alternate member of the Supervisory Committee at Loteria Nacional S.E.
160
Cecilia Leonor Carabelli
Ms. Carabelli has a law degree from the School of Law and Social Science of UBA. She completed postgraduate studies in
Governmental Control at the Economics School of UBA. Among other positions she previously worked for the legal affairs Direction of the
National Social Security Administration, in the Secretary of Social Development, she was also head of a Senators’ Bureau at the Argentine
National Senate, and she served as Member of the Administration Committee to the Fiduciary Fund for Mortgage Debtors, representing the
Argentine National Ministry of Economy and Finance. She worked as Manager on behalf of the National Social Security Administration for
the Federal Projects “Anses I and Anses II,” financed partly by the World Bank. Currently, she is a member of the Argentine National Office
of the Comptroller General, and is member of the Supervisory Committee of SIDERAR SACI (since 2001) and Nación Fideicomisos S.A.
Employee Matters
Our total workforce consists of permanent and temporary employees. As of December 31, 2013, 2014 and 2015, we had 17,747, 22,032
and 22,025 employees, respectively. In 2015, this included 10,192 employees in the Downstream business segment, 4,443 employees in the
Upstream business segment, and 7,390 employees in the Corporate and Other business segments. We had 2,608 temporary employees in
2015. The most significant variations in 2015 included an increase in the Upstream business of 225 employees and the increase of 96
employees in OPESSA as a result of natural rotation of oil station personnel. In addition, a decrease of 125 employees as a result of the
merging process of staff units in YSUR (2015 acquisition of Apache Group in Argentina), a part of the Upstream business, and A-Evangelista
S.A., which is part of the Corporate and Other business segments, decreased during 2015 by approximately 423 employees (411 of which are
temporary labor contracts to prevent further claims which is standard in construction hires) mostly dedicated to the final stage of the coke unit
at our refinery in La Plata. Approximately 40% of our employees are represented by the Federation of Oil Workers Union (“SUPeH”) that
negotiates labor agreements and salaries that apply to YPF and OPESSA unionized employees. SUPeH is continually negotiating with us, and
we maintain a good level of communication. In general, requests of labor unions related to the petrochemical industry were consistent with
general wage increases given by the General Unions Confederation.
In addition, labor conditions and salaries of third-party employees, are represented by sixteen other unions. Approximately 60% of third-
party employees, mostly in Upstream business, are represented by nine unions with whom we directly negotiate their labor agreements and
salaries. These unions are clustered in three groups, Petroleros Privados with five unions, Personal Jerárquico with three unions and SUPeH
Emprendimientos. The remaining 40% of third-party employees are represented by unions with whom we do not participate in labor
agreements.
As part of its privatization, YPF restructured its internal organization and significantly reduced the number of its employees. YPF
reduced its work force from over 51,000 employees (including approximately 15,000 personnel under contract) as of December 31, 1990 to
approximately 7,500 at December 31, 1993. YPF paid to the employees affected by these reductions the termination payments required under
Argentine labor laws that amounted to Ps. 686 million. A substantial majority of lawsuits that originated as a consequence of this restructuring
process have been brought by former employees who allege that they received insufficient severance payments in connection with their
dismissal and various job-related illnesses, injuries, typically seeking unspecified relief.
As of December 31, 2015, YPF was a party in approximately 1,243 labor lawsuits that relate to events or acts that took place after
December 31, 1990. The outcome of said lawsuits depends on factual issues that vary from case to case, and it is not always feasible to predict
the outcome of particular cases. However, based on the number and character of the lawsuits already commenced, the estimated likelihood of
additional claims in view of the number of dismissed employees, applicable statutes of limitations, the legal principles involved in the suits
and the financial statement reserves previously established, our management does not expect the outcome of these lawsuits to have a material
adverse effect on our financial condition or future results of operations.
Maxus (a YPF subsidiary) has a number of contributory health and welfare plans covering its full-time employees and their dependents.
Maxus provides matching contributions of up to 6% of employees’ deferrals to the employee savings plan, along with a non-discretionary
contribution of 7.5%, which was implemented following the termination of the Maxus pension plan. There is a non-qualified pension plan
where a small number of executives receive contributions associated with the savings plan, which would have been denied them due to IRS
annual limits. Retiree health and life insurance coverage for active employees was terminated in October 2011. Maxus continues to provide
health and welfare plans to a select group of retired employees who were promised coverage for life at no cost to them. The coverage provided
varies by the year in which the employees retired and the companies they retired from. Due to the advanced ages of these retirees, this is a
significantly decreasing population. Maxus continues to provide supplemental noncontributory and non-qualified retirement payments to
certain former executives, officers, and surviving spouses, which is a closed group.
As of December 31, 2015, there were also approximately 49,000 third-party employees under contract, mostly with large international
service providers. Although we have policies regarding compliance with labor and social security obligations by its contractors, we are not in
a position to ensure that contractors’ employees will not initiate legal actions to seek indemnification from us based upon a number of
Argentine judicial labor court precedents recognizing joint and several liability between the contractor and the entity to which it is supplying
services under certain circumstances.
161
The following table provides a breakdown of our employees by business units as of December 31, 2015.
Employees by Business Units
Upstream
Downstream
Refining and Marketing
Chemicals
Natural gas distribution and Electricity Generation(1)
Corporate and Other(2)
Total YPF
(1)
(2)
Includes 1,303 employees of Metrogas S.A. and its subsidiaries
Includes 5,437 employees of A-Evangelista S.A. and its subsidiaries.
The following table provides a breakdown of our employees by geographic locations.
Employees by geographic location
Argentina
Rest of South America
United States
Total YPF
4,443
10,192
8,765
39
1,388
7,390
22,025
21,852
146
27
22,025
ITEM 7. Major Shareholders and Related Party Transactions
The Expropriation Law has significantly changed our shareholding structure. The Class D shares subject to expropriation from
Repsol or its controlling or controlled entities, which represent 51% of our share capital and have been declared of public interest,
will be assigned as follows: 51% to the federal government and 49% to the governments of the provinces that compose the National
Organization of Hydrocarbon Producing States. In addition, the Argentine federal government and certain provincial governments
already own our Class A and Class B shares. See “Item 3. Key Information—Risk Factors—Risks Relating to Argentina—The
Argentine federal government has taken control over the Company and will operate it according to domestic energy policies in
accordance with the Expropriation Law.” Additionally, see “Item 4. Information on the Company—Regulatory Framework and
Relationship with the Argentine Government—Law No. 26,932” for a description of the agreement between Repsol and the
Argentine Republic relating to compensation for the expropriation of 51% of the share capital of YPF owned, directly or indirectly,
by Repsol.
As of the date of this annual report, the transfer of the shares subject to expropriation between the National Executive Office and
the provinces that compose the National Organization of Hydrocarbon Producing States is still pending. According to Article 8 of the
Expropriation Law, the distribution of the shares among the provinces that accept their transfer must be conducted in an equitable
manner, considering their respective levels of hydrocarbon production and proved reserves. To ensure compliance with its objectives,
the Expropriation Law provides that the National Executive Office, by itself or through an appointed public entity, shall exercise all
the political rights associated with the shares subject to expropriation until the transfer of political and economic rights to the
provinces that compose the National Organization of Hydrocarbon Producing States is completed. In addition, in accordance with
Article 9 of the Expropriation Law, each of the Argentine provinces to which shares subject to expropriation are allocated must enter
into a shareholder’s agreement with the federal government which will provide for the unified exercise of its rights as a shareholder.
See “Item 4. Information on the Company—Regulatory Framework and Relationship with the Argentine Government—The
Expropriation Law.”
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The following table sets forth information relating to the beneficial ownership of our shares as of March 9, 2016:
National State - Ministry of Energy and Mining (1)
Public (2)(3)
Slim Family (4)
Argentine federal and provincial governments (5)
Employee fund (6)
Number of
shares
200,589,525
171,545,458
21,126,000
11,388
40,422
(%)
51.000%
43.621%
5.372%
0.003%
0.010%
(1) The expropriated Class D shares, which represent 51% of our share capital, and which now are owned by the Republic of
Argentina will be assigned as follows: 51% to the federal government and 49% to the governments of the provinces that
compose the National Organization of Hydrocarbon Producing States. The completion of this assignment is pending. To ensure
compliance with its objectives, the Expropriation Law provides that the National Executive Office, by itself or through an
appointed public entity, shall exercise all the political rights associated with the shares subject to expropriation until the transfer
of political and economic rights to the provinces that compose the National Organization of Hydrocarbon Producing States is
completed. In addition, in accordance with Article 9 of the Expropriation Law, each of the Argentine provinces to which shares
subject to expropriation are allocated must enter into a shareholder’s agreement with the federal government which will provide
for the unified exercise of its rights as a shareholder. See “Item 4. Information on the Company—Regulatory Framework and
Relationship with the Argentine Government—The Expropriation Law,” “Decree 13/2015” and “Decree 272/2015.”
(2) According to data provided by The Bank of New York Mellon, as of March 9, 2016.
(3) According to data provided by The Bank of New York Mellon, as of March 9, 2016, there were 172,078,241 ADSs outstanding
and 54 holders of record of ADSs. Such ADSs represented approximately 44 % of the total number of issued and outstanding
Class D shares as of such date.
(4) According to Schedule 13G filed with the SEC on February 16, 2016. “Slim Family” consists of Carlos Slim Helú, Carlos Slim
Domit, Marco Antonio Slim Domit, Patrick Slim Domit, María Soumaya Slim Domit, Vanessa Paola Slim Domit and Johanna
Monique Slim Domit through Inmobiliaria Carso, S.A. de C.V. and Grupo Financiero Inbursa, S.A.B. de C.V.
(5) Reflects the ownership of 3,764 Class A shares and 7,624 Class B shares by the Argentine federal government and provincial
governments, respectively.
(6) Reflects the ownership of 40,422 Class C shares.
Related Party Transactions
All material transactions and balances with related parties as of December 31, 2015 are set forth in Note 6 to the Audited
Consolidated Financial Statements. The main related party transactions were our sales of refined and other products to certain joint
ventures and affiliates (which amounted to Ps. 3,596 million in 2015), our purchase of petroleum and other products that we do not
produce ourselves from certain joint ventures and affiliates (which amounted to Ps. 1,773 million in 2015), all this in addition to what
is mentioned in the following paragraphs.
In addition, the Expropriation Law was passed by the Argentine congress, which was ruled by Decree No. 660 of the National
Executive Office. Among other matters this Law declares of public interest and subject to expropriation 51% of the share capital of
YPF represented by an identical stake of Class D shares owned, directly or indirectly, by Repsol and its controlled or controlling
entities. See “Item 4. Information on the Company—Regulatory Framework and Relationship with the Argentine Government—The
Expropriation Law.” Consequently, since the passage on May 3, 2012 of the Expropriation Law, the federal government is a related
party of the Company. Consequently, and in addition to transactions mentioned in paragraph above, we are party to numerous
agreements with the federal government, as well as with certain agencies or institutions dependent on such governments and stated-
owned companies.
The information disclosed in Note 6 to the Audited Consolidated Financial Statements disclose the balances with joint ventures
and affiliated companies as of December 31, 2015, December 31, 2014 and December 31, 2013, and transactions with the
aforementioned parties for the twelve-month periods ended December 31, 2015, 2014 and 2013. Additionally, the balances and
transactions held with the entities within the Repsol group are included until the date the conditions required to be considered as
related parties were met. Information regarding major transactions with government entities are also described in Note 6 to the
Audited Consolidated Financial Statements.
In addition, see Note 1.b.10.iii to our Audited Consolidated Financial Statements regarding our long-term share compensation
plan offered to certain personnel.
For an organizational chart showing our organizational structure, including our interests in our principal affiliates, see “Item 4.
Information on the Company—Overview.”
163
Argentine Law Concerning Related Party Transactions
Section 72 of the Stock Market Law provides that before a company whose shares are listed in Argentina may enter into an act
or contract involving a “significant amount” with a related party or parties, such company must obtain approval from its board of
directors, and obtain an opinion, prior to such board approval, from its audit committee or from two independent valuation firms that
states that the terms of the transaction are consistent with those that could be obtained on an arm’s-length basis.
For the purpose of Section 72 of the Stock Market Law and CNV Regulations, “significant amount” means an amount that
exceeds 1% of the issuer’s net worth as reflected in the latest approved financial statements. For purposes of the Stock Market Law,
“related party” means (i) directors, members of the supervisory committee or managers; (ii) the persons or entities that control or hold
a significant participation in the company or in its controlling shareholder (to be regulated by CNV); (iii) any other company under
common control; (iv) direct relatives of the persons mentioned in (i) and (ii); or (v) companies in which the persons referred to in
(i) to (iv) hold directly or indirectly significant participations.
The acts or contracts referred to above, immediately after being approved by the board of directors, shall be disclosed to the
CNV, making express indication of the audit committee’s or independent valuation firm’s opinion, as the case may be. Also,
beginning on the business day following the day the transaction was approved by the board of directors, the audit committee’s or
independent valuation firm’s reports shall be made available to the shareholders at the company’s principal executive offices.
If the audit committee or the two independent valuation firms do not find that the contract is on arm’s-length terms, prior
approval must be obtained at the company’s shareholders’ meeting.
ITEM 8. Financial Information
Financial Statements
See Item 18 for our Audited Consolidated Financial Statements.
Legal Proceedings
Argentina
The Privatization Law provides that the Argentine State shall be responsible, and shall hold us harmless, for any liabilities,
obligations or other commitments existing as of December 31, 1990 that were not acknowledged as such in the financial statements of
Yacimientos Petrolíferos Fiscales Sociedad del Estado, our predecessor, as of that date arising out of any transactions or events that
had occurred as of that date, provided that any such liability, obligation or other commitment is established or verified by a final
decision of a competent judicial authority. In certain lawsuits related to events or acts that took place before December 31, 1990, we
have been required to advance the payment of amounts established in certain judicial decisions, and have subsequently been
reimbursed or are currently in the process of requesting reimbursement from the Argentine government of all material amounts in
such cases. We are required to keep the Argentine government apprised of any claim against us arising from the obligations assumed
by the Argentine government. We believe we have the right to be reimbursed for all such payments by the Argentine government
pursuant to the above-mentioned indemnity, which payments in any event have to date not been material. This indemnity also covers
fees and expenses of lawyers and technical consultants subject, in the case of our lawyers and consultants, to the requirement that
such fees and expenses not be contingent upon the amounts in dispute.
Accrued, probable contingencies
Accruals totaling Ps. 8,495 million net of Ps. 2.029 million corresponding to YPF Holdings, Ps. 6,513 million and Ps.
4,674 million as of December 31, 2015, 2014 and 2013, respectively, have been provided in connection with contingencies which are
probable and can be reasonably estimated. In the opinion of our management, in consultation with our external counsel, the amount
accrued reflects management’s reasonable estimate, based on the information available as of the date of the issuance of the
accompanying Financial Statements, of the probable outcome of the above-mentioned contingencies. The most significant legal
proceedings and claims accrued are described in the following paragraphs.
Alleged defaults under natural gas supply contracts. Since 2004, the Argentine Secretariat of Energy and the Undersecretariat of
Fuels, through Rule No. 27/04, Resolutions No. 265/04, 659/04, 752/05, 1329/06 and 599/07, have on various occasions instructed us
to supply certain quantities of natural gas to the Argentine domestic market, in each case notwithstanding the lack of a contractual
commitment on our part to do so. In addition, the Argentine government has, at various times since 2004, including ENARGAS
Resolution No. 1410/10, imposed direct volume limitations on natural gas exports in different ways. On January 5, 2012, the Official
Gazette published Resolution SE No. 172 which temporarily extends the allocation rules and other criteria established by Resolution
No. 599/07. As a result of these measures, from 2004 to the present we have been required in many instances to partially or fully
suspend natural gas export deliveries that are contemplated by our contracts with export customers. See “Item 4. Information on the
Company—Exploration and Production—Delivery commitments—Natural gas supply contracts” for additional information on
the restrictions affecting contracted volumes.
We appealed these measures, but, pending favorable final resolution of such appeals, we have been obliged to comply in order
to avoid greater losses to us and our export customers that could be occasioned by the revocation of our export permits or other
penalties. We informed our natural gas export customers of our position that these governmental measures constitute an event of force
majeure that releases us from any contractual or extra-contractual liability deriving from the failure to deliver the agreed upon
volumes of gas. Some of our customers have rejected our position and a number of them have sought damages and/or penalties for
breach of supply commitments under a contractual “deliver or pay” clause and/or preserving their rights for future claims related to
these matters.
164
On June 25, 2008, AES Uruguaiana Emprendimientos S.A. (“AESU”) claimed damages in a total amount of U.S.$28.1 million
for natural gas “deliver or pay” penalties for cutbacks accumulated from September 16, 2007 through June 25, 2008. AESU also
claimed an additional amount of U.S.$2.7 million for natural gas “deliver or pay” penalties for cutbacks accumulated from
January 18, 2006 until December 1, 2006. YPF has contested both claims. On September 15, 2008, AESU notified YPF of the
interruption of the fulfillment of its commitments alleging delay and breach of YPF obligations. YPF has contested the arguments of
this notification. On December 4, 2008, YPF notified AESU that the force majeure conditions had ceased and, pursuant to the
contract in force, it would suspend its delivery commitments due to the repeated breaches of AESU’s obligations. AESU has
contested this notification. On December 30, 2008, AESU contested YPF’s right to suspend its natural gas deliveries and on
March 20, 2009, notified YPF of the termination of the contract. On March 20, 2009 AESU formally notified YPF of the termination
of the contract. On April 6, 2009, YPF initiated an arbitration process at the International Chamber of Commerce (“ICC”) against
AESU, Companhía do Gas do Estado do Río Grande do Sul (“Sulgás”) and Transportadora de Gas del Mercosur S.A. (“TGM”). On
the same date YPF was notified by the ICC of an arbitration process initiated by AESU and Sulgás against YPF in which they claim,
among other matters considered inadmissible by YPF, consequential loss, AESU’s plant dismantling costs and the payment of
“deliver or pay” penalties mentioned above, all of which totaled approximately U.S.$1,052 million.
Additionally, YPF was notified of an arbitration process brought by TGM at the ICC, claiming YPF owed approximately
U.S.$10 million plus interest up to the date of effective payment in connection with the payment of invoices related to a gas
transportation contract entered into in September 1998 between YPF and TGM, associated with the aforementioned natural gas
exportation contract signed with AESU. On April 8, 2009, YPF requested that this claim be denied and counterclaimed for the
termination of the natural gas transportation contract based on its rights upon the termination by AESU and Sulgás of the related
natural gas export contract. In turn, YPF initiated an arbitration process at the ICC against TGM, among others. YPF received the
reply to the complaint from TGM, who requested the full denial of YPF’s claims and introduced a counterclaim against YPF asking
the arbitration tribunal to compel YPF to compensate TGM for all present and future damages suffered by TGM due to the
termination of the gas transportation contract and the memorandum of agreement dated October 2, 1998 by which YPF undertook to
pay irrevocable non-capital contributions to TGM in return for the Uruguayana Project pipeline expansion. TGM also requested the
panel hold AESU-Sulgás – if it finds that the termination of the Gas Contract occurred due to the breach of AESU or Sulgás—jointly
and severally liable to indemnify TGM for all damages caused by such termination. Additionally, on July 10, 2009, TGM increased
the amount of its claim to U.S.$17 million and claimed an additional amount of approximately U.S.$366 million for loss of profits,
both contested by YPF.
On April 6, 2011, the arbitration tribunal appointed in the “YPF vs. AESU” arbitration sustained YPF’s motion, and
consolidated all the related arbitrations (“AESU vs. YPF,” “TGM vs. YPF” and “YPF vs. AESU”) into the “YPF vs. AESU”
arbitration.
On May 24, 2013 YPF was notified of the partial award decreed by a majority in the “YPF vs. AESU and TGM” arbitration
whereby YPF was held responsible for the termination in 2009 of the natural gas export and transportation contracts signed with
AESU and TGM. The award only determined the liability of the parties, leaving the determination of the damages that could exist
subject to the subsequent proceedings before the same tribunal. Moreover, the tribunal rejected the admissibility of “deliver or pay”
claims asserted by Sulgás and AESU for the years 2007 and 2008 for U.S.$28 million and for the year 2006 for U.S.$2.4 million.
On May 31, 2013, YPF filed with the arbitration tribunal a writ of nullity, in addition to making several presentations in order to
safeguard its rights. Against the rejection of the writ of nullity, on August 5, 2013 YPF filed an appeal with the National Court of
Appeals in commercial matters.
On July 29, 2013, the arbitration tribunal rejected the nullity request and suspended the arbitration proceedings until
September 30, 2013. On October 17, 2013 the arbitration tribunal resumed the proceedings and established a proceeding schedule to
be held during 2014, during which the reports of the experts proposed by the parties occurred.
On October 23, 2013 the National Court of Appeals in commercial matters declared its jurisdictional incompetency and
reassigned the nullity request to the National Court of Appeals in the Federal Contentious Administrative Tribunal. On December 16,
2013, the intervening official issued its opinion in favor of the competence of this court.
On December 27, 2013, the Federal Court of Appeals in administrative litigation matters granted the reconsideration motion
from denial on appeal, then sustained the appeal for procedural violations and stayed relief pending the arbitration process. In
addition, the court granted, until the appeal for procedural violations is finally admitted, a restrictive injunction to prevent the advance
of the arbitration process while a decision on the reconsideration motion from denial on appeal and on the appeal for procedural
violations filed by YPF is pending.
165
On January 10, 2014, YPF was served with (i) the complaint for damages filed by AESU with the arbitration tribunal claiming a
total amount of U.S.$815.5 million and (ii) the complaint for damages filed by TGM with the arbitration tribunal claiming a total
amount of U.S.$362.6 million. On April 25, 2014, YPF filed a reply to the complaint for damages with the arbitration tribunal,
contesting the amounts claimed by TGM and AESU and alleging that the amounts were incorrect due to errors in the technical
valuations. On July 8, 2014, TGM filed an answer to the reply, to which YPF in turn replied on September 23, 2014 with a second
answer.
On October 7, 2014, the Argentine Federal Court of Appeals ordered a suspension of the second stage of arbitration until it
issues a final decision on the writ of nullity filed by YPF against the arbitral award on adjudication of liability. On October 31, 2014,
the arbitration tribunal suspended the arbitration process until February 2, 2015. On April 24, 2015, the arbitral panel resumed the
proceedings and invited the parties to consult with each other regarding the continuation of the arbitration and to provide a joint or
individual report on next steps. YPF notified the Federal Contentious Administrative Tribunal of the decision on April 27, 2015 given
that the order to suspend the arbitration proceedings was in effect. On July 2, 2015 the arbitration tribunal ordered hearings for the
second stage of arbitration to take place on November 16 and 17 of 2015. YPF notified the Federal Court of Appeals of the decision
on July 13, 2015. Although the Federal Court of Appeals ordered the suspension of the second stage of the arbitration, the hearings
proceeded without the presence of TGM and YPF. On December 23, 2015, the National Court of Appeals in the Federal Contentious
Administrative Tribunal granted the nullity request and vacated the partial arbitral award. On the same date, YPF notified the
arbitration tribunal of the decision and requested the termination of the arbitration proceeding. On February 3, 2016 TGM filed an
extraordinary appeal against the National Court of Appeals ruling to the Supreme Court of Justice. On February 2, 2016 AESU and
Sulgas filed a nullity request against the National Court of Appeals ruling. On February 23, 2016 the National Court of Appeals
rejected AESU and Sulgas nullity request “in limine.”
AESU petitioned the Uruguayan courts to nullify the rulings of the arbitration tribunal regarding the suspension of the
arbitration process and injunction preventing YPF from attempting to halt the arbitration process. AESU has attempted to serve notice
of the rulings of the Uruguayan courts, and YPF opposed this notice due to formal defects and the lack of jurisdiction of the
Uruguayan courts in this matter. The Argentine Federal Court of Appeals notified the Uruguayan courts. On July 16, 2015 the Federal
Contentious Administrative Tribunal 3 rejected one of the judicial petitions through which AESU tried to serve the nullity petition of
the Arbitration Tribunal that declared the suspension of the Arbitration. On September 4, 2015 AESU requested an appeal. On
December 23, 2015 the National Court of Appeals in the Federal Contentious Administrative Tribunal rejected the appeal and
confirmed the resolution of the lower court.
Considering the information available as of the date of issuance of the accompanying financial statements, the estimated time
remaining until the end of the proceedings, the outcomes of the additional evidence presented in the continuation of the dispute and
the provisions of the partial award, YPF has accrued its best estimate with respect to the amount of the claims.
In addition, YPF is subject to certain claims related to transportation fees and charges associated with transportation services
under contracts associated with natural gas exports. Transportadora de Gas del Norte S.A. (“TGN”), one of the parties to these
contracts, initiated mediation proceedings with us in order to determine the merits of its claim. The mediation proceedings did not
result in an agreement and, on March 12, 2010, YPF was notified of the lawsuit filed by TGN claiming the fulfillment of contractual
obligations and the payment of unpaid invoices while reserving the right to claim for damages. TGN subsequently claimed the alleged
related damages in a notice addressed to the Company in November 2011. On April 3, 2013, YPF was notified of the lawsuit filed by
TGN claiming damages. The total amount claimed by TGN amounts to approximately U.S.$207 million. Additionally, the plaintiff
notified us that it was terminating the contract, claiming YPF’s alleged breach of such contract due to an alleged lack of payment of
the related transportation fees. The Federal Court of Appeals in civil and commercial matters has ruled in favor of the jurisdiction of
the federal civil and commercial courts (and against the jurisdiction of ENARGAS) to resolve this matter. Additionally, on
January 12, 2012 and following a mediation process which ended without any agreement, Nación Fideicomisos S.A. (“NAFISA”)
filed a complaint against YPF before ENARGAS, under Article 66 of Law No. 24,076, claiming the payment of Ps.339 million in
relation to payments of applicable fees for natural gas transportation services to Uruguaiana relating to the transportation invoices
claimed by TGN. On February 8, 2012, we answered the claim raising ENARGAS’s lack of jurisdiction as we did in the proceeding
against TGN, in consolidation with the trial “TGN / YPF”, and rejecting the claim based on the theory of legal impossibility. On the
same date, a similar order of confirmation was also submitted in the “TGN / YPF” matter. On April 12, 2012, ENARGAS ruled in
favor of NAFISA.
On May 12, 2012, YPF filed an appeal against such ruling to the National Court of Appeals in the Federal Contentious
Administrative Tribunal. On November 11, 2013 the National Court of Appeals in the Federal Contentious Administrative Tribunal
ruled in favor of NAFISA. On November 19, 2013, YPF filed an ordinary appeal against such ruling to the Supreme Court of Justice.
On November 27, 2013 YPF filed an extraordinary appeal against such ruling to the Supreme Court of Justice. In the opinion of
YPF’s management, the matters referred to above will not have a material adverse effect on the Company’s results of operations. On
September 29, 2015, the Supreme Court of Justice overruled the National Court of Appeals in the Federal Contentious Administrative
Tribunal holding that ENARGAS has no jurisdiction in order to hear NAFISA’s claim.
166
On September 18, 2012, the judge presiding in the “TGN / YPF” matters: a) dismissed the order of consolidation made by YPF
on the ground that the court has no jurisdiction to hear the case because it lacks administrative jurisdiction in NAFISA litigation and
considering that there is no possibility that the decision made to any of them have the same effect on the other; b) accepted YPF’s
claim that notification made by TGN on December 16, 2010 in respect of the termination of the contract and the call of a public
tender by TGN on March 10, 2011 to award the public and firm service transportation of natural gas through its northern pipeline
system, including transport capacity remaining under the contract with YPF, terminated the contract; c) extended the demand for
which TGN claims invoices relating to services for November and December 2010; and d) opened the case to trial.
In connection with the above, on April 8, 2009, YPF filed a complaint against TGN with ENARGAS, seeking the termination of
the natural gas transportation contract with TGN for the transport of natural gas in connection with the natural gas export contract
entered with AESU and other parties. The complaint is based on the termination of the referenced natural gas export contract and the
legal impossibility of assigning the transportation contract to other shippers because of certain changes in law in effect since 2002; as
a second matter, the legal impossibility for TGN to render the transportation service on a firm basis because of certain changes in law
in effect since 2004; and as a third matter, the Teoría de la Imprevisión (hardship provision under Article 1198 of the Argentine Civil
Code) available under Argentine law when extraordinary events render a party’s obligations excessively burdensome.
On April 3, 2013, the complaint for damages brought by TGN was filed, whereby TGN claimed YPF should pay the amount of
U.S.$ 142 million, plus interests and legal fees for the termination of the transportation contract, and that YPF would have 30 days to
file and answer thereto. On May 31, 2013, YPF answered the claim requesting the dismissal thereof. On April 3, 2014, the evidence
production period commenced for a 40-day lapse, and the court notified the parties that they shall submit a copy of evidence offered
by them to create exhibit binder. As of the date of these annual report, evidence offered by the parties is being produced.
La Plata and Quilmes environmental disputes. On June 29, 1999, a group of three neighbors of the La Plata refinery filed claims
for the remediation of alleged environmental damages in the peripheral water channels of the refinery and for payment related to
contamination and compensation for alleged health and property damages as a consequence of environmental pollution caused by
YPF prior to and after privatization. We notified the National Executive Office that there is a chance that the tribunal may find us
responsible for the damages. In such event, due to the indemnity provided by Privatization Law (Law No. 24,145) and in accordance
with that law, we should be allowed to request reimbursement of the expenses for liabilities existing on or prior to January 1, 1991
(before privatization) from the Argentine government.
On December 27, 2002, a group of 264 claimants who resided near the La Plata refinery requested compensation for alleged
quality of life deterioration and environmental damages purportedly caused by the operation of the La Plata refinery. The amount
claimed is approximately Ps. 42 million. We filed a writ answering the complaint. There are three similar additional claims raised by
three groups of 120, 343 and 126 neighbors, respectively. The first group has made a claim for compensation of approximately Ps.
16 million, the second group has made a claim for compensation of approximately Ps. 45 million and the third one has made a claim
of approximately Ps. 16 million, in addition to a request for environmental cleanup.
On December 17, 1999, a group of 37 claimants who resided near La Plata refinery, demanded the specific performance by us of
different works, installation of equipment, technology and execution of work necessary to stop any environmental damage, as well as
compensation for health damages alleged to be the consequence of gaseous emissions produced by the refinery, currently under
monitoring. On August 11, 2011, the judge ruled against YPF and the Argentine government requiring us to pay approximately Ps.
3.5 million plus interest. The Court of Appeals confirmed the lower court judge’s ruling and ordered YPF to file an improvement plan
to reduce gaseous emissions produced by the refinery. YPF filed an appeal before the Supreme Court but it was rejected on March
2013. Subsequently, the Judge ordered YPF to file an improvement plan, which YPF filed on March 2013. The plan was analyzed by
court experts, who presented their report. YPF was served and presented a request for clarification. The court approved the
improvement plan on June 25, 2013. On March 17, 2015, the court requested YPF to provide certain information on the plan and
stated it would be premature to start a monitoring program.
On January 25, 2011, we entered into an agreement with the Provincial Entity for Sustainable Development (“OPDS”) of the
government of the province of Buenos Aires, within the scope of the remediation, liability and environmental risk control program,
created by Resolution 88/10 of the OPDS. Pursuant to such agreement, YPF and the relevant authorities agreed to jointly perform an
eight-year work program in the canals adjacent to the La Plata refinery, including the conduct of characterization and risk assessment
studies of sediments. The agreement provides that when a required remediation action is identified as a result of a risk assessment
study, different alternatives and available techniques will be considered, as well as the steps needed for its implementation. Studies to
determine how old the contamination is will also be performed pursuant to the agreement, in order to evaluate whether the Argentine
government should be liable for such contamination pursuant to its obligation to hold us harmless under the Privatization Law, which
established the procedures for our privatization. YPF has provided an accrual of the estimated cost of the characterization and risk
assessment studies mentioned above. The cost of the remediation actions, if required, will be recorded in those situations where the
loss is probable and can be reasonably estimated.
167
Quilmes claims. We have been notified of several claims filed by neighbors living near the riverside in Quilmes, in the province
of Buenos Aires, as a consequence of a leak related to the La Plata – Dock Sud pipeline, which occurred in 1988 as third parties
damaged and stole fuel from the pipeline, which was then repaired by Yacimientos Petrolíferos Fiscales.
One of the claims has been filed by a group of people that allegedly live in this area and have requested the remediation of
environmental damages and the payment of approximately Ps. 47 million plus interest as compensation for alleged personal damages
for hydrocarbons exposure. We have answered the complaint requesting its rejection and impleading the Argentine government. We
have also notified the Argentine government of the existence of this claim and that we plan to request that it hold us harmless and
indemnify us against any liability derived from this lawsuit, as provided by the Privatization Law. The Argentine government,
through an administrative decision, has denied any responsibility to indemnify us for this matter; therefore, we have sued the
Argentine government to obtain a declaratory judgment declaring this administrative decision null and void. Such declaratory
judgment is still pending. On December 18, 2014 the Argentine government was cited, by notification of the demand and its
extensions, by letter to the Ministry of Federal Planning.
There are 24 other judicial claims that have been brought against us based on similar allegations, amounting to approximately
Ps. 19 million. Additionally, we are aware of the existence of other actions brought against us that have not yet been served and
which are based on similar allegations. As of the date of this annual report, a remediation plan is being performed in the affected area,
under the supervision of the environmental authority of the province of Buenos Aires.
New Jersey claims. On December 13, 2005, the New Jersey Department of Environmental Protection (the “DEP”) and the New
Jersey Spill Compensation Fund filed a claim with a New Jersey court against Occidental Chemical Corporation, Tierra, Maxus,
Repsol YPF, YPF, YPF Holdings and CLH Holdings. See “Item 4. Information on the Company—Environmental Matters—YPF
Holdings-Operations in the United States.” YPF International S.A. and Maxus International Energy Company were added to the
claim in 2010. For detailed information about this legal proceeding, see “YPF Holdings—Passaic River/Newark Bay, New Jersey—
New Jersey—litigation with DEP.”
Tax claims. We have received several claims from the AFIP and from the provincial and municipal fiscal authorities, which are
not individually significant, and which have been accrued based on the best information available as of the date of the issuance of the
accompanying financial statements.
Users and Consumers Union Association claim. The Users and Consumers Union Association is seeking reimbursement of
allegedly excessive prices charged to bulk LPG consumers between 1993 and 2001. The original claim was against Repsol YPF but
has been extended to YPF. The claim is for a sum of Ps. 91.2 million for the period 1993 to 1997 (this sum, in current pesos, would
amount to approximately Ps. 502 million), together with an undetermined amount for the period 1997 to 2001. We invoked the statute
of limitations, since the applicable two-year statute of limitations had already elapsed.
On December 28, 2015, the Court of First Instance ruled partially in favor of the plaintiffs. The court ordered YPF to remit Ps.
98.2 million plus interest to the National Secretariat of Energy into the trust fund created by Law No. 26,020. This amount pertains to
the claims for the period 1993 through 1997. Determination of the final amount is pending a subsequent settlement stage.
The court ruled against the plaintiffs in respect of their claim for damages from 1997 to 2001. YPF appealed the decision. As of
December 31, 2015, YPF has provisioned approximately Ps. 503 million plus trial costs for these matters.
Non-accrued, possible contingencies
In addition to the probable contingencies described in the preceding paragraphs, we are subject to several labor, civil,
commercial and environmental claims in respect of which, we have not provided any accrual since management, based on the
evidence available to the date of issuance of the accompanying financial statements and in consultation with our external counsel,
have considered them to be possible contingencies.
Based on the information available to the Company, including the amount of time remaining before trial, the results of discovery
and the judgment of internal and external counsel, the Company is unable to estimate the reasonably possible loss or range of loss
resulting for these contingencies.
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The most significant of these contingencies are described below:
Patagonian Association of Land-Owners claims. On August 21, 2003, the Patagonian Association of Land-Owners
(“ASSUPA”) sued the companies operating production concessions and exploration permits in the Neuquina basin, including us,
claiming for the remediation of the general environmental damage purportedly caused in the development of such activities or the
establishment of an environmental restoration fund, and the implementation of measures to prevent environmental damages in the
future. The total amount claimed against all companies is more than U.S.$547.6 million. The plaintiff requested that the Argentine
government (Secretariat of Energy), the Federal Environmental Council, the provinces of Buenos Aires, La Pampa, Neuquén, Río
Negro and Mendoza and the National Ombudsman be summoned. It requested, as a preliminary injunction, that the defendants refrain
from carrying out activities affecting the environment. Both the Ombudsman’s summons as well as the requested preliminary
injunction were rejected by the Argentine Supreme Court. Once the complaint was served, we and the other defendants filed a motion
for a more definitive statement of claims. The court granted the motion, and the plaintiff had to file a supplementary complaint. We
requested that the claim be rejected because the defects of the complaint indicated by the Argentine Supreme Court have not been
corrected, but such request was denied. However, we have also requested its rejection for other reasons, and impleaded the Argentine
government, due to its obligation to indemnify us against any liability and hold us harmless for events and claims arising prior to
January 1, 1991, according to the Privatization Law and Decree 546/1993.
On February 23, 2009, the Argentine Supreme Court ordered that certain provinces, the Argentine government and the Federal
Environmental Council be summoned. Therefore, pending issues were deferred until the impleaded parties appear before the court
and procedural issues are resolved. The provinces of Río Negro, Buenos Aires, Neuquén, Mendoza, and the Argentine government
have presented their arguments to the Supreme Court, although such arguments are not available to us. The provinces of Neuquén and
La Pampa have claimed lack of jurisdiction, which has been opposed by the plaintiff, and the claim is pending resolution. On
December 13, 2011, the Supreme Court suspended the proceeding for 60 days and ordered YPF and the plaintiff to present a schedule
of the conferences that would take place during said suspension, authorizing the participation of the rest of the parties as well as third
parties in such conferences. ASSUPA reported the interruption of the negotiations in the claim and the Supreme Court finalized the
60-day period of suspension ordered.
On December 1, 2014, ASSUPA sued the companies operating production concessions and exploration permits in the Northwest
basin, including us, claiming for the remediation of environmental damage purportedly caused in the execution of such activities, or
the establishment of an environmental restoration fund, and the implementation of measures to prevent environmental damages in the
future. YPF expects to respond within the required time period and to assert available defense appropriate to the case. The required
time period to answer the complaint is currently suspended.
On December 30, 2014 the Supreme Court issued two interlocutory judgments. In the first judgment, it supported the claim of
the Provinces of Neuquén and La Pampa, and declared that all environmental damages related to local and provincial situations were
outside the scope of his original competence, and that only “inter-jurisdictional situations” (such as the Colorado River basin) would
fall under his venue.
In the second judgment, the court rejected the petition filed by ASSUPA to incorporate Repsol and the directors who served in
YPF until April 2012 as a necessary third party. The Court also rejected precautionary measures and other proceedings related to such
request. Additionally, it should be noted that the Company is aware of three other legal claims that have been brought by ASSUPA
against:
i)
ii)
iii)
Concessionaire companies in the San Jorge Gulf basin areas: YPF received a notification which was declared
invalid because of formalities that were not followed. As a result, the terms of the procedure were suspended;
Concessionaire companies in the Austral basin areas: In this case, a highly expedited action has been ordered. A
precautionary measure has also been ordered to inform different entities about the existence of the trial and the
defendants may provide certain information, a decision already appealed by YPF, which has not been ruled on by
the Appellate Court. On November 3, 2015, YPF was served with the complaint. Currently, the reply period is
suspended at YPF’s request.
Concessionaire companies in the Northwest basin areas: On December 1, 2014, YPF was notified of the complaint.
Currently, the reply period is suspended at YPF’s request. In addition, Pan American Energy peremptorily
challenged the intervening judge, and as a result the case was referred to the Federal Court No. 2 of Salta.
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Dock Sud environmental claim. We have been sued in the following environmental lawsuits that have been filed by residents
living near Dock Sud, in the province of Buenos Aires: (i) “Mendoza, Beatriz against National State et al.,” and (ii) “Cicero, María
Cristina against Antivari S.A.C.I. et al. for damages.” In the Mendoza lawsuit before the Argentine Supreme Court, the Argentine
government, the province of Buenos Aires, the City of Buenos Aires, 14 municipalities and 44 companies (including us) were sued.
The plaintiffs have requested unspecified compensation for collective environmental damage to the Matanza and Riachuelo river
basins and for physical and property damage, which they claim to have suffered. The Argentine Supreme Court declared itself legally
competent to settle only the conflict related to the collective environmental damages, including prevention of future pollution,
remediation of environmental damages already caused and monetary compensation for irreparable environmental damages, and has
requested that the defendants submit specific reports. In particular, it has requested that the Argentine government, the province of
Buenos Aires, the City of Buenos Aires and the Federal Environmental Council submit a plan with environmental objectives. We
answered the complaint and requested the impleading of the Argentine government, based on its obligation to indemnify us against
any liability and hold us harmless for events and claims prior to January 1, 1991, according to the Privatization Law and Decree
No. 546/1993. In July 2008, the Argentine Supreme Court decided that the Basin Authority (Law 26,168) (“ACUMAR”) will be in
charge of performing a remediation plan as well as taking preventive measures in the area. The Argentine government, as well as the
province and City of Buenos Aires, will be responsible for the performance of these measures. It also declared the exclusive
competence of the First Instance Federal Court in Quilmes to hear any claims or disputes arising out of the remediation plan or the
preventive measures and determined that any future action seeking the environmental remediation of the basin will be dismissed (litis
pendentia). We have been notified of certain resolutions issued by ACUMAR, pursuant to which we are required to submit a
Restructuring Industrial Plan regarding certain of our facilities. While we have appealed such resolutions, we have submitted to the
relevant authority a Restructuring Industrial Plan. Additionally, the Argentine Supreme Court declared that it will determine whether
and how much liability is to be borne by the parties involved. In the Cicero lawsuit, the plaintiffs, who are residents of Villa
Inflamable, Dock Sud, also demand the environmental remediation of Dock Sud and Ps.33 million in compensation for physical and
property damages against many companies that have operations there, including us. We answered the complaint by requesting its
rejection and asked the citation of the Argentine government, due to its obligation to indemnify us against any liability and hold us
harmless for events and claims prior to January 1, 1991, according to the Privatization Law and Decree No. 546/1993.
Claims related to the gas market and others. In addition to the claims described under “—Accrued, probable contingencies—
Alleged defaults under natural gas supply contracts,” we are involved in the following proceedings also related to the administration
of exports imposed by the Argentine government in the natural gas market:
CNDC claims. On November 17, 2003, the CNDC requested explanations, within the framework of an official investigation
pursuant to Article 29 of the antitrust protection law, from a group of almost 30 natural gas production companies, including us, with
respect to the following items: (i) the inclusion of clauses purportedly restraining trade in natural gas purchase/sale contracts and
(ii) gas imports from Bolivia, in particular (a) expired contracts signed by YPF, when it was state-owned, and YPFB (the Bolivian
state-owned oil company), under which YPF allegedly sold Bolivian gas in Argentina at prices below the purchase price; and (b) the
unsuccessful attempts in 2001 by Duke and Distribuidora de Gas del Centro to import gas into Argentina from Bolivia. On
January 12, 2004, we submitted explanations in accordance with Article 29 of the Antitrust Protection Law, contending that no
antitrust violations had been committed and that there had been no price discrimination between natural gas sales in the Argentine
market and the export market. On January 20, 2006, we received a notification of resolution dated December 2, 2005, whereby the
CNDC (i) rejected the “non bis in idem” petition filed by us, on the grounds that ENARGAS was not empowered to resolve the issue
when ENARGAS Resolution No. 1,289 was enacted; and (ii) ordered that the preliminary opening of the proceedings be undertaken
pursuant to the provisions of Section 30 of Law No. 25,156. On January 15, 2007, the CNDC charged us and eight other producers
with violations of Law No. 25,156. We have contested the complaint on the basis that no violation of the Law took place and that the
charges are barred by the applicable statute of limitations, and have presented evidence in support of our position. On June 22, 2007,
without acknowledging any conduct in violation of the Antitrust Protection Law, we filed with the CNDC a commitment according to
Article 36 of the Antitrust Protection Law requesting that the CNDC approve the commitment, suspend the investigation and dismiss
the proceedings. We are still awaiting a formal response. On December 14, 2007, the CNDC elevated the investigation to the Court of
Appeals.
In addition, on January 11, 2012, the Argentine Secretary of Transport filed with the CNDC a complaint against five oil
companies (including YPF) for alleged abuse of a dominant position regarding bulk sales of diesel to public bus transportation
companies. The alleged conduct consists of selling bulk diesel to public bus transportation companies at prices higher than the price
charged in service stations. According to the provisions of Article 29 of the Antitrust Protection Law, YPF has submitted the
corresponding explanations to the CNDC, questioning certain formal aspects of the complaint, and arguing that YPF has acted at all
times in conformity with current regulations and that it did not engage in any discrimination or abuse in determining prices.
On January 26, 2012, the Argentine Secretariat of Domestic Commerce issued Resolution No. 6/2012 whereby (i) each of these
five oil companies was ordered to sell diesel to public bus transportation companies at a price no higher than the retail price charged
by its service station located, in general terms, nearest to the place of delivery of diesel to each such transportation company, while
maintaining both historic volumes and delivery conditions; and (ii) it created a price monitoring scheme of both the retail and the bulk
markets to be implemented by the CNDC. YPF has challenged this Resolution and requested a preliminary injunction against its
implementation. YPF’s preliminary injunction has been granted and the effects of the Resolution No. 6/2012 have been
temporarily suspended, until the appeal is ruled upon. Against that preliminary injunction, the Argentinian government presented an
extraordinary federal appeal, which has not yet been served to YPF. On December 9, 2014, the Federal Civil and Commercial
Appeals Court has ruled that the case has become moot and that there are no actual consequences for YPF arising from the challenged
Resolution, since prices of the diesel to public bus transportation have suffered several variations since the date such Resolution
entered into effect.
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We are also subject to other claims before the CNDC that are related to alleged price discrimination in the sale of fuels. Our
management, based on the evidence available to date and upon the opinion of our external counsel, has considered them to be
possible contingencies.
Quilmes and other relevant claims. The Company has been notified of a complaint filed by a group of neighbors of Quilmes, in
the province of Buenos Aires, claiming approximately Ps. 421 million in compensation for personal damages.
Petersen Energía Inversora, S.A.U. and Petersen Energía, S.A.U. claims. On April 8, 2015, Petersen Energía Inversora, S.A.U.
and Petersen Energía, S.A.U. (together, “Petersen”) both former shareholders of YPF’s Class D shares, sued the Argentine Republic
and YPF in the United States District Court for the Southern District of New York.
The suit is being brought by Petersen’s receiver pursuant to a liquidation proceeding in a Spanish bankruptcy court. The
complaint sets forth claims relating to the expropriation of Repsol’s majority interest in YPF by the Argentine Republic in 2012,
alleging that it triggered an obligation by the Argentine Republic to make a tender offer to all other YPF shareholders. The claims are
based on allegations that the expropriation violated contractual obligations in the prospectus for YPF’s IPO and in YPF’s bylaws and
seeks unspecified damages.
The Company believes the lawsuit has no merit and has filed a motion to dismiss the complaint. Petersen has filed an opposition
to YPF’s motion. As of the date of this annual report, YPF’s motion remains pending before the court.
Bankruptcy petition by Pan American Sur S.A., Pan American Fueguina S.A. and Pan American Energy LLC Sucursal
Argentina: On September 18, 2015, Metrogas became aware of the existence of bankruptcy petitions by Pan American Sur S.A., Pan
American Fueguina S.A. and Pan American Energy LLC Sucursal Argentina pending before the National Court of First Instance in
Commercial Issues No. 26, Secretariat No. 51, Autonomous City of Buenos Aires. As of the date of this annual report, Metrogas has
not received any notification regarding this petition; however, it will vigorously defend its rights.
Non-accrued, remote contingencies
Our management, in consultation with our external counsel, believes that the following contingencies, while individually
significant, are remote:
Congressional request for investigation to CNDC. On November 7, 2003, certain former members of the Argentine congress,
Arturo Lafalla, Ricardo Falu and others, filed with the CNDC a complaint against us for abuse of a dominant position in the bulk
LPG market during 2002 and part of 2003. The alleged conduct consisted of selling bulk LPG in the domestic market at prices higher
than the export price, thereby restricting the availability of bulk LPG in the domestic market. On December 15, 2003, the CNDC
forwarded the complaint to us, and requested explanations under Article 29 of the Antitrust Protection Law. On January 21, 2004, we
submitted explanations in accordance with Article 29 of the Antitrust Protection Law, contending that no antitrust violations had been
committed. At this point, the CNDC may accept our explanations or begin a criminal investigation. We contend that we did not
restrict LPG supply in the domestic market during the relevant period, that during this period all domestic demand for LPG could
have been supplied by our competitors and that therefore our market share could not be deemed a dominant position. The CNDC
requested information in relation to the prices in the internal and external markets for 2000 to 2008 and that we file the LPG export
contracts signed from 2001 to 2004 as well as explain the evolution of the prices in the internal and external markets of propane and
butane during the March to December period from 2001 to 2004. We provided the requested information. Having provided the
requested information, we have become aware that the CNDC has issued an opinion suggesting that the proceedings be dismissed.
However, the matter is still pending before the Argentine Secretariat of Domestic Commerce.
Pursuant to the provisions of Resolution No. 189/99, referred to above, certain third parties have claimed compensation for
alleged damages suffered by them as a consequence of our sanctioned conduct. We have denied these claims and presented our
defenses.
Other export tax disputes. Between 2006 and 2009, the Customs General Administrations in Neuquén, Comodoro Rivadavia
and Puerto Deseado informed us that certain summary proceedings had been brought against us based on alleged formal
misstatements on forward oil deliveries (future commitments of crude oil deliveries) in the loading permits submitted before these
agencies. In December 2008, the Customs General Administration of Neuquén rejected our arguments and issued a ruling against us.
We will appeal before the National Fiscal Court. Although our management, taking into account the opinion of legal counsel, believes
the claim has no legal basis, the potential fines imposed could be substantial.
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Additional Information
La Plata refinery environmental claims. We are aware of an action in which we have not yet been served, in which the plaintiff
requests the cessation of contamination and the cleanup of the canals adjacent to the La Plata refinery, in Río Santiago, and other
sectors near the coast (removal of mud, drainage of wetlands, restoration of biodiversity, among other things), and, if such cleanup is
not practicable, the plaintiff request a compensation of Ps. 500 million or an amount to be determined from evidence produced in
discovery. We believe that this claim partially overlaps with the requests made by a group of neighbors of the La Plata refinery on
June 29, 1999. Accordingly, we consider that if we are served in this proceeding or any other proceeding related to the same subject
matters, the cases will need to be consolidated to the extent that the claims overlap. With respect to claims that would not be included
in the previous proceedings, for the time being we are unable to estimate the prospects of such claims. Additionally, we believe that
most of the damages that do not overlap with the aforementioned claims may be attributable to events that occurred prior to YPF’s
privatization and could therefore be the responsibility of the Argentine government in accordance with the Privatization Law
concerning YPF. The complaint was never served to the Company and the docket is filed.
YPF Holdings
The following is a brief description of certain environmental and other liabilities related to YPF Holdings, a Delaware
corporation and a wholly-owned subsidiary of YPF, and certain of its subsidiaries, including Maxus and Tierra. See “Item 4.
Information on the Company—Environmental Matters—YPF Holdings—Operations in the United States” for additional information.
In connection with the sale of Maxus’ former chemical subsidiary, Chemicals Company, to Occidental in 1986, Maxus
agreed to indemnify Chemicals Company and Occidental from and against certain liabilities relating to the business or activities of
Chemicals Company prior to the Closing Date, including certain environmental liabilities relating to certain chemical plants and
waste disposal sites used by Chemicals Company prior to the Closing Date. See “Item 4. Information on the Company—
Environmental Matters—YPF Holdings—Operations in the United States.”
As of December 31, 2015, YPF Holdings’ accruals for environmental and other contingencies totaled approximately Ps.
3.821 million. YPF Holdings management believes it has adequately accrued for all environmental and other contingencies that are
probable and can be reasonably estimated based on information available as of such time; however, such contingencies are subject to
significant uncertainties, including the completion of ongoing studies, the discovery of new facts, allocation of responsibility among
potentially responsible parties, and the possibility of administrative or judicial enforcement actions by authorities, which could result
in material additions to such accruals in the future. It is possible that additional claims will be made, and additional information about
new or existing claims (such as results of ongoing investigations, the issuance of court decisions, the signing of participation
agreements, or the signing of settlement agreements) is likely to develop over time. YPF Holdings’ accruals for the environmental
and other contingencies described below are based solely on available information as of the date of issuance of the accompanying
Financial Statements and as a result, YPF Holdings, Maxus and Tierra may have to incur costs that may be material, in addition to the
accruals already taken.
In the following discussion concerning plant sites and third party sites, references to YPF Holdings include, as appropriate
and solely for ease of reference, references to Maxus and Tierra. As indicated above, Tierra is also a subsidiary of YPF Holdings and
has assumed certain of Maxus’s obligations.
1.
Environmental matters at the Lister Avenue site and the Passaic River
1.1. Environmental issues related to the lower eight miles of the Passaic River
Newark, New Jersey. A consent decree, previously agreed upon by the EPA, the New Jersey DEP and Occidental, as
successor to Chemicals Company, was entered in 1990 by the United States District Court of New Jersey for Chemicals Company’s
former Newark, New Jersey agricultural chemicals plant. The approved interim remedy has been completed and paid for by Tierra
pursuant to the above described indemnification agreement between Maxus and Occidental. Operations and maintenance of the
constructed remedy are ongoing.
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Passaic River/Newark Bay, New Jersey. Maxus, acting on behalf of Occidental, negotiated an agreement with the EPA (the
“1994 AOC”) under which Tierra has conducted testing and studies to characterize contaminated sediment and biota in a six-mile
portion of the Passaic River near the Newark, New Jersey plant site described above. While some work remains, the work under the
1994 AOC was substantially subsumed by about 70 companies (including Occidental and TS) of the lower 17-mile portion of the
Passaic River (including the portion already studied) pursuant to a 2007 administrative settlement agreement (the “2007 AOC”). The
parties to the 2007 AOC are discussing the possibility of further remediation work with the EPA. The entities that have agreed to fund
the remedial investigation and feasibility study (“RI/FS”) have negotiated an interim allocation of RI/FS costs among themselves
based on a number of considerations. This group, consisting of approximately 70 companies is referred to as the Cooperating Parties
Group (the “CPG”). The 2007 AOC is being coordinated with a joint federal, state, local and private sector cooperative effort
designated as the Lower Passaic River Restoration Project (“PRRP”). On May 29, 2012, Occidental, Maxus and Tierra withdrew
from the CPG under protest and reserving all their rights. A description of the circumstances of such decision can be found below in
the paragraph titled “Passaic River—Mile 10.9—Removal Action.” However, Occidental remains a respondent to the 2007 AOC and
its withdrawal from the CPG does not change its obligations under the aforementioned AOC. The RI/FS concerning the 2007 AOC is
expected to be completed in 2016 together with the filing with the EPA by the CPG of a preliminary report containing its
recommendation as to preferred remediation. The EPA will have to assess such recommendation and then render an opinion in this
connection. This process may take from 12 to 18 months. After an agreement is reached by the CPG and the EPA on preferred
remediation, the report will be published for public comment, which will be considered for the purpose of issuing an ROD or final
decision on remediation of the RI/FS area (which includes the FFS area described in the ROD).
The EPA’s findings of fact in the 2007 AOC indicate that combined sewer overflow/storm water outfall discharges are an
ongoing source of hazardous substances to the Lower Passaic River Study Area (the 17-mile stretch of the Passaic River from the
Dundee Dam south to Newark Bay). For this reason, during the first half of 2011, Maxus and Tierra negotiated with the EPA, on
behalf of Occidental, a draft Administrative Settlement Agreement and Order on Consent for Combined Sewer Overflow/Storm
Water Outfall Investigation (“CSO AOC”), which was signed and became effective in September 2011. Besides providing for a study
of combined sewer overflows in the Passaic River, the CSO AOC confirms that there will be no further obligations to be performed
under the 1994 AOC. In the second half of 2014, Tierra submitted to the EPA its report (thus completing phase 1) and still expects the
EPA’s comments on the proposed work plan. Tierra previously estimated that the total cost to implement the CSO AOC is
approximately U.S.$5.0 million and will take approximately two more years to be completed once the EPA authorizes phase 2 (the
work plan).
Tierra, acting on behalf of Occidental, is also performing and funding a separate RI/FS to characterize sediment
contamination and evaluate remedial alternatives in Newark Bay and portions of the Hackensack River, the Arthur Kill, and the Kill
van Kull pursuant to a 2004 administrative order on consent with the EPA (the “2004 AOC”). The EPA has issued General Notice
Letters to a series of additional parties concerning the contamination of Newark Bay and the work being performed by Tierra under
the 2004 AOC. In addition, in August 2010, Tierra proposed to the other parties that, for the third stage of the RI/FS undertaken in
Newark Bay, the costs be allocated on a per capita basis. As of December 31, 2013, the parties had not agreed to Tierra’s proposal. In
July 2014, the EPA advised Tierra that it anticipated at the end of 2014 to propose the means by which Tierra would accomplish the
necessary modeling of Newark Bay sediment processes. Although the EPA was considering three alternatives, at December 31, 2015
EPA had not yet laid out a course of action for Tierra. At this time, YPF Holdings lacks sufficient information to determine additional
costs, if any, it might have with respect to this matter once the final scope of the phase III is approved, as well as the proposed
distribution mentioned above.
In December 2005, the DEP issued a directive to Tierra, Maxus and Occidental directing said parties to pay the State of
New Jersey’s costs of developing a Source Control Dredge Plan focused on allegedly dioxin-contaminated sediment in the lower six-
mile portion of the Passaic River described above. The development of this Plan was estimated by the DEP to cost approximately
U.S.$2.3 million. The DEP has advised the recipients that they are not required to respond to the directive until otherwise notified.
In August 2007, the National Oceanic Atmospheric Administration (“NOAA”), as one of the Federal Natural Resources
Trustees (“Trustees”), sent a letter to a number of entities that it alleged have liability for natural resource damages, including Tierra
and Occidental, requesting that the group enter into an agreement to conduct a cooperative assessment of natural resources damages
in the Passaic River and Newark Bay. In January 2008, the NOAA sent a letter to YPF Holdings, CLH Holdings Inc. and other
entities. In November 2008, Occidental and Tierra entered into an agreement with the Trustees to fund a portion of the Trustees’ past
costs and conduct certain assessment activities during 2009. A group of approximately 20 other parties has also entered into a similar
agreement with the Trustees. In November 2009, Tierra declined to extend this agreement.
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•
Lister Avenue Removal Action.
In June 2008, the EPA, Occidental, and Tierra entered into an Administrative Order on Consent (“Removal AOC 2008”), pursuant to
which Tierra (on behalf of Occidental) will undertake the removal of sediment from a portion of the Passaic River in the vicinity of Chemicals
Company’s former Newark, New Jersey facility described above. This action will result in the removal of approximately 200,000 cubic yards of
sediment, which will be carried out in two phases. The field work on the first phase, which encompassed the removal of 40,000 cubic yards,
started in July 2011 and was substantially completed in the fourth quarter of 2012. The EPA inspection was held in January 2013 and Tierra
received written confirmation of completion in March 2013. The second phase, which will encompass the removal of approximately 160,000
cubic yards of sediment, will be completed on a different schedule. Pursuant to the Removal AOC of 2008, the EPA has required the provision of
financial assurance for the execution of the removal work which could decrease or increase over time if the anticipated cost of completing the
removal work contemplated by the AOC changes. The removal work will remove a number of contaminants, such as dioxin, PCBs, and mercury,
which may have come from sources other than or in addition to the former Chemicals Company plant. YPF Holdings may seek cost recovery
from the parties responsible for such contamination; however, at this time it is not possible to make any predictions regarding the likelihood of
success or the funds potentially recoverable in a cost-recovery action. The removal work required pursuant to the Removal AOC will be
conducted concurrently with and in addition to the other investigations and remedial actions described above, including those undertaken in
connection with the FFS concerning the lower eight miles of the Passaic River, the RI/FS addressing the lower 17-mile portion of the Passaic
River, and the RI/FS relating to contamination in Newark Bay, portions of the Hackensack River, the Arthur Kill and the Kill van Kull. The FFS
published on April 11, 2014 states that Phase II of the removal action will be implemented consistently with the FFS. On September 18, 2014, the
EPA requested TS develop a work plan to carry out an additional sampling of the Phase II area. The sampling was completed in the first quarter
of 2015 and TS is expected to present the validated results to the EPA during 2016. The Record of Decision issued by the EPA on March 4, 2016
referred to in section 1.2 below assumes that Phase II would be implemented in advance of or in conjunction with the remedial work in the lower
8.3 miles of the Passaic River.
1.2. Focused Feasibility Study (“FFS”) for remedial action in the lower eight miles of the Passaic River
First draft – 2007. In June 2007, the EPA released a draft Focused Feasibility Study that outlined several alternatives for remedial
action in the lower eight miles of the Passaic River. As a result of comments received, the EPA withdrew the FFS for revision and further
consideration of the comments.
On November 14, 2013, the EPA described four alternatives it was considering in the revised FFS, including: (i) no action, (ii) deep
dredging with backfill of 9.7 million cubic yards over 12 years, which it estimated would cost U.S.$1.4 billion to U.S.$3.5 billion, depending on
whether the dredged sediment is disposed of in a confined aquatic disposal facility (“CAD”) at the bottom of Newark Bay, at an off-site disposal
facility or locally decontaminated and put to beneficial use; (iii) capping with dredging of 4.3 million cubic yards over six years, which it
estimated would cost U.S.$1.0 billion to U.S.$1.8 billion, depending on whether there is a CAD, off-site disposal or local decontamination and
beneficial use; and (iv) one additional alternative that it subsequently discarded.
Second draft – 2014. On April 11, 2014, the EPA published the revised FFS for the lower eight miles of the Passaic River in final
form. In the final FFS, the EPA recommended as its preferred remedial action for this area removal of approximately 4.3 million cubic yards of
sediment through bank-to-bank dredging, which sediments would then be dehydrated locally and transported by train for their incineration or
disposal at an off-site disposal facility. An engineering cap (a physical barrier mainly consisting of sand and stone) would then be placed over the
bank-to-bank dredged area. In its final FFS, the EPA estimated the cost of the preferred remedy (without CAD) for the lower eight miles of
Passaic River to be U.S.$1,731 million (present value estimated with a 7% discount rate).
On August 20, 2014, Maxus and Tierra, on behalf of Occidental, submitted extensive comments on the final FFS to the EPA. The
main comments offered by Maxus, Tierra and Occidental on the final FFS were:
•
•
•
•
•
•
The FFS is not a process legally authorized to select the type and size of remediation proposed by the EPA for the lower
eight miles of the Passaic River;
The FFS is based on a flawed site design;
The FFS overstates the human health and ecological risk issues;
The proposed remediation plan is not executable or economically reasonable in terms of cost-benefit;
The processes of the EPA Region 2 have a lack of public transparency; and
The inclusion in the remediation plan of dredging for navigational purposes is not covered by the regulation.
In addition to the comments received from Maxus and Tierra, the EPA also received comments from approximately 400 other
companies, institutions, government agencies, non-governmental organizations and individuals, including the CPG, Amtrak (the federal railway
company), NJ Transit, the American Army Corps of Engineers, the Passaic Valley Sewerage Commission, yacht clubs, public officials and
others.
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In addition to commenting on the final FFS, Maxus and Tierra have proposed a preliminary project called In-ECO, which
is an ecological and sustainable bio-remediation alternative, as a substitute for the remediation chosen by the EPA in its final FFS.
Maxus and Tierra presented In-ECO to the EPA in May 2014. The EPA provided comments in September 2014, and Maxus and
Tierra presented a revised version in November 2014. The EPA provided additional comments to the In-ECO Statement of Work in
March 2015. Tierra subsequently developed responses to those comments and submitted them to the EPA. A meeting was held in
September 2015 between Tierra, its experts, and the EPA. During this meeting, certain issues were resolved, and laboratory studies
are now anticipated to begin sometime in early 2016.
In October 2015, the U.S. Government Accountability Office (the “GAO”) advised Maxus, Tierra and Occidental that it
had commenced a study on some “Superfund” sites with sediment contamination issues, including the Lower Section of the Passaic
River, at the request of the Committee of Environmental Matters and Public Works of the United States Senate. It is anticipated that
the GAO’s report will be made public in the third quarter of 2016.
On March 4, 2016, subsequent to the issuance of the accompanying Financial Statements, EPA released the Record of
Decision for the “Lower 8.3 Miles of the Lower Passaic River, Part of the Diamond Alkali Superfund Site—Essex and Hudson
Counties, New Jersey” (hereinafter, the “ROD”).
The ROD presented the selected remedy to address contaminated sediments found in the lower 8.3 miles of the Lower
Passaic River, a part of the Diamond Alkali Superfund Site. In this regard, the EPA selected Alternative 3 (capping with dredging for
flooding and navigation of 3.5 million cubic yard over 6 years term). This approach is consistent with the alternative selected in the
Second Draft FFS – 2014 but for the amount of sediment to be removed through bank-to-bank dredging (which was approximately
4.3 million cubic yards in the FFS 2014 draft and is approximately 3.5 million cubic yards in the ROD).
The ROD provides that the estimated total net present value costs to be US$ 1,382 million. This amount is consistent with
the amount provided in the FFS – 2014 Draft, taking in consideration a reduction of 0.8 million cubic yards to be removed between
the two reports. According to the EPA, a major source of dioxin in the river was discharges from the former Diamond Alkali facility
in Newark, where the production of Agent Orange and other pesticides during the 1960s generated dioxin that contaminated the land
and the river.
The EPA further stated that the selected alternative is the first of three remedies to be selected for the Lower
Passaic/Newark Bay waterway, highlighting that separate RI/FSs are being conducted for the full 17-mile Lower Passaic River Study
Area and for the Newark Bay Study Area. Accordingly, the EPA expects the three remedies to be integrated into a comprehensive
response action.
In accordance with the issuance of the ROD, the EPA stated that now that the cleanup plan has been selected, the EPA will
immediately begin discussions with those responsible for the contamination to seek their performance of or payment for the cleanup
work. The EPA stated that once the legal process concludes, the design of the activities necessary to carry out the cleanup will be
outlined in a legally binding document. The EPA expects that the design will take three to four years to complete. In accordance with
the EPA, the dredging, dewatering and disposal of dredged materials and related construction work will follow and is expected to take
six years to complete.
At this time, there is significant uncertainty regarding the outcome of any allocation negotiation or mediation process to
estimate the percentage share to Occidental for which Maxus might be liable under the indemnity.
Based on (a) the uncertainties identified by the Company as of the date of this annual report, including but not limited to
(i) the extraordinary volume of sediment materials for which, to date, the sediment treatment technologies have neither been
constructed nor operated in the United States on a scale commensurate with the capacity that would be necessary for the remedial
work this remediation that this project would be requiring, (ii) the results of the studies and discoveries yet to be produced, (iii) the
number and diversity of contaminants of concern identified by the ROD (furans, PCB’s, mercury, copper, dieldrin, PAHs, lead,
dioxins and DDT), many of which have not been previously associated with the Lister Site and/or have been generated by other
potentially responsible parties, (iv) the number and diversity of potential responsible parties involved in the matter (EPA identified
more than one hundred potential responsible parties), and (v) the final allocation of the removal and remediation costs;
(b) consultation with our internal and external counsel; (c) the amounts previously incurred and recorded by YPF Holdings in
remediation activities in the area covered by the ROD; and (d) the limitation on responsibility that YPF may have as an indirect
controlling shareholder of Maxus, no additional liability has been accrued for this environmental matter as of the date of this annual
report.
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Environmental issues related to the lower 17-mile portion of the Passaic River
Passaic River Mile 10.9 Removal Action. In February 2012, the EPA issued to the CPG, of which Tierra then was a member, a
draft Administrative Settlement Agreement and order on Consent (“AOC RM 10.9”) for Removal Action and Pilot Studies to address high
levels of contamination of TCDD, PCBs, mercury and other contaminants of concern in the vicinity of the Passaic River’s mile 10.9,
comprised of a sediment formation (“mud flat”) of approximately 8.9 acres. This proposed AOC RM 10.9 ordered that 16,000-30,000 cubic
yards of sediments be removed and that pilot scale studies be conducted to evaluate ex situ decontamination beneficial reuse technologies,
innovative capping technologies, and in situ stabilization technologies for consideration and potential selection as components of the
remedial action to be evaluated in the 2007 AOC and the FFS and selected in one or more subsequent records of decision. Occidental
declined to execute this AOC and Occidental, Maxus and Tierra formalized their resignations from the CPG, effective May 29, 2012, under
protest and subject to a reservation of rights. On June 18, 2012, the EPA announced that it had signed an AOC for RM 10.9 with 70 Settling
Parties, all members of the CPG, which contained, among other requirements, an obligation to provide to the EPA financial assurance, in the
amount of U.S.$20 million, that the work would be completed. On June 25, 2012, the EPA issued Occidental a Unilateral Administrative
Order (UAO) for Removal Response Activities. Occidental sent to the CPG and EPA its notice of intent to comply with such order on
July 23, 2012 followed by its good faith offer on July 27, 2012 to provide the use of Tierra’s existing dewatering facility. On August 10,
2012, the CPG rejected Occidental’s good faith offer and, on September 7, 2012, the CPG stated that it has alternative plans for handling
sediment to be excavated at RM 10.9 and, therefore, has no use for the existing dewatering facility. The EPA, by letter of September 26,
2012, advised that it will be necessary for the EPA and Occidental to discuss other options for Occidental to participate and cooperate in the
RM 10.9 removal action, as required by its Unilateral Administrative Order. On September 18, 2012, the EPA advised the Passaic River
CAG that the bench scale studies of the treatment technologies did not sufficiently lower concentrations of the chemicals to justify the cost,
so the RM 10.9 sediments will be removed offsite for disposal. In March 2014, responding to the EPA’s request for action, Tierra, on behalf
of Occidental, submitted a Statement of Work (“SOW”) for the conduct of surveys to more precisely locate two water mains that cross under
the Passaic River at RM 10.9. The EPA granted conditional acceptance of the SOW, and Tierra in early April 2014 responded to EPA’s
comments on the SOW. EPA extended the deadline for delivering financial assurance to March 14, 2014 and later further extended the
deadline indefinitely. The field work for this investigation was conducted in August. This work was inconclusive and an additional field
investigation began in December 2014 and was completed in February 2015. Tierra submitted to the EPA its report on the pipeline probing
survey in March 2015.
FFS for remedial action in the lower 17-mile of the Passaic River. Notwithstanding the discussion above, for the lower 17-mile
portion of the Passaic River, from its confluence with the Newark Bay to the Dundee Dam, under the 2007 AOC, the RI/FS is expected to be
completed in 2016, after which the EPA would select a remedial action and open the decision for public comments.
The CPG submitted the Draft Remedial Investigation and Feasibility Study for the Lower 17 miles of the Passaic River during
the first semester of 2015. As of the date of this annual report, the EPA has not submitted any comments.
New Jersey Litigation with DEP. With respect to the alleged contamination, that dioxin, DDT and other “hazardous substances”
discharged from Chemicals Company’s former Newark plant and contaminated the lower 17-mile portion of the Passaic River, Newark Bay,
and other nearby waterways and surrounding areas, in December 2005 the DEP, Commissioner of the New Jersey Department of
Environmental Protection and the New Jersey Spill Compensation Fund sued YPF, YPF Holdings, Tierra, Maxus and other affiliates, as well
as Occidental and Repsol (the “New Jersey Litigation with DEP”). These plaintiffs sought damages for the past cost of investigation and
cleanup of these waterways, property damage and other economic impacts (such as decreases in tax revenues and value of real estate and
increases in public medical costs, etc.), and punitive damages. The defendants made responsive pleadings and/or filings. Occidental sought
leave to file cross-claims in June 2007, and was granted leave to file in October 2008. In March 2008, the court denied motions to dismiss
for failure to state a claim by Occidental Chemical Corporation, and by Tierra and Maxus. DEP filed its Second Amended Complaint in
April 2008; YPF’s motion to dismiss for lack of personal jurisdiction was denied in September 2008. The decision was affirmed by the
Court of Appeals following an appeal by YPF. The court denied the plaintiffs’ motion to bar third party practice and allowed defendants to
file third-party claims. Third-party claims against approximately 300 companies and governmental entities (including certain municipalities
and sewage treatment authorities), which could have responsibility in connection with the claim were filed by Tierra and Maxus in February
2009. Anticipating this considerable expansion of the number of parties in the litigation, the court appointed a Special Master to assist the
court in the administration of discovery. DEP filed its Third Amended Complaint in August 2010, adding Maxus International Energy
Company and YPF International S.A. as additional named defendants. Plaintiffs and Occidental allege that defendants Repsol, YPF, YPF
International S.A., YPF Holdings, CLH Holdings, Maxus, Maxus International Energy Company and Tierra are alter egos of one another
and engaged in a scheme to defraud the plaintiffs through corporate restructurings designed to cap and strand the environmental liabilities
associated with the contamination of the area. To this end, plaintiffs and Occidental asserted claims for the breach of contract, statutory
contribution, fraudulent transfer of Maxus’ assets, civil conspiracy, breach of fiduciary duty, aiding and abetting and alter ego liability. In
September 2010, governmental entities of the State of New Jersey and a number of third-party defendants filed motions to dismiss and
Maxus and Tierra filed their responses. Except in a few cases, these motions were rejected in January 2011. In October 2010, a number of
public third-party defendants filed a motion to sever and stay, which would allow the State of New Jersey to proceed against the direct
defendants. However, the judge ruled against this motion in November 2010. Third- party defendants have also brought motions to dismiss,
which have been rejected by the Special Master in January 2011. Some of the mentioned third-parties appealed the decision, but the judge
denied such appeal in March 2011.
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In May 2011, the judge issued Case Management Order XVII (“CMO XVII”), which contains the Trial Plan for the case.
This Trial Plan divides the case into two phases and nine tracks. Phase One will determine liability and Phase Two will determine
damages. Regarding the sub-stages: (a) sub-stages I to III (Tracks I to III) correspond to damage claimed by the Occidental and the
State of New Jersey; (B) sub-stages IV to VII (Tracks IV to VII) correspond to liability by alter ego and fraudulent conveyance with
respect to YPF, Maxus and Repsol and to the liability of third parties to Maxus; (C) sub-stage VIII (Track VIII) corresponds to
damages claimed by the State of New Jersey; (D) sub-stage IX (Track IX) is the percentage of liability that would correspond to
Maxus for the cleanup and remediation costs.
Specifically, sub-stage III (Track III) will determine the extent of Maxus’ liability for the operation of the Lister Site; sub-
stage IV (Track IV) will determine the possible scope of YPF and Repsol’s liability for damages to the Lister Site (alter ego and
conveyance).
Following the issuance of CMO XVII, the State of New Jersey and Occidental filed motions for partial summary
judgment. The State of New Jersey filed two motions: one against Occidental and Maxus on liability under the Spill Act and the other
against Tierra on liability under the Spill Act. In addition, Occidental filed a motion for partial summary judgment that Maxus owes a
duty of contractual indemnity to Occidental for liabilities under the Spill Act. In July and August 2011, the judge ruled that, although
the discharge of hazardous substances by Chemicals Company has been proved, liability cannot be imposed if the nexus between any
discharge and the alleged damage is not established. Additionally, the court ruled that Tierra has Spill Act liability to the State of New
Jersey based merely on its current ownership of the Lister Avenue site (an area located nearby the Passaic River); and that Maxus has
an obligation under the 1986 Stock Purchase Agreement to indemnify Occidental for any Spill Act liability arising from contaminants
discharged on the Lister Avenue site, and that Maxus and Tierra share each other’s liabilities as alter egos.
During the fourth quarter of 2011, the parties agreed on a consensus trial plan for Track III under CMO XVII, which
narrowed the scope of issues for discovery and trial in May 2012 to factual issues relevant to determining Maxus’s alleged direct
liability to the State of New Jersey and to issues relating to responsibility for discharges during the era when the Newark plant site
was under the ownership of Kolker Chemical Works. The Court accepted six applications for Fast Track Arbitration-discovery
proceeded in January 2012, to be followed by depositions and arbitration briefing. In addition, Maxus submitted to the Special Master
and the “Additional Dischargers” Committee a plan to sample the area around mile 10.9 of the Passaic River for the HCX chemical
marker that Maxus suspects may be associated with dioxin discharged by one or more third-party defendants. The HCX sampling was
completed in January 2012 and validated results were received in March.
In February 2012, plaintiffs and Occidental filed motions for partial summary judgment, seeking summary adjudication
that Maxus has liability under the Spill Act. The judge held that Maxus and Tierra have direct liability for the contamination
generated into the Passaic River. However, volume, toxicity and cost of the contamination were not verified (these issues will be
determined in a later phase of the trial). Maxus and Tierra have the right to appeal such decision.
On September 21, 2012, the presiding judge granted the State’s application for an Order to Show Cause to Stay all
proceedings against third party defendants who entered into a Memorandum of Understanding (“MOU”) with the State to discuss
settlement of the claims against the third party defendants.
On September 27, 2012, Occidental filed its Second Amended Cross-Claims and the following day, the State of New
Jersey filed its Fourth Amended Complaint. The principal changes to the State of New Jersey’s pleading concern the State of New
Jersey’s allegations against YPF and Repsol, all of which Occidental has adopted in its cross-claims. In particular, there are three new
allegations against Repsol involving asset stripping from Maxus and also from YPF based on the Argentine government’s Mosconi
Report.
During the fourth quarter of 2012 and the first quarter of 2013, YPF and certain affiliates (among them, YPF Holdings,
Maxus and Tierra) and Repsol, engaged in on-going mediation and negotiation, seeking the possibility of a settlement with the State
of New Jersey.
On February 14, 2013, the State of New Jersey and all defendants except Occidental appeared before the court to seek a
stay of the litigation because they had agreed to recommend terms for a settlement framework to resolve the claims between them.
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YPF and certain affiliates (among them, YPF Holdings, Maxus and Tierra) subsequently approved a Settlement Agreement
with Repsol and the State of New Jersey. The Settlement Agreement provides, without acknowledging any fact or right: (i) a payment
of U.S.$65 million by Maxus and/or YPF to the State of New Jersey and (ii) a hard cap of up to U.S.$400 million with respect to
certain of Occidental’s unresolved cross-claims against Repsol, YPF and YPFI; and would resolve certain environmental claims of
the plaintiffs against all Settling Defendants within a certain range of the Passaic River, and the deferral of Tracks II and IV until after
trial of the State of New Jersey’s damages against Occidental in Track VIII. The Settlement Agreement does not resolve Occidental’s
cross-claims.
On December 12, 2013, the court approved the Settlement Agreement. On January 24, 2014 Occidental filed a notice of
appeal from the court’s approval of the Settlement Agreement. On February 10, 2014 Maxus made the U.S.$65 million payment
provided in the Settlement Agreement to an escrow account. Occidental’s appeal was subsequently dismissed on March 26, 2014, and
the settlement amount was paid out of escrow to the State of New Jersey.
On August 20, 2014, the State of New Jersey and Occidental informed the Superior Court that they had agreed on the
general terms and conditions of a settlement of the Plaintiff’s claims against Occidental (the “Consent Judgment”). On December 16,
2014 the court approved the Consent Judgment by which the State of New Jersey accepted to resolve all claims against Occidental
related to environmental claims within a certain area of the Passaic River. In exchange, Occidental will pay U.S.$190 million in three
installments, the last one due on June 15, 2015; and the contingency payment of up to U.S.$400 million in case the State of New
Jersey is required to pay its share for future remediation actions.
On November 21, 2014, YPF and certain affiliates filed motions to dismiss Occidental’s cross-claims. On January 13,
2015, the Special Master issued a recommendation largely granting the motions. On January 29, 2015, Judge Lombardi affirmed the
recommendation and dismissed Occidental’s claims for the fraudulent transfer of Maxus’ assets, civil conspiracy, breach of fiduciary
duty, aiding and abetting and the stand-alone declaratory judgment claim for alter ego liability.
On January 5, 2015, Maxus received a letter from Occidental requesting that Maxus agree to indemnify Occidental for all
of the settlement payments that Occidental agreed to make to the State of New Jersey. The Court previously issued an interlocutory
order in 2011, which is subject to appeal after all trial proceedings are concluded, stating that Maxus had the contractual duty to
indemnify Occidental for the liabilities under the New Jersey Spill Act arising from contaminants discharged into the Passaic River
from the Lister Avenue Plant Site, which was owned by a company Occidental acquired and merged with in 1986. Maxus contends
that whether and to what extent its obligation to indemnify Occidental applies to the settlement payments Occidental has agreed to
make to the State of New Jersey pursuant to the Consent Judgment must await the outcome of further proceedings in the Passaic
River litigation.
Also, Repsol S.A. countersued Occidental, alleging that the U.S.$65 million paid by Repsol as per the agreement between
Repsol, YPF, YPF Holdings, Maxus and Tierra Solutions with the State of New Jersey was paid for damages caused by (a) Diamond
Shamrock Chemicals Company, for which Occidental is liable under the share purchase agreement of 1986 or (b) Occidental’s
individual conduct.
On March 26, 2015 a new judge was appointed to the case.
On April 15, 2015, Occidental sent Maxus a letter claiming indemnity protection under the share purchase agreement with
respect to the counterclaim filed by Repsol against Occidental. On 28 April 2015, Maxus replied contesting the claims.
On July 1, 2015, the judge issued Case Management Order XXVII, under which the judge extended the deadline to
complete all discovery to January 29, 2016, established a briefing schedule pursuant to which summary judgment will not be decide
until late April or early May 2016, at the earliest, and included a provision that trial shall be scheduled in June 2016. On December 4,
2015, the judge issued the “Second Consent Order to Amend Expert Discovery Schedule” by which the following dates were
extended: (a) January 21, 2016, rebuttal expert reports are due, (b) February 29, 2016, all expert depositions and all discovery must be
completed; (c) March 4, 2016 summary judgment briefs are due and (d) June 2016, trial is scheduled to begin. Since December 2014,
almost 60 witnesses have been deposed, including the corporate representatives of all the parties, and the expert witness for YPF and
Occidental, which was completed in the first quarter of 2016.
Notwithstanding the above, the Special Master authorized the parties to file briefs specifying any issue in respect of which
each party believed that the court should authorize early summary judgement motions.
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The motions filed by the parties and the non-binding opinions, as issued by the Special Master on January 14, 2016, are
summarized below.
YPF filed for early summary judgment against Occidental on four issues: 1) dismissal of the portion of Occidental’s claims
for alter ego liability, based on the transfer of Maxus’ assets from 1995 through 1999; 2) dismissal of the portion of Occidental’s claims
for alter ego liability, based on the financing of YPF’s acquisition of Maxus shares in 1995; 3) dismissal of the portion of Occidental’s
liability claims based on the alleged “control” by YPF of Maxus’s Board of Directors’ decision, in 1996, to sell its subsidiaries in
Bolivia and Venezuela to YPF International; and 4) dismissal of the portion of Occidental’s claims for alter ego liability, based on the
transfer of Maxus’ environmental liabilities to Tierra in 1996. The Special Master’s recommendation on YPF’s motion recommended to
deny the motion on the grounds that 1) a finder of fact should be permitted to consider all portions of YPF actions when determining if
there is alter ego liability so dismissal of portions of these claims is inappropriate and 2) the statute of repose for fraudulent transfers is
not applicable to the remedy of alter ego for breach of contract. In reaching this conclusion, the Special Master stated she was obliged to
view all the factual assertions “in the light most favorable to” Occidental, which on summary judgment presents a much higher burden
for YPF than the burden of proof YPF will have at trial.
Occidental filed for early summary judgment against Maxus in relation to Occidental’s claim to recover the amount of US$
190 million paid to the State of New Jersey under the settlement agreement. The motion sought to establish that Maxus is liable for all
conduct at the Lister Site, regardless of any actions taken by Occidental. Occidental did not seek summary judgment on the amount of
damages Maxus would owe, which Occidental asserts is US$ 190 million, plus legal fees. The Special Master’s recommendation on
Occidental’s motion against Maxus recommended to grant the motion on the grounds that (1) the language of the SPA was not
ambiguous and required Maxus to indemnify Occidental for its own conduct at the Lister Site and (2) Occidental was not estopped from
seeking indemnity from Maxus for its own conduct at the Lister Site because it did not take inconsistent legal positions in prior
litigations. Notwithstanding the foregoing, Occidental will have to prove the reasonableness of the U.S.190 million amount settled with
the State of New Jersey, for which Maxus may eventually be liable.
In addition, Occidental filed for early summary judgment dismissing the cross-claims of Repsol against Occidental, which
seek to recover from Occidental the U.S.$ 65 million payment made by Repsol to New Jersey State under the settlement agreement
among the State, YPF, Maxus and Repsol. The Special Master’s recommendation on Occidental’s motion against Repsol recommended
to deny the motion in part as to Repsol’s contribution claim and to grant the motion in part as to Repsol’s unjust enrichment claim, on
the grounds that 1) Repsol’s contribution claims are permissible under the New Jersey Spill Act even if a settlement did not fully
discharge liability to the State; 2) demonstrating Repsol’s liability under the Spill Act is not a prerequisite for Repsol to receive
contribution from Occidental; 3) Repsol is not liable to Occidental for indemnification as an alter ego of Maxus, and 4) Occidental was
not unjustly enriched when Repsol settled with the state.
Repsol filed for early summary judgment against Occidental to dismiss Occidental’s cross-claims 1) to extent that
Occidental’s claims are based on prescribed claims for fraudulent transfers; 2) on the grounds that Occidental cannot prove that it has
suffered damages due to a failure to perform an agreement; 3) on the grounds that Occidental cannot prove that Repsol has caused any
damage even if a non-performance occurred, because Occidental has alleged that Maxus became insolvent before Repsol acquired YPF
in 1999; and 4) on the grounds that Occidental has failed to pierce the corporate veil between YPF and Repsol, and because seeking alter
ego relief from Repsol is unwarranted because YPF is solvent. The Special Master’s recommendation on Repsol’s motion against
Occidental recommended to grant the motion on the grounds that Occidental failed to set out any basis to pierce the corporate veil
between YPF and Repsol, which the Special Master held Occidental was required to do, and because Occidental did not allege that YPF
was insolvent.
Finally, Maxus filed for early summary judgment against Occidental to dismiss the claims for damages filed by Occidental
regarding costs not yet incurred by Occidental. YPF joined in this motion. The Special Master’s recommendation on Maxus’s motion
against Occidental recommended to grant the motion on the grounds that Occidental’s request for declaratory judgment would not be
beneficial or useful due to the uncertainty regarding future costs.
In addition, the Special Master’s recommendation on Occidental’s motion to amend its second amended cross-claims adding
claims against YPF and Repsol regarding an alleged interference with Occidental’s contractual right under the SPA, recommended to
deny the motion on the grounds that Occidental improperly delayed in seeking to supplement its claims despite having multiple earlier
opportunities to do so.
The parties appealed the Special Master’s recommendations on February 16, 2016. Oral argument on the appeals of the
Special Master’s recommendations will be held on April 4, 2016.
On March 1, 2016, the judge entered an order partially granting a stay of discovery, which deferred the depositions of certain
Occidental, Repsol and Maxus expert witnesses pending a decision by the judge on the parties’ appeal of the Special Master’s
recommendations.
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On February 27, 2016, YPF sought leave from the Special Master to file a motion for summary judgment partially dismissing
Occidental’s remaining claims. Repsol additionally sought leave to file a motion for summary judgment seeking to recover from
Occidental the U.S.$65 million paid by Repsol pursuant to the Settlement Agreement. Occidental additionally sought leave to file a
motion for summary judgment seeking to hold Maxus liable for the U.S.$65 million recovery sought by Repsol from Occidental. On
March 7, 2016, the Special Master denied each of the parties’ request for leave to file summary judgment on the grounds that each
motion contains factual issues.
As of December 31, 2015, for all matters relating to environmental issues related to the lower 17-mile portion of the Passaic
River, YPF Holdings has accrued a total of Ps. 2,665 million, management’s reasonable estimate of the expenditures that YPF Holdings
Inc. may incur for remediation activities based on information available at the time of the issuance of the accompanying Financial
Statements, given the impossibility of reasonably estimating a loss or range of loss in relation to the possible costs of the previously
discussed FFS. The provision considers studies by Tierra, estimated costs for the Removal AOC of 2008 and other matters related to the
Passaic River and Newark Bay. This includes associated legal issues discussed above. However, it is possible that other work, including
remedial measures in addition to or different from those considered may be required. Additionally, the development of new information,
the imposition of penalties or remedial action or outcome of negotiations related to those cases that differ from the situations assessed by
YPF Holdings could result in the need to incur higher expenses by the company than those currently provisioned.
Considering the information available to YPF Holdings as of the date of the issuance of the accompanying Financial
Statements; the results of the studies and testing phase; as well as the potential liability of the other parties involved in this issue and the
possible allocation of the costs of removal; and in consultation with our internal and external legal counsel, the accrual represents
management’s reasonable estimate of the probable cost.
2. Other environmental issues unrelated to the Passaic River
Hudson and Essex Counties, New Jersey. Until the 1970s, Chemicals Company operated a chromite ore processing plant at
Kearny, New Jersey (the “Kearny Plant”). DEP has identified over 200 sites in Hudson and Essex Counties alleged to contain chromite
ore processing residue either from the Kearny Plant or from plants operated by two other chromium manufacturers. Tierra, Occidental
and DEP signed an administrative consent order in April 1990 (“ACO”) which requires remediation at 40 sites in Hudson and Essex
Counties alleged to be impacted by the Kearny Plant operations. Tierra, on behalf of Occidental, is providing financial assurance in the
amount of U.S.$20 million for performance of the work required by the ACO (which is ongoing at all ACO Sites at various stages) and
associated with the issues described below.
In May 2005, the DEP took two actions in connection with the chrome sites in Hudson and Essex Counties. First, the DEP
issued a directive to Maxus, Occidental and two other chromium manufacturers (the “Respondents”) directing them to arrange for the
cleanup of chromite ore residue at three sites in Jersey City and for the conduct of a study by paying the DEP a total of U.S.$19.5
million. Second, the DEP filed a lawsuit against Occidental and two other entities in state court in Hudson County seeking, among other
things, cleanup of various sites where chromite ore processing residue is allegedly located, recovery of past costs incurred by the state at
such sites (including in excess of U.S.$2.3 million dollars allegedly spent for investigations and studies) and, with respect to certain
costs at 18 sites, treble damages. In February 2008, the parties reached an agreement in principle, pursuant to which Tierra agreed to
pay, on behalf of Occidental, U.S.$5 million and agreed to perform remediation works at three sites, with a total cost of approximately
U.S.$2.1 million, subject to the terms of a Consent Judgment between and among DEP, Occidental and two other parties, which was
published in the New Jersey register in June 2011 and became final and effective as of September 2011. Pursuant to the Consent
Judgment, the U.S.$5 million dollar payment was made in October 2011 and a master schedule was delivered to DEP for the
remediation, during a ten-year period, of the three orphan sites plus the remaining chromite ore sites (approximately 28 sites) under the
Kearny ACO. DEP indicated that it could not approve a ten-year term; therefore, in March 2012, Maxus submitted a revised eight-year
schedule, which was approved by DEP on March 24, 2013. Tierra is currently performing work pursuant to the Master Schedule. In
November 2005, several environmental groups sent a notice of intent to sue the owner of the property adjacent to the former Kearny
Plant and five other parties, including Tierra, under the Resource Conservation and Recovery Act. The parties have entered into an
agreement that addresses the concerns of the environmental groups and these groups have agreed not to file suit. After the original
agreement expired, the parties entered into a new Standstill Agreement, effective March 7, 2013.
In March 2008, the DEP approved an Interim Response Action (“IRA”) work plan for work to be performed at the Kearny
Plant site by Tierra and at the adjacent property by Tierra in conjunction with other parties. Work on the IRA has begun. In addition, this
adjacent property was listed by the EPA on the National Priority List in 2007. In July 2010, the EPA notified Tierra, along with three
other parties, which are considered potentially responsible for this adjacent property and requested to conduct a RIFS for the site. The
three parties have agreed to coordinate remedial efforts, forming the “Peninsula Restoration Group” or “PRG.” In the fourth quarter of
2011, the PRG reached an agreement with another potentially responsible party (Cooper Industries), whereby Cooper Industries would
join the PRG. In May 2013, the PRG and the EPA entered into an RI/FS AOC for the Standard Chlorine Chemical Company site.
180
Under the terms of the AOC, the Group is able to rely on the substantial work that has already or is now taking place at the site (including the
IRA), to streamline the RI/FS (now denominated an RI/FFS) and press for selection of a final remedy that includes the features of the IRA as the
major component. The Remedial Investigation Work Plan for the site was submitted to the EPA on April 8, 2013 in advance of the execution of
the AOC as part of the PRP Group’s show of good faith. The Remedial Investigation Work Plan was approved in September 2013 and work
under the RI/FFS AOC began in the fourth quarter 2013 and has proceeded since that time. The PRP Group also responded to an EPA request to
draft an Community Involvement Plan (CIP) which the EPA has adopted. The following AOC deliverables have been submitted, approved and/or
are pending during 2014:
•
•
•
•
Candidate Technologies Memo (CTM) and Draft Pathway Analysis Report (PAR).
Screening Level Ecological Risk Assessment (SLERA).
Work Plan for Supplemental Investigation in localized area outside barrier wall.
Baseline Ecological Risk Assessment (BERA).
The remedial investigation was completed during the fourth quarter of 2014, and the EPA approved the Remedial Investigation
Report in October 2015. The draft FFS was submitted to the EPA during the third quarter of 2015. The PRP Group received the EPA’s initial
comments on the FFS on October 1, 2015, and the revised FFS is due to the EPA on March 11, 2016.
Pursuant to a request of the DEP, in the second half of 2006, the PRG tested the sediments in a portion of the Hackensack River near
the former Kearny Plant. A report of those test results was submitted to the DEP. DEP requested additional sampling, and the PRG submitted to
DEP work plans for additional sampling in January 2009. In March 2012, the PRG received a Notice of Deficiency (“NOD”) letter from DEP
relating to the Hackensack River Study Area (“HRSA”) Supplemental Remedial Investigation Work Plan (“SRIWP”) that the PRG had submitted
to the DEP in January 2009. In the NOD, DEP seeks to expand the scope of work that would be required in the Hackensack River under the
SRIWP to add both additional sample locations/core segments and parameters. While the PRG acknowledges that it is required to investigate and
prevent chrome releases from certain upland sites into the river, the PRG contends that it is has no obligation under the governing ACOs and
Consent Judgment to investigate chrome contamination in the river generally. Negotiations between the PRG and the DEP are ongoing.
As of December 31, 2015, YPF Holdings has accrued a total of approximately Ps. 608 million in connection with the foregoing
chrome-related matters. Soil action levels for chromium in New Jersey have not been finalized, and the DEP continues to review the proposed
action levels. The cost of addressing these chrome-related matters could increase significantly depending upon the final soil action levels, the
DEP’s response to Tierra’s studies and reports and other developments.
Painesville, Ohio. From about 1912 through 1976, Chemicals Company operated manufacturing facilities in Painesville, Ohio (the
“Painesville Works Site”). The operations there over the years involved several discrete but contiguous plant sites over an area of about 1,300
acres. The investigation and remediation of the Painesville Works Site is governed by agreements and orders in place with the EPA and the Ohio
Environmental Protection Agency (“OEPA”). The primary area of concern historically has been Chemicals Company’s former chromite ore
processing plant (the “Chrome Plant”). The OEPA has approved certain work, including the remediation of 20 specific operable units within the
former Painesville Works Site and work associated with development plans (the “Remediation Work”). The Remediation Work has begun. As
each operable unit within the Site receives OEPA approval for projects related to investigation, Remediation Work, or operation and maintenance
activities, additional orders and agreements will be implemented, and additional amounts may need to be accrued. YPF Holdings has accrued a
total of approximately Ps. 134 million as of December 31, 2015 for its estimated share of the cost to perform the remedial investigation and
feasibility study, the Remediation Work and other operation and maintenance activities at this site.
The scope and nature of any further investigation or remediation that may be required cannot be determined at this time; however, as
the RI/FS progresses, YPF Holdings will continuously assess the condition of the Painesville Works Site and make any required changes,
including additions, to its provision as may be necessary.
Third Party Sites. Pursuant to settlement agreements with the Port of Houston Authority (the “Port”) and other parties, Tierra and
Maxus are participating (on behalf of Occidental) in the remediation of property adjoining Chemicals Company’s former Greens Bayou facility
where dichloro-diphenyl-trichloroethane (“DDT”) and certain other chemicals were manufactured. Additionally, in 2007 the parties entered into
a Memorandum of Agreement (“MOA”) with federal and state natural resources trustees in connection with claims for natural resources
damages. In 2008, the Final Damage Assessment and Restoration Plan/Environmental Assessment was approved specifying the restoration
projects to be implemented. During the first half of 2011, Tierra negotiated, on behalf of Occidental, a draft Consent Decree with governmental
agencies of the United States and Texas addressing natural resource damages at the Greens Bayou Site. The Consent Decree was signed by the
parties in January 2013 and notice of approval of the Consent Decree was published in the Official Gazette on January 29, 2013. After the
publication of the notice a period of 30 days was opened for comments. Under the Consent Decree, Occidental agreed to reimburse certain costs
incurred by the aforementioned governmental agencies and conducting two restoration projects for a total amount of U.S.$0.8 million. Although
the primary work was largely finished in 2009, some follow-up activities and operation and maintenance remain pending. As of December 31,
2015, YPF Holdings has accrued approximately Ps. 50 million for its estimated share of the remediation and the MOA associated with the Greens
Bayou facility. The remediation activities were largely finished in 2009, but some minor closure activities, as well as ongoing operations and
maintenance, are still in progress.
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•
Milwaukee Solvay Site
In June 2005, the EPA designated Maxus as a PRP at the Milwaukee Solvay Coke & Gas Site in Milwaukee, Wisconsin. The
basis for this designation is Maxus’ alleged status as the successor to Pickands Mather & Co. and Milwaukee Solvay Coke Co.
companies that the EPA has asserted are former owners or operators of such site.
In November 2006, Maxus and four other PRPs entered into a Joint Participation and Defense Agreement, which establishes the
allocation of costs for making a RI/FS. Under the agreement Maxus is responsible for a significant part of the costs. In January 2007
those PRPs and the EPA entered into an AOC to perform a RI/FS regarding the investigation of “upland” soil and groundwater, as
well as sediment in the Kinnickinnic River. Maxus’ exposure at the Site appears tied to the 1966-1973 period, although there is some
dispute about it. The PRP Agreement includes an interim allocation, under which Maxus has a substantial share.
On April 25, 2012 EPA made a proposal concerning the scope of future investigations of sediments, which was rejected by the
PRP group.
On June 6, 2012 the PPR Group submitted a proposed Field Sampling Plan (“FSP”) that included detailed plans for the
remaining upland investigation and a phased approach to the sediment investigation. In July 2012, the EPA responded to the FSP
requiring expanded sediment sampling as part of the next phase of the investigation and additional evaluation for the possible
presence of distinct coal and coke layers on parts of the upland portion of the Site. In December 2012, the EPA approved the PRP
Group’s revised FSP, and the PRP Group commenced upland and sediment investigation activities. The estimated cost of
implementing the field work associated with the FSP is approximately U.S.$0.8 million.
In February 2014, the PRP Group submitted to the EPA and Wisconsin Department of Natural Resources (“DNR”) a Baseline
Human Health Risk Assessment (“BHHRA”) Scoping Document, an Upland Screening Level Ecological Risk Assessment
(“SLERA”) Scoping Document and an Aquatic Baseline Ecological Risk Assessment (“BERA”). Currently, additional upland and
sediment investigation activities continued pursuant to the approved FSP.
In June 2014, the PRP Group submitted to the EPA and WDNR the draft Remedial Investigation (“RI”) Report and risk
assessment documents (i.e., Baseline Human Health Risk Assessment, Screening Level Ecological Risk Assessment, and Aquatic
Baseline Ecological Risk Assessment) and a Remedial Action Objectives Technical Memorandum. Comments to the draft RI Report
were received in October 2014. In accordance with the timeline established by the Agencies, in November 2014 the PRP Group
submitted written responses to the EPA/WDNR comments concerning the draft RI and risk assessment documents. The PRP Group
received approval from EPA to defer preparation of responses to the comments on the draft RAOs until after the RI has been
approved. EPA commented on the RI Report in November 2015, and the PRP Group submitted a revised RI Report in December
2015.
YPF Holdings has accrued approximately Ps. 4 million as of December 31, 2015 for its estimated share of the costs of the
RI/FS. The main area of concern and focus is the extent of river sediment investigation that will be required. Maxus lacks sufficient
information to determine additional exposure or costs, if any, it might have in respect of this site.
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Other sites—Black Leaf Chemical Site
In September 2011, Occidental and Exxon Mobil received a liability notice from EPA under the ruling known as 104(e) for the
site called Black Leaf Chemical located at Louisville, Kentucky. Occidental requested that Maxus undertake the defense of this
matter by virtue of the indemnity established in the Stock Purchase Agreement of 1986. Maxus accepted the defense, reserving its
rights with respect to the case and without acknowledging any responsibility in November 2011. In March 2013, the EPA requested
that Maxus, on behalf of Occidental, and Exxon Mobil, perform specific remedial tasks and to reimburse EPA and the local
regulatory authority certain past costs (estimated at between U.S.$3 and U.S.$5 million). In September 2014, the Environmental
Protection Department of Kentucky (“EPDK”) initiated investigation procedures. In October 2015, the EPDK approved the site
characterization report submitted by the cooperation group and required presentation of a remediation action plan. In January 2016,
the cooperation group presented the required remediation action plan. As of December 31, 2015, the Company provisioned its
contribution to the estimated site remediation costs.
•
Tuscaloosa Site
The Company completed the remediation activities at this site. As of December 31, 2015, YPF accrued Ps. 52 million for future
operational and maintenance related activities.
•
Malone Services Site
Maxus is responsible for certain liabilities attributable to Occidental, as successor to Chemicals Company, in respect of the
Malone Service Company Superfund Site in Galveston County, Texas. This site is a former waste disposal site where Chemicals
Company is alleged to have sent waste products prior to September 1986. The potentially responsible parties, including Maxus, on
behalf of Occidental, formed a PRP Group to finance and perform an AOC RI/FS. The RI/FS has been completed and the EPA has
selected a Final Remedy, the EPA Superfund Division Director signed the Record of Decision on September 30, 2009. The PRP
Group signed the Consent Decree in the second quarter of 2012, and it became effective in July 2012. During 2012, 2013, 2014 and
2015, the PRP Group proceeded with the planning and design phase and remediation, which is ongoing. As of December 31, 2015 the
Company has reserved approximately Ps. 5 million in connection with its obligations for this matter.
Central Chemical Company Superfund Site (Hagerstown, Maryland)
The Central Chemical PRP Group has been responding to questions from the authorities, which has controlled the federal
superfund site in Hagerstown, Maryland since the 1990s. The PRP Group consists of parties who the EPA alleges are former Central
Chemical Company customers (or who are the legal successors thereof) which arranged for the disposal of certain CERCLA
hazardous substances at the site. Maxus participates in the PRP Group on behalf of Occidental. In 1998, the EPA entered into a
CERCLA Administrative Order on Consent with certain PRPs to conduct an RI/FS. The PRP Group, including Maxus, on behalf of
Occidental, funded and performed the RI/FS, which was completed in 2007. In 2009 the EPA issued its Record of Decision which
selected the final Site remedy. In 2010, EPA divided the Site into two Operable Units: “Operable Unit 1” (OU-1) – Site soils, waste
and shallow groundwater, and; “Operable Unit 2” (OU-2)—bedrock groundwater. In September 2012, the EPA issued CERCLA
Special Notice Letters to the PRPs, including Occidental, requesting that they fund and perform the Site OU-1 remedy. In August
2013, the PRP Group members, including Occidental, entered into a CERCLA Administrative Order on Consent to fund and perform
the Remedial Design for Operable Unit 1. In early 2014, the PRP Group and the EPA began negotiations of a judicial Consent Decree
for the funding and performance of the Remedial Action for Operable Unit No. 1. During 3Q 2015, the Central Chemical PRP Group
members (including Maxus on behalf of Occidental) entered into a judicial Consent Decree for the funding and performance of the
OU-1 Remedy (the “OU-1 Consent Decree”). The OU-1 Consent Decree was approved and entered with the court in October 2015.
Performance of the Remedial Action for Operable Unit No. 1 is currently forecasted to occur between 2016 and 2021; and according
to EPA, is estimated to cost approximately $14.2 million. In addition, the EPA may also require the Central Chemical PRP Group to
initiate a Remedial Design/Remedial Action for Operable Unit 2 in 2016 or 2017; which the PRP Group has estimated could cost at
least $3 million. As of December 31, 2015, YPF Holdings Inc. has accrued Ps. 17 million for known probable and reliably estimable
Site related losses to allow continued response for this matter on Occidental’s behalf.
•
Other third party sites
Chemicals Company has also been designated as a PRP by the EPA under the Comprehensive Environmental Response,
Compensation and Liability Act of 1980, as amended (“CERCLA”) with respect to a number of third-party sites where hazardous
substances from Chemicals Company’s plant operations allegedly were disposed or have come to be located. Numerous PRPs have
been named at substantially all of these sites. At several of these, Chemicals Company has no known exposure. At December 31,
2015, YPF Holdings had accrued approximately Ps. 48 million in connection with its estimated share of costs related to the
Milwaukee Solvay Coke & Gas Site, the Malone Service Company Superfund Site, and the other sites mentioned in this paragraph.
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•
Occidental’s claim for past events—Texas
Dallas Litigation. In 2002, Occidental sued Maxus and Tierra in state court in Dallas, Texas seeking a declaration that Maxus and
Tierra have the obligation under the agreement pursuant to which Maxus sold Chemicals Company to Occidental to defend and
indemnify Occidental from and against certain historical obligations of Chemicals Company, notwithstanding the fact that said
agreement contains a 12-year cut-off for defense and indemnity obligations with respect to most litigation. Tierra was dismissed as a
party, and the matter was tried in May 2006. The trial court decided that the 12-year cut-off period did not apply and entered judgment
against Maxus. This decision was affirmed by the Court of Appeals in February 2008. Maxus’ petition to the Texas Supreme Court for
review was denied. This decision will require Maxus to accept responsibility for various matters for which it has refused to indemnify
Occidental since 1998, which could result in the incurrence of costs in addition to YPF Holdings’ current accrued for this matter. This
decision will also require Maxus to reimburse Occidental for past costs. In 2009, Maxus received a statement from Occidental of the
costs Occidental believed to be due under the judgment, in the amount of U.S.$16.7 million. In March 2009, Maxus paid U.S.$14.9
million in respect of court costs, interests through the end of 2007 and estimates of future costs for which Maxus could become liable
under the declaratory judgment. In September 2009, Maxus paid to Occidental U.S.$1.9 million. In March 2012, Maxus paid to
Occidental U.S.$0.6 million covering Occidental’s costs for 2010 and 2011, and in September 2012 Maxus paid to Occidental an
additional U.S.$31,000 for Occidental’s costs for the first semester of 2012. Maxus anticipates that Occidental’s costs in the future under
the Dallas case will not exceed those incurred in 2012. A significant category of claims refused by Maxus on the basis of its
interpretation of the 12-year clause, were claims relating to “Agent Orange.” All pending Agent Orange litigation in the United States
was dismissed in December 2009, except with respect to one case filed in 2012, which was dismissed in March 2013. Although it is
possible that additional claimants may come forward in the future, it is estimated that no significant liability will result from this
category of claims.
•
Turtle Bayou
Turtle Bayou Litigation. In March 2005, Maxus agreed to defend Occidental, as successor to Chemicals Company, in respect of an
action seeking the contribution of costs for the remediation of the Turtle Bayou waste disposal site in Liberty County, Texas. Judgment
was entered in this action, and Maxus filed a motion for reconsideration which was partially successful. The court’s decision was
appealed by Maxus In June 2010, the Court of Appeals ruled that the District Court had committed errors in the admission of certain
documents and remanded the case to the District Court for further proceedings. A new ruling was issued in January 2011, requiring
Maxus to pay, on behalf of Occidental, 15.86% of the costs incurred by one of the plaintiffs. On behalf of Occidental, Maxus filed its
appeal in the February 2011, and the Court of Appeals affirmed the District Court’s ruling in March 2012. Maxus paid to the plaintiff,
on behalf of Occidental, U.S.$2 million in June 2012 covering past costs and $0.9 million in November 2012 to cover the costs incurred
by El Paso in 2007-2011. As of December 31, 2015, YPF accrued approximately Ps. 5 million in respect of this matter.
•
Ruby Mhire Litigation
Ruby Mhire Litigation. In May 2008, Ruby Mhire and others (“Mhire”) brought suit against Maxus and third parties, alleging that
various parties including a predecessor of Maxus had contaminated certain property in Cameron Parish, Louisiana, during oil and gas
activities on the property; Maxus’ predecessor operated on the property from 1969 to 1989. The Mhire plaintiffs demanded remediation
and other compensation from approximately U.S.$159 million to U.S.$210 million, basing themselves on plaintiffs’ expert’s study.
During June 2012, the parties in the case held a court-ordered mediation. On June 11, 2013, Maxus signed a Settlement Agreement with
the plaintiffs pursuant to which Maxus shall make installment payments totaling U.S.$12 million over three years and also perform
remediation at the site, which is estimated to cost between U.S.$1 and U.S.$3 million. On July 31, 2013, the 38th Judicial District Court
for the Parish of Cameron, State of Louisiana, approved the Settlement Agreement following receipt on July 8, 2013 of the No
Objection Letter from the Louisiana Department of Natural Resources, Office of Conservation. In August 2013, pursuant to the
Settlement Agreement, Maxus made an initial payment of U.S.$2 million and in December 2013, Maxus made a second payment of
U.S.$3 million. In June 2014, Maxus made a third payment of U.S.$3 million, and in December 2014 Maxus made a fourth payment of
U.S.$3 million. One last instalment in the amount of U.S.$1 million was paid in June 2015, which is Maxus’s final payment obliation.
However, Maxis must still perform site remediation, which is expected to be completed by the end of 2016.
•
Bedivere Litigation
Bedivere Litigation. This litigation consists of an insurance related declaratory judgment (the “Declaratory Judgment”) filed
against Maxus in Federal District Court in Texas. The plaintiffs issued insurance policies for the benefit of Maxus and its predecessors
to cover certain risks related to the exploration of oil and gas, as well as the risks related to the production activities in the State of
Louisiana. The underlying fundamentals of the declaratory judgment claim are related to the losses and respective payments claimed
against Maxus in the Ruby Mhire litigation. The Ruby Mhire litigation relates to a legacy liability from a Louisiana oilfield action filed
in Cameron Parish, Louisiana in 2008 against several oil and gas companies, including Maxus. In 2013, Maxus settled the Ruby Mhire
litigation. Prior to the filing of the Declaratory Judgment, Maxus was involved in substantial discussions with the plaintiff insurance
companies’ claims administrator regarding a possible agreement with Maxus under the policies. On June 18, 2015, the insurer denied
coverage and, without prior notice, filed the Declaratory Judgment the following day. Maxus is contesting the Declaratory Judgment.
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•
Actions for Environmental Pollution in Louisiana
Maxus is also defending two cases filed in Louisiana related to environmental pollution, in connection with legacy oil
exploration and production activities.
•
Jumonville Litigation
Jumonville Litigation. This litigation was filed in 2012, in Port Coupee Parish, Louisiana, against Murphy Oil and Maxus, as a
successor of Apexco/Natomas, regarding environmental pollution caused by drilling activities in 1976. The claims are related to a
deep unproductive well that was closed and abandoned in 1978. The claim against Murphy Oil relates to a breach of contract claim
with a statute of limitations of ten years from the date of the initiation of the trial. The claim against Maxus is an action for liability
with a statute of limitations of one year from the date of the trial period. Murphy Oil argues, without documentary evidence to date,
which probably assigned or transferred the lease to Maxus, and that apparently the lease had an indemnification provision. Murphy
Oil claims indemnification rights from Maxus as the successor to the operator of the well. Maxus is contesting the claim based in part
on lack of documentary evidence of the indemnification right. In May 2014, the court separated the plaintiffs’ claims against Maxus
and Murphy Oil from their claims against other defendants and scheduled a trial. In July 2015, Maxus and the plaintiffs entered into a
nonbinding Memorandum of Understanding (“MOU”). Under the MOU, the litigation is suspended to permit Maxus and Murphy Oil
to continue negotiations. The MOU contemplates a final settlement with two main components: (i) payments from Maxus and
(ii) financing and implementation by Maxus of a remediation project. As of December 31, 2015, Maxus and the plaintiffs are
negotiating the settlement.
Dividend Policy
See “Item 10. Additional Information—Dividends.”
Significant Changes
Since December 31, 2015, there have been no significant changes regarding the Company.
ITEM 9. The Offer and Listing
Shares and ADSs
New York Stock Exchange
The ADSs, each representing one Class D share, are listed on the NYSE under the trading symbol “YPF.” The ADSs began
trading on the NYSE on June 28, 1993, and were issued by The Bank of New York Mellon, as depositary (the “Depositary”).
The following table sets forth, for the five most recent full financial years and for the current financial year, the high and low
closing prices in U.S. dollars of our ADSs on the NYSE:
2011
2012
2013
2014
2015
2016 (1)
(1) Through March 10, 2016
High
54.58
41.14
34.17
38.91
31.58
18.83
Low
31.25
9.57
12.26
21.85
14.91
12.83
The following table sets forth, for each quarter of the most recent two financial years and for each quarter of the current
financial year, the high and low closing prices in U.S. dollars of our ADSs on the NYSE.
2014:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2015:
First Quarter
Second Quarter
High
Low
33.08
35.95
38.91
35.42
21.85
27.90
30.97
22.50
29.55
31.58
23.00
26.18
Third Quarter
Fourth Quarter
2016:
First Quarter (1)
(1) Through March 10, 2016
185
27.42
22.18
14.91
15.05
18.83
12.83
The following table sets forth, for each of the most recent six months and for the current month, the high and low closing prices
in U.S. dollars of our ADSs on the NYSE.
2015:
September
October
November
December
2016:
January
February
March (1)
(1) Through March 10, 2016
High
Low
22.02
21.36
22.18
18.07
14.91
15.05
18.21
15.72
16.84
18.83
18.81
12.83
15.23
17.48
According to data provided by The Bank of New York Mellon, as of March 9, 2016, there were 172,078,241 ADSs outstanding and
54 holders of record of ADSs. Such ADSs represented approximately 44% of the total number of issued and outstanding Class D
shares as of such date. Buenos Aires Stock Market
The Buenos Aires Stock Market is the principal Argentine market for trading the ordinary shares.
The Buenos Aires Stock Market (Mercado de Valores de Buenos Aires) (“MERVAL”) is the largest stock market in Argentina
and has been authorized by the CNV to delegate certain functions to the Buenos Aires Stock Exchange (“BASE”). Trading on the
MERVAL is conducted either through the traditional auction system from 11 a.m. to 5 p.m. on trading days, or through the
Computer-Assisted Integrated Negotiation System (Sistema Integrado de Negociación Asistida por Computación) (“SINAC”).
SINAC is a computer trading system that permits trading in both debt and equity securities and is accessed by brokers directly from
workstations located in their offices. Currently, all transactions relating to listed negotiable obligations and listed government
securities can be effectuated through SINAC. In order to control price volatility, MERVAL imposes a 15-minute suspension on
trading when the price of a security registers a variation in price between 10% and 15% and between 15% and 20%. Any additional
5% variation in the price of a security will result in an additional 10-minute successive suspension period.
Investors in the Argentine securities market are mostly individuals and companies. Institutional investors, which are responsible
for a growing percentage of trading activity, consist mainly of insurance companies and to a lesser extent mutual funds.
Certain information regarding the Argentine stock market is set forth in the table below
Market capitalization (in billions of pesos) (1)
As percent of GDP (1)
Volume (in millions of pesos)
Average daily trading volume (in millions of pesos)
2015
3,292
— (1)
749,829
4,822.6
2014
3,893
86%
2013
3,356
124%
2009
2,185
191%
621,831 367,830 242,324 207,805 177,613 133,208
2,581.0 1,526.3 1,005.5 848.2 722.0 545.93
2012
2,300 1,611 1,900
87% 132%
107%
2010
2011
(1)
INDEC will not publish new information until at least June 2016. See “Item 3—Key Information—Risk Factors—Our business
is largely dependent upon economic conditions in Argentina.”
186
The following table sets forth, for the five most recent full financial years and for the current financial year, the high and low prices in
Argentine pesos of our Class D shares on the Buenos Aires Stock Market:
2011
2012
2013
2014
2015
2016 (1)
(1) Through March 10, 2016
High
222.60
188.50
294.00
558.00
375.50
295.00
Low
150.50
66.50
101.30
250.00
207.00
179.00
The following table sets forth, for each quarter of the most recent two financial years and for each quarter of the current financial year, the
high and low prices in Argentine pesos of our Class D shares on the Buenos Aires Stock Market.
2014:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2015:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2016:
First Quarter (1)
(1) Through March 10, 2016
High
Low
330.00
357.00
558.00
506.00
250.00
277.00
340.00
255.00
355.50
375.50
361.00
305.00
277.00
321.00
209.00
207.00
295.00
179.00
The following table sets forth, for each of the most recent six months and for the current month, the high and low prices in Argentine pesos
of our Class D shares on the Buenos Aires Stock Market.
2015:
September
October
November
December
2016:
January
February
March (1)
(1) Through March 10, 2016
High
Low
309.75
290.00
305.00
265.00
209.00
207.00
267.00
218.00
235.00
295.00
293.50
179.00
229.00
266.00
As of December 31, 2015, there were approximately 34,017 holders of Class D shares in Buenos Aires Stock Market.
Stock Exchange Automated Quotations System International
The ADSs are also quoted on the Stock Exchange Automated Quotations System International.
Argentine Securities Market
The securities market in Argentina was originally composed of 13 stock exchanges, which are located in the City of Buenos Aires (the
“BASE”), Bahía Blanca, Chaco, Corrientes, Córdoba, La Plata, La Rioja, Mendoza, Rosario, Salta, Santa Fe, and Tucumán. Six of these
exchanges (the BASE, Rosario, Córdoba, La Rioja, Mendoza, and Santa Fe) had affiliated stock markets and, accordingly, were authorized to
quote publicly offered securities. However this system was affected by the enactment of Law No. 26,831 and the new regulations issued by the
CNV, mainly contained in Resolution No. 622/2013, which stated that securities can only be listed and exchanged in stock markets authorized to
function as such by the CNV.
187
The BASE, which began operating in 1854, was the principal and longest-established stock exchange in Argentina. The
exchange functions of the BASE have now been absorbed by the Merval, which is stock market authorized by the CNV to function as
such, under Law No. 26,831. The Merval and the BASE have entered into an agreement which has been approved by the CNV, by
which the Merval has delegated to the BASE certain functions, suchs as: (i) the authority to grant listing authorization for securities;
(ii) the authority to constitute arbitration courts; and (iii) the issuance of a public information bulletin.
Argentina’s equity markets have historically been composed of individual investors, though in recent years there has been an
increase in the level of investment by banks and insurance companies in these markets; however, Argentine mutual funds (fondos
comunes de inversión) continue to have very low participation.
The Argentine securities market is regulated and overseen by the CNV, pursuant to Law No. 26,831 (the “Stock Market Law”)
which governs the regulation of security exchanges, as well as stockbroker transactions, market operations, the public offering of
securities, corporate governance matters relating to public companies and the trading of futures and options. Argentine institutional
investors and insurance companies are regulated by separate government agencies, whereas financial institutions are regulated
primarily by the Argentine Central Bank.
In Argentina, debt and equity securities traded on an exchange or the over-the-counter market must, unless otherwise instructed
by their shareholders, be deposited with Stock Exchange Incorporated (Caja de Valores S.A.), a corporation owned by the MERVAL
and certain provincial exchanges. Stock Exchange Incorporated is the central securities depositary of Argentina and provides central
depositary facilities, as well as acting as a clearinghouse for securities trading and as a transfer and paying agent for securities
transactions. Additionally, it handles the settlement of securities transactions carried out by the Merval and operates SINAC.
Among the key provisions of the Stock Market Law are the following: the definition of a “security,” that governs the treatment
of negotiable securities; the corporate governance requirements, including the obligations for publicly listed companies to form audit
committees composed of three or more members of the Board of Directors (the majority of whom must be independent under CNV
regulations); regulations for market stabilization transactions under certain circumstances, regulations that governs insider trading,
market manipulation and securities fraud and regulates going-private transactions and acquisitions of voting shares, including
controlling stakes in public companies. In addition, the Stock Market Law included very relevant changes for the modernization and
future design of the capital market, like the demutualization of the stock exchanges; new regulatory powers and resources for the
CNV; a mandatory tender offer system and other provisions, like the new requirements for brokers/dealers and other market
participants. These provisions were regulated by the CNV with Resolution No. 622/2013. Before offering securities to the public in
Argentina, an issuer must meet certain requirements established by the CNV with regard to the issuer’s assets, operating history and
management. Only securities approved for a public offering by the CNV may be listed on a stock exchange. However, CNV approval
does not imply any kind of certification as to the quality of the securities or the solvency of the issuer, even though issuers of listed
securities are required to file unaudited quarterly financial statements and audited annual financial statements in accordance with
IFRS and various other periodic reports with the CNV and the stock exchange on which their securities are listed, as well as to report
to the CNV and the relevant stock exchange any event related to the issuer and its shareholders that may affect materially the value of
the securities traded.
Money laundering regulations
Recent modifications to Argentine money laundering regulations have resulted in their application to increasing numbers and
types of securities transactions.
The notion of money laundering is generally used to refer to transactions aimed at introducing funds derived from unlawful
activities into the institutionalized system and therefore, transforming profits obtained from unlawful activities into assets having a
presumed lawful origin.
Law No. 25,246 (as subsequently amended by Law No. 26,087, Law No. 26,119, Law No. 26,268 and Law No 26,683) provides
for an administrative criminal system and replaces several sections of the Argentine Criminal Code, incorporating, among other
matters, the definition of money laundering as a type of crime committed whenever a person converts, transfers, manages, sells,
charges, conceals or otherwise markets any asset derived from a criminal offense, with the possible consequence that the original
assets or substitutes thereof appear to come from a lawful source, provided that the total value of the asset exceeds Ps.300,000
regardless of whether such amount results from one act or a series of related acts.
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According to Article 303 of the Argentine Criminal Code, money laundering (as defined above) shall be punished with three to
ten years of imprisonment and a fine of two to ten times the amount of the transactions made. The penalty prescribed above shall be
increased by one third of the maximum and one half of the minimum if: (a) the wrongdoer carries out the act on a regular basis or as a
member of an association or gang organized with the purpose of continuously committing acts of a similar nature; or (b) if the
primary wrongdoer is a public officer who committed the infringement in the exercise of his/her duties (in such a case, the wrongdoer
shall also be punished by special disqualification for three to ten years, and the same penalty shall apply to a wrongdoer who commits
the offense in the service of a profession or trade requiring special qualification). The individual who receives money or other assets
derived from a criminal offense with the purpose of applying them to a money laundering transaction shall be punished with
imprisonment from six months to three years. If the value of the assets is not over Ps.300,000, the wrongdoer will be punished with
imprisonment from six months to three years. The provisions in this section shall apply even when the criminal offense is committed
outside the geographical jurisdiction of the Argentine Criminal Code, so long as the crime is also penalized in the jurisdiction where it
was committed.
Article 277 of the Argentine Criminal Code sets forth that an imprisonment of between six months and three years shall be
applied (with varying minimum terms attaching depending on the particular circumstances) to any person who helps a perpetrator to
avoid investigation, obscures or destroys evidence of a crime, acquires, receives, hides or alters money or other proceeds from a
crime, does not report the commission of the crime or does not identify the perpetrator or participant in a crime with knowledge that
such person would have been obliged to assist in the criminal prosecution of such crime and/or aids or abets the perpetrator or
participant to make safe the proceeds of the crime. The minimum and maximum terms of punishment shall be doubled when: (a) the
offense implies a particularly serious crime (for which minimum penalty is higher than three years of imprisonment); (b) the abettor
acts for profit; (c) the abettor habitually commits concealment acts; or (d) the abettor is a public official.
Law No. 25,246 contemplates that the legal entity whose management collected or provided assets or money, whatever their
value, knowing that such assets were to be used by a terrorist organization, may be subject to a fine between five to 20 times the value
of such assets. Furthermore, whenever the management of the legal entity infringes the duty to treat the information submitted to the
Financial Information Unit (Unidad de Información Financiera “UIF”) as confidential, the legal entity shall be subject to a fine
between Ps. 50,000 to Ps. 500,000. Additionally such regulation created the UIF as an autonomous and financially self-sufficient
entity within the jurisdiction of the Argentine Ministry of Justice and Human Rights, in charge of analyzing, treating and transmitting
information in order to preclude and prevent money laundering. Pursuant to this legislation, the UIF is empowered to receive and
request reports, documents, background and any other information deemed useful to fulfill its duties from any public entity, whether
federal, provincial or municipal, and from individuals or public or private entities, all of which entities must furnish such information
in accordance with Law No. 25,246. Whenever the information furnished or analyses performed by the UIF show the existence of
sufficient evidence to suspect that a money laundering or terrorist financing crime has been committed, the UIF shall transmit such
evidence to the Government Attorney’s Office so that it may start the relevant criminal action, and the UIF may appear as an accusing
party to such proceedings. Moreover, Law No. 26,087 mandates that banking secrecy or professional privilege, or legal or contractual
commitments, cannot be considered exceptions to the compliance with the obligation to submit information to the UIF in the context
of an investigation of suspicious activity.
The main goal of Law No. 25,246 is to prevent money laundering. In line with internationally accepted practices, the duty to
control such illegal transactions is not concentrated solely in Argentine federal governmental entities but also distributed among
several private sector entities such as banks, brokers, brokerage firms and insurance companies. Such duties mainly consist of data
collection functions, such as: (i) gathering from clients, applicants or contributors any documentation sufficient to prove their identity,
legal capacity, domicile and further data as necessary on a case by case basis; (ii) reporting any suspicious fact or transaction
irrespective of its amount; and (iii) abstaining from disclosing to the client or third parties any procedures being followed pursuant to
law. According to Law No. 25,246, a suspicious transaction shall mean any transaction that, in accordance with standard business
practices and in the experience of the entities and individuals subject to reporting obligations, is regarded as unusual, unjustified from
an economic or legal standpoint, or unnecessarily complex, whether it is a one-time transaction or a series of transactions.
In February 2016, the National Executive Office issued Decree No. 360/16, under which the National Coordination Program to
Combat Money Laundering and Terrorism Financing was created under the Ministry of Justice and Human Rights. The program aims
to reorganize, coordinate and strengthen Argentina’s anti-money laundering and combat of terrorism financing in line with
international guidelines established by United Nations conventions and the Financial Action Task Force.
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Resolution No. 121/2011 issued by the UIF (“Resolution 121”), as amended by Resolutions No. 1/12, 2/12, 68/13 and 03/14,
195/2015 and 196/2015, is applicable to financial entities subject to Law No. 21,526, to entities subject to the Law No. 18,924, as
amended, and to natural and legal entities authorized by the Argentine Central Bank to intervene in the purchase and sale of foreign
currency through cash or checks issued in foreign currency or through the use of credit or payment cards, or in the transfer of funds
within or outside the national territory. Resolution No. 229/2011 of the UIF (“Resolution 229”), as amended by Resolution No
140/12, 03/14, 195/2015 and 196/2015, is applicable to brokers and brokerage firms, companies managing common investment
funds, agents of the over-the-counter market, intermediaries in the purchase or leasing of securities affiliated with stock exchange
entities with or without associated markets, and intermediary agents registered on forwards or option markets. Resolution 121 and
Resolution 229 regulate, among other matters, the obligation to collect documentation from clients and the terms, obligations and
restrictions for compliance with the reporting duty regarding suspicious money laundering and terrorism financing operations.
Resolution 121 and Resolution 229 set forth general guidelines in connection with the client’s identification (including the
distinction between occasional and regular clients), the information to be requested, the documentation to be archived and the
procedures to detect and report suspicious transactions. Moreover, the main duties established by such resolutions are the following:
a) creating a manual establishing the mechanisms and procedures to be used to prevent money laundering and terrorism financing; b)
designation of a compliance officer; c) the implementation of periodic audits; d) personnel training; e) elaboration of analysis records
and risk management of detected unusual operations and of those which have been reported because they were considered suspicious;
f) implementation of technological tools which allow the establishment of efficient control systems and prevention of money
laundering and terrorism financing; and g) implementation of measures which allow subjects obliged under Resolution 121 and
subjects obliged under Resolution 229, respectively, to electronically consolidate the operations carried out with clients, and
electronic tools which allow the analysis and control of different variables in order to identify certain behaviors and observe possible
suspicious transactions. Entities covered by Resolution 121 and Resolution 229 must report any suspected money laundering to the
UIF within 30 calendar days of its occurrence (or attempt) and any terrorism financing suspicious activity before a 48 hour period has
elapsed.
According to Resolution 229, unusual transactions are those attempted or consummated transactions, on a one-time or on a
regular basis, without economic or legal justification, inconsistent with the economic and financial profile of the client, and which
deviate from standard market practices, based on their frequency, regularity, amount, complexity, nature or other particular features.
According to Resolution 229, an unusual transaction is one that, considering the suitability of the reporter in light of the activity it
carries out, and the analysis made, may be suspicious of money laundering and financing terrorism. On other hand, suspicious
transactions are those attempted or consummated transactions that, having been previously identified as unusual transactions, are
inconsistent with the lawful activities declared by the client or, even if related to lawful activities, give rise to suspicion that they are
linked or used to finance terrorism.
Likewise, Resolution 229 provides for a list of factors which shall be specially taken into account in order to determine whether
a transaction should be reported to UIF, including but not limited to: (i) clients who refuse to provide data or documents required by
Resolution 229, or data provided by clients which is proved to be irregular; (ii) clients attempting to avoid compliance with the
requirements set forth by Resolution 229 or other anti-money laundering regulations; (iii) indications about the illicit origin,
management or destination of funds and other assets used in the transactions, in respect of which the reporting person or company
does not receive a viable explanation; (iv) transactions involving countries or jurisdictions which are deemed tax heavens or identified
as non-cooperative by the Financial Action Task Force; (v) the purchase or sale of securities at prices conspicuously higher or lower
that those quoted at the moment the transaction is consummated; (vi) the purchase of securities at extremely high prices;
(vii) transactions where the client declares assets not consistent with the size of their business, thereby implying the possibility that
such client is not acting in its own name but as an agent of an anonymous third party; (viii) investment transactions with securities for
high nominal values, which are not consistent with the volume of securities historically negotiated according to the client’s
transactional profile; and (ix) the receipt of an electronic transfer of funds without all the required information.
In addition, the CNV rules establish that brokers and brokerage firms, and companies managing common investment funds,
agents of the over-the-counter market, intermediaries in the purchase or lease of securities affiliated with stock exchange entities with
or without associated markets and intermediary agents registered on forwards or option markets, and individuals or legal entities
acting as trustees, for any type of trust fund, and individuals or legal entities, owners of or related to, directly or indirectly, with trust
accounts, trustees and grantors in the context of a trust agreement, shall comply with Law No. 25,246, the UIF’s rulings and the
CNV’s regulations. Additionally, companies managing common investment funds, any person acting as placement agent or
performing activities relating to the trading of common investment funds, any person acting as placement agent in any primary
issuance of marketable securities, and any issuer with respect to capital contributions, irrevocable capital contributions for future
issuances of stock or significant loans, must also comply with such regulations.
Such resolutions also contain certain requirements for the reception and delivery of checks and payments made between the
individuals and entities listed above, as well as the prohibition of transactions relating to the public offering of securities, when they
are consummated or ordered by individuals or companies domiciled or residing in domains, jurisdictions, territories or associated
states not included in the list of Decree 589/2013 (Regulatory Law of Income Tax No. 20,628 and its amendments), among other
provisions, which mainly includes jurisdictions considered “cooperating for the purpose of tax transparency.” Brokers and
dealers must duly know their clients and apply policies and maintain adequate structures and systems in line with a policy against
money laundering and terrorist financing. Also, interested investors undertake the obligation to submit any information and
documents that may be required in order to comply with criminal regulations and other laws and regulation in connection with money
laundering, including capital markets’ regulations preventing money laundering issued by the UIF and similar regulations issued by
the CNV.
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ITEM 10.
Additional Information
Capital Stock
Our capital stock consists of Ps.3,933,127,930, divided into 3,764 Class A shares, 7,624 Class B shares, 40,422 Class C shares and
393,260,983 Class D shares, each fully subscribed and paid, with a par value of ten pesos each and the right to one vote per share. Our total capital
stock has not changed since December 31, 2004.
In November 1992, the Privatization Law became effective. Pursuant to the Privatization Law, in July 1993, we completed a worldwide
offering of 160 million Class D shares, representing approximately 45% of our outstanding capital stock, which had been owned by the Argentine
government. Concurrently with the completion of such offering, the Argentine government transferred approximately 40 million Class B shares to
the Argentine provinces, which represented approximately 11% of our outstanding capital stock, and made an offer to holders of pension bonds
and certain other claims to exchange such bonds and other claims for approximately 46.1 million Class B shares, representing approximately 13%
of our outstanding capital stock. As a result of these transactions, the Argentine government’s ownership percentage of our capital stock was
reduced from 100% to approximately 30%, including shares that had been set aside to be offered to our employees upon establishment of the terms
and conditions by the Argentine government in accordance with Argentine law. The shares set aside to be offered to employees represented 10% of
our outstanding capital stock.
In July 1997, the Class C shares set aside for the benefit of our employees in conjunction with the privatization, excluding approximately
1.5 million Class C shares set aside as a reserve against potential claims, were sold through a global public offering, increasing the percentage of
our outstanding shares of capital stock held by the public to 75%. Proceeds from the transactions were used to cancel debt related to the employee
plan, with the remainder distributed to participants in the plan. Additionally, Resolution 1,023/06 of the Ministry of Economy, dated December 21,
2006, effected the transfer to the employees covered by the employee share ownership plan, or PPP, of 1,117,717 Class C shares, corresponding to
the Class C shares set aside as a reserve against potential claims, and reserving 357,987 Class C shares until a decision was reached in a pending
lawsuit. Subsequently, with a final decision having been reached in the lawsuit, and consistent with the mechanism of conversion of Class C shares
into Class D shares established by Decree 628/1997 and its accompanying rules, as of December 31, 2009, 1,447,983 Class C shares had been
converted into Class D shares. In 2010, a former employee of the Company who was allegedly excluded from the Argentine government’s YPF
share ownership plan filed a claim against YPF seeking recognition of his status as a shareholder of YPF. In addition, the Federation of Former
Employees of YPF joined the proceeding as a supporting third-party claimant, purportedly acting on behalf of other former employees who were
also allegedly excluded from the share ownership plan. Under the jurisprudence of the Argentine Supreme Court upholding numerous decisions of
the relevant Argentine Courts of Appeals, YPF believes it will not be held liable for claims of this nature related to the PPP. Through Law
No. 25.471, the Argentine government assumed sole responsibility for any compensation to be received by YPF’s former employees who were
excluded from the PPP.
The Class A shares held by the Argentine government became eligible for sale in April 1995 upon the effectiveness of legislation which
permitted the Argentine government to sell such shares. In January 1999, Repsol YPF acquired 52,914,700 Class A shares in block (14.99% of our
shares) which were converted to Class D shares. Additionally, on April 30, 1999, Repsol YPF announced a tender offer to purchase all outstanding
Class A, B, C and D shares at a price of U.S.$44.78 per share (the “Offer”). Pursuant to the Offer, in June 1999, Repsol YPF acquired an additional
82.47% of our outstanding capital stock. On November 4, 1999, Repsol YPF acquired an additional 0.35%. On June 7, 2000, Repsol YPF
announced a tender offer to exchange newly issued Repsol YPF’s shares for 2.16% of our Class B, C and D shares held by minority shareholders.
Pursuant to the tender offer, and after the merger with Astra Compañía Argentina de Petróleo, S.A. (“Astra”) and Repsol Argentina, S.A., Repsol
YPF owned 330,551,981 Class D shares and therefore controlled us through a 99.04% ownership interest until 2008. Following the different
transactions that started in 2008, Repsol YPF ended up with a total ownership of 57.43% in April 2012.
The Expropriation Law has significantly changed our shareholding structure. The Class D shares subject to expropriation from Repsol YPF
or its controlling or controlled entities, which represent 51% of our share capital and were declared of public interest and are currently held by the
Republic of Argentina, will be assigned as follows: 51% to the federal government and 49% to the governments of the provinces that compose the
National Organization of Hydrocarbon Producing States. In addition, the Argentine federal government and certain provincial governments already
own our Class A and Class B shares. See “Item 3. Key Information—Risk Factors—Risks Relating to Argentina—The Argentine federal
government will control the Company according to domestic energy policies in accordance with the Expropriation Law.”
As of the date of this annual report, the transfer of the shares subject to expropriation between the National Executive Office and the
provinces that compose the National Organization of Hydrocarbon Producing States was still pending. According to Article 8 of the Expropriation
Law, the distribution of the shares among the provinces that accept their transfer must be conducted in an equitable manner, considering their
respective levels of hydrocarbon production and proved reserves. To ensure compliance with its objectives, the Expropriation Law provides that
the National Executive Office, by itself or through an appointed public entity, shall exercise all the political rights associated with the shares
subject to expropriation until the transfer of political and economic rights to the provinces that compose the National Organization of Hydrocarbon
Producing States is completed. In addition, in accordance with Article 9 of the Expropriation Law, each of the Argentine provinces to which shares
subject to expropriation are allocated must enter into a shareholder’s agreement with the federal government that will provide for the unified
exercise of its rights as a shareholder. See “Item 4. Information on the Company—Regulatory Framework and Relationship with the Argentine
Government—The Expropriation Law”, “—Decree 272/2015” and “Item 7. Major Shareholders and Related Party Transactions.”
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Memorandum and Articles of Association
YPF’s by-laws were approved by National Executive Decree No. 1,106, dated May 31, 1993, and notarized by public deed
No. 175, dated June 15, 1993 at the National Notary Public Office, sheet 801 of the National Registry, and registered at the Inspection
Board of Legal Entities of the Argentine Republic on the same date, June 15, 1993 under number 5,109 of the book of Corporations
number 113, volume “A.”
At a shareholders’ meeting on April 14, 2010, YPF’s shareholders approved an amendment to YPF’s by-laws. Copies of the by-
laws, which have been filed as described in “Item 19. Exhibits” in this annual report, are also available at the offices of YPF.
For a detailed description of YPF’s object and purpose, see “Item 4. Information on the Company.” YPF’s object is set forth in
Section 4 of its by-laws.
Pursuant to Argentine Corporations Law, the Board of Directors or the Supervisory Committee shall call either annual general
or extraordinary shareholders’ meetings in the cases provided by law and whenever they consider appropriate. Shareholders
representing not less than 5% of YPF’s capital stock may also request that a shareholders’ meeting be called.
A shareholders’ meeting shall be called at least twenty days prior to the meeting date by notice published in the legal
publications journal for a period of five days. The notice shall include the nature, date, time and place of the meeting, the agenda to be
discussed and the specific requirements shareholders must meet to attend the meeting.
Shareholders’ Meetings
Pursuant to the Argentine Corporations Law, the Board of Directors or the Supervisory Committee shall call either annual
ordinary or extraordinary shareholders’ meetings in the cases provided by law and whenever they consider appropriate. Shareholders
representing not less than 5% of our capital stock may also request that a shareholders’ meeting be called, in which case the meeting
must take place within 40 days of such shareholders’ request. If the Board of Directors or the Supervisory Committee fails to call a
meeting following such a request, a meeting may be ordered by the CNV or by the courts.
Shareholders’ meetings may be ordinary meetings or extraordinary meetings. We are required to convene and hold an ordinary
meeting of shareholders within four months of the closing of each fiscal year to consider the matters specified in the first two
paragraphs of Section 234 of the Argentine Corporations Law, such as the approval of our financial statements, allocation of net
income for such fiscal year, approval of the reports of the Board of Directors and the Audit Committee and the election, performance
and remuneration of directors and members of the Supervisory Committee. In addition, pursuant to the Stock Market Law, at ordinary
shareholders’ meetings, shareholders must consider (i) the disposition of, or creation of any lien over, assets as long as such decision
has not been performed in the ordinary course of business and (ii) the execution of administration or management agreements and
whether to approve any agreement by virtue of which the assets or services provided to us are paid partial or totally with a percentage
of our income, results or earnings, if the payment is material when measured against the volume of the ordinary course of business
and our shareholders’ equity. Other matters which may be considered at an ordinary shareholders’ meeting convened and held at any
time include the responsibility of directors and members of the Supervisory Committee, capital increases and the issuance of certain
notes. Extraordinary shareholders’ meetings may be called at any time to consider matters beyond the authority of an ordinary
meeting including, without limitation, the amendment of our by-laws, issuance of debentures, early dissolution, merger, spin-off,
reduction of capital stock and redemption of shares, transformation from one type of entity to another and limitation or suspension of
shareholders’ preemptive rights.
Notices of meetings
Notice of shareholders’ meetings must be published for five days in the Official Gazette, in an Argentina newspaper of wide
circulation and in the bulletin of the BASE, at least 20 but not more than 45 days prior to the date on which the meeting is to be held.
Such notice must include information regarding the type of meeting to be held, the date, time and place of such meeting and the
agenda. If a quorum is not available at such meeting, a notice for a meeting on second call, which must be held within 30 days of the
date on which the first meeting was called, must be published for three days at least eight days before the date of the meeting on
second call. The above-described notices of shareholders’ meetings may be effected simultaneously for the meeting on second call to
be held on the same day as the first meeting, only in the case of ordinary meetings. Shareholders’ meetings may be validly held
without notice if all the shares of our outstanding share capital are present and resolutions are adopted by unanimous vote of shares
entitled to vote.
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Quorum and voting requirements
Except as described below, the quorum for ordinary meetings of shareholders on first call is a majority of the shares entitled to
vote, and action may be taken by the affirmative vote of an absolute majority of the shares present that are entitled to vote on such
action. If a quorum is not available at the first meeting, a meeting on second call may be held at which action may be taken by the
holders of an absolute majority of the shares present, regardless of the number of such shares. The quorum for an extraordinary
shareholders’ meeting on first call is 60% of the shares entitled to vote, and if such quorum is not available, a meeting or second call
may be held, at which action may be taken by the holders of an absolute majority of the shares present, regardless of the number of
such shares.
Our by-laws establish that in order to approve (i) the transfer of our domicile outside Argentina, (ii) a fundamental change of the
corporate purpose set forth in our by-laws, (iii) delisting of our shares from the BASE or NYSE, and (iv) a spin-off by us, when as a
result of such spin-off more than 25% of our assets are transferred to the resulting corporations, a majority of the shares representing
75% or more of our voting shares is required, both in first and second call. Our by-laws also establish that in order to approve
(i) certain amendments to our by-laws concerning tender offers of shares (as described below), (ii) the granting of certain guarantees
in favor of our shareholders, (iii) full stop of refining, commercialization and distribution activities and (iv) rules regarding
appointment, election and number of members of our Board of Directors, a majority of the shares representing 66% or more of our
voting shares is required, both in first and second call, as is the affirmative vote of the Class A shares, voting at a special meeting of
the holders of such shares.
In order to attend the meeting, shareholders must deposit their shares, or a certificate representing book-entry shares issued by a
bank, clearing house or depository trust company, with us. This certificate will allow each shareholder to be registered in the
attendance book which closes three business days before the date on which the meeting will be held. We will issue to each
shareholder a deposit certificate required for admission into the meeting. Shares certified and registered in the attendance book may
not be disposed of before the meeting is held unless the corresponding deposit is cancelled.
Under the Argentine Corporations Law, foreign companies that own shares in an Argentine corporation are required to register
with the IGJ in order to exercise certain shareholder rights, including voting rights. Such registration requires the filing of certain
corporate and accounting documents. Accordingly, if a shareholder owns Class D shares directly (rather than in the form of ADSs)
and it is a non-Argentine company, and such shareholder fails to register with the IGJ, the ability to exercise its rights as a holder of
Class D shares may be limited.
Directors, members of the Supervisory Committee and senior managers are both entitled and required to attend all shareholders’
meetings. These persons may only exercise voting power to the extent they have been previously registered as shareholders, in
accordance with the provisions described in the above paragraph. Nevertheless, these persons are not allowed to vote on any proposal
regarding the approval of their management duties or their removal for cause.
Shareholders who have a conflict of interest with us and who do not abstain from voting may be liable for damages to us, but
only if the transaction would not have been approved without such shareholders’ votes. Furthermore, shareholders who willfully or
negligently vote in favor of a resolution that is subsequently declared void by a court as contrary to the law or our by-laws may be
held jointly and severally liable for damages to us or to other third parties, including shareholders.
Directors
Election of Directors
Our business and affairs are managed by the Board of Directors in accordance with our by-laws and the Argentine Corporations
Law. Our by-laws provide for a Board of Directors of eleven to 21 members, and up to an equal number of alternates. Alternates are
those elected by the shareholders to replace directors who are absent from meetings or who are unable to exercise their duties, when
and for whatever period appointed to do so by the Board of Directors. Alternates have the responsibilities, duties and powers of
directors only if and to the extent they are called upon to attend board meetings or for such longer period as they may act as
replacements.
Directors hold office from one to three years, as determined by the shareholders’ meetings. Since the Board of Director’s
meeting held on December 22, 2015, our Board of Directors is composed of 15 directors and seven alternates.
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In accordance with our by-laws, the Argentine government, as sole holder of Class A shares, is entitled to elect one director and
one alternate.
Under the Argentine Corporations Law, a majority of our directors must be residents of Argentina. All directors must establish a
legal domicile in Argentina for service of notices in connection with their duties.
Our by-laws require the Board of Directors to meet at least once every quarter in person or by video conference, and a majority
of directors is required in order to constitute a quorum. If a quorum is not met one hour after the start time set for the meeting, the
President or his substitute may invite alternates of the same class as that of the absent directors to join the meeting, or call a meeting
for another day. Resolutions must be adopted by a majority of the directors present, and the President or his substitute is entitled to
cast the deciding vote in the event of a tie.
Duties and liabilities of Directors
In accordance with the Argentine Corporations Law, directors have an obligation to perform their duties with loyalty and with
the diligence of a prudent business person. Directors are jointly and severally liable to us, our shareholders and to third parties for the
improper performance of their duties, for violating the law or our by-laws or regulations, and for any damage caused by fraud, abuse
of authority or gross negligence. Specific duties may be assigned to a director by the by-laws, company regulations, or by resolution
of the shareholders’ meeting. In such cases, a director’s liability will be determined by reference to the performance of such duties.
Only shareholders, through a shareholders’ meeting may authorize directors to engage in activities in competition with us.
Transactions or contracts between directors and us in connection with our activities are permitted to the extent they are performed
under fair market conditions. Transactions that do not comply with the Argentine Corporations Law require prior approval of the
Board of Directors or the Supervisory Committee. In addition, these transactions must be subsequently approved by the shareholders
at a general meeting. If our shareholders do not approve the relevant transaction, the directors and members of the Supervisory
Committee who approved such transactions are jointly and severally liable for any damages caused to us.
Any director whose personal interests are adverse to ours shall notify the Board of Directors and the Supervisory Committee and
abstain from voting on such matters. Otherwise, such director may be held liable to us.
A director will not be liable if, notwithstanding his presence at the meeting at which a resolution was adopted or his knowledge
of such resolution, a written record exists of his opposition to such resolution and he reports his opposition to the Supervisory
Committee before any complaint against him is brought before the Board of Directors, the Supervisory Committee, the shareholders’
meeting, the appropriate governmental agency or the courts. Any liability of a director to us terminates upon approval of the
director’s actions by the shareholders at a general meeting, provided that shareholders representing at least 5% of our capital stock do
not object and provided further that such liability does not result from a violation of the law, our by-laws or other regulations.
Foreign Investment Legislation
Under the Argentine Foreign Investment Law, as amended, and its implementing regulations (together, referred to as the
“Foreign Investment Legislation”), the purchase of shares of an Argentine corporation by an individual or legal entity domiciled
abroad or by an Argentine company of “foreign capital” (as defined in the Foreign Investment Legislation) constitutes foreign
investment. Currently, foreign investment in industries other than broadcasting, purchase land located in frontier and other security
areas by foreigners and limits on the ownership of rural land by foreign individuals or legal entities according to Law 26,737, is not
restricted, and no prior approval is required to make foreign investments. No prior approval is required in order to purchase Class D
shares or ADSs or to exercise financial or corporate rights thereunder.
Dividends
Under our by-laws, all Class A, Class B, Class C and Class D shares rank equally with respect to the payment of dividends. All
shares outstanding as of a particular record date share equally in the dividend being paid, except that shares issued during the period
to which a dividend relates may be entitled only to a partial dividend with respect to such period if the shareholders’ meeting that
approved the issuance so resolved. No provision of our by-laws or of the Argentine Corporations Law gives rise to future special
dividends only to certain shareholders.
The amount and payment of dividends are determined by majority vote of our shareholders voting as a single class, generally,
but not necessarily, on the recommendation of the Board of Directors. In addition, under the Argentine Corporations Law, our Board
of Directors has the right to declare dividends subject to further approval of shareholders at the next shareholders’ meeting.
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After the passage of the Expropriation Law, at our shareholder’s meeting held on July 17, 2012 a dividend of Ps. 303 million
(Ps. 0.77 per share or ADS) was authorized for payment during 2012. Our strategy provides for an increased level of investments that
will require a significant reinvestment of earnings and therefore considers a potential dividend distribution consistent with such
strategy. At our shareholders’ meeting held on April 30, 2013 and its continuation on May 30, 2013, a dividend of Ps. 326 million
(Ps. 0.83 per share or ADS) was authorized for payment during August 2013. Furthermore, at the shareholders’ ordinary and
extraordinary general meeting held on April 30, 2014 and its continuation on May 21, 2014 a dividend of Ps. 464 million (Ps.
1.18 per share or ADS) was authorized for payment during July 2014. At the shareholders’ ordinary and extraordinary general
meeting held on April 30, 2015, a dividend of Ps. 503 million (Ps. 1.28 per share or ADS) was authorized for distribution by
December 31, 2015, which was paid in July 2015. On March 3, 2016, the Board agreed to propose to the Shareholders’ meeting the
following distribution of profits: (i) allocate the amount of Ps. 50 million to constitute a reserve for purchasing YPF shares pursuant
to our stock compensation plan, in order to give the opportunity to the Board to acquire YPF shares at the time it deems appropriate,
and comply, during the execution of plans, with commitments generated and to be generated in the future, (ii) allocate the amount of
Ps. 3,640 million to constitute a reserve for investments in terms of Article 70, third paragraph of Argentine General Corporation Law
No.19,550, and its amendments, and (iii) allocate the amount of Ps. 889 million to a reserve for the payment of dividends, authorizing
the Board to determine the opportunity for its distribution within a period not exceeding the end of 2016. The following table sets
forth for the periods and dates indicated, the quarterly dividend payments made by us, expressed in pesos.
Year Ended December 31,
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
Pesos Per Share/ADS
1Q 2Q 3Q 4Q
Total
— 8.00 — 4.40 12.40
— 6.00 — — 6.00
6.00 — — — 6.00
10.76 6.50 — 6.35 23.61
— 6.30 — 6.15 12.45
— 5.50 — 5.80 11.30
— 7.00 — 7.15 14.15
— — — 0.77 0.77
— — 0.83 — 0.83
— — 1.18 — 1.18
— — 1.28 — 1.28
Amount Available for Distribution
Under Argentine law, dividends may be lawfully paid only out of our retained earnings reflected in the annual audited financial
statements prepared in accordance with accounting rules prevailing in Argentina and CNV regulations and approved by a
shareholders’ meeting. The Board of Directors of a listed Argentine company that makes public offering of its shares may declare
interim dividends, in which case the members of the Board and of the Supervisory Committee is jointly and severally liables for the
repayment of such dividend if retained earnings at the close of the fiscal year in which the interim dividend was paid would not have
been sufficient to permit the payment of such dividend.
According to the Argentine Corporations Law and our by-laws, we are required to maintain a legal reserve of at least 5% of the
fiscal year’s income until such reserve equals 20% of our then-outstanding capital stock. The legal reserve is not available for
distribution to shareholders.
Under our by-laws, our net income is applied as follows:
•
•
•
•
first, at least 5% of net income, plus (less) prior year adjustments, is segregated to build the legal reserve until such reserve
is equal to 20% of our subscribed capital;
second, an amount is segregated to pay the accrued fees of the members of the Board of Directors and of the Supervisory
Committee. See “Item 6. Directors, Senior Management and Employees—Compensation of members of our Board of
Directors and Supervisory Committee”;
third, an amount is segregated to pay dividends on preferred stock, if any; and
fourth, the remainder of net income in whole or in part may be distributed as dividends to common shareholders or
allocated for voluntary or contingent reserves as determined by the shareholders’ meeting.
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Our Board of Directors submits our financial statements for the preceding fiscal year, together with reports thereon by the
Supervisory Committee and the auditors, at the annual ordinary shareholders’ meeting for approval. Within four months of the end of
each fiscal year, an ordinary shareholders’ meeting must be held to consider our yearly financial statements and determine the
allocation of our net income for such year.
Under applicable CNV regulations, cash dividends must be paid to shareholders within 30 days of the shareholders’ meeting
approving such dividends or, in the case in which the shareholders’ meeting delegates the authority to distribute dividends to the
Board of Directors, within 30 days of the Board of Directors’ meeting approving such dividends. In the case of payment of stock
dividends, or payment of both stock and cash dividends, both shares and cash are required to be available within three months of the
receipt of notice of the authorization of the CNV for the public offering of the shares arising from such dividends. In accordance with
the Argentine Civil and Commercial Code, the statute of limitations to the right of any shareholder to receive dividends declared by
the shareholders’ meeting is five years from the date on which it has been made available to the shareholder. However, according to
Article 2537 of the Argentine Civil and Commercial Code, the statute of limitations on the right of any shareholder to receive
dividends declared before August 1, 2015 is three years.
Owners of ADSs are entitled to receive any dividends payable with respect to the underlying Class D shares. Cash dividends are
paid to the Depositary in pesos, directly or through BoNY, as depositary, although we may choose to pay cash dividends outside
Argentina in a currency other than pesos, including U.S. dollars. The deposit agreement provides that the Depositary shall convert
cash dividends received by the Depositary in pesos to dollars, to the extent that, in the judgment of the Depositary, such conversion
may be made on a reasonable basis, and, after deduction or upon payment of the fees and expenses of the Depositary, shall make
payment to the holders of ADSs in U.S. dollars.
Preemptive and Accretion Rights
Except as described below, in the event of a capital increase, a holder of existing shares of a given class has a preferential right
to subscribe a number of shares of the same class sufficient to maintain the holder’s existing proportionate holdings of shares of that
class. Preemptive rights also apply to issuances of convertible securities, but do not apply upon conversion of such securities.
Pursuant to the Argentine Corporations Law, in exceptional cases and on a case-by-case basis when required for our best interest, the
shareholders at an extraordinary meeting with a special majority may decide to limit or suspend shareholders’ preemptive rights,
provided that such limitation or suspension of the shareholders’ preemptive rights is included in the agenda of the meeting and the
shares to be issued are paid in kind or are issued to cancel preexisting obligations.
Under our by-laws, we may only issue securities convertible into Class D shares, and the issuance of any such convertible
securities must be approved by a special meeting of the holders of Class D shares.
Holders of ADSs may be restricted in their ability to exercise preemptive rights if a registration statement under the Stock
Market Law relating thereto has not been filed or is not effective. Preemptive rights are exercisable during the 30 days following the
last publication of notice informing shareholders of their right to exercise such preemptive rights in the Official Gazette and in an
Argentine newspaper of wide circulation. Pursuant to the Argentine Corporations Law, if authorized by an extraordinary
shareholders’ meeting, companies authorized to make public offering of their securities, such as us, may shorten the period during
which preemptive rights may be exercised from 30 to ten days following the publication of notice of the offering to the shareholders
to exercise preemptive rights in the Official Gazette and a newspaper of wide circulation in Argentina. Pursuant to our by-laws, the
terms and conditions on which preemptive rights may be exercised with respect to Class C shares may be more favorable than those
applicable to Class A, Class B and Class D shares.
Shareholders who have exercised their preemptive rights have the right to exercise accretion rights, in proportion to their
respective ownership, with respect to any unpreempted shares, in accordance with the following procedure:
•
•
Any unpreempted Class A shares will be converted into Class D shares and offered to holders of Class D shares that
exercised preemptive rights and indicated their intention to exercise additional preemptive rights with respect to any such
Class A shares.
Any unpreempted Class B shares will be assigned to those provinces that exercised preemptive rights and indicated their
intention to exercise accretion rights with respect to such shares; any excess will be converted into Class D shares and
offered to holders of Class D shares that exercised preemptive rights and indicated their intention to exercise accretion
rights with respect to any such Class D shares.
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•
Any unpreempted Class C shares will be assigned to any PPP participants who exercised preemptive rights and indicated
their intention to exercise accretion rights with respect to such shares; any excess will be converted into Class D shares and
offered to holders of Class D shares that exercised preemptive rights and indicated their intention to exercise accretion
rights with respect to any such Class C shares.
•
Any unpreempted rights will be assigned to holders of Class D shares that exercised their preemptive rights and indicated
their intention to exercise accretion rights; any remaining Class D shares will be assigned pro rata to any holder of shares
of another class that indicated his or her intention to exercise accretion rights.
The term for exercise of additional preemptive rights is the same as that fixed for exercising preemptive rights.
Voting of the Underlying Class D Shares
Under the by-laws, each Class A, Class B, Class C and Class D share entitles the holder thereof to one vote at any meeting of
the shareholders of YPF, except that a specified number of Directors is elected by majority vote of each class (except as provided
below). See “—Directors—Election of Directors” above for information regarding the number of directors that holders of each class
of shares are entitled to elect and certain other provisions governing nomination and election of directors. The Depositary has agreed
that, as soon as practicable after receipt of a notice of any meeting of shareholders of YPF, it will mail a notice to the holders of
ADRs, evidencing ADSs, registered on the books of the Depositary which will contain the following:
•
•
•
a summary in English of the information contained in the notice of such meeting;
a statement that the holders of ADRs at the close of business on a specified record date will be entitled, subject to any
applicable provisions of Argentine law, the by-laws of YPF and the Class D shares, to instruct the Depositary to exercise
the voting rights, if any, pertaining to the Class D shares evidenced by their respective ADSs; and
a statement as to the manner in which such instructions may be given to the Depositary.
The Depositary shall endeavor, to the extent practicable, to vote or cause to be voted the amount of Class D shares represented
by the ADSs in accordance with the written instructions of the holders thereof. The Depositary will vote Class D shares, as to which
no instructions are received, in accordance with the recommendations of the Board of Directors of YPF. The Depositary will not vote
Class D shares, as to which no instructions have been received, in accordance with the recommendations of the Board of Directors,
however, unless YPF has provided to the Depositary an opinion of Argentine counsel stating that the action recommended by the
Board of Directors is not illegal under Argentine law or contrary to the by-laws or Board regulations of YPF. In addition, the
Depositary will, if requested by the Board of Directors and unless prohibited by any applicable provision of Argentine law, deposit all
Class D shares represented by ADSs for purposes of establishing a quorum at meetings of shareholders, whether or not voting
instructions with respect to such shares have been received.
Voting
Under our by-laws, each Class A, Class B, Class C and Class D share entitles the holder thereof to one vote at any meeting of
our shareholders, except that the Class A shares (i) vote separately with respect to the election of our Board of Directors and are
entitled to appoint one director and one alternate director and, (ii) have certain veto rights, as described below.
Class A Veto Rights
Under the by-laws, so long as any Class A shares remain outstanding, the affirmative vote of such shares is required in order to:
(i) decide upon the merger of the company; (ii) approve any acquisition of shares by a third party representing more than 50% of the
company’s capital; (iii) transfer to third parties all the exploitation rights granted to YPF pursuant to the Hydrocarbons Law,
applicable regulations thereunder or the Privatization Law, if such transfer would result in the total suspension of the company’s
exploration and production activities; (iv) voluntarily dissolve the company; and (v) transfer our legal or fiscal domicile outside
Argentina. The actions described in clauses (iii) and (iv) above also require prior approval of the Argentine congress through
enactment of a law.
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Reporting Requirements
Pursuant to our by-laws, any person who, directly or indirectly, through or together with its affiliates and persons acting in
concert with it, acquires Class D shares or securities convertible into Class D shares, so that such person controls more than 3% of the
Class D shares, is required to notify us of such acquisition within five days of such acquisition, in addition to complying with any
requirements imposed by any other authority in Argentina or elsewhere where our Class D shares are traded. Such notice must
include the name or names of the person and persons, if any, acting in concert with it, the date of the acquisition, the number of shares
acquired, the price at which the acquisition was made, and a statement as to whether it is the purpose of the person or persons to
acquire a greater shareholding in, or control of, us. Each subsequent acquisition by such person or persons requires a similar notice.
Certain Provisions Relating to Acquisitions of Shares
Pursuant to our by-laws:
•
each acquisition of shares or convertible securities, as a result of which the acquirer, directly or indirectly through or
together with its affiliates and persons acting in concert with it (collectively, an “Offeror”), would own or control shares
that, combined with such Offeror’s prior holdings, if any, of shares of such class, would represent:
•
•
15% or more of the outstanding capital stock, or
20% or more of the outstanding Class D shares; and
•
each subsequent acquisition by an Offeror (other than subsequent acquisitions by an Offeror owning or controlling more
than 50% of our capital prior to such acquisition) (collectively, “Control Acquisitions”), must be carried out in accordance
with the procedure described under “—Restrictions on Control Acquisitions” below.
In addition, any merger, consolidation or other combination with substantially the same effect involving an Offeror that has
previously carried out a Control Acquisition, or by any other person or persons, if such transaction would have for such person or
persons substantially the same effect as a Control Acquisition (“Related Party Share Acquisition”), must be carried out in accordance
with the provisions described under “—Restrictions on Related Party Share Acquisitions” below. The voting, dividend and other
distribution rights of any shares acquired in a Control Acquisition or a Related Party Share Acquisition carried out other than in
accordance with such provisions will be suspended, and such shares will not be counted for purposes of determining the existence of
a quorum at shareholders’ meetings.
The Expropriation Law has not triggered these obligations.
Restrictions on Control Acquisitions
Prior to consummating any Control Acquisition, an Offeror must obtain the approval of the Class A shares, if any are
outstanding, and make a public tender offer for all of our outstanding shares and convertible securities. The Offeror will be required
to provide us with notice of, and certain specified information with respect to, any such tender offer at least fifteen business days prior
to the commencement of the offer, as well as the terms and conditions of any agreement with any shareholder proposed for the
Control Acquisition (a “Prior Agreement”). We will send each shareholder and holder of convertible securities a copy of such notice
at the Offeror’s expense. The Offeror is also required to publish a notice containing substantially the same information in a newspaper
of general circulation in Argentina, New York and each other city in which our securities are traded on an exchange or other
securities market, at least once per week, beginning on the date notice is provided to us, until the offer expires.
Our Board of Directors shall call a special meeting of the holders of Class A shares to be held ten business days following the
receipt of such notice for the purpose of considering the tender offer. If the special meeting is not held, or if the shareholders do not
approve the tender offer at such meeting, neither the tender offer nor the proposed Control Acquisition may be completed.
The tender offer must be carried out in accordance with a procedure specified in our by-laws and in accordance with any
additional or stricter requirements of jurisdictions, exchanges or markets in which the offer is made or in which our securities are
traded. Under the by-laws, the tender offer must provide for the same price for all shares tendered, which price may not be less than
the highest of the following (the “Minimum Price”):
(i)
(ii)
the highest price paid by, or on behalf of, the Offeror for Class D shares or convertible securities during the two years prior
to the notice provided to us, subject to certain antidilution adjustments with respect to Class D shares;
the highest closing price for the Class D shares on the BASE during the thirty-day period immediately preceding the notice
provided to us, subject to certain antidilution adjustments;
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(iii) the price resulting from clause (ii) above multiplied by a fraction, the numerator of which shall be the highest price paid by
or on behalf of the Offeror for Class D shares during the two years immediately preceding the date of the notice provided
to us and the denominator of which shall be the closing price for the Class D shares on the BASE on the date immediately
preceding the first day in such two-year period on which the Offeror acquired any interest in or right to any Class D shares,
in each case subject to certain antidilution adjustments; and
(iv)
the net earnings per Class D share during the four most recent full fiscal quarters immediately preceding the date of the
notice provided to us, multiplied by the higher of (A) the price/earnings ratio during such period for Class D shares (if any)
and (B) the highest price/earnings ratio for us in the two-year period immediately preceding the date of the notice provided
to us, in each case determined in accordance with standard practices in the financial community.
Any such offer must remain open for a minimum of 20 days and a maximum of 30 days following the provision of notice to the
shareholders or publication of the offer, plus an additional period of a minimum of five days and a maximum of ten days required by
CNV regulations, and shareholders must have the right to withdraw tendered shares at any time up until the close of the offer.
Following the close of such tender offer, the Offeror will be obligated to acquire all tendered shares or convertible securities, unless
the number of shares tendered is less than the minimum, if any, upon which such tender offer was conditioned, in which case the
Offeror may withdraw the tender offer. Following the close of the tender offer, the Offeror may consummate any Prior Agreement
within thirty days following the close of the tender offer; provided, however, that if such tender offer was conditioned on the
acquisition of a minimum number of shares, the Prior Agreement may be consummated only if such minimum was reached. If no
Prior Agreement existed, the Offeror may acquire the number of shares indicated in the notice provided to us on the terms indicated
in such notice, to the extent such number of shares were not acquired in the tender offer, provided that any condition relating to a
minimum number of shares tendered has been met.
The Expropriation Law has not triggered these obligations.
Restrictions on Related Party Share Acquisitions
The price per share to be received by each shareholder in any Related Party Share Acquisition must be the same as, and must not
be less, than the highest of the following:
(i)
the highest price paid by or on behalf of the party seeking to carry out the Related Party Share Acquisition (an “Interested
Shareholder”) for (A) shares of the class to be transferred in the Related Party Share Acquisition (the “Class”) within the
two-year period immediately preceding the first public announcement of the Related Party Share Acquisition or (B) shares
of the Class acquired in any Control Acquisition, in each case as adjusted for any stock split, reverse stock split, stock
dividend or other reclassification affecting the Class;
(ii)
the highest closing sale price of shares of the Class on the BASE during the thirty days immediately preceding the
announcement of the Related Party Share Acquisition or the date of any Control Acquisition by the Interested Shareholder,
adjusted as described above;
(iii) the price resulting from clause (ii) multiplied by a fraction, the numerator of which shall be the highest price paid by or on
behalf of the Interested Shareholder for any share of the Class during the two years immediately preceding the
announcement of the Related Party Transaction and the denominator of which shall be the closing sale price for shares of
the Class on the date immediately preceding the first day in the two-year period referred to above on which the Interested
Shareholder acquired any interest or right in shares of the Class, in each case as adjusted as described above; and
(iv)
the net earnings per share of the shares of the Class during the four most recent full fiscal quarters preceding the
announcement of the Related Party Transaction multiplied by the higher of the (A) the price/earnings ratio during such
period for the shares of the Class and (B) the highest price/earnings ratio for us in the two-year period preceding the
announcement of the Related Party Transaction, in each case determined in accordance with standard practices in the
financial community.
In addition, any transaction that would result in the acquisition by any Offeror of ownership or control of more than 50% of our
capital stock, or that constitutes a merger or consolidation of us, must be approved in advance by the Class A shares while any such
shares remain outstanding.
Material Contracts
None.
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Exchange Regulations
See “Item 3. Key Information—Exchange Regulations” for information on the monetary and currency exchange control
restrictions in effect in Argentina.
Taxation
Argentine Tax Considerations
The following discussion is a summary of the material Argentine tax considerations relating to the purchase, ownership and
disposition of our Class D shares or ADSs.
Dividends tax
Dividends paid on our Class D shares or ADSs, whether in cash, property or other equity securities, are not subject to income
tax withholding, except for dividends paid in excess of our taxable accumulated income for the previous fiscal period, which are
subject to withholding at a rate of 35% in respect of such excess. This is a final tax, and it is not applicable if dividends are paid in
shares (acciones liberadas) rather than in cash.
Personal assets tax
Argentine individuals and undivided estates, foreign individuals and undivided estates, and foreign entities are subject to
personal assets tax of 0.5% of the value of any shares or ADSs issued by Argentine entities, held at December 31 of each year. The
tax is levied on the Argentine issuers of such shares or ADSs, such as the Company, which must pay this tax in substitution of the
relevant shareholders, and is based on the equity value (valor patrimonial proporcional), of the shares derived from the latest
financial statements at December 31 of each year. Pursuant to the Personal Assets Tax Law, we are entitled and expect to seek
reimbursement of such paid tax from the applicable shareholders, including by foreclosing on the shares, or by withholding
dividends.
Tax on debits and credits in bank accounts
Tax on debits and credits in bank accounts is levied, with certain exceptions, for debits and credits on checking accounts
maintained at financial institutions located in Argentina and other transactions that are used as a substitute for the use of checking
accounts. The general tax rate is 0.6% for each debit and credit, although in certain cases a decreased rate may apply. The account
holder may use up to 34% of the tax paid in respect of credits as a credit against other federal taxes.
Value added tax
The sale, exchange or other disposition of our Class D shares or ADSs and the distribution of dividends are exempt from the
value added tax.
Stamp taxes
Stamp taxes may apply in certain Argentine provinces if transfer of our Class D shares or ADSs is performed or executed in
such jurisdictions by means of written agreements. Transfer of our Class D shares or ADSs is exempt from stamp tax in the City of
Buenos Aires.
Estate and gift tax
The Province of Buenos Aires has imposed a tax on the reception of assets through inheritance or gift, effective January 1, 2011.
The tax rates vary from 4% to 21.925%, depending on the value of the transferred assets and the relationship between the transferor
and the transferee. The transfer of Class D shares or ADSs among residents of the Province of Buenos Aires shall be subject to this
tax if other applicable conditions are met.
Other taxes
Subject to the discussion above regarding estate and gift taxes in the Province of Buenos Aires, there are no Argentine
inheritance or succession taxes applicable to the ownership, transfer or disposition of our Class D shares or ADSs. In addition, neither
the minimum presumed income tax nor any local gross turnover tax is applicable to the ownership, transfer or disposition of our Class
D shares or ADSs.
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In the case of litigation regarding the Class D shares or ADSs before a court of the City of Buenos Aires, a 3% court fee would
be charged, calculated on the basis of the claim.
Tax treaties
Argentina has tax treaties for the avoidance of double taxation currently in force with Australia, Belgium, Bolivia, Brazil,
Canada, Denmark, Finland, France, Germany, Italy, the Netherlands, Norway, Russia, Spain, Sweden, Switzerland, the United
Kingdom and Uruguay. The tax treaties between Argentina and Chile and Argentina and Mexico have been signed but the treaties
have not yet been ratified by their governments. The new tax treaty between Argentina and Switzerland was ratified by their
governments and went into effect as of January 1, 2015. There is currently no tax treaty or convention in effect between Argentina
and the United States. It is not clear when, if ever, a treaty will be ratified or entered into effect. As a result, the Argentine tax
consequences described in this section will apply, without modification, to a holder of our Class D shares or ADSs that is a U.S.
resident. Foreign shareholders located in certain jurisdictions with a tax treaty in force with Argentina may be (i) exempted from the
payment of the personal assets tax and (ii) entitled to apply for reduced withholding tax rates on payments to be made by Argentine
parties.
Modifications to the Income Tax Law
On September 23, 2013, Law No. 26,893 introducing modifications to the Income Tax was published in the Official Gazette.
The above-mentioned modifications are mainly related to the taxability of the income originating for the purchase and sale of shares
and the collection of dividends. The scope of the law was clarified by means of the Regulatory Decree 2334. Below is a description of
the main modifications introduced by Law No. 26,893:
•
Income originating from the purchase and sale of shares
–
–
–
–
–
As from its entry into force, any income originated from the disposal of shares, quotas, equity interests, certificates,
bonds and other securities shall be taxable regardless of the subject that holds them.
However, the income originating from the transfer of those securities listed in the stock exchange or securities
market authorized by Comision Nacional de Valores, and obtained by undivided state and individuals residing in the
country is exempted.
The income obtained by overseas beneficiaries originating from the disposal of shares, quotas, equity interests,
certificates, bonds and other securities, is also subject to the tax.
When ownership corresponds to a subject abroad and the acquirer is also an individual or legal entity abroad, the tax
will be borne by the purchaser of the shares, quotas, equity interests or other security.
The tax rate is 15%. Furthermore, it was established that when income was obtained by a subject abroad, the
calculation of the tax, at the option of the taxpayer, shall be performed by using any of the methods detailed below:
•
•
Applying the 15% tax rate on 90% of the sums paid.
Applying the 15% tax rate, on the sum resulting from the deduction of the gross profit paid or credited, the
expenses incurred in the country necessary for its obtaining, maintenance and conservation, as well as the
deductions admitted by the Income Tax Law.
•
Distribution of Dividends
The collection of dividends and profits, in cash or in kind, except for shares or quotas, distributed by companies and other
entities incorporated in the country mentioned by article a), paragraphs 1,2,3,6 and 7 e paragraph b), of article 69 of the Income Tax
Law, are included in the 10% tax rate, except for the dividends received by companies and other local entities, which are still not
computed for tax purposes. Dividends distributed to overseas beneficiaries shall be subject to a one-time 10% withholding. Therefore,
every distribution of dividends performed by the Company to its shareholders shall be covered by the extension of the scope of the
tax, except for those beneficiaries that are local “subjects- companies.”
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United States Federal Income Tax Considerations
The following are the material U.S. federal income tax consequences of owning and disposing of our Class D shares or ADSs.
This discussion does not purport to be a comprehensive description of all of the tax considerations that may be relevant to a particular
person’s decision to hold such securities.
This discussion applies only if you are a U.S. Holder (as defined below) and you hold our Class D shares or ADSs as capital
assets for U.S. federal income tax purposes, and it does not describe all of the tax consequences that may be relevant to holders
subject to special rules, such as:
•
•
•
•
•
•
•
•
•
•
•
certain financial institutions;
insurance companies;
dealers and traders in securities or financial instruments, who use a mark-to-market method of tax accounting;
persons holding Class D shares or ADSs as part of a hedge, “straddle,” wash sale, conversion transaction, integrated
transaction or similar transaction or persons entering into a constructive sale with respect to the Class D shares or ADSs;
persons whose functional currency for U.S. federal income tax purposes is not the U.S. dollar;
entities classified as partnerships for U.S. federal income tax purposes;
persons liable for the alternative minimum tax;
persons who acquired our Class D shares or ADSs pursuant to the exercise of an employee stock option or otherwise as
compensation;
persons holding Class D shares or ADSs in connection with a trade or business conducted outside of the United States;
tax-exempt entities, including “individual retirement accounts” or “Roth IRAs”; or
persons holding Class D shares or ADSs that own or are deemed to own ten percent or more of our voting stock.
If an entity that is classified as a partnership for U.S. federal income tax purposes holds Class D shares or ADSs, the U.S.
federal income tax treatment of a partner will generally depend on the status of the partner and upon the activities of the partnership.
Partnerships holding Class D shares or ADSs and partners in such partnerships should consult their tax advisers as to the particular
U.S. federal income tax consequences of holding and disposing of the Class D shares or ADSs.
This discussion is based on the Internal Revenue Code of 1986, as amended (the “Code”), administrative pronouncements,
judicial decisions and final, temporary and proposed Treasury regulations, all as of the date hereof. These laws are subject to change,
possibly on a retroactive basis. It is also based in part on representations by the Depositary and assumes that each obligation under the
deposit agreement and any related agreement will be performed in accordance with its terms.
You are a “U.S. Holder” if you are a beneficial owner of Class D shares or ADSs and are, for U.S. federal income tax purposes:
•
•
•
a citizen or individual resident of the United States for U.S. federal income tax purposes;
a corporation, or other entity taxable as a corporation, created or organized in or under the laws of the United States, any
state therein or the District of Columbia; or
an estate or trust the income of which is subject to U.S. federal income taxation regardless of its source.
In general, if you own ADSs, you will be treated as the owner of the underlying shares represented by those ADSs for U.S.
federal income tax purposes. Accordingly, no gain or loss will be recognized if you exchange ADSs for the underlying shares
represented by those ADSs.
202
The U.S. Treasury has expressed concerns that parties to whom American depositary shares are released before the underlying shares are
delivered to the depositary, or intermediaries in the chain of ownership between U.S. Holders and the issuer of the shares underlying the
American depositary shares, may be taking actions that are inconsistent with the claiming of foreign tax credits by U.S. holders of American
depositary shares. Such actions would also be inconsistent with the claiming of the reduced rate of tax, described below, applicable to
dividends received by certain non-corporate holders. Accordingly, the analysis of the creditability of Argentine taxes, and the availability of
the reduced tax rate for dividends received by certain non-corporate holders, each described below, could be affected by actions taken by such
parties or intermediaries.
Please consult your own tax adviser concerning the U.S. federal, state, local and foreign tax consequences of owning and disposing of
Class D shares or ADSs in your particular circumstances.
This discussion assumes that YPF is not, and will not become, a passive foreign investment company, as described below.
Taxation of distributions
Distributions paid on Class D shares or ADSs, other than certain pro rata distributions of ordinary shares, will be treated as dividends to
the extent paid out of current or accumulated earnings and profits (as determined under U.S. federal income tax principles). Because we do not
maintain calculations of earnings and profits under U.S. federal income tax principles, it is expected that distributions will generally be
reported to U.S. Holders as dividends. Subject to applicable limitations (including a minimum holding period requirement), the discussion
above regarding concerns expressed by the U.S. Treasury and the discussion below regarding passive foreign investment company rules,
certain non-corporate U.S. dividends paid by qualified foreign corporations to certain non-corporate U.S. Holders are taxable at a maximum
rate of 20%. Some non-corporate U.S. Holders may also be subject to a 3.8% net investment surtax. A foreign corporation is treated as a
qualified foreign corporation with respect to dividends paid on stock that is readily tradable on an established securities market in the United
States, such as the NYSE, where our ADSs are listed. You should consult your own tax adviser to determine whether the favorable rate may
apply to dividends you receive in respect of our Class D shares or ADSs and whether you are subject to any special rules that limit your ability
to be taxed at this favorable rate. The amount of a dividend will include any amounts withheld by us in respect of Argentine income taxes. The
dividends will be treated as foreign-source dividend income and will not be eligible for the dividends-received deduction generally allowed to
U.S. corporations under the Code.
Any dividends paid in Argentine pesos will be included in your income in a U.S. dollar amount calculated by reference to the exchange
rate in effect on the date of your, or in the case of ADSs, the Depositary’s, receipt of the dividend, regardless of whether the payment is in fact
converted into U.S. dollars. If the dividend is converted into U.S. dollars on the date of receipt, you generally would not recognize foreign
currency gain or loss in respect of the dividend income. You may have foreign currency gain or loss if the dividend is converted into U.S.
dollars after the date of receipt. Foreign currency gain or loss that you recognize will generally be treated as U.S.-source ordinary income.
Subject to applicable limitations (including a minimum holding period requirement) that may vary depending upon your circumstances
and, in the case of ADSs, subject to the discussion above regarding concerns expressed by the U.S. Treasury, Argentine income taxes, if any,
withheld from dividends on Class D shares or ADSs will be creditable against your U.S. federal income tax liability. Amounts paid on account
of the Argentine personal assets tax will not be eligible for credit against your U.S. federal income tax liability. You should consult your tax
adviser to determine the tax consequences applicable to you as a result of the payment of the Argentine personal assets tax or the withholding
of the amount of such tax from distributions, including whether such amounts are includible in income or are deductible for U.S. federal
income tax purposes. The rules governing the foreign tax credit are complex. You are urged to consult your tax adviser regarding the
availability of the foreign tax credit under your particular circumstances.
Sale or other disposition of Class D shares or ADSs
For U.S. federal income tax purposes, gain or loss you realize on the sale or other disposition of Class D shares or ADSs will, subject to
the discussion below regarding passive foreign investment company rules, be capital gain or loss and will be long-term capital gain or loss if
you held the Class D shares or ADSs for more than one year. The amount of your gain or loss will be equal to the difference between the
amount realized on the disposition and your tax basis in the relevant Class D shares or ADSs, each as determined in U.S. dollars. The
deductibility of capital losses is subject to limitations.
If Argentine income tax is withheld on the sale or other taxable disposition of a Class D share or ADS, the amount realized by a U.S.
Holder will include the gross amount of the proceeds of the sale or other taxable disposition before deduction of such tax. Capital gain or loss,
if any, realized by a U.S. Holder on the sale or other taxable disposition of the Class D share or ADS generally will be treated as U.S.-source
gain or loss for U.S. foreign tax credit purposes. Consequently, in the case of a gain from the disposition of a Class D share or ADS that is
subject to Argentine income tax, the U.S. Holder may not be able to benefit from the U.S. foreign tax credit for the tax unless the U.S. Holder
can apply the credit against U.S. federal income tax payable on other income from foreign sources. Alternatively, the U.S. Holder may take a
deduction for the Argentine income tax if it does not elect to claim a foreign tax credit for any non-U.S. income taxes paid during the taxable
year.
203
Passive foreign investment company rules
YPF believes that it was not a “passive foreign investment company” (“PFIC”) for U.S. federal income tax purposes for the
taxable year of 2015 and does not expect to be a PFIC in the foreseeable future. However, since PFIC status depends upon the
composition of a company’s income and assets and the market value of its assets (including, among other things, less than 25 percent
owned equity investments) from time to time, there can be no assurance that YPF will not be considered a PFIC for any taxable year.
If YPF were treated as a PFIC for any taxable year during which you held a Class D share or ADS, you generally would be subject to
additional filing requirements, imputed interest charges and other disadvantageous tax treatment (including the denial of taxation at
the lower rates applicable to long-term capital gains with respect to any gain from the sale or exchange of Class D shares or ADSs).
Certain elections might be available that would result in alternative treatments (such as mark-to-market treatment). U.S. Holders
should consult their tax advisers to determine whether any of these elections would be available and, if so, what the consequences of
the alternative treatments would be in their particular circumstances.
In addition, if YPF were to be treated as a PFIC in a taxable year in which it paid a dividend or the prior taxable year, the 20%
dividend rate discussed above with respect to dividends paid by qualified foreign corporations to certain non-corporate holders would
not apply.
Information reporting and backup withholding
Payments of dividends and sales proceeds that are made within the United States or through certain U.S.-related financial
intermediaries generally are subject to information reporting and may be subject to backup withholding unless (i) you are an exempt
recipient or (ii) in the case of backup withholding, you provide a correct taxpayer identification number and certify that you are not
subject to backup withholding.
The amount of any backup withholding from a payment to you will be allowed as a credit against your U.S. federal income tax
liability and may entitle you to a refund, provided that the required information is timely furnished to the Internal Revenue Service.
Certain U.S. Holders may be required, generally on IRS Form 8938, to report information relating to their ownership of
securities of a non-U.S. person, subject to certain exceptions (including an exception for stock held in certain accounts maintained by
a U.S. financial institution, such as our ADSs). A U.S. Holder who fails to timely furnish the required information may be subject to a
penalty. U.S. Holders are urged to consult their tax advisers regarding the effect, if any, of these rules on their ownership and
disposition of Class D shares or ADSs.
Available Information
YPF is subject to the information requirements of the U.S. Securities Exchange Act (the “Exchange Act”), except that as a
foreign issuer, YPF is not subject to the proxy rules or the short-swing profit disclosure rules of the Exchange Act. In accordance with
these statutory requirements, YPF files or furnishes reports and other information with the SEC. Reports and other information filed
or furnished by YPF with the SEC may be inspected and copied at the public reference facilities maintained by the SEC at 100 F
Street, N. E., Washington, D.C. 20549. Copies of such material may be obtained by mail from the Public Reference Section of the
SEC at 100 F Street, N.E., Washington, D.C. 20549, at prescribed rates. You may obtain information on the operation of the Public
Reference Section by calling the SEC at +1-800-732-0330. The SEC maintains a World Wide Web site on the Internet at
http://www.sec.gov that contains reports and information statements and other information regarding us. Such reports and other
information may also be inspected at the offices of the New York Stock Exchange, 11 Wall Street, New York, New York 10005, on
which YPF’s American Depositary Shares are listed.
ITEM 11. Quantitative and Qualitative Disclosures about Market Risk
The following quantitative and qualitative information is provided about financial instruments to which we are a party as of
December 31, 2015, and from which we may derive gains or incur losses from changes in market, interest rates, foreign exchange
rates or commodity prices. We do not enter into derivative or other financial instruments for trading purposes.
This discussion contains forward-looking statements that are subject to risks and uncertainties. Actual results could vary
materially as a result of a number of factors including those set forth in “Item 3. Key Information—Risk Factors.”
204
Foreign currency exposure
The value of financial assets and liabilities denominated in a currency different from the Company’s functional currency is
subject to variations resulting from fluctuations in exchange rates. Since YPF’s functional currency is the U.S. dollar, the currency
that generates the greatest exposure is the Argentine peso, the Argentine legal currency. See Note 1.d to the Audited Consolidated
Financial Statements).
In addition, our costs and receipts denominated in currencies other than the Argentine peso, including the U.S. dollar, often do
not match. We generally follow a policy of not hedging our debt obligations in U.S. dollars. See “Item 3. Key Information—Risk
Factors—Risks Relating to Argentina—We may be exposed to fluctuations in foreign exchange rates.”
Additionally, YPF is enabled to operate as settlement agent in the Rosario Futures Market (“ROFEX”). In this regard, in
October 2015, YPF acquired ROFEX futures contracts whose underlying asset is the U.S. dollar, for a total of U.S.$ 255, which
mature between February and May 2016. See Note 11.c to the Audited Consolidated Financial Statements.
The annual rate of devaluation of the Argentine peso was approximately 52.1% considering the period-end exchange rates for
U.S. dollars as of December 31, 2015 and 2014. See “Item 5. Operating and Financial Review and Prospects—Macroeconomic
Conditions” for additional information. The main effects of a devaluation of the Argentine Peso on our net income are those related to
the accounting of deferred income tax related mainly to fixed assets, which we expect would have a negative effect; current income
tax which we expect would have a positive effect; increased depreciation and amortization resulting from the remeasurement in pesos
of our fixed and intangible assets; and exchange rate differences as a result of our exposure to the peso, which we expect would have
a positive effect due to the fact that our functional currency is the U.S. dollar. See “Item 3. Key Information—Risk Factors—Risks
Relating to Argentina—We may be exposed to fluctuations in foreign exchange rates.”
As mentioned in Note 1.b to Audited Consolidated Financial Statements, the Company has determined that the U.S. dollar is its
functional currency. Therefore, the effect of changes in the dollar exchange rate on dollar currency positions have no impact on the
exchange difference recorded in the consolidated statements of comprehensive income included in the Audited Consolidated
Financial Statements, but affect the amount of our assets and liabilities remeasured in pesos as a consequence of devaluation and
considering our reporting currency (pesos). For additional information about our assets and liabilities denominated in currencies other
than pesos (principally U.S. dollars) see Annex iii to our Audited Consolidated Financial Statements.
Interest rate exposure
The table below provides information about our assets and liabilities as of December 31, 2015 that may be sensitive to changes
in interest rates. See “Item 3. Key Information—Risk Factors—Risks Relating to Argentina—Variations in interest rates and
exchange rate on our current and/or future financing arrangements may result in significant increases in our borrowing costs.”
Assets
Fixed rate
Other Receivables
Interest rate
Variable rate
Other Receivables
Interest rate
Liabilities
YPF’s Negotiable Obligations
Interest rate
Other debt
Interest rate
Variable rate
YPF’s Negotiable Obligations
Interest rate
Other debt
Interest rate
Less than
1 year
1 – 2 years
2 – 3 years
Expected Maturity Date
3 – 4 years
(in millions of pesos)
4 – 5 years
More than
5 years
Total Fair Value
667
—
—
—
—
—
667
667
3.5%-
22.5%
44
10
CER(1)+8%
10
CER(1)+8%
10
CER(1)+8%
—
—
74
74
CER(1)+8%/
2
20.71%
24.64%
7,899
2%-8.875%
12,379
1,850
1.29%
25.75%
225
2%-31%
2%-26%
13,304
3.5%
8.875%
28
9.38%-
15.23%
157
3.5%
8.875%
12
9.38%-
15.23%
157
36,629 59,997
60,500
3.5% 8.5%-10%
—
17 12,661
12,648
15.23%
1,669
3,428
4,503
3,519
5,716
2,667 21,501
21,501
BADLAR(2)
+3.2%-
4.25% /
LIBOR
+7.5%
3,125
Libor +4-
BADLAR (2)
+3.5 +
4.75% /
LIBOR
+7.5%
1,398
Libor +4-
BADLAR (2)
+0%- 4.75%
/ LIBOR
+7.5%
BADLAR (2)
+ 0%-
+4.75%
BADLAR (2)
0%-+4.75%
BADLAR (2)
0%-0.1%
4,106
214
40
— 8,883
8,883
Libor +6%-
Libor +6%-
Libor +6%-
6.5%/
BADLAR(2)
+3-+4.5%%
6.2%/
BADLAR(2)
+3%-+4.5%
6.5%/
BADLAR
+3%
6.2%/
BADLAR
+3%
6.2%/
BADLAR
+3%
(1) Coeficiente de Estabilización de Referencia (CER) is a reference stabilization index established by the Public Emergency Law
and published by the Argentine Central Bank.
(2) Refers to the average interest rate that banks pay for deposits of more than Ps. 1 million.
205
Crude oil and other hydrocarbon product price exposure
Our results of operations are also exposed to volatility mainly in the prices of certain oil products, especially in connection with
imports. Although we have occasionally contracted financial derivatives in the past with the aim of decreasing exposure to these
commodities price risks, as of the date of this annual report YPF was not a party to any commodity hedging instruments in conection
with crude oil and other hydrocarbon product prices. For information on our hydrocarbons delivery commitments as of December 31,
2015, see “Item 4. Information on the Company—Exploration and Production—Delivery commitments.”
ITEM 12. Description of Securities Other than Equity Securities
American Depositary Shares
Our ADSs are listed on the NYSE under the symbol “YPF.” The Bank of New York Mellon is the Depositary. Each ADS
represents the right to receive one share.
The Depositary collects its fees for delivery and surrender of ADSs directly from investors depositing shares or surrendering
ADSs for the purpose of withdrawal or from intermediaries acting for them. The Depositary collects fees for making distributions to
investors by deducting those fees from the amounts distributed or by selling a portion of distributable property to pay the fees. The
Depositary may collect its annual fee for depositary services by deductions from cash distributions or by directly billing investors or
by charging the book-entry system accounts of participants acting for them. The Depositary may generally refuse to provide fee-
attracting services until its fees for those services are paid.
The table below sets forth the fees payable, either directly or indirectly, by a holder of ADSs as of the date of this annual report.
Persons depositing or withdrawing shares must pay:
U.S.$5.00 (or less) per 100 ADSs (or portion of 100 ADSs)
Cancellation of ADSs for the purpose of withdrawal
A fee equivalent to the fee that would be payable if securities
distributed to a holder had been shares and the shares had been
deposited for issuance of ADSs
Transfer fees, as may from time to time be in effect
For:
Issuance of ADRs (including, without limitation, issuance
pursuant to a stock dividend or stock split declared by YPF, an
exchange of stock or a distribution of rights) and surrender of
ADRs
Sale, on behalf of the holder, of rights to subscribe for
additional shares or any right of any nature distributed by YPF
Transfer and registration of shares on YPF share register to or
from the name of the depositary or its agent when a holder
deposits or withdraws shares
206
Expenses of the depositary
Cable, telex and facsimile transmission expenses, as provided in
the deposit agreement
Expenses incurred by the depositary in the conversion of
foreign currency(1)
Taxes and other governmental charges the depositary or the
custodian have to pay on any ADS or share underlying an ADS, for
example, stock transfer taxes, stamp duty or withholding taxes
As necessary
(1) Pursuant to our deposit agreement, whenever the depositary shall receive foreign currency, as a cash dividend or other distribution
which, in the judgment of the depositary, can be converted on a reasonable basis into U.S. dollars and transferred to the United
States, it will convert such foreign currency into U.S. dollars and transfer the resulting U.S. dollars (after deduction of its
customary charges and expenses in effecting such conversion) to the United States.
In 2015, the Depositary made no direct or indirect payments to YPF.
ITEM 13. Defaults, Dividend Arrearages and Delinquencies
None.
PART II
ITEM 14. Material Modifications to the Rights of Security Holders and Use of Proceeds
None.
ITEM 15. Controls and Procedures
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
As of December 31, 2015, YPF, under the supervision and with the participation of YPF’s management, including our current
Principal Executive Officer and Principal Financial Officer, performed an evaluation of the effectiveness of the design and operation of
our disclosure controls and procedures (as defined in Rule 13a-15(e) or Rule 15d-15(e) under the Exchange Act). There are, as described
below, inherent limitations to the effectiveness of any control system, including disclosure controls and procedures. Accordingly, even
effective disclosure controls and procedures can provide only reasonable assurance of achieving their control objectives.
Based on such evaluation, YPF’s Principal Executive Officer and Principal Financial Officer concluded that YPF’s disclosure
controls and procedures were effective at the reasonable assurance level in ensuring that information relating to YPF, required to be
disclosed in reports it files under the Exchange Act is (1) recorded, processed, summarized and reported within the time periods
specified in the SEC’s rules and forms, and (2) accumulated and communicated to our management, including our Principal Executive
Officer and Principal Financial Officer, as appropriate to allow timely decisions regarding required disclosure.
Management’s Report on Internal Control Over Financial Reporting
Management of YPF is responsible for establishing and maintaining adequate internal control over financial reporting (as defined
in Rule 13a-15(f) under the Exchange Act). YPF’s internal control over financial reporting is a process designed to provide reasonable
assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance
with IFRS and includes those policies and procedures that:
•
•
•
Pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions
of the assets of YPF;
Provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in
accordance with generally accepted accounting principles, and that our receipts and expenditures are being made only in
accordance with authorizations of YPF’s management and directors; and
Provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our
assets that could have a material effect on the financial statements.
207
Because of its inherent limitations, any system of internal control over financial reporting, no matter how well designed, may
not prevent or detect misstatements, due to the possibility that a control can be circumvented or overridden or that misstatements due
to error or fraud may occur that are not detected. Also, projections of any evaluation of effectiveness to future periods are subject to
the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or
procedures may deteriorate.
Under the supervision and with the participation of YPF’s management, including our current Principal Executive Officer and
Principal Financial Officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on
the criteria established in Internal Control-Integrated Framework (2013 framework) issued by the Committee of Sponsoring
Organizations of the Treadway Commission (“the COSO criteria”). Based on this assessment, our management concluded that, as of
December 31, 2015, our internal control over financial reporting was effective based on those criteria.
Our internal control over financial reporting as of December 31, 2015 has been audited by Deloitte & Co. S.A., an independent
registered public accounting firm, as stated in their report included in the F-pages.
Changes in Internal Control Over Financial Reporting
There has been no change in YPF’s internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange
Act) that occurred during the period covered by this annual report on Form 20-F that has materially affected, or is reasonably likely to
materially affect, internal control over financial reporting.
ITEM 16.
ITEM 16A.
Audit Committee Financial Expert
Our Board of Directors determined that Carlos Felices is an Audit Committee Financial Expert at the meeting held on
December, 22, 2015. YPF believes that Mr. Felices possesses the attributes of an Audit Committee Financial Expert set forth in the
instructions to Item 16A of Form 20-F. Mr. Felices is an independent director.
ITEM 16B.
Code of Ethics
YPF has adopted a Code of Ethics and Conduct (“Code of Ethics”) applicable to the Board of Directors and all employees,
which was most recently amended effective August 22, 2014. Since January 1, 2015, we have not waived compliance with the Code
of Ethics. YPF undertakes to provide to any person without charge, upon request, a copy of such Code of Ethics.
The Code of Ethics establishes the implementation of an ethics hotline to receive complaints regarding the lack of fulfilment of
the Code of Ethics, an Ethics Committee that will consider complaints received, the appointment of an Ethics Officer who will
conduct pertinent investigations, the incorporation of a policy on prohibited periods for trading YPF securities to be followed by
officers and those others to whom the Code of Ethics is applicable when conducting stock transactions, among other requirements.
A copy of the Code of Ethics can be found at the Company’s web page, www.ypf.com, or it can be requested in writing by
telephone or facsimile from us at the following address:
YPF S.A.
Office of Shareholders Relations
Macacha Güemes 515
C1106BKK Buenos Aires, Argentina
Tel. (011-54-11) 5441-3500
Fax (011-54-11) 5441-3726
208
ITEM 16C.
Principal Accountant Fees and Services
The following table provides information on the aggregate fees billed by our principal accountants, Deloitte & Co. S.A. and
affiliates by type of service rendered for the periods indicated.
Services Rendered
Audit Fees
Audit-Related Fees (1)
Tax Fees
All Other Fees
2015
2014
2013
Fees
Expenses
Fees
Expenses Fees
Expenses
(in thousands of pesos)
41,561
2,384
895
2,824
47,664
931 30,156
—
—
—
— 34,637
3,646 —
666 —
170 —
651 18,943
455
85
288
651 19,771
295
—
—
—
295
(1)
Includes the fees for the issuance of agreed upon procedures reports.
The annual shareholders’ meeting of YPF appoints the external auditor of YPF, along with the Audit Committee’s non-binding
opinion, which is submitted for consideration to the annual shareholders’ meeting.
The Audit Committee of YPF has a pre-approval policy regarding the contracting of YPF’s external auditor, or any affiliate of
the external auditor, for professional services. The professional services covered by such policy include audit and non-audit services
provided to YPF or any of its subsidiaries.
The pre-approval policy is as follows:
1.
2.
The Audit Committee must pre-approve all audit and non-audit services to be provided to YPF or any of its subsidiaries by
the external auditor (or any of its affiliates) of YPF.
The Chairman of the Audit Committee has been delegated the authority to approve the hiring of YPF’s external auditor (or
any of its affiliates) without first obtaining the approval of the Audit Committee for any of the services which require pre-
approval as described in (1) above.
Services approved by the Chairman of the Audit Committee as set forth above must be ratified at the next plenary meeting of the
Audit Committee.
All of the services described in the table above were approved by the Audit Committee of YPF.
ITEM 16D.
Exemptions from the Listing Standards for Audit Committees
None
ITEM 16E.
Purchases of Equity Securities by the Issuer and Affiliated Purchasers
Period
January 2015
February 2015
March 2015
April 2015
May 2015
June 2015
Total Number
of Shares
Purchased
Average Prices
Paid per Share
(Ps. per share)
Total Number of Shares
Purchased as Part of
Publicly Announced
Plans or Programs
Maximum Approximate Ps.
Value of Shares that May
Yet Be Purchased Under
the Plans or Programs (a)
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
120,000,000
June 2015 (from 09/06/2015
to 30/06/2015)
179,514
297.77
179,514
66,546,205
July 2015 (from 01/07/2015
to 31/07/2015)
August 2015 (from 03/08/2015
173,521
331.30
173,521
9,057,923
to 05/08/2015)
September 2015
October 2015
November 2015
December 2015
29,950
302.43
—
—
—
—
—
—
29,950
—
—
—
—
—
—
—
—
(a) The Board of Directors, at its meeting held on June 8, 2015, approved a Stock Compensation Plan for employees, which allows
YPF to repurchase its shares on the BASE and NYSE for an aggregate amount of up to Ps. 120 million.
See Note 1.b.10.iii to the Audited Consolidated Financial Statements.
209
ITEM 16F.
Change in Registrant’s Certifying Accountant
During the years ended December 31, 2015, 2014 and 2013 and through the date of this annual report, the principal independent
accountant engaged to audit our financial statements, Deloitte & Co S.A., has not resigned, indicated that it has declined to stand for
re-election after the completion of its current audit or been dismissed.
ITEM 16G.
Corporate Governance
See “Item 6. Directors, Senior Management and Employees—Compliance with New York Stock Exchange Listing Standards on
Corporate Governance.”
PART III
ITEM 17. Financial Statements
The registrant has responded to Item 18 in lieu of responding to this Item.
ITEM 18. Financial Statements
The following financial statements are filed as part of this annual report:
Reports of Independent Registered Public Accounting Firm
Consolidated Statements of Comprehensive Income of YPF S.A. for the years ended December 31, 2015, 2014 and 2013
Consolidated Statement of Financial Position of YPF S.A. as of December 31, 2015, 2014 and 2013
Consolidated Statements of Cash Flow of YPF S.A. for the years ended December 31, 2015, 2014 and 2013
Consolidated Statements of Changes in Shareholders’ Equity of YPF S.A. for the years ended December 31, 2015, 2014 and
F-2
F-8
F-7
F-12
F-9
F-13
2013
Notes to the Audited Consolidated Financial Statements of YPF S.A. for the years ended December 31, 2015, 2014 and
2013
ITEM 19. Exhibits
1.1
1.2
11.1
12.1
12.2
13.1
23.1
23.2
By-laws (Estatutos) of YPF S.A. as amended (Spanish Version) *
By-laws (Estatutos) of YPF S.A. as amended (English Version) **
Code of Ethics***
Section 302 Certification by Chief Executive Officer
Section 302 Certification by Chief Financial Officer
Section 906 Certification
Consent of DeGolyer and MacNaughton
Consent of IHS Global Canada Limited
99.1(a)
Reserves Audit Report of DeGolyer and MacNaughton for Maxus Energy Corporation as of December 31, 2015, dated
January 25, 2016.
99.1(b)
Reserves Audit Report of IHS Global Canada Limited for YPF S.A. as of December 31, 2015, dated February 17, 2016.
Filed as Exhibit 1.1 to YPF’s 2009 annual report on Form 20-F filed on June 29, 2010.
Filed as Exhibit 1.2 to YPF’s 2009 annual report on Form 20-F filed on June 29, 2010.
*
**
*** Incorporated by reference to YPF’s 2014 annual report on Form 20-F filed on March 30, 2015.
210
The registrant hereby certifies that it meets all of the requirements for filing on Form 20-F and that it has duly caused and authorized
the undersigned to sign this annual report on its behalf.
SIGNATURES
YPF SOCIEDAD ANÓNIMA
By: /s/ Daniel Gonzalez
Name: Daniel Gonzalez
Title: Chief Financial Officer
Dated: March 17, 2016
211
SOCIEDAD ANONIMA
Consolidated Financial Statements
as of December 31, 2015
and Comparative Information
Independent Auditors’ Report
Report of Independent Registered Public Accounting Firm
To the Board of Directors and Shareholders of YPF SOCIEDAD ANONIMA:
We have audited the accompanying consolidated statements of financial position of YPF SOCIEDAD ANONIMA (an Argentine
Corporation) and its controlled companies (the “Company”) as of December 31, 2015, 2014 and 2013, and the related consolidated
statements of comprehensive income, cash flows and changes in shareholders’ equity for each of the three years in the period ended
December 31, 2015. These consolidated financial statements are the responsibility of the Company’s Management. Our responsibility
is to express an opinion on these consolidated financial statements based on our audits.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States of
America). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated
financial statements are free of material misstatements. An audit includes examining, on a test basis, evidence supporting the amounts
and disclosures in the consolidated financial statements. An audit also includes assessing the accounting principles used and
significant estimates made by Management, as well as evaluating the overall consolidated financial statements presentation. We
believe that our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of
YPF SOCIEDAD ANONIMA and its controlled companies as of December 31, 2015, 2014 and 2013, and the results of their
operations and their cash flows for each of the three years in the period ended December 31, 2015, in conformity with International
Financial Reporting Standards (“IFRS”) as issued by International Accounting Standards Board (“IASB”).
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States of
America), the Company’s internal control over financial reporting as of December 31, 2015, based on the criteria established in
Internal Control—Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission
and our report dated March 3, 2016, expressed an unqualified opinion on the Company’s internal control over financial reporting.
Buenos Aires City, Argentina
March 3, 2016
Deloitte & Co. S.A.
/s/ Guillermo D. Cohen
Partner
Report of Independent Registered Public Accounting Firm
To the Board of Directors and Shareholders of YPF SOCIEDAD ANONIMA:
We have audited the internal control over financial reporting of YPF SOCIEDAD ANONIMA (an Argentine Corporation) and its
controlled companies (the “Company”) as of December 31, 2015, based on the criteria established in Internal Control—Integrated
Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s
management is responsible for maintaining effective internal control over financial reporting and for its assessment of the
effectiveness of internal control over financial reporting included in the accompanying Management’s Report on Internal Control
over Financial Reporting (Item 15). Our responsibility is to express an opinion on the Company’s internal control over financial
reporting based on our audit.
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States of
America). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal
control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal
control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating
effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the
circumstances. We believe that our audit provides a reasonable basis for our opinion.
A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal
executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors,
management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation
of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal
control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in
reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable
assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally
accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with
authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely
detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial
statements.
Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper
management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely
basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are
subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with
the policies or procedures may deteriorate.
In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of
December 31, 2015, based on the criteria established in Internal Control—Integrated Framework (2013) issued by the Committee of
Sponsoring Organizations of the Treadway Commission.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States of
America), the consolidated financial statements of YPF SOCIEDAD ANONIMA and its controlled companies as of and for the year
ended December 31, 2015 and our report dated March 3, 2016 expressed an unqualified opinion on those consolidated financial
statements.
Buenos Aires City, Argentina
March 3, 2016
Deloitte & Co. S.A.
/s/ Guillermo D. Cohen
Partner
CONSOLIDATED FINANCIAL STATEMENTS AS OF DECEMBER 31, 2015
AND COMPARATIVE INFORMATION
Index
– Cover
– Consolidated statements of financial position
– Consolidated statements of comprehensive income
– Consolidated statements of changes in shareholders’ equity
– Consolidated statements of cash flow
– Notes to the consolidated financial statements:
1) Basis of preparation of the consolidated financial statements
a. Basis of preparation
b. Significant Accounting Policies
c. Accounting Estimates and Judgments
d. Comparative Information
2) Acquisitions and disposals
3) Financial Risk Management
4) Segment information
5) Financial instruments by category
6) Analysis of the main accounts of the consolidated financial statements
a. Intangible assets
b. Fixed assets
c. Investments in companies
d. Inventories
e. Other receivables
f.
Trade receivables
g. Cash and cash equivalents
h. Provisions
i.
Income Tax
j.
Loans
k. Accounts payable
l.
Revenues
m. Cost of sales
n. Expenses
o. Other operating results, net
p. Financial results, net
Page
F-6
F-7
F-8
F-9
F-12
F-13
F-15
F-35
F-37
F-37
F-41
F-45
F-46
F-50
F-50
F-52
F-52
F-53
F-53
F-53
F-54
F-55
F-56
F-59
F-59
F-59
F-60
F-61
F-61
7) Investments in Companies and joint operations
8) Shareholders’ equity
9) Earnings per share
10) Provisions for pending lawsuits, claims and environmental liabilities
11) Contingent liabilities, contingent assets, contractual commitments, main regulations and other
a. Contingent liabilities
b. Contingent assets
c. Contractual Commitments
d. Main regulations and other
12) Balances and transactions with Related Parties
13) Employee benefit plans and share-based payments
14) Operating Leases
15) Information required by regulatory authorities
16) Investments in companies
17) Interest in Joint Operations and other exploration and production agreements
18) Assets and liabilities in currencies other than the Argentine peso
19) Subsequent events
20) Supplemental information on Oil and Gas producing activities (unaudited)
F-61
F-62
F-63
F-63
F-86
F-89
F-90
F-98
F-108
F-111
F-113
F-114
F-115
F-117
F-118
F-119
F-119
YPF SOCIEDAD ANONIMA
Macacha Güemes 515 – Autonomous City of Buenos Aires, Argentina
FISCAL YEAR NUMBER 39
BEGINNING ON JANUARY 1, 2015
CONSOLIDATED FINANCIAL STATEMENTS AS OF DECEMBER 31, 2015 AND COMPARATIVE INFORMATION
LEGAL INFORMATION
Principal business of the Company: exploration, development and production of oil, natural gas and other minerals and refining,
transportation, marketing and distribution of oil and petroleum products and petroleum derivatives, including petrochemicals,
chemicals and non-fossil fuels, biofuels and their components; production of electric power from hydrocarbons; rendering
telecommunications services, as well as the production, industrialization, processing, marketing, preparation services, transportation
and storage of grains and its derivatives.
Filing with the Public Registry: Bylaws filed on February 5, 1991 under No. 404, Book 108, Volume “A”, Corporations, with the
Public Registry of Buenos Aires City, in charge of Inspección General de Justicia (Argentine Registrar of Companies); and Bylaws in
substitution of previous Bylaws, filed on June 15, 1993, under No. 5109, Book 113, Volume “A”, Corporations, with the above
mentioned Registry.
Duration of the Company: through June 15, 2093.
Last amendment to the bylaws: April 14, 2010.
Optional Statutory Regime related to Compulsory Tender Offer provided by Decree No. 677/2001 art. 24: not incorporated (modified
by Law No. 26,831).
Capital structure as of December 31, 2015
(expressed in Argentine pesos)
– Subscribed, paid-in and authorized for stock exchange listing
3,933,127,930 (1)
(1) Represented by 393,312,793 shares of common stock, Argentine pesos 10 per value and 1 vote per share
F-6
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
CONSOLIDATED STATEMENTS OF FINANCIAL POSITION AS OF DECEMBER 31, 2015, 2014 AND 2013
(Amounts expressed in millions of Argentine Pesos, except shares and per share amounts expressed in Argentine Pesos, and as
otherwise indicated – Note 1.b.1)
ASSETS
Noncurrent Assets
Intangible assets
Fixed assets
Investments in companies
Deferred income tax assets, net
Other receivables
Trade receivables
Total noncurrent assets
Current Assets
Inventories
Other receivables
Trade receivables
Investment in financial assets
Cash and cash equivalents
Total current assets
TOTAL ASSETS
SHAREHOLDER’S EQUITY
Shareholders’ contributions
Reserves, other comprehensive income and retained earnings
SHAREHOLDERS’EQUITY ATTRIBUTABLE TO THE SHAREHOLDERS OF
THE PARENT COMPANY
Non-controlling interest
TOTAL SHAREHOLDERS’ EQUITY
LIABILITIES
Noncurrent Liabilities
Provisions
Deferred income tax liabilities, net
Taxes payable
Salaries and social security
Loans
Accounts Payable
Total noncurrent liabilities
Current Liabilities
Provisions
Income tax liability
Taxes payable
Salaries and social security
Loans
Accounts Payable
Total current liabilities
TOTAL LIABILITIES
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY
Notes
2015
2014
2013
6.a 7,279 4,393
2,446
6.b 270,905 156,930 93,496
2,124
6.c 4,372 3,177
6.i
34
244
954
2,927
6.e 2,501 1,691
54
19
469
6.f
286,480 166,454 101,081
6.d 19,258 13,001
9,881
6.e 19,413 7,170
6,506
6.f 22,111 12,171
7,414
—
804 —
5
6.g 15,387 9,758 10,713
76,973 42,100 34,514
363,453 208,554 135,595
10,349 10,400 10,600
110,064 62,230 37,416
120,413 72,630 48,016
224
120,461 72,781 48,240
151
48
207
299
— —
6.h 39,623 26,564 19,172
6.i 44,812 18,948 11,459
362
8
6.j 77,934 36,030 23,076
470
6.k
163,201 82,407 54,547
625
566
1,396
6.h 2,009 2,399
122
1,487 3,972
1,045
6,047 1,411
1,119
2,452 1,903
6.j 27,817 13,275
8,814
6.k 39,979 30,406 20,312
79,791 53,366 32,808
242,992 135,773 87,355
363,453 208,554 135,595
Accompanying notes are an integral part of consolidated financial statements.
F-7
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
FOR THE YEAR ENDED DECEMBER 31, 2015, 2014 and 2013
(Amounts expressed in millions of Argentine pesos, except for per share amounts in Argentine pesos, and as otherwise indicated –
Note 1.b.1)
Revenues
Cost of sales
Gross profit
Selling expenses
Administrative expenses
Exploration expenses
Other operating results, net
Operating income
Income on investments in companies
Financial income
Financial loss
Other financial results
Financial results, net
Net income before income tax
Income tax
Net income for the year
Net income for the year attributable to:
– Shareholders of the parent company
– Non-controlling interest
Earnings per share attributable to shareholders of the parent company basic
and diluted
Other comprehensive income:
Actuarial results – Pension plans(1)
Exchange differences from investments in companies(2)
Translation differences from investments in companies(3)
Translation differences from YPF S.A.(4)
Total other comprehensive income for the year(5)
Total comprehensive income for the year
2015
2014
Notes
6.l
156,136 141,942
6.m (119,537) (104,492)
36,599 37,450
6.n (11,099) (10,114)
(4,530)
(5,586)
6.n
(2,034)
(2,473)
6.n
(1,030)
(853)
6.o
16,588 19,742
7
558
318
6.p 27,263 11,301
(9,826)
6.p (16,016)
297
910
6.p
1,772
6.p 12,157
29,063 22,072
(24,637) (13,223)
8,849
4,426
6.i
2013
90,113
(68,094)
22,019
(7,571)
(2,686)
(829)
227
11,160
353
8,740
(6,008)
103
2,835
14,348
(9,269)
5,079
4,579
(153)
9,002
(153)
5,125
(46)
9
11.68
22.95
13.05
6
(189)
(1,466)
25
—
(677)
45,407 16,928
43,758 16,276
48,184 25,125
6
—
(416)
12,441
12,031
17,110
Immediately reclassified to retained earnings
(1)
(2) Exchange differences as recognized by the indirectly controlled company Gas Argentino S.A. in its statement of comprehensive
income, which was reclassified by YPF as other comprehensive income upon the acquisition of negotiable obligations of the
said controlled company (See Note 6.j).
(3) Will be reversed to net income at the moment of the sale of the investment or full or partial reimbursement of the capital.
(4) Will not be reversed to net income.
(5) Entirely assigned to the parent company’s shareholders.
Accompanying notes are an integral part of consolidated financial statements.
F-8
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YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOW
FOR THE YEAR ENDED DECEMBER 31, 2015, 2014 AND 2013
(Amounts expressed in millions of Argentine Pesos, except shares and per share amounts expressed in Argentine Pesos, and as
otherwise indicated – Note 1.b.1)
Cash flows from operating activities
Net income
Adjustments to reconcile net income to cash flows provided by operating activities:
Result on investments in companies
Depreciation of fixed assets
Amortization of intangible assets
Consumption of materials and retirement of fixed assets and intangible assets, net of
provisions.
Charge on income tax
Net increase in provisions
Exchange differences, interest and other (1)
Share-based benefit plan
Accrued insurance
Changes in assets and liabilities:
Trade receivables
Other receivables
Inventories
Accounts payable
Taxes payables
Salaries and social security
Decrease in provisions due to payment/use
Dividends received
Proceeds from collection of lost profit insurance
Income tax payments
Net cash flows provided by operating activities
Investing activities: (2)
Acquisition of fixed assets and intangible assets
Contributions and acquisitions of interests in companies and joint operations
Advances received from sale of fixed and intangible assets
Acquisition of subsidiaries net of acquired cash and cash equivalents
Investments in financial assets
Proceeds from collection of damaged property’s insurance
Net cash flows used in investing activities
Financing activities: (2)
Payments of loans
Payments of interest
Proceeds from loans
Repurchase of treasury shares
Contributions of non-controlling interests
Dividends paid
Net cash flows provided by financing activities
Translation differences provided by cash and cash equivalents
Net increase (decrease) in cash and cash equivalents
Cash and cash equivalents at the beginning of year
Cash and cash equivalents at the end of year
Net increase (decrease) in cash and cash equivalents
COMPONENTS OF CASH AND CASH EQUIVALENTS AT THE END OF THE YEAR
- Cash
- Cash equivalents
TOTAL CASH AND CASH EQUIVALENTS AT THE END OF THE YEAR
2015
2014
2013
4,426 8,849
5,079
(318)
(558)
26,685 19,936
469
323
3,773 4,041
24,637 13,223
6,133 5,561
(13,449) (2,116)
80
(1,688) (2,041)
124
(8,031) (3,824)
(6,143)
248
(244)
101
6,211 5,067
218
4,544
727
549
(1,758) (1,974)
299
2,036 1,689
(6,931) (3,496)
41,404 46,154
180
(353)
11,236
197
2,336
9,269
3,390
(3,669)
81
(1,956)
(2,627)
(1,332)
(732)
3,243
272
253
(713)
280
—
(3,290)
20,964
(163)
(63,774) (50,213)
(967)
— 2,060
— (6,103)
(324) —
212 1,818
(64,049) (53,405)
(27,639)
(20)
5,351
107
—
—
(22,201)
(120)
—
(503)
(24,090) (13,320)
(6,780) (5,059)
55,158 23,949
(200)
80
(464)
23,665 4,986
4,609 1,310
5,629
(955)
9,758 10,713
15,387 9,758
(955)
5,629
(6,804)
(2,696)
16,829
(120)
96
(326)
6,979
224
5,966
4,747
10,713
5,966
13,920 6,731
1,467 3,027
15,387 9,758
4,533
6,180
10,713
(1) Does not include exchange differences generated by cash and cash equivalents, which is exposed separately in the statement.
(2) The main investing and financing transactions that have not affected cash and cash equivalents correspond to :
Acquisition of fixed assets and concession extension easements not paid
Net increases (decreases) related to hydrocarbon wells abandonment obligation costs
Dividends receivable
Decrease of loans for “El Orejano” agreement
Contributions of non-controlling interests
Capital contributions in kind from investments in companies
2013
2014
2015
6,799 7,567 5,604
(1,281) (268) 4,357
100 — —
2,373 — —
50 — —
133
— 342
Accompanying notes are an integral part of consolidated financial statements.
F-12
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
FOR THE YEAR ENDED DECEMBER 31, 2015 AND COMPARATIVE INFORMATION
(Amounts expressed in millions of Argentine Pesos, except shares and per share amounts expressed in Argentine Pesos, and as
otherwise indicated – Note 1.b.1)
1. BASIS OF PREPARATION OF THE CONSOLIDATED FINANCIAL STATEMENTS
1.a. Basis of preparation
–
Application of International Financial Reporting Standards
The consolidated financial statements of YPF S.A. (hereinafter “YPF” or “the Company”) and its controlled companies
(hereinafter and all together, the “Group”) for the year ended December 31, 2015 are presented in accordance with International
Financial Reporting Standard (“IFRS”). The adoption of these standards as issued by the International Accounting Standards
Board (“IASB”) was determined by the Technical Resolution No. 26 (ordered text) issued by Argentine Federation of
Professional Councils in Economic Sciences (“FACPCE”) and the Regulations of the Argentine Securities Commission
(“CNV”).
Also, some additional issues required by the Argentine General Corporations Law and/or CNV’s regulations have been
included. This information is contained in the Notes to these consolidated financial statements, only for purposes of fulfillment
of these regulatory requirements.
The amounts and other information corresponding to the years ended on December 31, 2014 and 2013 are an integral part of the
consolidated financial statements mentioned above and are intended to be read only in relation to these financial statements.
These financial statements were approved by the Board of Directors’ meeting and authorized to be issued on March 3, 2016 and
will be considered by the next annual Shareholders’ meeting. In addition for purpose of its presentation to the Securities and
Exchange Commission of the United States of America, the Note 20 “Supplemental information on Oil and Gas producing
activities (unaudited)” has been included.
–
Current and non-current classification
The presentation in the statement of financial position makes a distinction between current and non-current assets and liabilities,
according to the activities operating cycle.
The operating cycle for the Group activities is 12 months. Therefore, current assets and liabilities include assets and liabilities
which are realized or settled within the 12-month period from the end of the fiscal year.
All other assets and liabilities are classified as non-current. Current and deferred tax assets and liabilities are presented
separately from each other and from other assets and liabilities, as current and non-current, respectively.
–
Fiscal year-end
The Company’s fiscal year begins on January 1 and ends on December 31, each year.
–
Use of estimates
The preparation of financial statements at a certain date requires the Management to make estimates and assessments affecting
the amount of assets and liabilities recorded, contingent assets and liabilities disclosed at such date, as well as income and
expenses recorded during the period. Actual future results might differ from the estimates and assessments made at the date of
preparation of these consolidated financial statements.
Significant judgments made by Management in applying the Group’s accounting policies and the main estimations and critical
judgments are disclosed in Note 1.c)
F-13
–
Consolidation policies
a) General criteria
For purpose of presenting the consolidated financial statements, the full consolidation method was used with respect to those
subsidiaries in which the Company holds, either directly or indirectly, control, understood as the ability to establish/manage the
financial and operating policies of a company to obtain benefits from its activities. This capacity is, in general but not
exclusively, obtained by the ownership, directly or indirectly of more than 50% of the voting shares of a company.
Interest in joint operations and other agreements which gives the Company a percentage contractually established over the rights
of the assets and obligations that emerge from the contract (“joint operations”), have been consolidated line by line on the basis
of the mentioned participation over the assets, liabilities, income and expenses related to each contract. Assets, liabilities,
income and expenses of joint operations are presented in the consolidated financial position and in the consolidated statement of
comprehensive income, in accordance with their respective nature.
Note 16 details the fully consolidated controlled companies. Note 17 details the main joint operations, on a pro rata
consolidation basis.
In the consolidation process, balances, transactions and profits between consolidated companies and joint operations have been
eliminated.
The Company’s consolidated financial statements are based on the most recent available financial statements of the companies
in which YPF holds control, taking into consideration, where necessary, significant subsequent events and transactions,
information available to the Company’s management and transactions between YPF and such controlled companies, which
could have produced changes to their shareholders’ equity. The date of the financial statements of such controlled companies
used in the consolidation process may differ from the date of YPF’s financial statements due to administrative reasons. The
accounting principles and procedures used by controlled companies have been homogenized, where appropriate, with those used
by YPF in order to present the consolidated financial statements based on uniform accounting and presentation policies. The
financial statements of controlled companies whose functional currency is different from the presentation currency are translated
using the procedure set out in Note 1.b.1.
The Company, directly and indirectly, holds approximately 100% of capital of the consolidated companies, with the exception
of the indirect holdings in Metrogas S.A. (“Metrogas”) and YPF Tecnología S.A. In accordance with the previously mentioned,
there are no material non-controlling interests to be disclosed, as required by IFRS 12 “Disclosure of Interests in Other Entities”.
b) Business combinations
As detailed in Note 2, on February 12, 2014, YPF and its subsidiary YPF Europe B.V. accepted the offer made by Apache
Overseas Inc. and Apache International S.à.r.l. for the acquisition of 100% of its interest in companies controlling Apache
Group’s assets in Argentina completing the precedent conditions set forth in that agreement on March 13, 2014 (take over
control date). Additionally, during the second quarter of 2013 the Company obtained control over Gas Argentino S.A.
(“GASA”), parent company of Metrogas, and as from August, 2013, over YPF Energía Eléctrica S.A. (“YPF Energía
Eléctrica”), a company resulting from the spin-off of Pluspetrol Energy S.A.
The Company has consolidated the results of operations of Apache Group (hereinafter YSUR), GASA, and consequently of its
subsidiaries, and of YPF Energía Eléctrica as from the moment in which it obtained control over such companies. The
accounting effects of the above mentioned transactions, which include the purchase price allocation to the assets and liabilities
acquired, are disclosed in Note 2.
F-14
1.b) Significant Accounting Policies
1.b.1) Functional and Reporting Currency and tax effect on Other Comprehensive Income
Functional Currency
YPF based on parameters set out in IAS 21 “The effects of change in foreign exchange rates”, has defined the U.S. dollar as its
functional currency. Consequently, non-monetary cost-based measured assets and liabilities, as well as income or expenses, are
remeasured into functional currency by applying the exchange rate prevailing at the date of the transaction.
Transactions in currencies other than the functional currency of the Company are deemed to be “foreign currency transactions”
and are remeasured into functional currency by applying the exchange rate prevailing at the date of the transaction (or, for
practical reasons and when exchange rates do not fluctuate significantly, the average exchange rate for each month). At the end
of each year or at the time of cancellation the balances of monetary assets and liabilities in currencies other than the functional
currency are measured at the exchange prevailing at such date and the exchange differences arising from such measurement are
recognized as “Financial results, net” in the consolidated statement of comprehensive income for the year in which they arise.
Assets, liabilities and results of controlled companies and investments in other companies are shown in their respective
functional currencies. The effects of the conversion into U.S. dollars of the financial information of those companies whose
functional currency is other than U.S. dollar are recorded as “Other comprehensive income” in the Consolidated Statement of
Comprehensive Income.
Presentation currency:
According to CNV Resolution No. 562, the Company must present its financial statements in pesos. Therefore, the financial
statements prepared in the Company’s functional currency are translated into the presentation currency, as per the following
procedures:
–
–
–
Assets and liabilities of each of the balance sheets presented are translated using the exchange rate at the balance sheet
closing date;
Items of the Consolidated Statement of Comprehensive Income are translated using the exchange rate at the time the
transactions were generated (or, for practical reasons, and provided the exchange rate has not changed significantly, using
each month’s average exchange rate);
All translation differences resulting from the foregoing are recognized under “Other Comprehensive Income”.
Tax effect on Other comprehensive Income:
Results included in Other Comprehensive Income in connection with translation differences generated by investments in
companies whose functional currency is other than US dollar as well as conversion differences arising from the translation of
YPF´s financial statements into its presentation currency (pesos), have no effect on the income tax or in the deferred tax since at
the time they were generated, the relevant transactions did not make any impact on net income or taxable income.
1.b.2) Financial Assets
a)
Classification
In accordance with IFRS 9 “Financial instruments”, the Group classifies its financial assets into two categories: assets measured
at fair value and assets measured at amortized cost. This classification depends on whether the financial asset is a debt
instrument or an equity instrument.
F-15
i. Debt instruments
–
Financial assets at amortized cost
A debt instrument is classified as an asset measured at amortized cost if both of the following criteria are met: (i) the objective
of the Group’s business model is to hold the assets to collect the contractual cash flow, and (ii) the contractual terms only
require specific dates for payment of capital and interest.
As of the closing date of these financial statements, the Group’s financial assets at amortized cost include certain elements of
cash and cash equivalent, trade receivables and other receivables.
–
Financial assets at fair value through profit or loss
If either of the two criteria above is not met, the debt instrument is classified as an asset measured “at fair value through profit or
loss”.
Changes in fair values and gains from disposals of financial assets at fair value through profit or loss (except for the derivative
instruments referred to in Note 1.b.17) are recorded within “Financial Results, net”, in the Consolidated Statement of
Comprehensive Income.
As of the closing date of these financial statements, the Group’s financial assets at fair value through profit or loss include
derivative financial instruments and mutual funds.
ii. Equity instruments
As of the closing date of these financial statements, the Group does not hold any equity instrument.
b) Recognition and measurement
Purchases and sales of financial assets are recognized on the date on which the Group commits to purchase or sell the assets.
Financial assets are derecognized when the rights to receive cash flows from the investments and the risks and rewards of
ownership have expired or have been transferred.
At initial recognition, the Group measures a financial asset at its fair value plus, in the case of a financial asset which is not
measured at fair value through profit or loss, transaction costs that are directly attributable to the acquisition of the financial
assets. Transaction costs of financial assets carried at fair value through profit or loss are expensed in the income statement.
In general, the Group uses the transaction price to ascertain the fair value of a financial instrument on initial recognition. In the
other cases, the Group records a gain or loss on initial recognition only if the fair value of the financial instrument can be
supported by other comparable and observable market transactions for the same type of instrument or if it is based in a technical
valuation that only inputs observable market information. Unrecognized gains or losses on initial recognition of a financial asset
are recognized later on, only to the extent they arise from a change in the factors (including time) that market participants would
consider upon setting the price.
Gains/losses on debt instruments measured at amortized cost and not included for hedging purposes are charged to income when
the financial assets are derecognized or an impairment loss is recognized and during the amortization process using the effective
interest rate method.
The Group reclassifies all affected debt instruments only when its business model for managing those assets changes.
c)
Impairment of financial assets
The Group assesses at the end of each reporting period whether there is objective evidence that a financial asset or group of
financial assets measured at amortized cost is impaired. Impairment losses are incurred only if there is objective evidence of
impairment as a result of one or more events that occurred after the initial recognition of the assets and such impairment may be
reliably measured.
Evidence of impairment may include indications that debtors or a group of debtors is experiencing significant financial
difficulty, default or delinquency in interest or principal payments, the probability that they will enter bankrupt or other financial
reorganization, and when observable information indicates that there is a measurable decrease in the estimated future cash flows.
F-16
The impairment amount is measured as the difference between the asset’s carrying amount and the present value of estimated
future cash flows (excluding future credit losses that have not been incurred), discounted at the financial asset’s original
effective interest rate . The carrying amount of the asset is reduced and the amount or the loss is recognized in the statement of
comprehensive income. For practical purposes, the Group may measure impairment on the basis of an instrument’s fair value,
using an observable market price. If, in a subsequent period, the amount the impairment loss decreases and the decrease can be
related objectively to and event occurring after the impairment was recognized, the reversal of the previously recognized
impairment loss is recognized in the statements of income.
d) Offsetting financial instruments
Financial assets and liabilities are offset when there is a legally enforceable right to offset the recognized amounts and there is
an intention to settle on a net basis, or realize the asset and settle the liability simultaneously.
1.b.3) Inventories
Inventories are valued at the lower of their cost and their net realizable value. Cost includes acquisition costs (less trade
discount, rebates and other similar items), transformation and other costs which have been incurred when bringing the inventory
to its present location and condition.
In the case of refined products, costs are allocated in proportion to the selling price of the related products (isomargen method)
due to the difficulty for distributing the production costs to each product.
The Group assesses the net realizable value of the inventories at the end of each year and recognizes in profit or loss in the
consolidated statement of comprehensive income the appropriate valuation adjustment if the inventories are overstated. When
the circumstances that previously caused impairment no longer exist or when there is clear evidence of an increase in the
inventories’ net realizable value because of changes in economic circumstances, the amount of a write-down is reversed.
Raw materials, packaging and others are valued at their acquisition cost.
1.b.4) Intangible assets
The Group initially recognizes intangible assets at their acquisition or development cost. This cost is amortized on a straight-line
basis over the useful lives of these assets (see Note 6.a). At the end of each year, such assets are measured at cost, considering
the criteria adopted by the Group in the transition to IFRS, less any accumulated amortization and any accumulated impairment
losses.
The main intangible assets of the Group are as follows:
I.
II.
Service concessions arrangements: includes transportation and storage concessions (see Note 6.a). These assets are valued
at their acquisition cost, considering the criteria adopted by the Group in the transition to IFRS, net of accumulated
amortization. They are depreciated using the straight-line method during the course of the concession period.
Exploration rights: the Group recognizes exploration rights as intangible assets, which are valued at their cost, considering
the criteria adopted by the Group in the transition to IFRS, net of the related impairment, if applicable. Investments related
to unproved properties are not depreciated. These investments are reviewed for impairment at least once a year or
whenever there are indicators that the assets may have become impaired. Any impairment loss or reversal is recognized in
profit or loss in the consolidated statement of comprehensive income. Exploration costs (geological and geophysical
expenditures, expenditures associated with the maintenance of unproved reserves and other expenditures relating to
exploration activities), excluding exploratory wells drilling costs, are charged to expense in the consolidated statement of
comprehensive income as incurred.
III. Other intangible assets: mainly includes costs relating to computer software development expenditures, as well as assets
that represent the rights to use technology and knowledge (“know how”) for the manufacture and commercial exploitation
of equipment related to oil extraction. These items are valued at their acquisition cost, considering the criteria adopted by
the Group in the transition to IFRS, net of the related depreciation and impairment, if applicable. These assets are
amortized on a straight-line basis over their useful lives, which range between 3 and 14 years. The Group reviews annually
the mentioned estimated useful life.
F-17
Service concessions: the Argentine Hydrocarbons Law permits the executive branch of the Argentine government to award 35-
year concessions for the transportation of oil, gas and petroleum products following submission of competitive bids. The term of
a transportation concession may be extended for an additional ten-year term. Pursuant to Law No. 26,197, provincial
governments have the same powers. Holders of production concessions are entitled to receive a transportation concession for the
oil, gas and petroleum products that they produce. The holder of a transportation concession has the right to:
–
–
transport oil, gas and petroleum products;
construct and operate oil, gas and products pipelines, storage facilities, pump stations, compressor plants, roads, railways
and other facilities and equipment necessary for the efficient operation of a pipeline system.
In addition, a transportation concession holder is under an obligation to transport hydrocarbons to third parties, without
discrimination, for a tariff. This obligation, however, is applicable to oil or gas producers only to the extent the concession
holder has available additional capacity, and is expressly subject to the transportation requirements of the concession holder.
Transportation tariffs are subject to approval by the Federal Energy Secretariat for oil and petroleum derivatives pipelines, and
by ENARGAS, for gas pipelines. Upon expiration of a transportation concession, oil pipelines and related facilities revert to the
Argentine Government, without any payment to the concession holder.
In connection with the foregoing, the Privatization Law granted the Company 35-year transportation concessions for the
transportation facilities operated by Yacimientos Petroquímicos Fiscales as of such date. The main pipelines related to said
transportation concessions are the following:
–
–
La Plata / Dock Sud
Puerto Rosales / La Plata
– Monte Cristo / San Lorenzo
–
–
Puesto Hernández / Luján de Cuyo
Luján de Cuyo / Villa Mercedes
Thus, assets meeting certain requirements set forth by the IFRIC 12, which at Management’s judgment are met in the facilities
mentioned in the preceding paragraphs, are recognized as intangible assets.
The Group has no intangible assets with indefinite useful lives as of December 31, 2015, 2014 and 2013.
1.b.5) Investments in companies
Investments in affiliated companies and Joint Ventures are valued using the equity method. Affiliated companies are considered
those in which the Company has significant influence, understood as the power to participate in the financial and operating
policy decisions of the investee but does not have control or joint control over those policies. Significant influence is presumed
when the Company has an interest of 20% or more in a company.
Under the provisions of IFRS 11, “Joint Arrangements”, and IAS 28 (2011), “Investments in Associates and Joint Ventures”,
investments in which two or more parties have joint control (defined as a “Joint Arrangement”) shall be classified as either a
Joint Operation (when the parties that have joint control have rights to the assets and obligations for the liabilities relating to the
Joint Arrangement) or a Joint Venture (when the parties that have joint control have rights to the net assets of the Joint
Arrangement). Considering such classification, Joint Operations shall be proportionally consolidated and Joint Ventures shall be
accounted for under the equity method.
The equity method consists in the incorporation in the balance sheet line “Investments in companies”, of the value of net assets
and goodwill, if any, of the participation in the affiliated company or Joint Venture. The net income or expense for each year
corresponding to the interest in these companies is reflected in the statement of comprehensive income in the “Income on
investments in companies” line.
F-18
Investments in companies have been valued based upon the latest available financial statements of these companies as of the end
of each year, taking into consideration, if applicable, significant subsequent events and transactions, available management
information and transactions between YPF and the related company which have produced changes on the latter’s shareholders’
equity. The dates of the financial statements of such related companies and Joint Operations used in the consolidation process
may differ from the date of the Company’s financial statements due to administrative reasons. The accounting principles and
procedures used by affiliated companies have been homogenized, where appropriate, with those used by YPF in order to present
the consolidated financial statements based on uniform accounting and presentation policies. The financial statements of
affiliated companies whose functional currency is different from the presentation currency are translated using the procedure set
out in Note 1.b.1).
Investments in companies in which the Company has no joint control or significant influence, have been valued at cost.
Investments in companies with negative shareholders’ equity are disclosed in the “Accounts payable” account.
The carrying value of the investments in companies does not exceed their estimated recoverable value.
In Note 16 are detailed the investments in companies.
As from the effective date of Law No. 25,063, dividends, either in cash or in kind, that the Company receives from investments
in other companies and which are in excess of the accumulated income that these companies carry upon distribution shall be
subject to a 35% income tax withholding as a sole and final payment. YPF has not recorded any charge for this tax since it has
estimated that dividends from earnings recorded by the equity method will not be subject to such tax.
1.b.6) Fixed assets
i. General criteria:
Fixed assets are valued at their acquisition cost, plus all the costs directly related to the location of such assets for their intended
use, considering the criteria adopted by the Group in the transition to IFRS.
Borrowing costs of assets that require a substantial period of time to be ready for their intended use are capitalized as part of the
cost of these assets.
Major inspections, necessary to restore the service capacity of the related asset are capitalized and depreciated on a straight-line
basis over the period until the next overhaul is scheduled.
The costs of renewals, betterments and enhancements that extend the useful life of properties and/or improve their service
capacity are capitalized. As fixed assets are retired, the related cost and accumulated depreciation are derecognized.
Repair, conservation and ordinary maintenance expenses are recognized in the statement of comprehensive income as incurred.
These assets are reviewed for impairment at least once a year or whenever there are indicators that the assets may have become
impaired, as detailed in Note 1.b.8.
ii. Depreciation:
Fixed assets, other than those related to oil and gas exploration and production activities, are depreciated using the straight-line
method, over the years of estimated useful life of the assets, as follows:
Buildings and other constructions
Refinery equipment and petrochemical plants
Infrastructure of natural gas distribution
Transportation equipment
Furniture, fixtures and installations
Selling equipment
Electric power generation facilities
Other property
Years of Estimated
Useful Life
50
20-25
20-50
5-25
10
10
15-20
10
Land is classified separately from the buildings or facilities that may be located on it and is deemed to have an indefinite useful
life. Therefore, it is not depreciated.
F-19
The Group reviews annually the estimated useful life of each class of assets.
iii. Oil and gas exploration and production activities:
The Group recognizes oil and gas exploration and production transactions using the “successful-efforts” method. The costs
incurred in the acquisition of new interests in areas with proved and unproved reserves are capitalized as incurred under Mineral
properties, wells and related equipment. Costs related to exploration permits are classified as intangible assets (see Notes 1.b.4
and 6.a).
Exploration costs, excluding the costs associated to exploratory wells, are charged to expense as incurred. Costs of drilling
exploratory wells, including stratigraphic test wells, are capitalized pending determination as to whether the wells have found
proved reserves that justify commercial development. If such reserves are not found, the mentioned costs are charged to
expense. Occasionally, an exploratory well may be determined to have found oil and gas reserves, but classification of those
reserves as proved cannot be made. In those cases, the cost of drilling the exploratory well shall continue to be capitalized if the
well has found a sufficient quantity of reserves to justify its completion as a producing well, and the Group is making sufficient
progress assessing the reserves as well as the economic and operating viability of the project. If any of the mentioned conditions
are not met, cost of drilling exploratory wells is charged to expense. In addition, the exploratory activity involves, in many
cases, the drilling of multiple wells through several years in order to completely evaluate a project. As a consequence some
exploratory wells may be kept in evaluation for long periods, pending the completion of additional wells and exploratory
activities needed to evaluate and quantify the reserves related to each project. The detail of the exploratory well costs in
evaluation stage is described in Note 6.b).
Intangible drilling costs applicable to productive wells and to developmental dry holes, as well as tangible equipment costs
related to the development of oil and gas reserves, have been capitalized.
The capitalized costs described above are depreciated as follows:
a)
b)
The capitalized costs related to productive activities have been depreciated by field on a unit-of-production basis by
applying the ratio of produced oil and gas to the estimated proved and developed oil and gas reserves.
The capitalized costs related to the acquisition of property and the extension of concessions with proved reserves
have been depreciated by field on a unit-of-production basis by applying the ratio of produced oil and gas to the
estimated proved oil and gas reserves.
Revisions in oil and gas proved reserves are considered prospectively in the calculation of depreciation. Revisions in estimates
of reserves are performed at least once a year. Additionally, estimates of reserves are audited by independent petroleum
engineers on a three-year rotation plan.
iv. Costs related to hydrocarbon wells abandonment obligations:
Costs related to hydrocarbon wells abandonment obligations are capitalized at their discounted value along with the related
assets, and are depreciated using the unit-of-production method. As compensation, a liability is recognized for this concept at
the estimated value of the discounted payable amounts. Revisions of the payable amounts are performed upon consideration of
the current costs incurred in abandonment obligations on a field-by-field basis or other external available information if
abandonment obligations were not performed. Due to the number of wells in operation and/or not abandoned and likewise the
complexity with respect to different geographic areas where the wells are located, current costs incurred in plugging activities
are used for estimating the plugging activities costs of the wells pending abandonment. Current costs incurred are the best
source of information in order to make the best estimate of asset retirement obligations. Future changes in the costs above
mentioned, as well as changes in regulations related to abandonment obligations, which are not possible to be predicted at the
date of issuance of these financial statements, could affect the value of the abandonment obligations and, consequently, the
related asset, affecting the results of future operations.
F-20
v. Environmental tangible assets:
The Group capitalizes the costs incurred in limiting, neutralizing or preventing environmental pollution only in those cases in
which at least one of the following conditions is met: (a) the expenditure improves the safety or efficiency of an operating plant
(or other productive assets); (b) the expenditure prevents or limits environmental pollution at operating facilities; or (c) the
expenditure is incurred to prepare assets for sale and do not raise the assets carrying value above their estimated recoverable
value.
The environmental related assets and the corresponding accumulated depreciation are disclosed in the consolidated financial
statements together with the other elements that are part of the corresponding assets which are classified according to their
accounting nature.
1.b.7) Provisions
The Group makes a distinction between:
a)
Provisions: represent legal or assumed obligations, arising from past events, the settlement of which is expected to give
rise to an outflow of resources and which amount and timing are uncertain. Provisions are recognized when the liability or
obligation giving rise to an indemnity or payment arises, to the extent that its amount can be reliably estimated and that the
obligation to settle is probable or certain. Provisions include both obligations whose occurrence does not depend on future
events (such as provisions for environmental liabilities and provision for hydrocarbon wells abandonment obligations), as
well as those obligations that are probable and can be reasonably estimated whose realization depends on the occurrence of
a future events that are out of the control of the Company (such as provisions for contingencies). The amount recorded as
provision corresponds to the best estimate of expenditures required to settle the obligation, taking into consideration the
relevant risks and uncertainties (see Note 10); and
b) Contingent liabilities: represent possible obligations that arise from past events and whose existence will be confirmed
only by the occurrence or non-occurrence of one or more future events not wholly within the control of the Company, or
present obligations arising from past events, the amount of which cannot be estimated reliably or whose settlement is not
likely to give rise to an outflow of resources embodying future economic benefits. Contingent liabilities are not recognized
in the consolidated financial statements, but rather are disclosed to the extent they are significant, as required by IAS 37,
“Provisions, contingent liabilities and contingent assets” (see Note11).
When a contract qualifies as onerous, the related unavoidable liabilities are recognized in the consolidated financial statements
as provisions, net of the expected benefits.
Except for provisions for hydrocarbon wells abandonment obligations, where the timing of settlement is estimated on the basis
of the work plan of the Group, and considering the estimated production of each field (and therefore its abandonment) and
provisions for pension plans, in relation to other noncurrent provisions, it is not possible to reasonably estimate a specific
schedule of settlement of the provisions considering the characteristics of the concepts included.
1.b.8) Impairment of fixed assets and intangible assets
For the purpose of evaluating the impairment of fixed assets and intangible assets, the Group compares their carrying value with
their recoverable amount at the end of each year, or more frequently, if there are indicators that the carrying value of an asset
may not be recoverable.
In order to assess impairment, assets are grouped into Cash-Generating Units (“CGU”), whereas the assets do not generate cash
flows that are independent of those generated by other assets or CGU, considering regulatory, economic, operational and
commercial conditions. Considering the above mentioned, the Group´s assets were grouped into eleven CGU.
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Exploration and Production Segment
The assets included in this segment have been grouped into seven CGU. One that gathers the assets of YPF fields, which
basically have crude oil reserves; five CGU that group the assets of YPF and YSUR fields which basically have natural gas
reserves, according to the Argentina’s basins, and another one that gathers the assets in the United States fields.
–
–
–
–
–
–
–
CGU Oil – YPF;
CGU Oil – YPF Holdings
CGU Gas – Neuquina Basin– YPF;
CGU Gas – Noroeste Basin – YPF;
CGU Gas – Austral Basin – YPF;
CGU Gas – Neuquina Basin – YSUR;
CGU Gas – Austral Basin – YSUR.
Downstream Segment
The assets included in this segment have been grouped in three CGU. The YPF Downstream CGU which mainly includes
the assets assigned to the crude oil refining activity (or that complement such activity), the petrochemical industry and
marketing of such products. The Metrogas CGU, which includes assets related to the distribution of natural gas and YPF
Energía Eléctrica CGU, which includes assets related to generation and commercialization of electric energy.
Corporate Segment
A-Evangelista CGU mainly included of the assets used for the construction activity related to the Company’s business.
This aggregation is the best reflection of how the Group currently makes its management decisions for the generation of
separate cash flows of the assets.
The recoverable amount is the higher of, the fair value less costs of disposal and the value in use. In assessing the value in use,
the estimated future cash flows are discounted to their present value using a rate that reflects the weighted average capital cost
employed for each CGU.
If the recoverable amount of a CGU is estimated to be less than its carrying amount, the carrying amount of the CGU is reduced
to its recoverable amount, and an impairment loss is recognized as an expense under “Other operating results, net” in the
Consolidated Statement of Comprehensive Income.
Any impairment loss is allocated to the assets comprising the CGU on a pro-rata basis based on their carrying amount.
Consequently, the basis for future depreciation or amortization will take into account the reduction in the value of the asset as a
result of any accumulated impairment losses.
Upon the occurrence of new events or changes in existing circumstances, which prove that an impairment loss previously
recognized could have disappeared or decreased, a new estimate of the recoverable amount of the corresponding asset is
calculated to determine whether a reversal of the impairment losses recognized in previous periods needs to be made.
In the event of a reversal, the carrying amount of the asset (or the CGU) is increased to the revised estimate of its recoverable
amount so that the increased carrying amount does not exceed the carrying amount that would have been determined in case no
impairment loss had been recognized for the asset (or the CGU) in the past.
1.b.9) Methodology used in the estimation of recoverable amounts
Group´s General Criteria: The recoverable amount of fixed assets and intangible assets is generally estimated on the basis of
their value in use, calculated on the basis of future expected cash flows derived from the use of the assets, discounted at a rate
that reflects the weighted average capital cost employed.
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In the assessment of the value in use, cash flow forecasts based on the best estimate of income and expense available for each
CGU using sector inputs, past results and future expectations of business evolution and market development are utilized. The
most sensitive aspects included in the cash flows used in all the CGU are the purchase and sale prices of hydrocarbons
(including gas distribution applicable fees), outstanding regulations, estimation of cost increase, employee costs and
investments.
The cash flows from the exploration and production assets are generally projected for a period that covers the economically
productive useful lives of the oil and gas fields and is limited by the contractual expiration of the concessions permits,
agreements or exploitation contracts. The estimated cash flows are based on production levels, commodity prices and estimates
of the future investments that will be necessary in relation to undeveloped oil and gas reserves, production costs, field decline
rates, market supply and demand, contractual conditions and other factors. The unproved reserves are weighted with risk factors,
on the basis of the type of each one of the exploration and production assets.
Downstream cash flows are estimated on the basis of the projected sales trends, contribution margins by unit, fixed costs and
investment flows, in line with the expectations regarding the specific strategic plans of each business. However, cash inflows
and outflows relating to planned restructurings or productivity enhancements are not considered. The projections evaluation
horizon is 10 years, considering an annual rent for the last period, based on the long useful life of this GCU assets.
The reference prices considered are based on a combination of market prices available in those markets where the Group
operates, also taking into consideration specific circumstances that could affect different products the Group commercializes and
management’s estimations and judgments.
Estimated net future cash flows are discounted to its present value using a rate that reflects the weighted average capital cost
employed for each CGU.
1.b.10) Employee benefit plans and share-based payments
i. Retirement plan:
Effective March 1, 1995, the Group have established a defined contribution retirement plan that provides benefits for each
employee who elects to join the plan. Each plan member will pay an amount between 3% and 10% of his monthly compensation
and the Group will pay an amount equal to that contributed by each member.
The plan members will receive from the Group the contributed funds before retirement only in the case of voluntary termination
under certain circumstances or dismissal without cause and, additionally, in case of death or incapacity. The Group has the right
to discontinue this plan at any time, without incurring termination costs.
ii. Performance Bonus Programs:
These programs cover certain YPF and its controlled companies’ personnel. These bonuses are based on compliance with
business unit objectives and performance. They are calculated considering the annual compensation of each employee, certain
key factors related to the fulfillment of these objectives and the performance of each employee and are paid in cash.
iii. Share-based benefit plan:
From the year 2013, YPF has decided to implement a share-based benefit plan. This plan organized in annual programs, covers
certain executive and management positions and key or with critical technical knowledge personnel. The above mentioned plan
is aimed at aligning the performance of these personnel with the objectives of the strategic plan of the Company.
This plan consists in giving participation, through shares of the Company, to each selected employee with the condition of
remaining in it for the previously defined period (up to three years from the grant date, hereinafter “service period”), being this
the only condition necessary to access the agreed final retribution. During the year 2013, the implementation of these plans has
included the conversion of certain long term compensation plans existing to date of implementation.
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Consequently, during the month of June 2013, the Company has converted these existing plans to new share-based schemes,
reversing a liability of 38 corresponding to existing plans as of December 31, 2012.
Consistent with share-based benefit plans approved in 2013, the Board of Directors at its meeting held on June 11, 2014,
approved the creation of a new share-based benefit plan 2014-2016, which will be valid for three years from July 1, 2014 (grant
date), with similar characteristics to those of the 2013-2015 plan.
Likewise, the Board of Directors at its meeting held on June 8, 2015, approved the creation of a new share-based benefit plan
2015-2017, which will be valid for three years from July 1, 2015 (grant date), with similar characteristics to the existing plans.
For accounting purposes, YPF recognizes the effects of the plans in accordance with the guidelines of IFRS 2, “Share-based
Payment”. In this order, the total cost of the plans granted is measured at the grant date, using the fair value or market price of
the Company’s share in the United States market. The above mentioned cost is accrued in the Company’s net income for the
year, over the vesting period, with the corresponding increase in Shareholders’ equity in the “Share-based Benefit Plans”
account.
iv. Pension plans and other Post- Retirement and Post- employment for YPF Holdings Inc.:
YPF Holdings Inc., which has operations in the United States of America, has certain defined benefit plans and post-retirement
and post-employment benefits.
The funding policy related to the defined benefit plan, is to contribute amounts to the plan sufficient to meet the minimum
funding requirements under governmental regulations, plus such additional amounts as management may determine to be
appropriate.
In addition, YPF Holdings Inc. provides certain health care and life insurance benefits for eligible retired employees, and also
certain insurance, and other post-employment benefits for eligible individuals in the event employment is terminated by YPF
Holdings Inc. before their normal retirement. Employees become eligible for these benefits if they meet minimum age and
years-of-service requirements. YPF Holdings Inc. accounts for benefits provided when payment of the benefit is probable and
the amount of the benefit can be reasonably estimated. No assets were specifically reserved for the post-retirement and post-
employment benefits, and consequently, payments related to them are funded as claims are received.
The plans mentioned above are valued at their net present value, are accrued based on the years of active service of the
participating employees and are disclosed as noncurrent liabilities in the ‘‘Salaries and social security’’ account. The actuarial
gains and losses arising from the remeasurement of the defined benefit liability of pension plans are recognized in Other
Comprehensive Income as a component of shareholders’ equity, and are transfer directly to the retained earnings. YPF Holdings
Inc. updates its actuarial assumptions at the end of each fiscal year.
Additional disclosures related to the mentioned plans, are included in Note 13.
Additionally, Management believes that the deferred tax asset generated by the cumulative actuarial losses related to the pension
plans of YPF Holdings Inc., will not be recoverable based on estimated taxable income generated in the jurisdiction in which
they are produced.
1.b.11) Revenue recognition
General criteria
Revenue is recognized on sales of crude oil, refined products and natural gas, in each case, when title and risks are transferred to
the customer following the conditions described below:
–
–
–
–
the Group has transferred to the buyer the significant risks and rewards of ownership of the goods;
the Group does not retain neither continuing managerial involvement to the degree usually associated with ownership nor
effective control over the goods sold;
the amount of revenue can be measured reliably;
it is probable that the economic benefits associated with the transaction will flow to the Group; and the costs incurred or to
be incurred in respect of the transaction can be measured reliably.
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Revenue recognition related to Government incentive programs
Incentives to the Additional Injection of natural gas and to the production of crude oil (see Note 11.c) granted by the Planning
and Strategic Coordination Commission of the National Plan of Hydrocarbons Investment by Resolutions No. 1/2013 and
No. 14/2015, respectively, fall within the scope of the IAS 20 “Accounting for Government grants and disclosure of government
assistance”, as they constitute economic compensations for the companies committed to increasing their respective production.
Incentives have been included in “Revenues” in the Consolidated Statement of Comprehensive Income.
Likewise, these regulations also apply to the temporary economic assistance by Metrogas (see Note 11.c), as approved by
Resolution No. 263/2015 of the Federal Energy Secretariat as its purpose is to fund the expenses and investments related to the
normal operation of the natural gas distribution service through networks, while preserving the chain of payment to natural gas
producers until the Tariff Review is concluded. The incentives have been included in the item “Other operating results, net” in
the Consolidated Statement of Comprehensive Income.
In addition, Argentine tax authorities provide a tax incentive for investment in capital goods, computers and telecommunications
for domestic manufacturers through a fiscal bond, provided that manufacturers have industrial establishments located in
Argentina, a requirement that is satisfied by the controlled company A-Evangelista S.A. The Group recognizes such incentive
when the formal requirements established by Decrees No. 379/01, 1551/01, its amendments and regulations are satisfied, to the
extent that there is reasonable certainty that the grants will be received. The bond received may be computed as a tax credit for
the payment of national taxes (i.e., Income Tax, Tax on Minimum Presumed Income, Value Added Tax and Domestic Taxes)
and may also be transferred to third parties. The incentives have been included in the item “Other operating results, net” in the
Consolidated Statement of Comprehensive Income.
Recognition of this income is made at its fair value when there is a reasonable certainty that incentives will be received and that
regulatory requirements related therewith have been fulfilled.
Recognition of revenues and costs associated with construction contracts method
Revenues and costs related to construction activities performed by A-Evangelista S.A. are accounted for in the consolidated
statement of comprehensive income for the year using the percentage of completion method, considering the final contribution
margin estimated for each project at the date of issuance of the financial statements, which arises from technical studies on sales
and total estimated costs for each of them, as well as their physical progress.
The adjustments in contract values, changes in estimated costs and anticipated losses on contracts in progress are reflected in
earnings in the year when they become evident.
The table below details information related to the construction contracts as of December 31, 2015, 2014 and 2013:
Contracts in progress
Revenues of the
year
Costs incurred plus
accumulated
recognized profits
455
419
312
577
418
2,359
Advances received
—
—
368
Retentions
—
—
—
2015
2014
2013
1.b.12) Leases
Operating leases
A lease is classified as an operating lease when the lessor does not transfer substantially to the lessee the entire risks and rewards
incidental to ownership of the asset.
Costs related to operating leases are recognized on a straight-line basis in “Rental of real estate and equipment” and “Operation
services and other service contracts” of the Consolidated Statement of Comprehensive Income for the year in which they arise.
Financial Leases
The Group has no financial leases as they are defined by IFRS.
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1.b.13) Earnings per share
Basic earnings per share is calculated by dividing the net income for the year attributable to YPF’s shareholders by the weighted
average of shares of YPF outstanding during the year net of repurchased shares as mentioned in Note 8.
Diluted earnings per share is calculated by dividing the net income for the fiscal year by the weighted average of shares
outstanding, and when dilutive, adjusted for the effect of all potentially dilutive shares, including share options, on an as if they
had been converted.
In computing diluted earnings per share, income available to ordinary shareholders, used in the basic earnings per share
calculation, is adjusted by those results that would result of the potential conversion into ordinary stock. The weighted average
number of ordinary shares outstanding is adjusted to include the number of additional ordinary shares that would have been
outstanding if the dilutive potential ordinary shares had been issued. Diluted earnings per share is based on the most
advantageous conversion rate or exercise price over the entire term of the instrument from the standpoint of the security holder.
The calculation of diluted earnings per share excludes potential ordinary shares if their effect is anti-dilutive.
As of the date of the issuance of these financial statements, there are no YPF´s instruments outstanding that imply the existence
of potential ordinary shares (also taking into account the Company’s intent to cancel the Share-based benefit plans through their
repurchase in the market). Thus the basic earnings per share matches the diluted earnings per share. See Note 9.
1.b.14) Financial liabilities
Financial liabilities are initially recognized at their fair value less the transaction costs incurred. Since the Group does not have
financial liabilities whose characteristics require the recognition at their fair value, according to IFRS, after their initial
recognition, financial liabilities are measured at amortized cost. Any difference between the financing received (net of
transaction costs) and the repayment value is recognized in the consolidated statement of comprehensive income over the life of
the related debt instrument, using the effective interest rate method.
The Group derecognizes financial liabilities when the related obligations are settled or expire.
At the closing of these consolidated financial statements, the Group’s financial liabilities at amortized cost include account
payables and loans.
In order to account for the exchange of debt obligations arising from the voluntary reorganization petition of Metrogas and
GASA for new negotiable obligations executed on January 11, 2013 and March 15, 2013, respectively, the Group has followed
the guidelines provided by IFRS 9, “Financial Instruments”.
IFRS 9 states that an exchange of debt instruments between a borrower and a lender shall be accounted for as an extinguishment
of the original financial liability and the recognition of a new financial liability when the instruments have substantially different
terms. The difference between the carrying amount of the financial liability extinguished and the consideration paid, which
includes any non-cash assets transferred or liabilities assumed, is recognized in net incomef for the period or fiscal year. The
Group considers that the terms of the outstanding debt obligations, arising from the voluntary reorganization petition, subject to
the exchange are substantially different from the new negotiable obligations. Additionally, the Group has evaluated and
positively concluded over the estimated funds that such companies will have to comply with the terms of the debt and that
allows the recognition of the debt relief. Consequently, Metrogas and GASA have recorded the debt instruments’ exchange
following the guidelines mentioned above. Also, according to IFRS 9 the new negotiable obligations were recognized initially at
fair value, net of transaction costs incurred and subsequently measured at amortized cost. In the initial recognition, the fair value
of such debt has been estimated using the discounted cash flow method, in the absence of quoted prices in active markets
representative for the amount issued.
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1.b.15) Taxes, withholdings and royalties
Income tax and tax on minimum presumed income
The Group recognizes the income tax applying the liability method, which considers the effect of the temporary differences
between the financial and tax basis of assets and liabilities and the tax loss carry forwards and other tax credits, which may be
used to offset future taxable income, at the current statutory rate of 35%.
Additionally, the Group calculates tax on minimum presumed income applying the current 1% tax rate to taxable assets as of the
end of each year. This tax complements income tax. The Company’s tax liability will coincide with the higher between the
determination of tax on minimum presumed income and the Company’s tax liability related to income tax, calculated applying
the current 35% income tax rate to taxable income for the year. However, if the tax on minimum presumed income exceeds
income tax during one tax year, such excess may be computed as prepayment of any income tax excess over the tax on
minimum presumed income that may be generated in the next ten years.
Under Law No. 25,063, dividends distributed, either in cash or in kind, in excess of accumulated taxable income as of the end of
the year immediately preceding the dividend payment or distribution date, shall be subject to a 35% income tax withholding as a
sole and final payment, except for those distributed to shareholders resident in countries benefited from treaties for the
avoidance of double taxation, which will be subject to a minor tax rate.
Additionally, on September 20, 2013, Law No. 26,893 was enacted, establishing changes to the Income Tax Law, and
determining, among other things, an obligation respecting such tax as a single and final payment of 10% on dividends paid in
cash or in kind (except in shares) to foreign beneficiaries and individuals residing in Argentina, in addition to the 35% retention
mentioned above. The dispositions of this Law came in force on September 23, 2013, date of its publication in the Official
Gazette.
Personal assets tax – Substitute responsible
Individuals and foreign entities, as well as their undistributed estates, regardless of whether they are domiciled or located in
Argentina or abroad, are subject to personal assets tax of 0.5% of the value of any shares or ADSs issued by Argentine entities,
held at December 31 of each year. The tax is levied on the Argentine issuers of such shares or ADSs, such as YPF, which must
pay this tax in substitution of the relevant shareholders, and is based on the equity value (following the equity method), or the
book value of the shares derived from the latest financial statements at December 31 of each year. Pursuant to the Personal
Assets Tax Law, the Group is entitled to seek reimbursement of such paid tax from the applicable shareholders, using the
method the Group considers appropriate.
Royalties and withholding systems for hydrocarbon exports
A 12% royalty is payable on the estimated value at the wellhead of crude oil production and the commercialized natural gas
volumes. The estimated value is calculated based upon the approximate sale price of the crude oil and gas produced, less the
costs of transportation and storage. To calculate royalties, the Company has considered price agreements according to crude oil
buying and selling operations obtained in the market for certain qualities of such product, and has applied these prices, net of the
discounts mentioned above, according to regulations of Law No. 17,319 and its amendments. In addition, and pursuant to the
extension of the original terms of exploitation concessions, the Company has agreed to pay an extraordinary production royalty
and in some cases a royalty of 10% is payable over the production of unconventional hydrocarbons (see Note 11).
Royalty expense and the extraordinary production royalties are accounted for as a production cost.
Law No. 25,561 on Public Emergency and Exchange System Reform (“Public emergency law”), issued in January 2002,
established duties for hydrocarbon exports for a five-year period. In January 2007, Law No. 26,217 extended this export
withholding system for an additional five-year period and also established specifically that this regime is also applicable to
exports from “Tierra del Fuego province”, which were previously exempted. In addition, Law No. 26,732 published in the
Official Gazette in December 2011 extended for an additional 5 years the mentioned regime. On November 16, 2007, the
Ministry of Economy and Production (“MEP”) published Resolution No. 394/2007, modifying the withholding regime on
exports of crude oil and other refined products. In addition, the Resolution No. 1/2013, published on January 3, 2013 and the
Resolution No. 803/2014 published on October 21, 2014 from the Ministry of Economy and Public Finance modified the
reference and floor prices.
F-27
Resolution No. 1,077/2014 dated on December 29, 2014 repealed Resolution No. 394/2007 and amended and established a new
withholding system based on the International Price of crude oil (“IP”), calculated on the basis of the “Brent value” applicable
to the export month minus eight dollars per barrel (US$ 8.0 per barrel). The new regime establishes a general nominal rate of
1% while IP is below US$ 71 per barrel. Additionally, the Resolution establishes an increasing variable rate for export of crude
oil while IP is above US$ 71 per barrel; therefore, the producer will collect a maximal value of about US$ 70 per exported
barrel, depending on the quality of crude oil sold. Likewise, the Resolution establishes a variable increasing withholding rates
for exports of diesel, gasoline, lubricants and other petroleum derivatives when IP exceeds US$ 71 per barrel by using formulas
allowing the producer to collect a portion of such higher price.
Furthermore, in March 2008, Resolution No. 127/2008 of the MEP increased the natural gas export withholding rate to 100% of
the highest price from any natural gas import contract. This resolution has also established a variable withholding system
applicable to liquefied petroleum gas, similar to the one established by the Resolution No. 394/2007.
1.b.16) Shareholders’ equity accounts
Shareholders’ equity accounts have been valued in accordance with accounting principles in effect as of the transition date. The
accounting transactions that affect shareholders’ equity accounts were accounted for in accordance with the decisions taken by
the Shareholders’ meetings, and legal standards or regulations.
Subscribed capital stock and adjustments to contributions
Consists of the shareholders’ contributions represented by shares and includes the outstanding shares at face value net of
treasury shares mentioned in the following paragraph “Treasury shares and adjustment to treasury shares”. The subscribed
capital account has remained at its historical value and the adjustment required previous Argentine GAAP to state this account
in constant Argentine pesos is disclosed in the “Adjustments to contributions” account.
The adjustment to contributions cannot be distributed in cash or in kind, but is allowed its capitalization by issuing shares. Also,
this item may be used to compensate accumulated losses.
Treasury shares and adjustments to treasury shares
Corresponds to the reclassification of the nominal value and the corresponding adjustment in constant peso (Adjustment to
Contributions) of shares issued and repurchased by YPF in market transactions, as is required by the CNVs regulations in force.
Share-based benefit plans
Corresponds to the balance related to the share-based benefit plans as mentioned in Note 1.b.10.iii).
Acquisition cost of repurchased shares
Corresponds to the cost incurred in the acquisition of the shares that YPF holds as treasury shares (see Note 8).
Considering the CNV regulations RG 562, the distribution of retained earnings is restricted by the balance of this account.
Share trading premium
Corresponds to the difference between accrued amount in relation to the shared-based benefit plan and acquisition cost of the
shares settled during the year in relation with the mentioned plan.
Considering the debit balance of the premium, distribution of retained earnings is restricted by the balance of this premium.
F-28
Issuance premiums
Corresponds to the difference between the amount of subscription of the capital increase and the corresponding face value of the
shares issued.
Legal reserve
In accordance with the provisions of Law No. 19,550, YPF has to appropriate to the legal reserve no less than 5% of the
algebraic sum of net income, prior year adjustments, transfers from other comprehensive income to retained earnings and
accumulated losses from previous years, until such reserve reaches 20% of the subscribed capital plus adjustment to
contributions. As of December 31, 2015, the legal reserve has been fully integrated amounting 2,007.
Reserve for future dividends
Corresponds to the allocation made by the YPF’s Shareholders’ meeting, whereby a specific amount is transferred to the reserve
for future dividends.
Reserve for investments and reserve for purchase of treasury shares
Corresponds to the allocation made by the YPF’s Shareholders’ meeting, whereby a specific amount is being assigned to be
used in future investments and in the purchase of YPF’s shares to meet the obligations arising from share-based benefit plan
described in Note 1.b.10.iii).
Initial IFRS adjustment reserve
Corresponds to the initial adjustment in the transition to IFRS application, which was approved by the Shareholders’ meeting of
April 30, 2013, in accordance with the General Resolution No. 609 of the CNV.
Such reserve cannot be used in distributions in cash or in kind to the shareholders or owners of YPF and may only be reversed
for capitalization or absorption of an eventual negative balance on the “Retained earnings” account according the
aforementioned Resolution.
Other comprehensive income
Includes income and expenses recognized directly in equity accounts and the transfer of such items from equity accounts to the
income statement of the year or to retained earnings, as defined by IFRS.
Retained earnings
Includes accumulated gains or losses without a specific appropriation that being positive can be distributed upon the decision of
the Shareholders’ meeting, while not subject to legal restrictions. Additionally, it includes the net income of previous years that
was not distributed, the amounts transferred from other comprehensive income and adjustments to income of previous years
produced by the application of new accounting standards.
Additionally, pursuant to the regulations on the CNV, when the net balance of other comprehensive income account is positive,
it shall not be distributed, capitalized nor used to compensate accumulated losses, and when the net balance of these results at
the end of a year is negative, a restriction on the distribution of retained earnings for the same amount will be imposed.
Non-controlling interest
Corresponds to the interest in the net assets acquired and net income of Metrogas (30%) and YPF Tecnología S.A. (49%),
representing the rights on shares that are not owned by YPF.
1.b.17) Derivative financial instruments and hedge transactions
Derivative financial instruments are recognized at fair value. The method of recognizing the resulting gain or loss depends on
whether the derivative is designated as a hedge instrument, and, if so, the nature of the item being hedged.
The Group manages exposures to several risks using different financial instruments. The Group does not use derivative financial
instruments for speculative purposes. As of this date, the Group has used US dollar future exchange rate agreements.
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The Group’s policy is to apply hedge accounting to hedging relationships where it is both permissible under IFRS 9, practical to
do so and its application reduces volatility. Transactions that may be effective hedges in economic terms may not always qualify
for hedge accounting under IFRS 9. As of this date, the Group has not applied hedge accounting to its derivative financial
instruments. Gains or losses from these derivative financial instruments are classified as “Financial results, net”, in the statement
of comprehensive income.
Fair values of derivative financial instruments that are traded in active markets are computed by reference to market prices. The
fair value of derivative financial instruments that are not traded in an active market is determined using valuation techniques.
The Group uses its judgment to select a variety of methods and make assumptions that are mainly based on market conditions
existing at the end of each fiscal year. As of December 31, 2015, the Group only holds derivative instruments traded on active
markets
1.b.18) Trade receivables and other receivables
Trade receivables are initially recognized at fair value and subsequently measured at amortized cost using the effective interest
rate method.
A provision for bad debt is created where there is objective evidence that the Group may not be able to collect all receivables
within the original payment terms. Indicators of bad debts include significant financial distress of the debtor, the debtor
potentially filing a petition for reorganization or bankrupt, or any event of default or past due account.
In the case of larger non-homogenous receivables, the impairment provision is calculated on an individual basis. When assessed
individually, the Group records a provision for impairment which amounts to the difference between the value of the discounted
expected future cash flows of the receivable and its carrying amount, taking into account existing collateral, if any. This
provision takes into consideration the financial condition of the debtor, the resources, payment track-record and, if applicable,
the value of collateral.
The Group does not hold significant homogeneous credits.
The carrying amount of the assets is reduced through the use of the provision account, and the amount of the loss is recognized
in the statement of comprehensive income within “Selling expenses”. Subsequent recoveries of amounts previously written off
are credited against “Selling expenses” in the statement of comprehensive income.
1.b.19) Cash and cash equivalents
In the consolidated statement of cash flow, cash and cash equivalents include cash in hand, deposits held at call with banks and
other short-term highly liquidity investments with original maturities of three months or less. They do not include bank
overdrafts.
1.b.20) Dividends distribution
Dividends payable by the Group are recognized as liabilities in the period in which they are approved.
1.b.21) Business combinations
Business combinations are accounted for by applying the acquisition method when YPF takes effective control over the
acquired company.
The Group recognizes in its financial statements the identifiable assets acquired, the liabilities assumed, any non-controlling
interest and, goodwill, if any, in accordance with IFRS 3.
The acquisition cost is measured as the sum of the consideration transferred, measured at fair value at their acquisition date and
the amount of any non-controlling interest in the acquired entity. The Group will measure the non-controlling interest in the
acquired entity at fair value or at the non-controlling interest’s proportionate share of the acquired entity’s identifiable net assets.
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If the business combination is achieved in stages, the Group shall remeasure its previously held equity interest in the acquired
entity at its acquisition date fair value and recognize a gain or loss in the statement of comprehensive income.
The goodwill cost is measured as the excess of the consideration transferred over the identifiable assets acquired and liabilities
assumed net by the Group. If this consideration is lower than the fair value of the assets identifiable and liabilities assumed, the
difference is recognized in the statement of comprehensive income.
1.b.22) Total or partial disposal of foreign operation whose functional currency is other than the U.S. Dollar
On the disposal of a foreign operation (that is, a disposal of the Group’s entire interest in a foreign operation, or a disposal
involving loss of control over a subsidiary that includes a foreign operation) all of the translation differences accumulated in
equity in respect of that operation attributable to the equity holders of the Company are reclassified to profit or loss.
In the case of a partial disposal that does not result in the Group losing control over a subsidiary that includes a foreign
operation, the proportionate share of accumulated translation differences are re-attributed to non-controlling interest and are not
recognized in profit or loss.
Goodwill and fair value adjustments arising on the acquisition of a foreign entity are treated as assets and liabilities of the
foreign entity and translated at the closing rate. Translation differences arising are recognized in other comprehensive income.
1.b.23) Segment Information
Operating segments are reported in a manner consistent with the internal reporting provided to the top authority decision-maker,
who is the person responsible for allocating resources and assessing the performance of the operating segments. Operating
segments are described in Note 4.
1.b.24) New standards issued
As required by IAS 8, “Accounting policies, changes in accounting estimates and errors”, we detail below a brief summary of
the standards or interpretations issued by the IASB, whose application is mandatory as of the closing date of these consolidated
financial statements, as well as of those whose application has not been mandatory as of the closing date of these consolidated
financial statement and, therefore, have not been adopted by the Group.
The standards, interpretations and related amendments published by the IASB whose application is mandatory as of the
closing date of these consolidated financial statements and, therefore, have been applied by the Group, are the following:
IAS 19 – Employee Benefits
In November 2013, IASB issued an amendment to IAS 19, to simplify the accounting on employees’ contribution or third party
to the defined benefit plans, allowing recognition of the aforementioned contribution as a reduction in the service cost in the
period in which the related service was rendered rather than recognizing it at the service period.
It is applicable for fiscal years beginning on or after July 1, 2014.
Annual improvements of IFRS –– 2010-2012 Cycle
The 2010-2012 annual improvements are applicable to fiscal years beginning on or after July 1, 2014. There follows a summary
of the main standards amended and the purposes thereof.
F-31
IFRS 2 Share-based payment
IFRS 3 Business Combinations
Standard
IFRS 8 Operating Segments
Definition of the vesting conditions.
Purpose of the amendment
Accounting for the contingent consideration under a business
combination
(i) Disclosure of criteria applied to decided whether or not to
group operating segments, (ii) when is required reconciliation
of all assets of the reportable segments to the assets of an
entity
IFRS 13 Fair value measurement
Short-term receivables and payables
IAS 16 Property, Plant and Equipment and IAS 38 Intangible assets
Method of revaluation, pro rata restructuring of acumulated
depreciation (amortization)
IAS 24 Relates Parties Disclosures
Key management staff
Annual improvements of IFRS. 2011-2013 Cycle
The 2011-2013 annual improvements are applicable to fiscal years beginning on or after July 1, 2014. There follows a summary
of the main standards amended and the purposes thereof.
Standard
IFRS 3 Business combinations
IFRS13 Fair value measurement
IAS 40 Investment Property
Exemptions to the scope of joint ventures
Purpose of the amendment
Scope of paragraph 52 (portfolio exception)
Clarification of the interpretation between IFRS 3 and IAS 40
in classifying of property as investment property or property
occupied by owner
Standards or interpretations issued by the IASB whose application is not mandatory at the closing date of these
consolidated financial statements and have not been adopted by the Company.
IFRS 9 – Financial Instruments
In July 2014, IASB introduced an amendment to supersede IAS 39. The standard includes the requirements for
classification and measurement, impairment and hedge accounting of financial instruments. It is effective for fiscal years
beginning on or after January 1, 2018 with early application permitted.
IFRS 11 – Join Arrangements
In May 2014, IASB amended IFRS 11 in order to establish that acquisitions of participations in joint operations whose
activities constitute a business as defined by IFRS 3, apply the accounting principles set out in this standard. It is effective
for fiscal years beginning on or after January 1, 2016, with the early application permitted.
Amendments to IFRS 11 provide guidelines as to how to account for the acquisition of an interest in a joint venture in
which activities constitute a business as per the definition of IFRS 3, “Business Combinations”.
Also, a joint operator is required to disclose the significant information requested by the IFRS 3 and other standards
applicable to business combinations.
Entities must apply amendments prospectively to the acquisitions of interests in joint ventures occurring from the
beginning of fiscal years commencing on January 1, 2016.
The Company’s Management does not anticipate that the application of these amendments to IFRS 11 will have a
significant effect on the financial statements of the Company, as the Company does not deal in these types of transactions.
F-32
IFRS 14 – Regulatory deferral accounts
In January 2014, the IASB approved IFRS 14 which is applicable to all fiscal years beginning on or after January 1, 2016,
and which is authorized to be applied in advance. The scope of this Standard is limited to entities which have adopted the
IFRS for the first time and which have recognized the balances of the regulated activities deferral accounts in their
financial statements according to their previous accounting standards. The first accounting statements presented by the
Group under the IFRS were as of December 31, 2012 and the standard was issued in January 2014. Therefore, the Group
has not applied this standard to its financial statements.
IFRS 15 – Revenues from contracts with customers
IFRS 15 is effective for periods reported as beginning on January 1, 2018 or later, though its early application is permitted.
Entities may decide whether to apply the model retrospectively or use an amended transition approach, to which the
standard will be applied retrospectively only in the event of contracts which have not been completed by the initial
application date (e.g. January 1, 2018 for a company whose fiscal year ends on December 31)
IFRS 15 sets forth a comprehensive and detailed model for the entities to use it in the accounting of revenues from
contracts with customers. It shall substitute for the following revenues Standards and Interpretations as of its effective date:
- IAS 18 Revenue;
- IAS 11 Construction contracts;
- IFRIC 13 Customer loyalty programmes;
- IFRIC 15 Agreements for the construction of real estate;
- IFRIC 18 Transfer of assets from customers; and
- SIC 31: Barter transactions involving advertising services.
IAS 16 and 38 – Depreciation and amortization methods
Amendments to IAS 16, “Property, plant and equipment” prohibits entities from applying a depreciation method based in
the income from property, plant and equipment items. On the other hand, amendments to IAS 38, “Intangible assets”
include legal presumptions ascertaining that revenues are not appropriate principles for the amortization of intangible
assets.
Amendments apply prospectively to annual fiscal years beginning on or after January 1, 2016, and its advanced application
is permitted.
IAS 16 and 41 – Agriculture – Production Plants
Amendments to IAS 16 and IAS 41, “Agriculture” define the concept of “production plant”. In addition they require
biological assets to meet this definition in order to be accounted for as property, plant and equipment under IAS 16 rather
than IAS 41. As to the amendments, production plants may be measured using the cost model or the revaluation model set
forth in IAS 16.
Amendments are retroactively applied for fiscal years beginning on or after January 1, 2016 and advanced application is
permitted. As a temporary provision, entities need not disclose the quantitative information required by paragraph 28 (f) of
IAS 8 for the current period. However, quantitative information is required for the previous fiscal year filed.
IAS 27 – Separate Financial Statements
Amendments focus on separate financial statements and allow the use of the equity method in such financial statements.
Amendments are retroactively applied for fiscal years beginning on or after January 1, 2016 and advanced application is
permitted
F-33
IFRS 10 and IAS 28 – Sale or contribution of assets between an investor and its associate or joint venture
In September 2014, the IASB amended IFRS 10 and the IAS 28 to clarify that in transactions involving a controlled
company, the extension of the profit or loss to be recognized in the financial statements depends on whether the controlled
company sold or contributed constitutes a business according to the IFRS 3.
On August 10, 2015, the IASB issued a proposal to postpone the effective date of these amendments indefinitely depending
on the result of its research project on the accounting through the equity method, which was approved on December 17, 2015.
IAS 1 – Presentation of the financial statements – Disclosures initiative
Amendments to IAS 1 are effective for fiscal years beginning on or after January 1, 2016 and advanced application is
permitted. The application of the amendments need not be disclosed.
The amendments were a response to the comments that there were difficulties in the application of the materiality concept in
practice at the time of drafting some of the requirements of IAS 1 has been interpreted to avoid the use of judgment. Some
highlights of the amendments are as follow:
•
•
•
The entity should not reduce the understandability of its financial statements by concealing substantial information
with irrelevant information or by adding material elements with different nature or function.
The entity does not need to disclose specific information required by the IAS if the resulting information is not
material.
In the section “Other comprehensive income” of a Statement of Comprehensive Income and other comprehensive
income, amendments require separate disclosures for the following elements:
-
-
the proportion of other comprehensive income of associates and joint ventures which is recognized by the equity
method and which will not be subsequently reclassified to results, and
the proportion of other comprehensive income of associates and joint ventures which is recognized by the equity
method and which will be subsequently reclassified to results.
In addition, amendments to IAS 1 are related to the following matters:
•
•
•
•
•
Materiality
Disaggregation and subtotals
Notes
Disclosure of accounting policies
Other comprehensive income resulting from investments recognized by the equity method
IFRS 10, IFRS 12 and IAS 28 – Exemption from consolidation for investment entities.
In December 2014, the IASB issued amendments to IFRS 10, IFRS 12 and IAS 28 which are applicable to fiscal years
beginning on or after January 1, 2016, and may be applied in advance.
Amendments clarify, among other things that the exemption from preparation of consolidated financial statements is
available for a controlling entity which is controlled by an investment entity, even if the investment entity measures all its
controlled companies at fair value under IFRS 10. The amendments resulting from IAS 28 to clarify the exemption from
applying the equity method is applicable to an investor in an associate or joint venture if such investor is controlled by an
investment entity which measures all its investments at fair value.
Amendments further clarify that the requirement that an investment entity consolidate a controlled company that provides
services related to the foregoing investment activities is only applicable to controlled companies which are not investment
entities.
On the other hand, amendments clarify that by applying the equity method to an associate or joint venture which is an
investment entity, an investor may retain the fair value measurements that the associate or joint venture used for its affiliates.
Finally, it is also made clear that an investment entity that measures all its controlled companies at fair value must make the
disclosures required by IFRS 12 “Disclosure of interest in other entities”.
F-34
Annual improvements to the IFRS- 2012-2014 Cycle
In September 2014, the IASB issued 2012-2014 annual improvements which are applicable to fiscal years beginning on or after
January 1, 2016, and may be applied in advance.
There follows a summary of the main standards amended and their respective purposes:
IFRS 5 Non-current assets held for sale and discontinued
operations.
Standard
IFRS 7 Financial instruments disclosures (with amendments results
from IFRS 1 amendments)
IAS 19 Employee Benefits
IAS 34 Interim financial reporting
Changes in assets disposal methods
Purpose of amendment
(i) Service Agreements
(ii) Applicability of IFRS 7 amendments to compensation
disclosures in condensed interim financial statements.
Discount rate: regional market issues
Disclosure of information included “elsewhere in the interim
financial statement’
Currently the Group is analyzing the impact of the enforcement of standard amended and new standards.
1.c) Accounting Estimates and Judgments
The items in the financial statements and areas which require the highest degree of judgment and estimates in the preparation of the
financial statements are: (1) crude oil and natural gas reserves; (2) provisions for litigation and other contingencies; (3) provisions for
environmental liabilities and hydrocarbon wells abandonment obligations (see Note 1.b.6 paragraph iv); (4) the calculation of income
tax and deferred income tax; and (5) provision for impairment of fixed assets and intangible asset (see Note 1.b.9).
Crude oil and natural gas reserves
Estimating crude oil and gas reserves is an integral part of the Company’s decision-making process. The volume of crude oil and gas
reserves is used to calculate the depreciation using unit of production ratio and to assess the impairment of the capitalized costs
related to the exploration and production assets (see Notes 1.b.8 and 1.b.9 and last paragraph of this note)
The Group prepares its estimates of crude oil and gas reserves in accordance with the rules and regulations established for the crude
oil and natural gas industry by the U.S. Securities and Exchange Commission (“SEC”).
Provisions for litigation and other contingencies
The final costs arising from litigation and other contingencies, and the perspective given to each issue by the Management may vary
from their estimates due to different interpretations of laws, contracts, opinions and final assessments of the amount of the claims.
Changes in the facts or circumstances related to these types of contingencies can have, as a consequence, a significant effect on the
amount of the provisions for litigation and other contingencies recorded or the perspective given by the Management.
Provisions for environmental costs
Given the nature of its operations, the Group is subject to various provincial and national laws and regulations relating to the
protection of the environment. These laws and regulations may, among other things, impose liability on companies for the cost of
pollution clean-up and environmental damages resulting from operations. YPF management believes that the Group’s operations are
in substantial compliance with laws and regulations of Argentina and the countries where the Group operates, relating to the
protection of the environment as such laws have historically been interpreted and enforced.
F-35
The Group periodically conducts new studies to increase its knowledge of the environmental situation in certain geographic areas
where it operates in order to establish the status, cause and remedy of a given environmental issue and, depending on its years of
existence, analyze the Argentine Government’s possible responsibility for any environmental liabilities existing prior to
December 31, 1990. The Group cannot estimate what additional costs, if any, will be required until such studies are completed and
evaluated; however, provisional remedial or other measures may be required.
In addition to the hydrocarbon wells abandonment legal obligation, the Group has accrued the environmental remediation which
evaluations and/or remediation works are probable and can be reasonably estimated, based on the Company’s existing remediation
program. Legislative changes, on individual costs and/or technologies may cause a re-evaluation of the estimates. The Group cannot
predict what environmental legislation or regulation will be enacted in the future or how future laws or regulations will be
administered. In the long-term, these potential changes and ongoing studies could materially affect the Group’s future results of
operations.
Additionally, certain environmental contingencies in the United States of America were assumed by Tierra Solutions Inc. and Maxus
Energy Corporation, indirect controlled companies through YPF Holdings Inc. The detail of these contingencies is disclosed in
Note 10.
Income tax and deferred income tax assets and liabilities
The proper assessment of income tax expenses depends on several factors, including interpretations related to tax treatment for
transactions and/or events that are not expressly provided for by current tax law, as well as estimates of the timing and realization of
deferred income taxes. The actual collection and payment of income tax expenses may differ from these estimates due to, among
others, changes in applicable tax regulations and/or their interpretations, as well as unanticipated future transactions impacting the
Group´s tax balances.
Provision for impairment of fixed assets and intangible assets
As indicated in Note 1.b.8 and 1.b.9, as a general criterion, the method used to estimate the recoverable amount of fixed assets and
intangible assets mainly consists in the calculation of the value in use, based on the future estimate cash flows resulting from the
exploitation of the relevant assets, discounted at a rate that reflects the weighted average capital employed.
For fiscal year 2015, the discount rate was 10.33% after taxes (the discount rate applied for fiscal year 2014 was 10.86% after taxes).
Calculations of crude oil price estimates for fiscal year 2015 for the CGU Oil—YPF of the Exploration and Production Segment have
taken into account the disengagement of internal market prices from international prices with respect to this product in the latest
years, based on the negotiations between country’s Producers and Refineries and Argentine Government policies intended to preserve
the sector activity levels and ensure the crude oil supply for the country. Therefore, the following local market price presumptions
have been considered for the different varieties of crude oil: i) for 2016 and 2017 the Company has considered local market prices
according to the negotiations between Producers and Refineries based on prices currently effective since January 2016, resulting in an
estimate of US$/Bbl 67.5 for Medanito crude oil, US$/Bbl 54.9 for Escalante crude oil and US$/Bbl 55.9 for Cañadón Seco crude oil;
ii) for 2018, 2019 and 2020, it has been considered the estimates for the local prices based on the the estimation of the international
price (adjusted by the quality of each type of crude oil, freight and the relative shortage situation in the local market) set on the basis
of estimate Brent crude oil values according to analysts’ consensus estimates available as of December 31, 2015 (at US$/Bbl 68.7 for
2018, US$/Bbl 68.3 for 2019 and US$/Bbl 69.3 for 2020); and iii) thereafter, a projected price curve is considered on the basis of an
adjustment by United States of America forecasted inflation.
Based on the above mentioned methodology and presumptions, the Group has recorded a charge for impairment of fixed assets with
respect to the CGU Oil - YPF of the Exploration and Production Segment of 2,361 as of December 31, 2015, mainly due to a
decrease in the short-term price of oil in the local market and a reduction in the expectations of medium and long term international
prices. The recoverable amount of the CGU Oil – YPF, after taxes, amounts to 76,829.
F-36
In addition, the Group has recorded a charge for impairment of fixed assets for the CGU Oil - YPF Holdings which groups the assets
of crude oil production fields in the United States, of 94 as of December 31, 2015, due to a decrease in crude oil international prices.
The recoverable amount of the CGU Oil – YPF Holdings amounts to 179. Likewise, the Group has recorded a charge for impairment
of intangible assets of 80 related to exploration rights of which the recoverable amount is zero.
For fiscal years ended December 31, 2014 and 2013, the Group has not recorded charges for impairment, or income from reversion of
impairment of assets.
Main factors that could result in additional charges for impairment in future periods would be any increase in the discount rate used
for the cash flow estimates and a further decline in the business, competitive and economic factors, such as oil and gas prices, change
in the number of equipment units, the competitive context and the cost of raw material, as well as a potential revisions of previous
estimates of reserves based on the new prices.
1.d) Comparative Information
Balance items as of December 31, 2014 and 2013 presented in these financial statements for comparison purposes arise from the
consolidated financial statements then ended. Certain reclassifications have been made in order to present figures comparatively with
those of this year.
2. ACQUISITIONS AND DISPOSALS
Fiscal year ended on December 31, 2015
– May 7 2015, Repsol Butano S.A. transferred to YPF shares representing 33.997 % of YPF Gas S.A.’s capital stock and Repsol
Trading S.A. transferred to YPF 17.79% of Oleoducto Transandino Chile’s capital stock, the transaction was made for an
amount of 161.
Fiscal year ended on December 31, 2014
– On February 12, 2014, YPF and its subsidiary YPF Europe BV (“YPF Europe”, constituted in January, 2014) accepted an offer
made by Apache Overseas Inc. and Apache International Finance II S.à r.I. (collectively, “Apache Group”) for the acquisition of
100% of Apache’s interest in controlled companies which are the owners of assets located in the Argentine Republic, and the
acquisition of certain intercompany loans owed by the acquired companies to the Apache Group companies. The price agreed
upon by the parties was US$ 786 million, which was canceled through by an initial deposit of US$ 50 million held on
February 12, 2014, and the remaining balance was paid on March 13, 2014, date from which YPF has taken control of the
mentioned companies (the “acquisition date”). Together with the assets and liabilities incorporated by these companies, local
market debt was assumed for US$ 31 million.
As of result of the previously described transaction, YPF acquired the following corporate shares: (i) 100% of the capital stock
of Apache Canada Argentina Investment S.à r.I. and 100% of the capital stock of Apache Canada Argentina Holdings S.à r.I.;
(ii) 100% of the capital stock of Apache Argentina Corporation, through which it will control 65.28% of Apache Petrolera
Argentina S.A., and (iii) 34.72% of Apache Petrolera Argentina S.A. Since YPF has acquired 100% of the interest, there is no
non-controlling interest recorded.
As of the date of acquisition these companies controlled directly or indirectly assets in the provinces of Neuquen, Tierra del
Fuego and Río Negro, with a total production of approximately 49,100 oil equivalent barrels per day and had an important
infrastructure of pipelines and facilities and around 350 employees. In addition, certain assets have potential for exploration and
development in the Vaca Muerta formation.
F-37
The fair value of the main identified assets and liabilities of the companies acquired (100% interest values and after
consolidation adjustments), which have been incorporated in the Company´s balance sheet as of the date of acquisition is
disclosed below:
Cash and cash equivalents
Assets held for sale
Inventories
Trade receivables
Other receivables and other assets
Intangible assets – Exploration rights
Fixed assets
Provisions
Deferred income tax liabilities
Loans
Accounts payables
Social security and other taxes payables
Income tax liability
95
1,538
55
520
213
1,246
5,469
781
1,241
110
639
134
24
Below is detailed the information related with revenues, costs and expenses of the acquired companies required by IFRS:
Since the acquisition date up to
December 31, 2014
Since the beginning of the year up to
December 31, 2014
Revenues
Cost of sales
Gross profit
Other operating
expenses
Operating income
Financial result, net
Income tax
Net income for the
period
3,370
(2,960)
410
(232)
178
(78)
560
660
4,099
(3,601)
498
(282)
216
(95)
681
802
Additionally, YPF and Apache Energía Argentina S.R.L. has entered into a transfer of assets agreement with Pluspetrol S.A.
(“Pluspetrol”) whereby it will transfer, in exchange for US$ 217 million, an interest that belongs to Apache Energía Argentina
S.R.L. (a subsidiary of Apache Canada Argentina Holdings S.à.r.l.), in three concessions and four joint operation contracts, as
well as an interest of YPF in a joint operation contract. The aforementioned interests correspond to assets located in the
Province of Neuquén, with the objective of jointly exploring and developing the Vaca Muerta formation. The mentioned
transaction has been approved by the regulatory authority during November, 2014.
During October, 2014, the registered names of some companies have changed as follows: Apache Energía Argentina S.R.L. to
YSUR Energía Argentina S.R.L.; Apache Natural Resources Petrolera Argentina S.R.L. to YSUR Recursos Naturales S.R.L.;
Apache Petrolera Argentina S.A. to YSUR Petrolera Argentina S.A.; Apache Argentina Corporation to YSUR Argentina
Corporation; Apache Canada Argentina Investment S.à.r.l. to YSUR Argentina Investment S.à.r.l.; and Apache Canada
Argentina Holdings S.à.r.l. to YSUR Argentina Holdings S.à.r.l.
–
On January 31, 2014, YPF acquired Petrobras Argentina S.A.’s 38.45% interest in the joint operation contract Puesto Hernández
signed between both companies for the exploitation of the Puesto Hernández area (the “Area”). The Area is an exploitation
concession located in the Provinces of Neuquén and Mendoza. YPF is the holder of the concession until 2027, which is operated
under the aforementioned joint operation contract which expires on June 30, 2016 and will be early terminated. Now YPF owns
100% interest in the Area, and has become the operator. Puesto Hernández currently produces approximately 10,000 barrels per
day of light crude oil (Medanito quality). The transaction was completed for the amount of US$ 40.7 million. By becoming the
operator of the Area, YPF will be able to accelerate its investments plans to optimize the Area’s production potential until 2027.
The amount paid was mainly classified as fixed assets.
F-38
–
–
–
On February 7, 2014, YPF acquired Potasio Rio Colorado S.A.’s 50% interest in the joint operation contract, Segment 5 Loma
La Lata – Sierra Barrosa (known as “Lajas” formation) signed by YPF and Potasio Rio Colorado S.A. for the exploitation of the
Lajas formation concession area (the “Area”). The Area is an exploitation concession, located in the Province of Neuquén. YPF
is the holder of the concession which expires in 2027. Exploitation of the Area was conducted under the aforementioned joint
operation contract. The terms of the joint operation contract provided that it would expire upon the earlier of the expiration of
the concession or the early termination of any agreement or contract that granted the right to continue exploiting the Area. As a
result of the termination of the joint operation contract YPF will own 100% interest in the Area. The consideration for the
transaction was US$ 25 million. The amount paid was mainly classified as fixed assets.
YPF and Sinopec Argentina Exploration and Production, Inc., Sucursal Argentina (“SINOPEC”), are part in a Joint Operating
Agreement (“JOA”) in the area “La Ventana”, located in the basin of Cuyo in the Province of Mendoza, whose original due date
was December 31, 2016. YPF is the exclusive owner of such exploitation concession whose due date was November 14, 2017,
and through executive order of the Province of Mendoza No. 1,465/2011 the original due date was extended for 10 years more,
to November 14, 2027, the new concession due date. On September 1, 2014 (“effective date”) YPF and SINOPEC extended the
JOA’s due date in relation with the Concession for the Exploitation of Hydrocarbons in the area “La Ventana”, until
December 31, 2026. The extension of the Concession and the JOA involve the continuity of the participation of the parties in the
rights and commitments that emerge from the Concession and that, as of the effective date, YPF’s percentage of participation
increased by an additional 10%, reaching 70%. The consideration for the transaction was US$ 44 million, an amount that
SINOPEC will pay to YPF for the extension of the Concession. Additionally, the transaction generated an income of 369, which
has been charged to “Other operating result, net”, in the statement of comprehensive income.
On December 5, 2014, an agreement has been signed between the Province of Neuquén, Gas y Petróleo del Neuquén S.A., YPF
S.A. and YSUR Energía Argentina S.R.L. in which the restructuring of the Joint Operating Agreement has been arranged related
to “La Amarga Chica” and “Bajada de Añelo” non-conventional hydrocarbons exploitation concession in which YPF and YSUR
will hold the following interests: (i) La Amarga Chica, YPF S.A. 100% (ii) Bajada de Añelo: YPF S.A. 85% and YSUR Energía
Argentina S.R.L. 15%. As compensation for the aforementioned restructuring (a), YPF S.A. has made a US$41 million payment
to the Neuquén Province, US$ 12 million for and on behalf of YSUR Energía Argentina S.R.L. and (b) YPF and YSUR granted
in favor of the Province of Neuquén, who thereby contributed to Gas y Petróleo de Neuquén S.A, the totality of YPF and
YSUR’s interests in the following areas: (i) Puesto Cortadera; (ii) Loma Negra NI; (iii) Cutral Co Sur; (iv) Neuquén del Medio;
(v) Collon Cura Bloque I; (vi) Bajo Baguales. These transferences became effective on January 1, 2015.
Fiscal year ended on December 31, 2013
–
During May 2013, the Company, through its subsidiary YPF Inversora Energética S.A. took control of GASA (controlling
company of Metrogas), by acquiring shares representing a 54.67% interest in GASA. Prior to this acquisition, the Company
through its interest in YPF Inversora Energética S.A. owned 45.33% of the capital of GASA
F-39
The main characteristics of the transaction, as well as information to enable users of the financial statements to assess the nature
and financial effects of the business combination resulting from the aforementioned operation, as IFRS requires are described
below.
Name and description of the
acquired entity:
GASA is the parent company of Metrogas, company awarded with the license for the
distribution of natural gas in the City of Buenos Aires and southern suburbs of Buenos Aires
Province.
GASA owns 70% equity interest of Metrogas by holding all of the class “A” representing a
stake of 51% in capital, and class “B” shares representing a stake of 19% in capital.
Metrogas provides distribution services to approximately 2.2 million customers within its
service area (city of Buenos Aires and eleven municipalities in the south of Buenos Aires).
The acquisition date, the
percentage acquired and
primary reasons for the
acquisition:
YPF has fulfilled with the obligations arising from the purchase agreement, which corresponded
to the payment of the balance of the purchase price, during May 2013. As a result of the
transaction (which includes shares representing 54.67% stake in GASA), YPF controls 100% of
GASA.
The acquisition-date fair value
of the total consideration
transferred and the
acquisition-date fair value of
each main asset:
As described in Resolution No. 1/2566 D from Enargas, the operation is expected to result in a
substantial benefit to customers of the distribution company as a consequence of applying to
Metrogas a responsible management, not only in economic and financial matters, but also taking
social principles upon which the welfare of current and future generations.
The price of the above operation (acquisition of shares representing 54.67% stake in GASA)
was US$ 9.7 million, which implies a total value for the 100% of the participation in GASA of
approximately US$ 17.7 million, which approximates the fair value of the net assets and
liabilities of the acquired company.
Below are the fair values of the main assets and liabilities of the acquired company (values at
100% interest) at acquisition date, which have been incorporated into YPF’s balance sheet as of
the acquisition date:
Cash and cash equivalents
Trade receivables
Other receivables and other assets
Fixed assets
Provisions
Loans
Accounts payables
Social security and other taxes payables
Deferred income tax liabilities
Income tax liability
143
318
23
1,788
104
879
461
102
328
12
Additionally, non-controlling interest amounted to 178 as of the date of acquisition,
corresponding to the 30% interest in Metrogas, a company controlled by GASA.
Prior to the transaction, the carrying value of the interest in GASA amounted to zero. As a
consequence of the acquisition, remeasurement of shares in GASA to fair value generated a gain
of approximately 136, which has been recorded in the second quarter of 2013 under “Income on
investments in companies” account in the comprehensive income statement of YPF for the year
ended December 31, 2013.
Income and expenses from
ordinary activities of GASA
since the acquisition date
included in the financial
statements of the YPF for the
year 2013:
Revenues
Cost of sales
Gross profit
Other operating expenses
Operating income
Financial result, net
Income tax
Net loss for the year
Income and expenses from
ordinary activities of GASA
since the beginning 2013 and
until December 31, 2013:
Revenues
Cost of sales
Gross profit
1,363
(1,044)
319
(266)
53
(326)
139
(134)
1,848
(1,425)
423
Other operating expenses
Operating income
Financial result, net
Income tax
Net income for the year
(394)
29
721(1)
(253)
497
(1)
Includes the gain as a result of debt restructuring of Metrogas and GASA prior to the acquisition date for a total amount of 1,141
F-40
–
On June 4, 2013, YPF, Pluspetrol Resources Corporation B.V. (“PPRC”) and Pluspetrol Energy S.A. (“PPE”) signed an
agreement to carry out a spin off PPE, without dissolving it, and allocate part of their assets to create a new spun off company.
This spin-off was done with effective date on August 1, 2013 and as a consequence, YPF Energía Eléctrica S.A. was created
(spun off company), on which YPF directly or indirectly holds 100% interest and YPF withdrew its participation in PPE.
As a result of the spin off, YPF Energía Eléctrica S.A. maintained the electric generation business, previously operated by PPE,
and a 27% interest in Ramos Consortium.
The main characteristics of the transaction, as well as information to enable users of the financial statements to assess the nature
and financial effects of the business combination resulting from the aforementioned operation as IFRS requires, are described
below.
Name and description of
the parent company:
Name and description of
the spun off company:
Pluspetrol Energy S.A. On July 31, 2013, YPF had 45% interest on its capital.
YPF Energía Eléctrica S.A. The main goal of this company is the electric generation business
operating two power plants in the province of Tucuman, plus a 27% interest in the Ramos
Consortium dedicated to the Exploration and Production of Hydrocarbons.
The spin off date:
July 31, 2013
Fair value of the
consideration transferred
and fair value of the main
assets of the acquisition:
The fair value of the net assets and liabilities transferred to the company’s spin off process,
amounted to 485. Below are the main items:
Trade receivables
Fixed assets
Accounts payables
Loans
Social security and other taxes payables
Deferred income tax liabilities
Other Liabilities
65
638
77
52
50
35
4
Prior to the transaction, the carrying amount of the investment in PPE was 350 and YPF
maintained a 115 translation difference reserve in relation with the mentioned investment. As a
consequence of the spin-off, the fair value of the assets and liabilities emerging from the spin-
off of Pluspetrol Energy S.A. generated a gain of approximately 20, that was recorded in the
second semester of 2013 under the “Income on investments in companies” account in the
comprehensive income statement of the Company for the year ended December 31, 2013.
Income and expenses from
ordinary activities of YPF
Energía Eléctrica since the
acquisition date included
in the financial statements
of the Company for the
year ended December 31,
2013:
Revenues
Cost of sales
Gross profit
Other operating expenses
Operating income
Financial results, net
Income tax
Net income for the year
266
(162)
104
8
112
(16)
(28)
68
3. FINANCIAL RISK MANAGEMENT
The Group´s activities involve various types of financial risks: market risk (including exchange rate risk, interest rate risk and price
risk, credit risk, liquidity risk, and capital risk). The Group maintains an organizational structure and systems that allow the
identification, measurement and control of the risks to which it is exposed.
Market Risk
The market risk to which the Group is exposed is the possibility that the valuation of the Group’s financial assets or financial
liabilities as well as certain expected cash flows may be adversely affected by changes in interest rates, exchange rates or certain other
price variables.
F-41
The following is a description of these risks as well as a detail of the extent to which the Company is exposed and a sensitivity
analysis of possible changes in each of the relevant market variables.
Exchange Rate Risk
The value of financial assets and liabilities denominated in a currency different from the Company´s functional currency is subject to
variations resulting from fluctuations in exchange rates. Since YPF’s functional currency is the U.S. dollar, the currency that
generates the greatest exposure is the Argentine peso, the Argentine legal currency.
The Group does not use derivatives as a hedge against exchange rate fluctuations. While during this fiscal year the Group started to
operate with US dollars future exchange rate agreements, for IFRS 7 “Financial instruments: disclosures” no exchange rate risk arises
from financial instruments denominated in the Entity´s functional currency.
Otherwise, according to the Company’s functional currency, and considering the translation process to presentation currency, the
fluctuations in the exchange rate related to the financial assets and liabilities´ value in pesos does not have any effect in the Other
comprehensive income in Shareholders’ equity.
The following table provides a breakdown of the effect a variation of 10% in the prevailing exchange rates on the Group’s net
income, taking into consideration the exposure of financial assets and liabilities denominated in pesos as of December 31, 2015
Impact on net income before income tax
corresponding to financial assets and
liabilities
Appreciation (+) /
depreciation (-) of
exchange rate of peso
against dollar
Income(loss) for fiscal year
ended December 31, 2015
+10%
-10%
1,912
(1,912)
Interest Rate Risk
The Group is exposed to risks related to interest rates to different extents, according to the different types of maturities and currencies
in which a loan was borrowed or cash was invested.
The Company’s short-term financial loans as of December 31, 2015 include negotiable obligations, pre-financing of exports and
imports´ financing arrangements, local bank credit lines and financial loans with local and international financial institutions. Long-
term financial loans include negotiable obligations and financial loans with local and international financial institutions.
Approximately 73% (77,538) of the total of the financial loans of the Group is denominated in U.S. dollars and the rest in Argentine
pesos, as of December 31, 2015. These loans are basically used for working capital and investments.
Financial assets mainly include, in addition to trade receivable which have low exposure to interest rate risk, bank deposits, fixed-
interest deposits and investments in mutual funds such as “money market” or short-term fixed interest rate instruments.
Historically, the strategy for hedging interest rates is based on the fragmentation of financial counterparts, the diversification of the
types of loans taken and, essentially, the maturities of such loans, taking into consideration the different levels of interest along the
yield curve in pesos or U.S. dollars, and the amount of the loans based on future expectations and the timing of the future investment
outlays to be financed.
The Group does not usually use derivative financial instruments to hedge the risks associated with interest rates.
Changes in interest rates may affect the interest income or expenses derived from financial assets and liabilities tied to a variable
interest rate. Additionally, the fair value of financial assets and liabilities that accrue interests based on fixed interest rates may also
be affected.
The table below provides information about the financial assets and liabilities as of December 31, 2015 that accrues interest
considering the applicable rate:
Fixed interest rate
Variable interest rate
December 31,2015
Financial Assets (1)
667
27
Financial Liabilities (2)
74,386
31,365
Total
694
105,751
(1)
(2)
It only includes temporary investments and loans to related companies. Does not include trade receivables which mostly do not
accrue interest.
Includes only financial loans. Does not include accounts payable which mostly do not accrue interest.
F-42
The portion of loans which accrues variable interest rate is mainly exposed to the fluctuations in LIBOR and BADLAR.
Approximately 22,564 accrues variable interest of BADLAR plus a maximum spread of 4.75% and 8,801 accrues variable interest of
LIBOR plus a spread between 4% and 7.5%.
The table below shows the estimated impact on the consolidated comprehensive income that an increase or decrease of 100 basis
points in the interest rate would have.
Impact on the
net income
after income
tax
Increase (+) / decrease (-) in the
interest rates (basis points)
Income(loss) for fiscal year
ended December 31, 2015
+100
-100
(129)
129
Other Price Risks
The Group is not significantly exposed to commodity price risks, as a result, among other reasons, of the existing regulatory,
economic and government policies, which determines that local prices charged for gasoline, diesel and other fuels are not affected in
the short-term by fluctuations in the price of such products in international and regional markets. Additionally, the Group is reached
by certain regulations that affect the determination of export prices received by the Group, such as those mentioned in Notes 1.b.15
and 11.c, which consequently limits the effects of short-term price volatility in the international market.
In addition, the Group is exposed to the own price risk for investments in financial instruments (mutual funds and US dollars future
exchange rate agreements), which were classified in the statement of financial position as “at fair value through profit or loss”. The
Group continuously monitors the change in these investments for significant movements.
As of December 31, 2015, the aggregate value of investments in financial assets at fair value through profit or loss amounts to 1,578.
The following table shows the effect that a 10% variation in the prices of investments in financial instruments would have on the
Company’s results as of December 31, 2015:
Impact on the net result
before income tax
Liquidity Risk
Increase (+) / decrease (-) in
the prices of investments in
financial
Profit (loss) for the year
ended
December 31, 2015
+10%
-10%
391
(453)
Liquidity risk is associated with the possibility of a mismatch between the need of funds to meet short, medium or long term
obligations.
As mentioned in previous paragraphs, the Group intends to align the maturity profile of its financial debt to be related to its ability to
generate enough cash flows for its payment, as well as to finance the projected expenditures for each year. As of December 31, 2015
the availability of liquidity reached 20,087, considering cash for 13,920, other liquid financial assets for 1,467 and available credit
lines with banks for 4,700. Additionally, YPF has the ability to issue debt under the negotiable obligations global program originally
approved by the Shareholders meeting in 2008 expanded in September 2012, in April 2013 and in February 2015 (see Note 6.j).
After the process which concluded with the change of shareholders mentioned in Note 8, the Group is still focused in structuring
more efficiently the structure of maturity of its debt, in order to facilitate the daily operations and to allow the proper financing of
planned investments.
To this end, the Group operates derivative financial instruments (US dollars future exchange rate agreements) as a way of managing
liquidity risk. As of December 31, 2015, there are US dollars future exchange rate agreements with maturities between February and
May 2016. These amount to 464 (see Note 5).
F-43
The following table sets forth the maturity dates of the Company’s financial liabilities as of December 2015:
Financial Liabilities
Accounts Payable (1)
Loans
December 31, 2015
Maturity date
0 - 1
year
1 - 2
years
2 - 3
years
3 - 4
years
4 - 5
years
More
than 5
years
Total
103 40,128
39,511
27,817 6,888 21,928 3,892 5,914 39,312 105,751
514 — — —
(1) The amounts disclosed are the contractual, undiscounted cash flows associated to the financial liabilities given that they do not differ
significantly from their face values
Most of the Company’s financial debt contains usual covenants for contracts of this nature. Additionally, approximately 50% of the outstanding
financial debt as of December 31, 2015 is subject to financial covenants related to the leverage ratio and debt service coverage ratio of the
Company.
A portion of the financial debt provides that certain changes in control with respect to the Company may constitute an event of default. In
addition, part of the financial debt also contains cross default or cross acceleration provisions (the “Acceleration Clauses”) which may result in
their advanced enforceability if the debt containing provisions related to change of control becomes in default.
Credit Risk
Credit risk is defined as the possibility of a third party not complying with its contractual obligations, thus negatively affecting results of
operations of the Group.
Credit risk in the Group is measured and controlled on an individual customer basis. The Group has its own systems to conduct a permanent
evaluation of credit performance of all of its debtors, and the determination of risk limits with respect to third parties, in line with best practices
using for such end internal customer records and external data sources.
Financial instruments that potentially expose the Group to a concentration of credit risk consist primarily of Cash and cash equivalents, trade
receivables and other receivables. The Group invests excess cash primarily in high liquid investments with financial institutions with a strong
credit rating both in Argentina and abroad. In the normal course of business and based on ongoing credit evaluations to its customers, the Group
provides credit to its customers and certain related parties. Likewise, the Group accounts for doubtful trade losses in the Statement of
Comprehensive Income, based on specific information regarding its clients. As of the date of these consolidated financial statements, the
Company’s customer portfolio is diversified.
The provisions for doubtful accounts are measured by the following criteria:
–
–
The aging of the receivable;
The analysis of the customer’s capacity to return the credit granted, also taking into consideration special situations such as the existence
of a voluntary reorganization petition, bankruptcy and arrears, guarantees, among others.
The maximum exposure to credit risk of the Group as of December 31, 2015 based on the type of its financial instruments and without
excluding the amounts covered by guarantees and other arrangements mentioned below, is set forth below:
Cash and cash equivalents
Other financial assets
Maximum exposure as
of December 31, 2015
15,387
29,743
Considering the maximum exposure to the risk of the Other financial assets based on the concentration variable of the counterparties, the credit
with the National Government and direct agencies accounts for 44% (12,848) while the Group’s remaining debtors are diversified.
Following is the breakdown of the financial assets past due as of December 31, 2015.
Less than three months past due
Between three and six months past due
More than six months past due
F-44
Current trade
receivable
4,395
952
1,991
7,338
Other current
receivables
1,557
112
197
1,866
At such date, the provision for doubtful trade receivables amounted to 848 and the provisions for other doubtful receivables amounted
to 33. These provisions are the Group´s best estimate of the losses incurred in relation with accounts receivables.
Guarantee Policy
As collateral of the credit limits granted to customers, the Group has several types of guarantees received from them. In the service
stations and distributors market, where generally long-term relationships with customers are established, mortgages prevail. For
foreign customers prevail the joint and several bonds from their parent companies. In the industrial and transport market, bank
guarantees prevail. With a lower presence, the Group has also obtained other guarantees as credit insurances, surety bonds, guarantee
customer – supplier, car pledges, etc.
The Group has effective guarantees granted by third parties for a total amount of 6,277, 3,676 and 2,131 as of December 31, 2015,
2014 and 2013, respectively.
During the year ended December 31, 2015, the Group executed guarantees received for an amount of 2. As of December 31, 2014 and
2013, the Group executed guarantees received for an amount of 1 and 4, respectively.
4. SEGMENT INFORMATION
The different segments in which the Group is organized have in consideration the different activities from which the Group obtains
income and incurs expenses. The mentioned organizational structure is based on the way in which the highest authority in the
operational decision-making process analyzes the main financial and operating magnitudes while making decisions about resource
allocation and performance assessment also considering the Group´s business strategy.
•
•
Exploration and production: it covers the exploration and production of hydrocarbons, including contractual purchases of
natural gas and purchase of crude oil arising from service contracts and concession obligations, as well as crude oil and
natural gas intersegment sales
Downstream: it covers the refining, petrochemistry, transport, purchase of crude oil and natural gas to third parties and
intersegment, and marketing of crude oil, natural gas, refined products, petrochemicals, electric power generation and
natural gas distribution. Grouping those businesses in a single segment is mainly because they are aligned in strategy,
which is shared among them, considering the operational synergies generated between refining and petrochemical
businesses, having the focus on maximizing fuel offered to the market carried out by the commercial department, in
respect to volume and quality.
•
Corporate and Other: it covers other activities, not falling into these categories, principally including corporate
administrative expenses and assets, construction activities, the environmental remediation and other legal expenses
according to the controlled company YPF Holdings (see Note 10).
Sales between business segments were made at internal transfer prices established by the Company, which generally seek to
approximate to market prices.
F-45
Operating income and assets for each segment have been determined after consolidation adjustments.
For the year ended December 31, 2015
Revenues from sales
Revenues from intersegment sales
Revenues
Operating income (loss)
Income (loss) on investments in companies
Depreciation of fixed assets
Impairment of fixed assets and intangible assets(4)
Acquisition of fixed assets
Assets
For the year ended December 31, 2014
Revenues from sales
Revenues from intersegment sales
Revenues
Operating income (loss)
Income (loss) on investments in companies
Depreciation of fixed assets
Acquisition of fixed assets(2)
Assets
For the year ended December 31, 2013
Revenues from sales
Revenues from intersegment sales
Revenues
Operating income (loss)
Income (loss) on investments in companies
Depreciation of fixed assets(3)
Acquisition of fixed assets(3)
Assets
Exploration
and Production
Downstream
Corporateand
Other
Consolidation
Adjustments(1)
Total
16,044
64,243
80,287
7,535
—
23,075
2,535
48,598
223,035
8,853
61,844
70,697
12,353
(10)
17,180
41,371
126,228
3,851
38,846
42,697
6,324
(93)
9,591
28,849
70,775
138,962
1,535
140,497
8,446
318
3,168
—
9,343
113,805
132,254
1,489
133,743
10,978
568
2,445
8,392
68,509
85,624
1,147
86,771
6,721
446
1,452
4,903
51,336
1,130
6,182
7,312
(2,331)
—
442
—
1,939
26,708
835
5,212
6,047
(3,343)
—
311
1,408
16,356
638
2,285
2,923
(1,522)
—
193
453
15,161
—
(71,960)
(71,960)
2,938
—
—
—
—
(95)
—
(68,545)
(68,545)
(246)
—
—
—
(2,539)
—
(42,278)
(42,278)
(363)
—
—
—
(1,677)
156,136
—
156,136
16,588
318
26,685
2,535
59,880
363,453
141,942
—
141,942
19,742
558
19,936
51,171
208,554
90,113
—
90,113
11,160
353
11,236
34,205
135,595
(1) Correspond to the elimination of income among segments of the group YPF.
(2)
Investments in fixed assets net of increases corresponding to YSUR Group at acquisition date, Joint Operations Puesto Hernández and
Las Lajas, and La Ventana agreement at acquisition date of the additional interest. See Note 2.
Investments and depreciations of fixed assets net of increases corresponding to GASA at acquisition date and YPF Energía Eléctrica at
spin-off date (see Note 2).
(3)
(4) See Note 1.c).
The distribution of revenues by geographic area, according to the markets for which they are intended, for the years ended on December 31,
2015, 2014 and 2013, and fixed assets by geographic area as of December 31, 2015, 2014 and 2013 are as follows:
2015
Revenues
2014
2013
2015
Fixed assets
2014
2013
Argentina
Mercosur and associated countries
Rest of America
Europe
Total
143,851 126,539 78,070 269,914 156,415 93,255
20
8,298 6,461
221
4,753 4,022
2,352 1,560 — — —
156,136 141,942 90,113 270,905 156,930 93,496
6,302
4,175
1,808
553
438
38
477
As of December 31, 2015 no foreign client represents 10% or more of the Group´s revenue from its ordinary activities.
5. FINANCIAL INSTRUMENTS BY CATEGORY
The following tables show the financial assets and liabilities by category of financial instrument and a reconciliation to the corresponding
line item in the statements of financial position, as appropriate. Since the line items “Trade receivables”, “Other receivables” and “Accounts
payable” contain both financial instruments and non-financial assets and liabilities (such as tax receivables, and receivables and payables in
kind, among other) reconciliation is presented in the columns headed “Non-financial assets” and “Non-financial Liabilities”.
F-46
Financial Assets
Other receivables (excluding provision for other
doubtful receivables)
Trade receivables (excluding provision for doubtful
trade receivables)
Investment in financial assets
Cash and cash equivalents
Financial Assets
Other receivables (excluding provision for other
doubtful receivables)
Trade receivables (excluding provision for doubtful
trade receivables)
Cash and cash equivalents
Financial Assets
Other receivables (excluding provision for other
doubtful receivables)
Trade receivables (excluding provision for doubtful
trade receivables)
Cash and cash equivalents
Financial Liabilities
Accounts Payable
Loans
Financial Liabilities
Accounts Payable
Loans
Provisions
Financial Liabilities
Accounts Payable
Loans
Provisions
Financial
Assets at
amortized cost
Financial
Assets at fair
value through
profit or loss
Subtotal
Financial Assets
Non-financial
Assets
Total
2015
6,392
23,428
—
14,613
44,433
—
6,392
15,574
21,966
—
804
774
1,578
23,428
804
15,387
46,011
—
—
—
15,574
23,428
804
15,387
61,585
Financial
Assets at
amortized cost
Financial
Assets at fair
value through
profit or loss
Subtotal
Financial Assets
Non-financial
Assets
Total
2014
3,096
13,063
8,223
24,382
—
3,096
5,875
8,971
—
1,535
1,535
13,063
9,758
25,917
—
—
5,875
13,063
9,758
31,792
Financial
Assets at
amortized cost
Financial
Assets at fair
value through
profit or loss
Subtotal
Financial Assets
Non-financial
Assets
Total
2013
4,018
8,126
8,691
20,835
—
4,018
5,517
9,535
—
2,022
2,022
8,126
10,713
22,857
—
—
5,517
8,126
10,713
28,374
Financial
Liabilities at
amortized cost
40,128
105,751
145,879
Financial
liabilities at fair
value through
profit or loss
2015
Subtotal
financial
liabilities
—
—
—
40,128
105,751
145,879
Financial
Liabilities at
amortized cost
Financial
liabilities at fair
value through
profit or loss
2014
Subtotal
financial
liabilities
30,552
49,305
718
80,575
—
—
—
—
30,552
49,305
718
80,575
Financial
Liabilities at
amortized cost
Financial
liabilities at fair
value through
profit or loss
2013
Subtotal
financial
liabilities
20,319
31,890
485
52,694
F-47
—
—
—
—
20,319
31,890
485
52,694
Non-financial
liabilities
476
—
476
Total
40,604
105,751
146,355
Non-financial
liabilities
420
—
28,245
28,665
Total
30,972
49,305
28,963
109,240
Non-financial
liabilities
463
—
20,083
20,546
Total
20,782
31,890
20,568
73,240
Gains and losses on financial instruments are allocated to the following categories:
Interest income
Interest loss
Financial accretion
Exchange differences , net
Fair value gains on financial assets at
fair value through profit or loss
Gains on derivative financial
instruments
Interest income
Interest loss
Financial accretion
Exchange differences, net
Fair value gains on financial assets at
fair value through profit or loss
Interest income
Interest loss
Financial accretion
Exchange differences , net
Fair value gains on financial assets at
fair value through profit or loss
Financial and non-
financial Assets /
Liabilities at amortized
cost
1,638
(8,618)
(1,987)
20,214
—
—
11,247
Financial and non-
financial Assets /
Liabilities at amortized
cost
1,029
(5,456)
(1,880)
7,782
—
1,475
Financial and non-
financial Assets /
Liabilities at amortized
cost
821
(2,514)
(1,319)
5,744
—
2,732
2015
Financial Assets /
Liabilities at fair value
through profit or loss
—
—
—
—
446
464
910
2014
Financial Assets /
Liabilities at fair value
through profit or loss
—
—
—
—
297
297
2013
Financial Assets /
Liabilities at fair value
through profit or loss
—
—
—
—
103
103
Total
1,638
(8,618)
(1,987)
20,214
446
464
12,157
Total
1,029
(5,456)
(1,880)
7,782
297
1,772
Total
821
(2,514)
(1,319)
5,744
103
2,835
Fair value measurements
IFRS 9 defines the fair value of a financial instrument as the amount for which an asset could be exchanged, or a financial liability
settled, between knowledgeable, willing parties in an arm’s length transaction. All financial instruments recognized at fair value are
allocated to one of the valuation hierarchy levels of IFRS 7. This valuation hierarchy provides for three levels.
In the case of Level 1, valuation is based on unadjusted quoted prices in active markets for identical financial assets or liabilities that
the Group can refer to at the end of the period. A market is deemed active if transactions take place with sufficient frequency and in
sufficient quantity for price information to be available on an ongoing basis. Since a quoted price in an active market is the most
reliable indicator of fair value, this should always be used if available. Financial instruments assigned by the Group to this level
comprise investments in listed mutual funds, and financial derivate.
In the case of Level 2, fair value is determined by using valuation methods based on inputs directly or indirectly observable in the
market. If the financial instrument concerned has a fixed contract period, the inputs used for valuation must be observable for the
whole of this period. The Group has not valued financial instruments under this category.
In the case of Level 3, the Group uses valuation techniques not based on inputs observable in the market. This is only permissible
insofar as no market data are available. The inputs used reflect the Group’s assumptions regarding the factors which market players
would consider in their pricing. The Group uses the best available information for this, including internal company data. The Group
has not valued financial instruments under this category.
YPF Finance Division has a team in place in charge of estimating valuation of financial instruments required to be reported in the
financial statements, including the fair value of Level-3 instruments. The team directly reports to the Chief Financial Officer
(“CFO”). The CFO and the valuation team discuss the valuation methods and results upon the acquisition of a financial instrument
and, if necessary, on a quarterly basis, in line with the Group’s quarterly reports.
F-48
The Group’s policy, transfers among the several categories of valuation hierarchies are recognized when occurred, or when there are
changes in the prevailing circumstances requiring the transfer.
In addition, no transfer has occurred among the different hierarchies used to determine the fair value of the Group’s financial
instruments.
The tables below show the Group’s financial assets and liabilities measured at fair value as of December 31, 2015, 2014 and 2013 and
their allocation to their fair value levels.
Financial Assets
Investments in financial assets:
- Mutual funds
- Other financial assets
Cash and cash equivalents:
- Mutual funds
Financial Assets
Cash and cash equivalents:
- Mutual funds
Financial Assets
Cash and cash equivalents:
- Mutual funds
Level 1 Level 2 Level 3
Total
2015
340 —
464 —
—
—
340
464
774 —
1,578 —
—
—
774
1,578
Level 1 Level 2 Level 3
Total
2014
1,535 —
1,535 —
—
—
1,535
1,535
Level 1 Level 2 Level 3
Total
2013
2,022 —
2,022 —
—
—
2,022
2,022
The Group has no financial liabilities at fair value through profit or loss.
Fair value of financial assets and financial liabilities measured at amortized cost
The estimated fair value of loans, considering unadjusted listed prices (Level 1) for Negotiable Obligations and interest rates offered
to the Group (Level 3) for the other financial loans remaining, amounted to 106,336, 53,108 and 33,784 as of December 31, 2015,
2014 and 2013, respectively.
The fair value of the following financial assets and financial liabilities do not differ significantly from their book value:
•
•
•
•
Other receivables
Trade receivables
Cash and cash equivalents
Accounts payable
F-49
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:
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The Group capitalizes the financial cost as a part of the cost of the assets. For the year ended December 31, 2015, 2014 and 2013 the
rate of capitalization has been 12.01%, 12.29% and 12.03%, respectively and the amount capitalized amounted to 1,003, 574 and 605,
respectively for the years above mentioned.
Set forth below is the evolution of the provision for obsolescence of materials and equipment for the years ended December, 31 2015,
2014 and 2013:
Amount at beginning of year
Increase charged to expenses
Decreases charged to income
Amounts incurred due to utilization
Translation differences
Amount at end of year
2015
313
243
—
(6)
212
762
2014
166
133
(4)
(32)
50
313
2013
132
16
—
—
18
166
Set forth below is the cost evolution for the exploratory wells in evaluation stage as of the years ended on December 31, 2015, 2014
and 2013:
Amount at beginning of year
Additions pending the determination of proved reserves
Decreases charged to exploration expenses
Decrease of assets assignment
Reclassifications to mineral property, wells and related equipment with proved
reserves
Translation difference
Amount at end of year
2015 2014 2013
993 710 815
1,219 921 424
(479) (336) (255)
(466) (336) —
(89) (188) (481)
599 222 207
1,777 993 710
The following table shows the capitalized cost for exploratory wells for a period greater than a year and the number of projects related
as of December 31, 2015.
Between 1 and 5 years
6.c) Investments in companies:
Investments in companies (Notes 7 and 16)
Provision for impairment of investments in companies
6.d) Inventories:
Refined products
Crude oil and natural gas
Products in process
Construction works in progress for third parties
Raw materials, packaging materials and others
Amount
242
Number of
proyects
3
Number of
Wells
3
2015
2014
2013
4,384 3,189 2,136
(12)
4,372 3,177 2,124
(12)
(12)
2015
10,709
7,155
169
85
1,140
19,258(1)
2014
7,720
4,187
99
271
724
13,001(1)
2013
5,713
3,451
115
107
495
9,881(1)
(1) As of December 31, 2015, 2014 and 2013, the fair value of the inventories does not differ, significantly, from their cost.
F-52
6.e) Other receivables:
Trade
Tax credit, export rebates and production incentives
Trust contributions – Obra Sur
Loans to clients and balances with Related parties (1)
Collateral deposits
Prepaid expenses
Advances and loans to employees
Advances to suppliers and custom agents (2)
Receivables with partners in Joint Operations and
agreements
Insurance receivables (Note 11.b)
Miscellaneous
Provision for other doubtful receivables
Provision for valuation of other receivables to their
estimated recoverable value
2015
2014
2013
Noncurrent
—
304
30
297
318
198
8
—
Current
Noncurrent
928
8,058
18
2,366
895
682
285
3,147
—
130
56
231
528
39
7
—
Current Noncurrent
—
22
67
517
397
11
3
—
664
1,066
22
53
435
451
299
2,224
Current
377
1,233
34
81
253
490
166
1,062
1,118
—
241
2,514
(13)
1,881
808
384
19,452
(39)
612
—
95
1,698
—
764
1,068
227
7,273
(102)
1,852(3)
—
62
2,931
—
595(3)
1,956
357
6,604
(98)
—
2,501
—
19,413
(7)
1,691
(1)
7,170
(4)
2,927
—
6,506
(1) See Note 12 for information about related parties.
(2)
Includes among others, advances to customs agents for the payment of taxes and import rights related to the imports of fuels and
goods.
Includes the receivables related to the investment agreement with Chevron Corporation (see Note 11.c).
(3)
6.f) Trade receivables:
Accounts receivable and related parties (1)
Provision for doubtful trade receivables
(1) See Note 12 for information about related parties.
Changes in the provision for doubtful trade receivables
2015
2014
2013
Noncurrent
Current
Noncurrent
469 22,959
(848)
—
469 22,111
26
(7)
19
Current Noncurrent
60
13,037
(6)
(866)
54
12,171
Current
8,066
(652)
7,414
2015
2014
2013
Amount at beginning of year
Increases charged to expenses
Decreases charged to income
Amounts incurred due to utilization
Translation differences
Amount at end of year
6.g) Cash and cash equivalents:
Noncurrent
7
—
—
(7)
—
—
Current
866
313
(412)
(17)
98
848
Noncurrent
Current Noncurrent
Current
6
—
—
—
1
7
652
210
(41)
(4)
49
866
5
—
—
494
191
(73)
1 —
40
652
—
6
Cash
Short-term investments
Financial assets at fair value through profit or loss
F-53
2015
13,920
693
774
15,387
2014
6,731
1,492
1,535
9,758
2013
4,533
4,158
2,022
10,713
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6.i) Income Tax:
The calculation of the income tax expense accrued for the years ended December 31, 2015, 2014 and 2013 is as follows:
Current income tax
Deferred income tax
2015
2014
517
(25,154)
(24,637)
(7,323)
(5,900)
(13,223)
2013
(2,844)
(6,425)
(9,269)
The reconciliation of pre-tax income included in the consolidated statement of comprehensive income, at the statutory tax rate, to the income tax
as disclosed in the consolidated statements of comprehensive income for the years ended December 31, 2015, 2014 and 2013, respectively, is as
follows:
Net income before income tax
Statutory tax rate
Statutory tax rate applied to net income before income tax
Effect of the valuation of fixed assets and intangible assets measured in
functional currency
Exchange differences
Effect of the valuation of inventories
Income on investments in companies
Miscellaneous
Income tax expense
2015
29,063
35%
2014
22,072
2013
14,348
35%
35%
(10,172)
(7,725)
(5,022)
(31,200)
19,164
(2,412)
111
(128)(1)
(24,637)
(10,064)
5,872
(1,156)
195
(345)
(13,223)
(7,186)
4,008
(807)
124
(386)
(9,269)
(1)
Includes 301 of tax loss carry-forwards originated during previous years.
Breakdown of deferred tax as of December 31, 2015, 2014 and 2013 is as follows:
Deferred tax assets
Provisions and other non-deductible liabilities
Tax losses carry-forward and other tax credits
Miscellaneous
Total deferred tax assets
Deferred tax liabilities
Fixed assets
Miscellaneous
Total deferred tax liabilities
Total deferred tax, net
2015
2014
2013
3,093
3,236
83
6,412
2,479
222
17
2,718
1,723
45
115
1,883
(45,393)
(4,877)
(50,270)
(43,858)
(19,250)
(2,172)
(21,422)
(18,704)(1)
(11,659)
(1,649)
(13,308)
(11,425)
(1)
Includes (1,241) arising form the business combination detailed in Note 2.
For fiscal year ended December 31, 2015, YPF estimated a tax loss carry-forward, therefore created a provision for 1,192 for minimum presumed
income tax, which was charged to Other current receivables.
Deferred income tax assets are recognized for tax loss carry-forwards to the extent their setoff through future taxable profits is probable. Tax loss
carry-forwards in Argentina expire within 5 years.
In order to fully realize the deferred income tax asset, the Group will need to generate taxable income. Based upon the level of historical taxable
income and projections for future over the years in which the deferred income tax are deductible, the management believes that as of
December 31, 2015 it is probable that the Group will realize all of the deferred income tax assets.
As of December 31, 2015, Group’s tax loss carry-forwards at the statutory tax rate were as follows:
Date of generation
2011
2012
2013
2014
2015
Date of expiration
2016
2017
2018
2019
2020
F-55
Jurisdiction
Argentina
Argentina
Argentina
Argentina
Argentina
Amount
4
85
85
134
2,928
3,236
As of December 31, 2015, 2014 and 2013 the Group did not recognized deferred income tax assets for 4,373, 3,511 and 978, respectively,
from which 2,041, 1,953 and 559 corresponds to taxable temporary differences not recoverable and 2,332, 1,558 and 419 corresponds to
tax loss carry forwards from a foreign subsidiary, since they do not meet the recognition criteria set forth under IFRS. From the tax loss
carry forwards above mentioned, as of December 2015, 957 will expire form 2017, 1,351 from 2032 and 24 have undetermined expiration
date.
As of December 31, 2015, 2014 and 2013 the Group has classified as deferred tax asset 954, 244 and 34, respectively, and as deferred tax
liability 44,812, 18,948 and 11,459, respectively, all of which arise from the net deferred tax balances of each of the separate companies
included in this consolidated financial statements.
Likewise, 100 has not been recorded for minimum presumed income tax, with expiration between 2016 and 2024.
As of December 31 2015, 2014 and 2013, the causes that generate allocations to other comprehensive income, did not create temporary
differences for income tax.
6.j) Loans:
Argentine pesos:
Negotiable obligations
Loans
Account overdraft
Currencies other than the
Argentine peso:
Negociable obligations(2)(4)
Export pre- financing
Imports financing
Loans
Interest rate (1)
Maturity
2015
Non-
current
Current
current Current
2014
Non-
2013
Non-
current
Current
20.83%
15.25%
24.50%
- 29.31% 2016-2024 19,280
- 29.06% 2016-2020 1,224(3)
—
- 29.00%
20,504
2016
2,050
1,104(3)
4,425(5)
7,579
847
10,858 2,329 9,553 1,666
580
613
— 2,398 —
111
11,705 5,364 10,166 2,357
637
1.29%
3.50%
4.00%
2.30%
- 10.00% 2016-2028 52,651
- 7.20% 2016-2018 1,039
—
- 6.81%
- 7.50% 2016-2019 3,740
57,430
77,934
2016
9,981
3,680
4,736
1,841
20,238
27,817
22,472 1,257 10,921 2,630
— 2,428 — 1,119
— 2,848 — 1,601
1,853 1,378 1,989 1,107
24,325 7,911 12,910 6,457
36,030 13,275 23,076 8,814
(1) Annual interest rate as of December 31, 2015.
(2) Disclosed net of 1,349, 252 and 137 corresponding to YPF’s outstanding Negotiable Obligations repurchased through open market
transactions as of December 31, 2015, 2014 and 2013, respectively.
Includes 460 corresponding to loans granted by Banco Nación Argentina, of which 210 accrue fixed interest rate of 15% until
December 2015 and then accrue variable interest of BADLAR plus a spread of percentage points and 250 accrue variable interest of
BADLAR plus a spread of 4 percentage points with a maximum lending interest rate of the overall portfolio of Banco Nación. See
Note 12.
Includes 9,970, 7,129 and 7,494 as of December 31, 2015, 2014 and 2013, respectively, of face value negotiable obligations, to be
cancelled in argentine pesos at the prevailing exchange rate according to terms of issued series.
Includes 1,926 of overdraft granted by Banco Nación Argentina as of December 31, 2015. See Note 12.
(3)
(4)
(5)
The breakdown of the Group’s borrowings as of the year ended on December 31, 2015, 2014 and 2013 is as follows:
Amount at beginning of the year
Proceed form loans
Payments of loans
Decease of loans for “El Orejano” agreement (2)
Payments of interest
Accrued interest(1)
Exchange differences and translation, net
Amount at the end of the year
Includes capitalized financial costs. See Note 6.b
(1)
(2) See Note 11.
F-56
2013
2014
2015
49,305 31,890 17,104
55,158 23,949 16,829
(24,090) (13,320) (6,804)
(2,373) — —
(6,780) (5,059) (2,696)
8,342 5,447 2,939
26,189 6,398 4,518
105,751 49,305 31,890
On February 5, 2015 the General Shareholder’s Meeting of YPF approved an increase of the amount of the Global Medium—Term
Notes (“M.T.N.”) Program of the Company for US$ 3,000 million, for a total maximum nominal outstanding amount at any time of
the Program of US$ 8,000 million or its equivalent in other currencies.
In December, 2015, YPF and an investors group entered into a purchase and sale agreement whereby YPF purchased 100% of Series
A-L Negotiable Obligations (NO) and Additional Series A-L NO (collectively, “Series A-L NO”) issued by GASA in a principal
amount of up to US$ 61.9 million. In consideration therefor, YPF has granted to GASA bondholders the right to underwrite Series
XXVI NO, which were issued in December 2015.
As a result of the above (i) YPF issued the relevant waiver to GASA with respect to any and all obligations assumed (including any
principal and interest payment) under the Indenture between GASA and The Bank of New York Mellon, dated March 15, 2013,
without such waiver implying a Triggering Event; (ii) The Bank of New York Mellon was given due notice of the acquisition of the
Series A-L NO so that, in its capacity of Trustee, it may proceed to the settlement thereof under the restructuring merger to be
executed by YPF with respect to GASA and YPF Inversora Energética S.A., the latter being the current controlling company of
GASA as well as a company controlled by YPF and (iii) YPF agreed not to transfer the Series A-L NO until surrender thereof for
cancellation.
As a result of the foregoing regarding the merger proceedings, and in compliance with IAS 21 “The effects of change in foreign
exchange rates” guidelines, the exchange difference recognized by GASA in its statement of comprehensive income following the
acquisition of Series A-L NO by YPF was accounted for in “Other comprehensive income – Exchange difference from investments in
companies” of the Company and will be offset with YPF’s translation difference resulting from the merger.
F-57
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-
5
8
6.k) Accounts payable:
2015
2014
2013
Noncurrent
Current
Noncurrent
Current Noncurrent
Current
Trade and related parties (1)
Investments in companies with negative shareholders’ equity
Extension of Concessions
Guarantee deposits
Miscellaneous
204 38,782
1
—
412
340
467
8
73
317
625 39,979
66 28,522
—
2
884
332
418
—
168
580
566 30,406
153 18,553
127
—
1,036
275
328
8
268
34
470 20,312
(1) For more information about related parties, see Note 12.
6.l) Revenues:
Sales (1)
Production incentive program (Note 11.c)
Revenues from construction contracts
Turnover tax
2015
2013
2014
159,387 147,020 92,978
1,988 — —
312
(5,694) (5,497) (3,177)
156,136 141,942 90,113
455
419
(1)
Includes 12,345, 7,762 and 4,289 for the year ended on December 2015, 2014 and 2013, respectively, associated with revenues
related to the natural gas additional injection stimulus program created by Resolution 1/2013 of the Planning and Strategic
Coordination Commission of the National Plan of Hydrocarbons Investment. See Note 11.c).
6.m) Cost of sales:
Inventories at beginning of year
Purchases for the year
Production costs
Translation effect
Inventories at end of year
Cost of sales
2014
2013
2015
13,001
9,881 6,922
33,886 35,951 25,846
85,550 68,840 42,980
2,821 2,227
6,358
(19,258) (13,001) (9,881)
119,537 104,492 68,094
F-59
6.n) Expenses:
Salaries and social security taxes
Fees and compensation for services
Other personnel expenses
Taxes, charges and contributions
Royalties, easements and canons
Insurance
Rental of real estate and equipment
Survey expenses
Depreciation of fixed assets
Amortization of intangible assets
Industrial inputs, consumable materials
and supplies
Operation services and other service
contracts
Preservation, repair and maintenance
Unproductive exploratory drillings
Transportation, products and charges
Provision for doubtful trade receivables
Publicity and advertising expenses
Contractual commitments
Fuel, gas, energy and miscellaneous
Total 2015
Total 2014
Total 2013
Production
costs
7,566
775
2,303
1,144
11,932
831
3,360
—
25,706
185
Administrative
expenses
2015
Selling
expenses
Exploration
expenses
Total
2014
2013
2,065
1,378(2)
277
259
—
38
33
—
382
117
1,207
280
121
2,885
17
56
394
—
597
21
Total
8,031
1,940
1,986
224 11,062
2,457
24
2,743
42
4,288(1) 5,660(1)
—
28 11,977
925
—
3,789
2
504
504
— 26,685
323
—
9,544
792
2,950
251
19,936
469
Total
5,906
1,361
1,370
3,893(1)
5,871
592
1,956
77
11,236
197
3,801
27
88
5
3,921
3,522
2,143
6,261
14,231
—
4,796
—
—
31
2,628
85,550
68,840
42,980
237
248
—
25
—
395
—
105
5,586
4,530
2,686
546
322
—
3,756
(99)
292
—
616
11,099
10,114
7,571
5,908
11,812
1,265
6,881
169
710
52
3,640
—
7,044
24 14,825
1,425
8,577
1,425
—
—
—
—
195
(99)
687
31
3,544
2,473 104,708
2,034
829
85,518
3,043
7,959
514
4,805
118
265
174
2,586
54,066
(1)
(2)
Include approximately 1,220, 1,775 and 1,757 corresponding to export withholdings for years ended December 2015, 2014 and
2013, respectively.
Includes 140 of YPF’s Directors and Statutory Auditor’s fees and remunerations for all concepts. On April 30, 2015, the
General Ordinary and Extraordinary Shareholder’s meeting of YPF decided to ratify fees for the year 2014 for 123 and decided
to approve as fees and remunerations for all concepts in advance for the year 2015 the sum of approximately 146.
The expense recognized in the consolidated statements of comprehensive income related to research and development activities
during the years ended December 31, 2015, 2014 and 2013 amounted to 270, 215 and 83, respectively.
F-60
6.o) Other operating results, net:
Lawsuits
Environmental remediation from YPF Holdings Inc
Impairment of fixed assets and intangible assets (Note 1.c)
Temporary economic assistance (1)
Sale of extension of “La Ventana” and “Magallanes” concession agreement
(Note 2)
Construction incentive (2)
Insurance (Note 11.b)
Miscellaneous
2015
(1,188)
(162)
(2,535)
711
2014
(2,034)
(214)
—
—
2013
(1,069)
(201)
—
—
—
621
371
1,329
(853)
428
233
—
557
(1,030)
—
169
1,479
(151)
227
(1) Corresponds to the temporary economic assistance received by Metrogas S.A. ordered by the Argentine Energy Secretariat in
Resolution No. 263/2015 (see Note 11.c).
(2) Corresponds to the incentive to Argentine manufacturers of capital goods received by A-Evangelista S.A. under the provisions
of Executive Order No. 379/2001 of the Argentine Ministry of Economy.
6.p) Financial results, net:
Financial income
Interest income
Exchange differences
Total financial income
Financial loss
Interest loss
Financial accretion
Exchange differences
Total financial loss
Other financial results
Fair value gains on financial assets at fair value through profit or loss
Gains on derivative financial instruments
Total other financial results
Other financial results, net
2015
2014
2013
1,638
25,625
27,263
1,029
10,272
11,301
821
7,919
8,740
(8,618)
(1,987)
(5,411)
(16,016)
(5,456)
(1,880)
(2,490)
(9,826)
(2,514)
(1,319)
(2,175)
(6,008)
446
464
910
12,157
297
—
297
1,772
103
—
103
2,835
7. INVESTMENTS IN COMPANIES AND JOINT OPERATIONS
The following table shows in aggregate, considering that none of the companies are individually material, the amount of investments
in affiliated companies and joint ventures as of December 31, 2015, 2014 and 2013:
Amount of investments in affiliated companies
Amount of investments in joint ventures
Provision for impairment of investments in companies
2015
2014
2013
1,248 757 227
3,136 2,432 1,909
(12)
4,372 3,177 2,124
(12)
(12)
Investments in companies with negative shareholders’ equity are disclosed in “Accounts payable”.
The main changes that affected the amount of the investments previously mentioned, during the fiscal years ended December 31,
2015, 2014, and 2013 are the following:
Amount at the beginning of year
Acquisitions and contributions
Loss from investments in companies and joint ventures
Translation differences
2015
3,177
163
318
999
2014
2,124
448
558
470
2013
1,914
153
353
470
Reclassification of investments in companies with negative shareholders’
equity
Distributed dividends
Other movements
Amount at the end of year
(1)
(280)
(4)
4,372
(125)
(299)
1
3,177
123
(280)
(609)(1)
2,124
(1)
Includes, among others, the movements related to Pluspetrol Energy SA split-off.
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Note 16 provides information of investments in companies.
The following table shows the main magnitudes of net results from the Group’s investments in companies, calculated according to the
equity method, for the fiscal year ended on December 31, 2015, 2014 and 2013. YPF has made adjustments, where applicable, to the
amounts reported by such companies in order to comply with the accounting principles used by such companies to those used by the
Company:
Net Income
Other comprehensive income
Comprehensive income for the year
Affiliated companies
2015 2014 2013
321 234 63(1)
50 18 120
371 252 183
Joint ventures
2015 2014 2013
(3) 324 290
949 452 350
946 776 640
(1)
Includes 156 corresponding to the comprehensive income generated in business combination with GASA and YPF Energía
Eléctrica S.A. (see Note 2).
Additionally, the Group participates in joint operations and other agreements which give to the Group a contractually established
percentage over the rights of the assets and obligations that emerge from the contracts. Interest in such joint operations have been
consolidated line by line on the basis of the mentioned interest over the assets, liabilities, income and expenses related to each contract.
Interest in Joint Operations have been calculated based upon the latest available financial statements as of the end of each year, taking
into consideration significant subsequent events and transactions as well as management information available.
The exploration and production joint operations and other agreements in which YPF participates allocate the hydrocarbon production to
each partner based on the ownership interest, consequently such hydrocarbons are commercialized directly by the partners recognizing
each of them the corresponding economic effects.
Note 17 discloses the most relevant Joint Operations and other agreements on which the Company participates, and their operation
nature.
The assets and liabilities as of December 31 2015, 2014 and 2013, and expenses for the three fiscal years ended on December 31, 2015,
2014 and 2013 of the Joint Operations and other agreements are as follows:
Noncurrent assets
Current assets
Total assets
Noncurrent liabilities
Current liabilities
Total liabilities
Production Cost
Exploration expenses
2015
47,322
944
48,266
4,593
6,391
10,984
2014
22,439
1,295
23,734
3,129
4,641
7,770
2013
9,472
661
10,133
2,342
1,247
3,589
2015
12,959
395
2014
9,047
672
2013
4,647
43
8. SHAREHOLDERS’ EQUITY
The Company’s subscribed capital as of December 31, 2015, is 3,933 and is represented by 393,312,793 shares of common stock and
divided into four classes of shares (A, B, C and D), with a par value of Argentine pesos 10 and one vote per share. These shares are fully
subscribed, paid-in and authorized for stock exchange listing.
As of December 31 2015, there are 3,764 Class A outstanding shares. As long as any Class A share remains outstanding, the affirmative
vote of Argentine Government is required for: 1) mergers, 2) acquisitions of more than 50% of YPF shares in an agreed or hostile bid, 3)
transfers of all the YPF’s production and exploration rights, 4) the voluntary dissolution of YPF or 5) change of corporate and/or tax
address outside the Argentine Republic. Items 3) and 4) will also require prior approval by the Argentine Congress.
Until the enforcement of Law No. 26,741 detailed in the next paragraphs, Repsol S.A. (“Repsol”) had a participation in the Company,
directly and indirectly, of approximately 57.43% shareholding while Petersen Energía S.A. (“PESA”) and its affiliates exercised
significant influence through a 25.46% shareholding of YPF’s capital stock.
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Law No. 26,741 enacted on May 4, 2012, changed YPF’s shareholding structure. The mentioned Law declared as national public
interest and subject to expropriation the Class D Shares of YPF owned by Repsol, its controlled or controlling entities, representing
the 51% of YPF’s equity. According to Law 26,741, achieving self-sufficiency in the supply of hydrocarbons as well as in the
exploitation, industrialization, transportation and sale of hydrocarbons, is thereby declared of national public interest and a priority for
Argentina, with the goal of guaranteeing socially equitable economic development, the creation of jobs, the increase of the
competitiveness of various economic sectors and the equitable and sustainable growth of the provinces and regions. The shares
subject to expropriation will be distributed as follows: 51% for the Argentine federal government and 49% for certain Argentine
Provinces.
According to reports by Repsol to the BCBA dated May 7, 2014, Repsol sold to Morgan Stanley & Co. LLC and 11.86% of the
capital stock of YPF, represented by 46,648,538 ordinary shares Class D, ceasing to be a shareholder of the company after such
transaction.
On April 30, 2015, a General Ordinary and Extraordinary Shareholders’ meeting was held, which has approved the financial
statements of YPF for the year ended December 31, 2014 and additionally decided the following in relation with the distribution of
earnings of fiscal year ended as of December 31, 2014: (i) appropriate the amount of 120 to a reserve for future acquisition of YPF
shares under the “performance and bonus program” mentioned in the Director’s report of the consolidated financial statements for the
year ended December 31, 2014 giving to the Board of Directors the opportunity to acquire shares when it considers it convenient and
to comply with the commitments assumed and to be assumed in relation with the mentioned program; (ii) to appropriate the amount
of 8,410 to constitute a reserve for investment in accordance with the article 70, third paragraph of the Law No. 19,550 of Argentine
Corporations as amended; and (iii) the appropriation to a reserve for future dividends in an amount of 503, empowering the Board of
Directors to determine the opportunity of payment which should not exceed the ending of the present fiscal year. On June 8, 2015, the
Board of Directors decided to pay a dividend of 1.28 pesos per share for the amount of 503 which was available for shareholders on
July 28, 2015.
During the fiscal years ended 2015, 2014 and 2013, YPF has repurchased 382,985, 634,204 and 1,232,362 shares for a total amount
of 120, 200 and 120, respectively, and has settled 623,350, 563,754 and 479,174 shares to the beneficiaries of the Share-Based
Benefit Plan, respectively, in order to fulfill the Share-Based Benefit Plans mentioned in Note 1.b.10.iii). The cost of such
repurchases is accounted in equity in the “Acquisition cost of treasury shares” account, while the nominal value and the adjustment
due to the monetary restatement effect pursuant Previous Argentine GAAP have been reclassified from Subscribed Capital and
Adjustments to Contributions accounts to “Treasury shares” and “Adjustment to treasury shares”, respectively.
9. EARNINGS PER SHARE
The following table shows the net income and the number of shares that have been used for the calculation of the basic earnings per
share:
2015
2014
2013
Net income
Average number of shares outstanding
Basic and diluted earnings per share
4,579
9,002
392,101,191 392,136,465
22.95
11.68
5,125
392,789,433
13.05
Basic and diluted earnings per share are calculated as shown in Note 1.b.13.
10. PROVISIONS FOR PENDING LAWSUITS, CLAIMS AND ENVIRONMENTAL LIABILITIES
The Group is party to a number of labor, commercial, civil, tax, criminal, environmental, customs and administrative proceedings
that, either alone or in combination with other proceedings, could, if resolved in whole or in part adversely against it, result in the
imposition of material costs, fines, judgments or other losses. While the Group believes that such risks have been provisioned
appropriately based on the opinions and advice of our external legal advisors and in accordance with applicable accounting standards,
certain loss contingencies, are subject to change as new information develops and results of the presented evidence is obtain, among
others. It is possible that losses resulting from such risks, if proceedings are decided in whole or in part adversely to the Group, could
significantly exceed the recorded provisions.
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As of December 31, 2015, the Group has accrued pending lawsuits, claims and contingencies which are probable and can be
reasonably estimated, amounting to 10,524. The most significant pending lawsuits and contingencies accrued are described in the
following paragraphs.
Additionally, YPF is subject to various provincial and national laws and regulations relating to the protection of the environment.
These laws and regulations may, among other things, impose liability on companies for the cost of pollution clean-up and
environmental damages resulting from operations. Management believes that the Company’s operations are in substantial compliance
with Argentine laws and regulations currently in force relating to the protection of the environment as such laws have historically
been interpreted and enforced.
However, the Company is periodically conducting new studies to increase its knowledge concerning the environmental situation in
certain geographic areas where the Company operates in order to establish their status, causes and necessary remediation and, based
on the aging of the environmental issue, to analyze the possible responsibility of Argentine Government, in accordance with the
contingencies assumed by the Argentine Government for liabilities existing as of December 31, 1990. Until these studies are
completed and evaluated, the Company cannot estimate what additional costs, if any, will be required. However, it is possible that
other works, including provisional remedial measures, may be required.
Pending lawsuits: In the normal course of its business, the Company has been sued in numerous labor, civil and commercial actions
and lawsuits. Management, in consultation with the external legal advisors, has recorded a provision considering its best estimation,
based on the information available as of the date of the issuance of these consolidated financial statements, including counsel fees and
judicial expenses.
Liabilities and contingencies assumed by the Argentine Government: The YPF Privatization Law provided for the assumption by the
Argentine Government of certain liabilities of the predecessor as of December 31, 1990. In certain lawsuits related to events or acts
that took place before December 31, 1990, YPF has been required to advance the payment established in certain judicial decisions.
YPF has the right to be reimbursed for these payments by the Argentine Government pursuant to the above-mentioned indemnity.
Natural gas market: Pursuant to Resolution No. 265/2004 of the Secretariat of Energy, the Argentine Government created a program
of useful curtailment of natural gas exports and their associated transportation service. Such program was initially implemented by
means of Regulation No. 27/2004 of the Under-Secretariat of Fuels, which was subsequently substituted by the Program of
Rationalization of Gas Exports and Use of Transportation Capacity (the “Program”) approved by Resolution No. 659/2004 of the
Secretariat of Energy. Additionally, Resolution No. 752/2005 of the Secretariat of Energy provided that industrial users and thermal
generators (which according to this resolution will have to request volumes of gas directly from the producers) could also acquire the
natural gas from the cutbacks on natural gas exports through the Permanent Additional Injections mechanism created by this
Resolution. By means of the Program and/or the Permanent Additional Injection, the Argentine Government requires natural gas
exporting producers to deliver additional volumes to the domestic market in order to satisfy natural gas demand of certain consumers
of the Argentine market (“Additional Injection Requirements”). Such additional volumes are not contractually committed by YPF,
who is thus forced to affect natural gas exports, which execution has been conditioned. The mechanisms established by the
Resolutions No. 659/2004 and 752/2005 have been adapted by the Secretariat of Energy Resolution No. 599/2007, modifying the
conditions for the imposition of the requirements, depending on whether the producers have signed or not the proposed agreement,
ratified by such resolution, between the Secretariat of Energy and the Producers. Also, through Resolution No. 1410/2010 of the
National Gas Regulatory Authority (“ENARGAS”) approved the procedure which sets new rules for natural gas dispatch applicable
to all participants in the natural gas industry, imposing new and more severe regulations to the producers’ availability of natural gas
(“Procedimiento para Solicitudes, Confirmaciones y Control de Gas”). Additionally, the Argentine Government, through instructions
made using different procedures, has ordered limitations over natural gas exports (in conjunction with the Program and the Permanent
Additional Injection, named the “Export Administration”). On January 5, 2012, the Official Gazette published Resolution of the
Secretariat of Energy No. 172 which temporarily extends the rules and criteria established by Resolution No. 599/07, until new
legislation replaces the Resolution previously mentioned. This Resolution was appealed on February 17, 2012 by filing a motion for
reconsideration with the Secretariat of Energy.
As a result of the resolution mentioned before, in several occasions since 2004, YPF has been forced to suspend, either totally or
partially, its natural gas deliveries to some of its export clients, with whom YPF has undertaken firm commitments to deliver natural
gas.
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YPF has challenged the Program, the Permanent Additional Injection and the Additional Injection Requirements, established by
Resolution of the Secretariat of Energy No. 599/2007, 172/2011 and Resolution ENARGAS No. 1410/2010, as arbitrary and
illegitimate, and has invoked vis-à-vis the relevant clients that the Export Administration constitute a fortuitous case or force majeure
event (act of authority) that releases YPF from any liability and/or penalty for the failure to deliver the contractual volumes. These
clients have rejected the force majeure argument invoked by YPF, and some of them have demanded the payment of indemnifications
and/or penalties for the failure to comply with firm supply commitments, and/or reserved their rights to future claims in such respect
(the “Claims”). On December 9, 2015, the ENARGAS rejected YPF´s challenged Resolution N° 1410/2010. YPF is evaluating the
course of action.
Among them, on June 25, 2008, AES Uruguaiana Emprendimientos S.A. (“AESU”) claimed damages in a total amount of US$
28.1 million for natural gas “deliver or pay” penalties for cutbacks accumulated from September 16, 2007 through June 25, 2008, and
also claimed an additional amount of US$ 2.7 million for natural gas “deliver or pay” penalties for cutbacks accumulated from
January 18, 2006 until December 1, 2006. YPF has rejected both claims. On September 15, 2008, AESU notified YPF the
interruption of the fulfillment of its commitments alleging delay and breach of YPF obligations. YPF has rejected the arguments of
this notification. On December 4, 2008, YPF notified that having ceased the force majeure conditions, pursuant to the contract in
force, it would suspend its delivery commitments, due to the repeated breaches of AESU obligations. AESU has rejected this
notification. On December 30, 2008, AESU rejected YPF’s right to suspend its natural gas deliveries. On March 20, 2009 AESU
formally notified the termination of the contract. On April 6, 2009, YPF promoted an arbitration process at the International Chamber
of Commerce (“ICC”) against AESU, Companhía do Gas do Estado do Río Grande do Sul (“Sulgás”) and Transportadora de Gas del
Mercosur S.A. (“TGM”). On the same date YPF was notified by the ICC of an arbitration process initiated by AESU and Sulgás
against YPF in which they claim, among other matters considered inadmissible by YPF, consequential loss, AESU’s plant
dismantling costs and the payment of “deliver or pay” penalties mentioned above, all of which totaled approximately US$ 1,052
million.
Additionally, YPF was notified of the arbitration process brought by TGM at the ICC, claiming YPF the payment of approximately
US$ 10 million plus interest up to the date of effective payment, in connection with the payment of invoices related to the
Transportation Gas Contract entered into in September 1998 between YPF and TGM, associated with the aforementioned exportation
of natural gas contract signed with AESU. On April 8, 2009 YPF requested that this claim be rejected and counterclaimed for the
termination of the natural gas transportation contract based on its termination rights upon the termination by AESU and Sulgás of the
related natural gas export contract. In turn, YPF had initiated an arbitration process at the ICC against TGM, among others. YPF
received the reply to the complaint from TGM, who requested the full rejection of YPF claims and deduced counterclaim against YPF
asking the Arbitration Tribunal to condemn YPF to compensate TGM for all present and future damages suffered by TGM due to the
extinction of the Transportation Gas Contract and the Memorandum of Agreement dated on October 2, 1998 by which YPF
undertook to pay irrevocable non-capital contributions to TGM in return for the Uruguayana Project pipeline expansion; and to
condemn AESU-Sulgás -in the case the Arbitration Tribunal finds that the termination of the Gas Contract occurred due to the failure
of AESU or Sulgás- jointly and severally to indemnify all damages caused by such termination to TGM. Additionally, on July 10,
2009 TGM increased the amount of its claim to US$ 17 million and claimed an additional amount of approximately US$ 366 million
for loss of profits, both considered inappropriate by YPF, and thus, rejected in its answer to such additional claim.
On April 6, 2011, the Arbitration Tribunal appointed in “YPF vs. AESU” arbitration decided to sustain YPF’s motion, and
determined the consolidation of all the related arbitrations (“AESU vs. YPF”, “TGM vs. YPF” and “YPF vs. AESU”) in “YPF vs.
AESU” arbitration. Consequently, AESU and TGM desisted from and abandoned their respective arbitrations, and all the matters
claimed in the three proceedings are to be solved in “YPF vs. AESU” arbitration. On April 19 and 24, 2012, AESU and SULGAS
presented new evidence claiming their admission in the arbitration process. YPF and TGM made their observations about the
evidence on April 27, 2012. On May 1, 2012, the Arbitration Tribunal denied the admission of such evidence and ruled that the
evidence would be accepted if the Tribunal considered it necessary.
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On May 24, 2013 YPF was notified of the partial award decreed by a majority in the ICC Arbitration “YPF vs. AESU and TGM”
whereby YPF was deemed responsible for the termination in 2009 of natural gas export and transportation contracts signed with
AESU and TGM. Such award only decides on the liability of the parties, leaving the determination of the damages that could exist
subject to the subsequent proceedings before the same Tribunal. Moreover, the Tribunal rejected the admissibility of “deliver or pay”
claims asserted by Sulgás and AESU for the years 2007 and 2008 for a value of US$ 28 million and for the year 2006 for US$ 2.4
million.
On May 31, 2013 YPF filed with the Arbitration Tribunal a writ of Nullity, in addition to making several presentations in order to
safeguard its rights. Against the rejection of the writ of nullity, on August 5, 2013 YPF filed a complaint appeal with the Argentinian
Court in Commercial matters. On October 24, 2013, the Argentinian Court in Commercial matters declared its incompetency and
submitted the file to the Federal Contentious Administrative Tribunal. On December 16, the acting prosecutor issued an opinion
supporting the jurisdiction of the court.
Besides, on October 17, 2013 the Arbitration Tribunal decided to resume the arbitration and set a procedural schedule for the
damages stage, which shall be developed along 2014 for which the reports of the experts proposed by the parties occurred.
On December 27, 2013, the Federal Contentious Administrative Tribunal hearing Administrative Litigation matters was moved to
grant the reconsideration motion from denial on appeal, then sustaining the appeal for procedural violations and declaring that the
grant thereof shall have stay effects in connection with the arbitration process. In addition, the court was moved to grant, until the
appeal for procedural violations is finally admitted, a restrictive injunction to prevent the development of the arbitration process while
a decision on the reconsideration motion from denial on appeal and on the appeal for procedural violations filed by YPF is pending.
On October 7, 2014, the Federal Court of Appeals hearing Administrative Litigation matters, besides its jurisdiction in the application
of the writ of nullity, ordered the suspension of the court calendar related to the second stage of its arbitration process until a final
court decision was rendered on the writ of nullity filed by YPF against the arbitral award on adjudication of liability. On October 8,
2014, the Arbitration Tribunal was served with notice of the decision rendered by the said Federal Court of Appeals and on
October 31, 2014, the Arbitration Tribunal determined to suspend the arbitration process until February 2, 2015. On November 5,
2014, YPF was notified of the extraordinary appeal filed by TGM against the resolution of suspension of the court schedule issued by
the mentioned Federal Contentious Administrative Tribunal. YPF answered such appeal on November 19, 2014; and on
December 30, 2014, the Federal Contentious Administrative Tribunal dismissed the extraordinary appeal filed by TGM. On April 24,
2015, the arbitration tribunal resumed the proceedings and invited the parties to consult with each other regarding the continuation of
the arbitration and to provide joint or individual report on next steps. YPF notified the Federal Contentious Administrative Tribunal
of the decision on April 27, 2015 given that its order to suspend the arbitration proceedings was in effect. On July 2, 2015 the
Arbitration Tribunal ordered hearings for the second stage of arbitration to take place on November 16 and 17 of 2015. Although the
Federal Contentious Administrative Tribunal ordered the suspension of the second stage of the arbitration, the hearings proceeded
without the presence of TGM and YPF. Dated December 4, 2015, YPF presented a document to the Arbitration Tribunal claiming the
nullity of the mediation. On December 23, 2015, the Federal Contentious Administrative Tribunal granted the nullity request and
vacated the partial arbitral award. On the same date, YPF notified the Arbitration Tribunal of the decision and requested the
termination of the arbitration proceeding. On February 3, 2016 TGM filed an extraordinary appeal against the Federal Contentious
Administrative Tribunal ruling to the Supreme Court of Justice. On February 2, 2016 AESU and SULGAS filed a nullity request
against the Federal Contentious Administrative Tribunal ruling.
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On the other hand, AESU filed a motion to the Uruguayan courts demanding the nullity of the Arbitration Tribunal’s decision
ordering the suspension of the arbitration proceedings and a restrictive injunction to prevent YPF from interrupting the development
of the arbitration. AESU is trying to notify the various decisions rendered by the Uruguayan courts through letters rogatory and YPF
has objected to such notification and also before the Argentine courts involved therein on the grounds of formal defects in such
intended notification and also arguing that Uruguayan courts have no competence to deal with matters of this kind. On July 16, 2015
the Federal Contentious Administrative Tribunal 3 rejected one of the judicial petitions through which AESU tried to serve the nullity
petition of the Arbitration Tribunal that declared the suspension of the Arbitration. On September 4, 2015 AESU requested an appeal.
On December 23, 2015 the Federal Contentious Administrative Tribunal rejected the appeal and confirmed the resolution of the lower
court.
On January 10, 2014, YPF was served with the complaint for damages filed by AESU with the Arbitration Tribunal claiming a total
amount of US$ 815.5 million and also with the complaint for damages filed by TGM with the Arbitration Tribunal claiming a total
amount of US$ 362.6 million. On April 25, 2014, YPF filed a reply to the complaint for damages with the Arbitration Tribunal
rejecting the alleged sums claimed by TGM and AESU based on the fact that the said amounts are disproportionate due to errors in
the technical valuations attached. On July 8, 2014, TGM filed an answer to the reply with the Arbitration Tribunal, which was in turn
responded to by YPF on September 23, 2014 by filing a second answer thereto.
Considering the information available to date, the estimated time remaining until the end of the proceedings, the outcomes of the
additional evidence presented in the continuation of the dispute and the provisions of the arbitral award, the Company has accrued its
best estimate with respect to the amount of the claims.
Furthermore, there are certain claims in relation with payments of natural gas transportation contracts associated with exports of such
hydrocarbon. Consequently, one of the parties, Transportadora de Gas del Norte S.A. (“TGN”), commenced mediation proceedings in
order to determine the merits of such claims. The mediation proceedings did not result in an agreement and YPF was notified of the
lawsuit filed against it, in which TGN is claiming the payment of unpaid invoices, according to their arguments, while reserving the
right to claim for damages, which were claimed in a note addressed to YPF during November 2011. Additionally, the plaintiff
notified YPF that it was terminating the contract invoking YPF’s fault, basing its decision on the alleged lack of payment of
transportation fees, reserving the right to claim for damages. After that, TGN filed the lawsuit claiming for damages mentioned
above. The total amount claimed by TGN amounts to approximately US$ 207 million. YPF has answered the mentioned claims,
rejecting them based in the legal impossibility for TGN to render the transportation service and in the termination of the
transportation contract determined by YPF and notified with a complaint initiated before ENARGAS. On the trial for the collection of
bills, on September 2011, YPF was notified of the resolution of the Court of Appeals rejecting YPF’s claims and declaring that
ENARGAS is not the appropriate forum to decide on the matter and giving jurisdiction to the Civil and Commercial Federal courts to
decide on the claim for the payment of unpaid invoices mentioned above.
Regarding the previously mentioned issue, on April 8, 2009, YPF had filed a complaint against TGN with ENARGAS, seeking the
termination of the natural gas transportation contract with TGN in connection with the natural gas export contract entered with AESU
and other parties. The termination of the contract with that company is based on: (a) the impossibility for YPF to receive the service
and for TGN to render the transportation service, due to (i) the termination of the natural gas contract with Sulgás/AESU and (ii) the
legal impossibility of assigning the transportation contract to other shippers because of the regulations in effect, (b) the legal
impossibility for TGN to render the transportation service on a firm basis because of certain changes in law in effect since 2004, and
(c) the “Teoría de la Imprevisión” available under Argentine law, when extraordinary events render a party’s obligations excessively
burdensome.
On April 3, 2013 the complaint for damages brought by TGN was notified whereby TGN claimed YPF the amount of US$
142 million, plus interests and legal fees for the termination of the transportation contract, and notified that YPF shall have 30 days to
file and answer thereto. On May 31, 2013 YPF answered the claim requesting the dismissal thereof. On April 3, 2014 the evidence
production period commenced for a 40-days lapse, and the court notified the parties that they shall submit a copy of evidence offered
by them to create exhibit binder. As of the date of issuance of these consolidated financial statements, evidence offered by the parties
is being produced.
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In addition, Nación Fideicomisos S.A. (NAFISA) had initiated a claim against YPF in relation to payments of applicable fees for
natural gas transportation services to Uruguaiana corresponding to the transportation invoices claimed by TGN. A mediation hearing
finished without arriving to an agreement, concluding the pre-trial stage. Additionally, on January 12, 2012 and following a mediation
process which ended without any agreement, NAFISA filed a complaint against YPF, under article 66 of Law No. 24,076, before
ENARGAS, claiming the payment of certain transportation charges in an approximate amount of 339. On February 8, 2012, YPF
answered the claim raising ENARGAS’ lack of jurisdiction (as the Company did in the proceeding against TGN), the accumulation in
the “TGN vs. YPF” trial and rejecting the claim based on the theory of legal impossibility. On the same date, was also submitted in
the trial “TGN vs. YPF” similar order of accumulation. On April 12, 2012, ENARGAS resolved in favor of NAFISA. On May 12,
2012 YPF filed an appeal against such resolution to the National Court of Appeals in the Federal Contentious Administrative. On
November 11, 2013, such court dismissed the direct appeal filed by YPF. In turn, on November 19, 2013 YPF submitted an ordinary
appeal before the National Supreme Court of Justice and on November 27, an extraordinary appeal was lodged, also before the
Supreme Court. The ordinary appeal was granted and YPF timely filed the grounds of such appeal. On September 29, 2015, the
Supreme Court upheld YPF’s appeal and reversed the resolution issued by the Federal Contentious Administrative Court – Division
IV – on the grounds that ENARGAS lacks legal capacity to participate in these proceedings as the parties are not subject to the Gas
Law.
YPF’s Management has accrued its best estimate with respect to the claims mentioned above. As of December 31, 2015, the
Company has accrued costs for penalties associated with the failure to deliver the contractual volumes of natural gas in the export and
domestic markets which are probable and can be reasonably estimated.
Users and Consumers’ Association claim:
The Users and Consumers Association claimed (originally against Repsol YPF before extending its claim to YPF) the reimbursement
of the overprice allegedly charged to bottled LPG consumers between 1993 and 1997 and 1997 to 2001. The claim amounts 91 for the
period 1993 to 1997 (this sum brought up-to-date, would be approximately 502), together with an undetermined amount for the
period 1997 to 2001. In the response to the claim, YPF requested the application of the statute of limitations since at the date of the
extension of the claim, the two-year limit had already elapsed.
On December 28, 2015, the lower court rendered judgment admitting the claim seeking compensation for the term between 1993 to
1997 filed by Users and Consumers Association against YPF S.A. and ordered the Company to transfer the amount of 98 plus interest
(to be estimated by the expert witness in the settlement period) to the Energy Secretariat, to be allocated to the trust fund created by
Law No. 26.020.
The judgment dismissed the claim for the items corresponding to the 1997-2001 period considering the dominant position of YPF in
the domestic bulk LPG market was not sufficiently proved. The Company appealed the decision of the lower court.
Finally, the judgment dismissed the complaint against Repsol as Repsol YPF S.A. had no equity interest in YPF S.A., nor any other
kind of relation with YPF from 1993 to 1997, period in which the plaintiffs claim YPF abused its dominant position.
The updated judgment amount as of the date of these financial statements amounts to about 503 plus court costs.
Tax claims:
The Company has received several claims from the Administración Federal de Ingresos Públicos (“AFIP”) and from provincial and
municipal fiscal authorities, which are not individually significant, and which have been accrued based on the best information
available as of the date of the issuance of these financial statements.
F-68
La Plata and Quilmes environmental claims:
La Plata: In relation with the operation of the refinery that YPF has in La Plata, there are certain claims for compensation of
individual damages purportedly caused by the operation of the La Plata refinery and the environmental remediation of the channels
adjacent to the mentioned refinery. During 2006, YPF submitted a presentation before the Environmental Secretariat of the Province
of Buenos Aires which put forward for consideration the performance of a study for the characterization of environmental associated
risks. As previously mentioned, YPF has the right of indemnity for events and claims prior to January 1, 1991, according to Law
No. 24,145 and Decree No. 546/1993. Besides, there are certain claims that could result in the requirement to make additional
investments connected with the operations of La Plata refinery.
On January 25, 2011, YPF entered into an agreement with the environmental agency of the Government of the Province of Buenos
Aires (Organismo Provincial para el Desarrollo Sostenible (“OPDS”)), within the scope of the Remediation, Liability and
Environmental Risk Control Program, created by Resolution No. 88/10 of the OPDS. Pursuant to the agreement, the parties agreed to
jointly perform an eight-year work program in the channels adjacent to the La Plata refinery, including characterization and risk
assessment studies of the sediments. The agreement provides that, in the case that a required remediation action is identified as a
result of the risk assessment studies, the different alternatives and available techniques will be considered, as well as the steps needed
for the implementation. Dating studies will also be performed pursuant to the agreement, in order to determine responsibilities of the
Argentine Government in accordance with its obligation to hold YPF harmless in accordance with the article 9 of the Privatization
Law No. 24,145. YPF has provisioned the estimated cost of the characterization and risk assessment studies mentioned above. The
cost of the remediation actions, if required, will be recorded in those situations where the loss is probable and can be reasonably
estimated.
Quilmes: Citizens which allege to be residents of Quilmes, Province of Buenos Aires, have filed a lawsuit in which they have
requested remediation of environmental damages and also the payment of 47 plus interests as a compensation for supposedly personal
damages. They base their claim mainly on a fuel leak in the pipeline running from La Plata to Dock Sud, currently operated by YPF,
which occurred in 1988 as a result of an illicit detected at that time, being at that moment YPF a state-owned company. Fuel would
have emerged and became perceptible on November 2002, which resulted in remediation works that are being performed by the
Company in the affected area, supervised by the environmental authority of the Province of Buenos Aires. The Argentine
Government has denied any responsibility to indemnify YPF for this matter, and the Company has sued the Argentine Government to
obtain a declaration of invalidity of such decision. The suit is still pending. On November 25, 2009, the proceedings were transferred
to the Federal Court on Civil and Commercial Matters No. 3, Secretariat No. 6 in Buenos Aires City and on March 4, 2010, YPF
answered the complaint and requested the citation of the Argentine Government. On December 18, 2014 the Argentine Government
was cited, by notification of the demand and its extensions, by letter to the Ministry of Federal Planning. In addition to the
aforementioned, the Company has other 24 judicial active claims against it with total claims amounting to approximately 19.
Additionally, YPF is aware of the existence of other out of court claims which are based on similar allegations.
Other claims and environmental liabilities:
In relation to environmental obligations, and in addition to the hydrocarbon wells abandonment legal obligations for 27,809 as of
December 31, 2015, the Group has accrued 3,020 corresponding to environmental remediation, which evaluations and/or remediation
works are probable and can also be reasonably estimated, based on the Group’s existing remediation program. Legislative changes,
on individual costs and/or technologies may cause a re-evaluation of the estimates. The Group cannot predict what environmental
legislation or regulation will be enacted in the future or how future laws or regulations will be administered. In the long-term, this
potential changes and ongoing studies could materially affect future results of operations.
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Environmental liabilities of YPF Holdings Inc.
1. Introduction
Laws and regulations relating to health and environmental quality in the United States of America affect nearly all the operations of
YPF Holdings Inc. (hereinafter mentioned as “YPF Holdings Inc.” or “YPF Holdings”). These laws and regulations set various
standards regulating certain aspects of health and environmental quality, provide for penalties and other liabilities for the violation of
such standards and establish in certain circumstances remedial obligations.
YPF Holdings Inc. believes that its policies and procedures in the area of pollution control, product safety and occupational health are
adequate to prevent reasonable risk of environmental and other damage, and of resulting financial liability, in connection with its
business. Some risk of environmental and other damage is, however, inherent in particular operations of YPF Holdings Inc. and, as
discussed below, Maxus Energy Corporation (“Maxus”) and Tierra Solutions Inc. (“TS”), both controlled by YPF Holdings Inc.,
could have certain potential liabilities associated with operations of Maxus’ former chemical subsidiary.
YPF Holdings Inc. cannot predict what environmental legislation or regulations will be enacted in the future or how existing or future
laws or regulations will be administered or enforced. Compliance with more stringent law regulations, as well as more vigorous
enforcement policies of the regulatory agencies, could in the future require material expenditures by YPF Holdings Inc. for the
installation and operation of systems and equipment for remedial measures, possible dredging requirements, among other things.
Also, certain laws allow for recovery of natural resource damages from responsible parties and ordering the implementation of
interim remedies to abate an imminent and substantial endangerment to the environment. Potential expenditures for any such actions
cannot be reasonably estimated.
In the following discussion, references to YPF Holdings Inc. include, as appropriate and solely for the purpose of this information,
references to Maxus and TS.
In connection with the sale of Maxus’ former chemical subsidiary, Diamond Shamrock Chemicals Company (“Chemicals”) to
Occidental Petroleum Corporation (“Occidental”) in 1986, Maxus agreed to indemnify Chemicals and Occidental from and against
certain liabilities relating to the business or activities of Chemicals prior to September 4, 1986 (the “selling date”), including
environmental liabilities relating to chemical plants and waste disposal sites used by Chemicals prior to the selling date.
YPF Holdings Inc.’s management believes it has adequately provisioned for all environmental contingencies, which are probable and
can be reasonably estimated; however, changes in circumstances, including new information or new requirements of governmental
entities, could result in changes, including additions, to such provisions in the future. The most significant contingencies are described
in the following paragraphs:
2. Environmental Issues relating to Lister site and Passaic River
2.1 Environmental administrative Issues relating to the lower 8 miles of the Passaic River
•
Newark, New Jersey
A consent decree, previously agreed upon by the U.S. Environmental Protection Agency (“EPA”), the New Jersey Department of
Environmental Protection and Energy (“DEP”) and Occidental, as successor to Chemicals, was entered in 1990 by the United States
District Court of New Jersey and requires implementation of a remedial action plan at Chemical’s former Newark, New Jersey
agricultural chemicals plant. The interim remedial plan has been completed and paid for by TS. This project is in the operation and
maintenance phase.
•
Passaic River, New Jersey
Maxus, complying with its contractual obligation to act on behalf of Occidental, negotiated an agreement with the EPA (the “1994
AOC”) under which TS has conducted testing and studies near the Newark plant site, adjacent to the Passaic River. While some work
remains, the work under the 1994 AOC was substantially subsumed by reason of an administrative arrangement dated 2007 (the
“2007 AOC”) with about 70 companies (including Occidental and TS). Under the 2007 AOC, the lower 17 miles of the Passaic River,
from the mouth at Newark Bay to Dundee Dam, should be subjected to a Remedial Investigation / Feasibility Study (“RI/FS”).
Participants of the 2007 AOC are discussing the possibility of conducting additional remedial works with the EPA. The entities that
have agreed to fund the RI/FS have negotiated an interim allocation of RI/FS costs among themselves based on a number of
considerations. This group is called the Cooperative Parties Group (the “CPG”). The 2007 AOC is being coordinated with a joint
federal, state, local and private sector cooperative effort designated as the Lower Passaic River Restoration Project (“PRRP”).
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On May 29, 2012, Occidental, Maxus and TS withdrew from the CPG under protest and reserving all their rights. A description of the
circumstances of such decision can be found below in the paragraph titled “Passaic River—Mile 10.9—Removal Action”. However,
Occidental continues to be a member of the 2007 AOC and its withdrawal from the CPG does not change its obligations under the
2007 AOC. The RI/FS concerning the 2007 AOC is expected to be completed by 2016 together with the filing with the EPA by the
CPG of a preliminary report containing its recommendation as to preferred remediation. EPA will have to assess such
recommendation and then render an opinion in this connection. This process may take from 12 to 18 months. After an agreement is
reached by the CPG and the EPA on preferred remediation, the report will be published for public opinion, which will be considered
for the purpose of issuing a Record of Decision or final decision on remediation.
The EPA’s findings of fact in the 2007 AOC (which amended the 1994 AOC) indicate that combined sewer overflow/storm water
outfall discharges are an ongoing source of hazardous substances to the Lower Passaic River Study Area. For this reason, during the
first half of 2011, Maxus and TS signed with the EPA, on behalf of Occidental, an Administrative Settlement Agreement and Order
on Consent for Combined Sewer Overflow/Storm Water Outfall Investigation (“CSO AOC”), which became effective in September
2011. Besides providing for a study of combined sewer overflows in the Passaic River, the CSO AOC confirms that there will be no
further obligations to be performed under the 1994 AOC. In the second half of 2014, TS submitted to the EPA its report (thus
completing phase 1) and still expects the EPA’s comments on the proposed work plan. TS estimates that the total cost to implement
the CSO AOC is approximately US$ 5 million and will take approximately 2 years to be completed once EPA authorizes phase 2 (the
work plan).
In 2003, the DEP issued Directive No. 1 to Occidental and Maxus and certain of their respective related entities as well as other third
parties. Directive No. 1 seeks to address natural resource damages allegedly resulting from almost 200 years of historic industrial and
commercial development along a portion of the Passaic River and a part of its watershed. Directive No. 1 asserts that the named
entities are jointly and severally liable for the alleged natural resource damages without regard to fault. The DEP asserted jurisdiction
in this matter even though all or part of the lower Passaic River is subject to the PRRP. Directive No. 1 calls for the following actions:
interim compensatory restoration, injury identification, injury quantification and value determination. Maxus and TS responded to
Directive No. 1 setting forth good faith defenses. Settlement discussions between the DEP and the named entities have been held;
however, no agreement has been reached or is assured.
In 2004, the EPA and Occidental entered into an administrative order on consent (the “2004 AOC”) pursuant to which TS (on behalf
of Occidental) has agreed to conduct testing and studies to characterize contaminated sediment and biota and evaluate remedial
alternatives in the Newark Bay and a portion of the Hackensack, the Arthur Kill and Kill van Kull rivers. The initial field work on this
study, which includes testing in the Newark Bay, has been substantially completed. Discussions with the EPA regarding additional
work that might be required are underway. EPA has issued General Notice Letters to a series of additional parties concerning the
contamination of Newark Bay and the work being performed by TS under the 2004 AOC. TS proposed to the other parties that, for
the third stage of the RI/FS undertaken in Newark Bay, the costs be allocated on a per capita basis. The parties have not agreed to
TS’s proposal. However, YPF Holdings lacks sufficient information to determine additional costs, if any, it might have with respect
to this matter once the final scope of the third stage is approved, as well as the proposed distribution mentioned above.
In December 2005, the DEP issued a directive to TS, Maxus and Occidental directing said parties to pay the State of New Jersey’s
cost of developing a Source Control Dredge Plan focused on allegedly dioxin-contaminated sediment in the lower six-mile portion of
the Passaic River. The development of this plan was estimated by the DEP to cost approximately US$ 2 million. The DEP has
advised the recipients that (a) it is engaged in discussions with the EPA regarding the subject matter of the directive, and (b) they are
not required to respond to the directive until otherwise notified.
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In August 2007, the National Oceanic Atmospheric Administration (“NOAA”) sent a letter to a number of entities it alleged have a
liability for natural resources damages, including TS and Occidental, requesting that the group enters into an agreement to conduct a
cooperative assessment of natural resources damages in the Passaic River and Newark Bay. In November 2008, TS and Occidental
entered into an agreement with the NOAA to fund a portion of the costs it has incurred and to conduct certain assessment activities
during 2009. Approximately 20 other PRRP members have also entered into similar agreements. In November 2009, TS declined to
extend this agreement.
•
Removal Action Next to Lister Avenue Site
During June 2008, the EPA, Occidental, and TS entered into an AOC (“Removal AOC from 2008”), pursuant to which TS (on behalf
of Occidental) will undertake a removal action of sediment from the Passaic River in the vicinity of the former Diamond Alkali
facility. This action results in the removal of approximately 200,000 cubic yards of sediment, which will be carried out in two
different phases. The first phase, which commenced in July 2011, encompasses the removal of 40,000 cubic yards (30,600 cubic
meters) of sediments and was substantially completed in the fourth quarter of 2012. The EPA conducted a site inspection in January
2013, and TS received written confirmation of completion in March 2013. The second phase involves the removal of approximately
160,000 cubic yards (122,400 cubic meters) of sediment. This second phase will start after according with EPA certain development’s
aspects related to it. Pursuant to the Removal AOC from 2008, the EPA has required the provision of financial assurance for the
execution of the removal work which could increase or decrease over time if the anticipated cost of completing the removal work
contemplated by the Removal AOC from 2008 changes. During the sediment removal action, contaminants which may have come
from sources other than the former Diamond Alkali plant will necessarily be removed.
The 2014 FFS published on April 11, 2014 provides that phase two of the removal action contemplated by the Removal AOC shall be
implemented in a manner consistent with the FFS. By letter of September 18, 2014, the EPA requested that TS submit a work plan to
conduct additional sampling of the Phase II area. The sampling was completed in the first quarter of 2015 and TS is expected to
present the validated results to the EPA during 2016.
2.2 Feasibility Study for the environmental remediation of the lower 8 miles of the Passaic River
•
First draft - Year 2007
On June 2007, EPA released a draft Focused Feasibility Study (the “FFS 2007”). The FFS 2007 outlines several alternatives for
remedial action in the lower eight miles of the Passaic River. These alternatives range from no action, which would result in
comparatively little cost, to extensive dredging and capping. TS, in conjunction with the other parties working under the CPG,
submitted comments over legal and technical defects of the FFS 2007 to EPA. As a result of all the comments received, EPA
withdrew FFS 2007 in order to modify it and give more consideration to comments. On November 14, 2013 at a Community
Advisory Group (“CAG”) meeting, the EPA described the alternatives considered in the FFS 2007, that consisted of four alternatives:
(i) no action; (ii) deep dredging of 9.7 million cubic yards during 12 years (cost: US$ 1.4 billion to US$ 3.5 billion, depending in part
on whether the dredged sediment is disposed of in a contained aquatic disposal facility on the floor of Newark Bay (“CAD”) or at an
off-site disposal facility); (iii) capping and dredging of 4.3 million cubic yards during 6 years (cost: US$ 1 billion to US$ 1.8 billion,
depending in part on whether there is a CAD or off-site disposal; (iv) focused capping and dredging of 0.9 million cubic yards during
3 years (the alternative proposed by the CPG). The EPA indicated that it had discarded alternative (iv) and that it was currently in
favor of alternative (iii).
•
Second draft - Year 2014
On April 11, 2014, the EPA published a new FFS draft (“FFS 2014”). The EPA submitted this draft for consideration for a period of
public comments starting on April 21, 2014, after two extensions, the process ended on August 20, 2014.
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The FFS 2014 contains the four remediation alternatives analysed by the EPA, as well as the estimation of the cost of each alternative
which consist of: (i) no action, (ii) deep dredging of 9.7 million cubic yard capping (cost estimated by EPA: US$ 1.34 billion to US$
3.24 billion, depending on the possibility of disposing dredged sediments in a contained subaquatic disposal facility on the floor of
Newark Bay (“CAD”) or at an off-site disposal facility, or local decontamination and beneficial use); (iii) capping and dredging of
4.3 million cubic yards and placing of an engineering cap (a physical barrier mainly built with sand and stone) (cost estimated by
EPA: US$ 1 billion to US$ 1.73 billion, depending on the existence of a CAD or an off-site disposal facility, or local decontamination
and beneficial use); and (iv) focused dredging and filling of 1 millon cubic yard (cost estimated by the EPA: US$ 0.4 billion to US$
0.6 billion, depending on the existence of a CAD or off-site disposal facility, or local decontamination and beneficial use). The
alternative favored by EPA at the time of issuance of FFS 2014 was the third one, considering the disposal of removed material at an
off-site disposal facility, with a current estimated value of US$ 1.73 billion (estimated at a 7% annual rate).
On August 20, 2014, Maxus and TS, on behalf of Occidental, submitted their comments on FFS 2014 to EPA. The main arguments
offered by Maxus, TS and Occidental in the comments about the FFS were as follows:
•
•
•
•
•
•
The FFS is not a legally authorized process to select the type and size of the remediation proposed by the EPA for the 8 miles of
the lower Passaic River.
The FFS is based on a flawed site design.
The FFS overstates the issues of human health and ecological risk.
The proposed plan is not executable and not economically reasonable in cost-benefit terms.
Processes in Region 2 of the EPA present lack public transparency.
The inclusion in the remediation plan of dredging for navigational purposes is not covered by the regulation.
In addition to the comments received from Maxus and TS, EPA also received comments from about 400 other companies,
institutions, government agencies, non-governmental and private organizations, including the CPG, Amtrak (federal railway
company), NJ Transit, United States Army Corps of Engineers, Passaic Valley Sewerage Commission, yacht clubs, public officials,
and others.
In parallel to the revision of FFS 2014, Maxus and TS have been working on a preliminary project called In-ECO, an ecological and
sustainable alternative of bioremediation as a substitute to the remediation chosen by EPA in its FFS 2014. Maxus and TS submitted
In-ECO to EPA in May 2014, EPA provided comments in September and Maxus and TS submitted a revision in November 2014.
EPA provided additional comments to the In ECO Statement of Work in March 2015. Tierra developed responses to those comments
and submitted them in the second semester. A meeting was held in September 2015 between Tierra, its experts, and the EPA. During
this meeting the final issues were resolved and laboratory studies are anticipated to begin by early 2016.
In October 2015, the federal Government Accountability Office (“GAO”) informed Maxus, Tierra and OCC that it had initiated a
study on a few select Superfund sediment sites across the United States, including the Lower Passaic River, at the request of the
Senate Committee on Environmental and Public Works. GAO stated that it plans to speak to EPA leadership and project managers, as
well as representatives from the community and PRP groups. At this time, it is unknown what effect, if any, the GAO’s review will
have on the timing or content of the Record of Decision for the FFS.
Currently, EPA is considering these comments and will issue a response before EPA makes its final decision on the remedial plan for
the area, which will probably be published in a “Record of Decision” during 2016.
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•
Conclusion
Based on the information available to the Company at the time of issuance of these financial statements, and also considering the
uncertainties related to the different remedial alternatives and those that may be incorporated in the final proposal and their associated
costs, the outcome of the discoveries and/or evidence that may be produced, the amounts previously incurred by YPF Holdings Inc. in
remedial activities in the area covered by FFS, the quantity and diversity of potential responsible parties involved, and consequently
the uncertainties related to the potential allocation of the removal costs, the opinion of external legal advisors, and the limit over its
liability that YPF could have as indirect controlling shareholder of Maxus, it is not possible to reasonably estimate a loss or range of a
loss on the mentioned matters, and therefore the Company has not recorded a provision for these matters.
2.3 Environmental Administrative Issues concerning to the lower 17 miles of the Passaic River
•
Passaic River Mile 10.9 Removal Action
In February 2012, the EPA issued to the Cooperating Parties Group (“CPG”), of which TS then was a member, a draft Administrative
Settlement Agreement and order on Consent (“AOC RM 10.9”) for Removal Action and Pilot Studies to address high levels of
contamination of 2, 3, 7, 8 TCDD, PCBs, mercury and other contaminants of concern in the vicinity of the Passaic River’s mile 10.9
(“RM 10.9”), comprised of a sediment formation (“mud flat”) of approximately 8.9 acres. This proposed AOC RM 10.9 ordered that
approximately 16,000 cubic yards of sediments be removed and that pilot scale studies be conducted to evaluate ex situ
decontamination beneficial reuse technologies, innovative capping technologies, and in situ stabilization technologies for
consideration and potential selection as components of the remedial action to be evaluated in the 2007 AOC and the FFS and selected
in one or more subsequent records of decision.
On June 18, 2012, the EPA announced that it had signed an AOC for RM 10.9 with 70 Settling Parties. Occidental, Maxus and TS
refused to sign this AOC since they failed to agree with the other parts of the CPG regarding the way of assigning the estimated cost
of the removal action. On June 25, 2012, EPA addressed to Occidental the order, pursuant to section 106 of CERCLA, to participate
and cooperate with the CPG members who had signed the AOC RM 10.9. Occidental sent to the CPG and EPA its notice of intent to
comply with such order on July 23, 2012 followed by its good faith offer on July 27, 2012 to provide the use of TS’s dewatering
facility. On August 10, 2012, the CPG rejected Occidental’s good faith offer and, on September 7, 2012, the CPG stated that it has
alternative plans for handling sediment to be excavated at RM 10.9 and, therefore, has no use for the existing dewatering facility.
EPA, by letter of September 26, 2012, advised that it will be necessary for EPA and Occidental to discuss other options for
Occidental to participate and cooperate in the RM 10.9 removal action, as required by its Unilateral Administrative Order.
On September 18, 2012, the EPA advised the Passaic River CAG that the bench scale studies of the treatment technologies did not
sufficiently lower concentrations of the chemicals to justify the cost, so the RM 10.9 sediments will be removed offsite for disposal.
Therefore, the EPA notified OCC, Maxus and TS that other options would be discussed in order to determine how to comply with the
Unilateral Administrative Order, which ends in a petition to constitute a financial guarantee. TS, on behalf of Occidental, worked
during the first four-month period in 2014 to prepare a proposal for the EPA in connection with RM 10.9. In March 2014, TS sent a
work schedule to conduct certain studies, which were conditionally accepted by the EPA. The fieldwork for this research was
undertaken in August and an additional field investigation was initiated in December 2014 and was completed in February 2015. TS
presented to the EPA its report regarding the pipelines during March 2015. EPA extended the deadline for the fulfillment of the
financial guarantee to March 2014 and then extended the deadline indefinitely.
•
Feasibility Study for the lower 17 miles of the Passaic River
Notwithstanding what is discussed above, the lower 17 mile section of the Passaic River, from the mouth at Newark Bay to the
Dundee Dam, is the subject of the Remedial Investigation/Feasibility Study contemplated in AOC 2007, with completion was
expected for 2015, after which EPA would choose a remediation action that will be made public in order to receive comments.
It is anticipated that the remediation and feasibility study will be completed during 2016 or thereafter.
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The CPG submitted the Draft Remedial Investigation and Feasibility Study for the Lower 17 miles of the Passaic River during the
first semester of 2015. Separate sections were submitted over a nine-month period from February to October 2015. The CGP draft
offers potential alternatives to the EPA’s FFS, which comprises the lower 8 miles of the Passaic River. The EPA may or may not
consider this report as they continue to address comments to the FFS. As of the date of this annual report, the EPA has not submitted
any comments.
2.4 Trial for the Passaic River
On the other hand, and in relation to the alleged contamination related to dioxin and other “hazardous substances” discharged from
Chemicals’ former Newark plant and the contamination of the lower stretch of the Passaic River, Newark Bay, other nearby
waterways and surrounding areas in December 2005 the DEP sued YPF Holdings, TS, Maxus and several companies, besides
Occidental. The DEP sought remediation of natural resources damaged and punitive damages and other matters. The defendants made
responsive pleadings and filings.
In March 2008, the Court denied motions to dismiss by Occidental, TS and Maxus. The DEP filed its Second Amended Complaint in
April 2008. YPF filed a motion to dismiss for lack of personal jurisdiction. The motion mentioned previously was denied in August
2008, and the denial was confirmed by the Court of Appeal. Notwithstanding, the Court denied to plaintiffs’ motion to bar third party
practice and allowed defendants to file third-party complaints. Third-party claims against approximately 300 companies and
governmental entities (including certain municipalities) which could have responsibility in connection with the claim were filed in
February 2009. DEP filed its Third Amended Complaint in August 2010, adding Maxus International Energy Company and YPF
International S.A. as additional named defendants. Anticipating this considerable expansion of the number of parties in the litigation,
the Court appointed a Special Master to assist the court in the administration of discovery.
In September 2010, Governmental entities of the State of New Jersey and a number of third-party defendants filed their dismissal
motions and Maxus and TS filed their responses. In October 2010, a number of public third-party defendants filed a motion to sever
and stay and the DEP joined their motion, which would allow the DEP to proceed against the direct defendants. However, the judge
has ruled against this motion in November 2010. Third-party defendants have also brought motions to dismiss, which have been
rejected by the assistant judge in January 2011. Some of the mentioned third-parties appealed the decision, but the judge denied such
appeal in March 2011.
In May 2011, the judge issued Case Management Order No. XVII (CMO XVII), which contained the Trial Plan for the case. This
Trial Plan divides the case into two phases, each with its own mini-trials (“Tracks”) which totalized nine Tracks considered as
individual trials. In phase one would be determined liability and phase two will determine damages. Regarding the sub-stages:
(a) sub-stages I to III (Tracks I to III) correspond to damage claimed by Occidental and the State of New Jersey; (b) sub-stages IV to
VII (Tracks IV to VII) correspond to liability by alter ego and fraudulent conveyance with respect to YPF, Maxus and Repsol and to
the liability of third parties to Maxus; (c) sub-stage VIII (Track VIII) corresponds to damages claimed by the State of New Jersey;
(d) sub-stage IX (Track IX) is the percentage of liability that would correspond to Maxus for the cleanup and remediation costs.
Specifically, sub-stage III (Track III) will determine the extent of Maxus’ liability for the operation of the Lister Site; sub-stage IV
(Track IV) will determine the possible scope of YPF and Repsol’s liability for damages to the Lister Site (alter ego and fraudulent
conveyance).
Following the issuance of CMO XVII, the State of New Jersey and Occidental filed motions for partial summary judgment. The State
filed two motions: the first one against Occidental and Maxus on liability under the Spill Act, and against TS on liability under the
Spill Act. In addition, Occidental filed a motion for partial summary judgment that Maxus owes a duty of contractual indemnity to
Occidental for liabilities under the Spill Act. In July and August 2011, the judge ruled that, although the discharge of hazardous
substances by Chemicals has been proved, liability allegation cannot be made if the nexus between any discharge and the alleged
damage is not established. Additionally, the Court ruled that TS has Spill Act liability to the State based merely on its current
ownership of the Lister Avenue site; and that Maxus has an obligation under the 1986 Stock Purchase Agreement to indemnify
Occidental for any Spill Act liability arising from contaminants discharged on the Lister Avenue site. The Special Master called for
and held a settlement conference in November 2011 between the State of New Jersey, on the one hand, and Repsol S.A., YPF and
Maxus, on the other hand to discuss the parties’ respective positions, but no agreement was reached.
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In February 2012, plaintiffs and Occidental filed motions for partial summary judgment, seeking summary adjudication that Maxus
has liability under the Spill Act of New Jersey. In the first quarter of 2012 Maxus, Occidental and plaintiffs submitted their respective
briefs. Oral arguments were heard on May 15 and 16, 2012. The Judge held that Maxus and TS have direct liability for the
contamination generated into the Passaic River. However, volume, toxicity and cost of the contamination were not verified (these
issues will be determined in a later phase of the trial). Maxus and TS have the right to appeal such decision.
On September 11, 2012 the Court issued the track VIII order. The track VIII order governs the process by which the Court would
conduct the discovery and trial of the State’s damages against Occidental, Maxus and TS (caused by the Diamond Alkali Lister
Avenue plant). Under the order, the trial for the first phase of track VIII was scheduled to commence in July 2013. However, this
schedule has been changed by the following occurrence.
On September 21, 2012, Judge Lombardi (trial judge) granted the State’s application for an Order to Show Cause to Stay all
proceedings against third party defendants who entered into a Memorandum of Understanding (“MOU”) with the State to discuss
settlement of the claims against the third party defendants.
On September 27, 2012, Occidental filed its Amended Cross-Claims and the following day, the State filed its fourth Amended
Complaint. The principal changes to the State’s pleading concern the State’s allegations against YPF and Repsol, all of which
Occidental has adopted in its cross-claims. In particular, there were three new allegations against Repsol involving asset stripping
from Maxus and also from YPF based on the Argentine Government’s Mosconi Report. On October 25, 2012, the parties to the
litigation agreed to a Consent Order, subject to approval by Judge Lombardi, which, in part, extended the deadline for YPF to respond
to the State’s and Occidental’s new pleadings by December 31, 2012, extends fact deposition discovery until April 26, 2013, extends
expert discovery until September 30, 2013, and sets trial on the merits for certain allegations for February 24, 2014, date on which it
lost effectiveness as it was replaced by subsequent court orders.
During the fourth quarter of 2012 and the first quarter of 2013, YPF, YPF Holdings, Maxus and TS together with certain other direct
defendants in the litigation, have engaged in on-going mediation and negotiation seeking the possibility of a settlement with the State
of New Jersey. During this time, the Court has stayed the litigation. On March 26, 2013, the State advised the Court that a proposed
settlement between the State and certain third party defendants had been approved by the requisite threshold number of private and
public third party defendants. YPF, YPF Holdings, Maxus and TS approved in Boards of Directors the authorization to sign the
settlement agreement (the “Agreement”) above mentioned. The proposal of the Agreement, which did not imply endorsement of facts
or rights and that it is presented only with conciliatory purposes, was subject to an approval process, publication, comment period and
court approval. According to the terms of the Agreement, the state of New Jersey would agree to solve certain claims related with
environmental liabilities within a geographic area of the Passaic River, New Jersey, United States of America, initiated against YPF
and certain subsidiaries, recognizing to YPF and other participants in the litigation, a limited liability of US$ 400 million, if they are
found responsible. In return, Maxus would make cash payment of US$ 65 million at the time of approval of the Agreement.
In September 2013, Judge Lombardi published its Case Management order XVIII (“CMO 18”), which provides a schedule for
approval of the settlement agreement. Pursuant to the CMO 18, the court heard oral arguments on December 12, 2013, after which,
Judge Lombardi ruled the rejecting of Occidental’s claims and approved the settlement agreement. On January 24, 2014, Occidental
appealed the approval of the settlement agreement. Notwithstanding, on February 10, 2014, in compliance with the settlement
agreement, Maxus made a deposit of US$ 65 million in an escrow account. Occidental appealed Judge Lombardi’s decision
approving the settlement agreement, which was dismissed. Later, on April 11, 2014 Occidental notified the parties that it would not
seek an additional revision of Judge Lombardi’s decision approving the settlement agreement.
Likewise, on June 23, 2014, lawyers of the State of New Jersey reported that Occidental and the State of New Jersey reached an
understanding about the general terms and conditions for a settlement agreement that would end the Track VIII proceedings; and on
August 20, 2014 they reported that an agreement had been reached on the text of such settlement agreement.
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On July 22, 2014, the Court issued the following:
(a) Case Management Order No. XXIII to conduct the proceedings, establishing a schedule for the first phase of Track IV (related to
claims by Occidental alleging “alter ego” between Maxus and its shareholders, and the transfer of assets to YPF and Repsol).
(b) a court Order for the process of approval of the agreement between the State of New Jersey and Occidental, which established a
schedule for the approval of the agreement between Occidental and the State of New Jersey.
On December 16, 2014, the Court approved the Settlement Agreement whereby the State of New Jersey agreed to settle all claims
against Occidental related to the environmental liabilities within a specific geographical area of the Passaic River, New Jersey, United
States of America, in consideration for the payment of US$ 190 million in three installments, the last payable on June 15, 2015; and a
sum amounting up to US$ 400 million if the State of New Jersey had to pay its percentage for future remedial actions.
On January 5, 2015, Maxus Energy Corporation (“Maxus”), a subsidiary of YPF S.A., received a letter from Occidental requesting
Maxus to indemnify Occidental for all the payments that Occidental agreed to pay to the State. Formerly, in 2011 the Court held that
Maxus had the contractual obligation to indemnify and hold Occidental harmless from any liability under the New Jersey Spill
Compensation and Control Act resulting from contaminants dumped in or from the Lister Avenue site owned by a company bought
by Occidental, and with which it merged in 1986. Maxus holds that both the existence and the amount of such obligation to indemnify
Occidental for the payments made to the State under the settlement agreement are pending issues that must wait for the Court
decision on the Passaic River case.
In addition, on July 31, 2014 Occidental submitted its third amendment to the complaint, in replacement of the second amendment
submitted in September 2012. YPF, Repsol and Maxus filed motions to limit Occidental’s third amended complaint arguing that the
claims incorporated in the third amendment were not included in the second. Occidental answered that the third amendment
incorporates new facts, but not new claims. On October 28, 2014 Judge Lombardi rejected Occidental’s arguments.
Also, Repsol S.A. countersued Occidental Petroleum Corporation (“Occidental”) alleging that the US$ 65 million paid by Repsol as
per the agreement between Repsol, YPF, YPF Holdings, Maxus and Tierra Solutions with the State of New Jersey was paid for
damages caused by (a) Diamond Shamrock Chemicals Company, for which Occidental is liable under the share purchase agreement
of 1986 or (b) Occidental’s individual conduct.
On March 26, 2015, a new presiding judge was appointed for the case (Hon. Gary Furnari).
On April 15, 2015, Occidental sent Maxus a letter claiming indemnity protection under the share purchase agreement with respect to
the counterclaim filed by Repsol against Occidental. On 28 April 2015, Maxus replied contesting the claims reserving all arguments
and defenses regarding the SPA’s indemnification provisions.
On March 9, 2015 the Special Master issued the Case Management Order XXVI and the Case Management Order XXVII dated
July 1, 2015 under which the new judge extended the deadline to complete all presentations until January 29, 2016, established a
briefing schedule pursuant to which summary judgment will not be decided until late April or early May 2016, at the earliest, and
included a provision that trial shall be scheduled in June 2016. Depositions of witnesses residing in the U.S. and abroad began in
December 2014 in accordance with the Case Management Order XXV. Since that time about forty witnesses have been deposed,
including the corporate representatives of all the parties. The issues being explored include Track IV (the alter-ego and fraudulent
transfers of assets) and Track III (indemnity claims filed by OCC against Maxus). Depositions of witnesses were completed in mid-
October 2015.
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Notwithstanding the above, the Special Master authorized the parties to file briefs specifying any issue in respect of which each party
believed that the court should authorize early summary judgment motions. The motions filed by the parties and the non-binding
opinions as issued by the special judge on January 14, 2016, are summarized below:
(a) YPF filed for early summary judgment against OCC on four issues: i) dismissal of the portion of OCC’s claims for alter ego
liability, based on the financing of YPF’s acquisition of Maxus shares in 1995; ii) dismissal of the portion of OCC’s claims for alter
ego liability, based on the transfer of Maxus’ assets from 1995 through 1999; iii) dismissal of the portion of OCC’s liability claims
based on the alleged “control” by YPF of Maxus’s Board of Directors’ decision, in 1996, to sell its subsidiaries in Bolivia and
Venezuela to YPF International; and iv) dismissal of the portion of OCC’s claims for alter ego liability, based on the transfer of
Maxus’ environmental liabilities to Tierra in 1996.
The Special Master’s Recommendation on YPF’s motion recommended to deny the motion on the grounds that i) the statute of repose
for fraudulent transfers is not applicable to the remedy of alter ego for breach of contract and ii) a finder of fact should be permitted to
consider all portions of YPF actions when determining if there is alter ego liability so dismissal of portions of these claims is
inappropriate.
(b) OCC filed for early summary judgment against Maxus in relation to OCC’s claim to recover the amount of US$ 190 million (plus
expenses) paid to the State of New Jersey under the settlement agreement.
The motion sought to establish that Maxus is liable for all conduct at the Lister Site, regardless of any actions taken by OCC
(including the period of time that the OCC operated Lister Site). Therefore, the Special Master’s Recommendation on OCC’s motion
against Maxus recommended to grant the motion on the grounds that (i) the language of the SPA was not ambiguous and required
Maxus to indemnify OCC for its own conduct at the Lister Site and (ii) OCC was not estopped from seeking indemnity from Maxus
for its own conduct at the Lister Site because it did not take inconsistent legal positions in prior litigations. Notwithstanding the
foregoing, Occidental will have to prove the reasonableness of the US$190 million amount settled with the State of New Jersey, for
which Maxus may eventually be liable.
In addition, OCC filed for early summary judgment dismissing the cross-claims of Repsol against OCC, which seek to recover from
OCC the US$ 65 million payment made by Repsol to New Jersey State under the settlement agreement.
The Special Master’s Recommendation on OCC’s motion against Repsol recommended to deny the motion in part as to Repsol’s
contribution claim and to grant the motion in part as to Repsol’s unjust enrichment claim, on the grounds that i) Repsol’s contribution
claims are permissible under the New Jersey Spill Act even if a settlement did not fully discharge liability to the State; ii)
demonstrating Repsol’s liability under the Spill Act is not a prerequisite for Repsol to receive contribution from OCC; iii) Repsol is
not liable to OCC for indemnification as an alter ego of Maxus, and iv) OCC was not unjustly enriched when Repsol settled with the
state.
(c) Repsol filed for early summary judgment against OCC to dismiss OCC’s cross-claims: i) to extent that OCC’s claims are based on
prescribed claims for fraudulent transfers; ii) on the grounds that OCC cannot prove that it has suffered damages due to a failure to
perform an agreement; iii) on the grounds that OCC cannot prove that Repsol has caused any damage even if a non-performance
occurred, because OCC has alleged that Maxus became insolvent before Repsol acquired YPF in 1999; and iv) on the grounds that
OCC has failed to pierce the corporate veil between YPF and Repsol.
The Special Master’s Recommendation on Repsol’s motion against OCC recommended to grant the motion on the grounds that OCC
failed to set out any basis to pierce the corporate veil between YPF and Repsol, which the Special Master held OCC was required to
do, and because OCC did not allege that YPF was insolvent.
(d) Maxus filed for early summary judgment against OCC to dismiss the claims for damages filed by OCC regarding costs not yet
incurred by OCC (future remediation costs). YPF joined in this motion. The Special Master’s Recommendation on Maxus’s motion
against OCC was to grant the motion on the grounds that OCC’s request for declaratory judgment has no basis due to the uncertainty
regarding future costs.
(e) Finally, related to the claims that OCC sought to add against YPF and Repsol for tortious interference with OCC’s contractual
rights under the Stock Purchase Agreement of 1986 (between Maxus and OCC), the Special Master’s recommended to deny the
motion on the grounds that OCC improperly delayed in seeking to supplement its claims despite having multiple earlier opportunities
to do so.
F-78
The parties appealed the Special Master’s Recommendations by February 16, 2016. The recommendations will be submitted to the
trial judge who may adopt them completely, partially or refuse them and issue a new judgment. Until the court rules on these
recommendations, Repsol and OCC have requested an interruption of the expert witness phase. The judge partially accepted the
suspension request regarding the evidence to be produced by Repsol. Accordingly, the court will have to issue a new Case
Management Order, reviewing the deadlines for the remaining phases of the process.
Furthermore, on October 23, 2015, YPF received a copy of the six reports produced by OCC regarding expert witnesses. Three of the
reports are intended to fully demonstrate claims set forth by OCC under Track III. The other three are intended to defend OCC’s
position in respect of Track IV. The remaining parties, including YPF, have submitted their reports regarding expert evidence and
have begun with the testimony of these experts, which is expected be completed in the first quarter of 2016.
2.5. Conclusion
As at December 31, 2015, an accrual for all matters related to the “Environmental Issues relating to Lister site and Passaic River” was
recorded for a total amount of 2,665 comprising the cost of studies, the most reasonable estimation of expenses that YPF Holdings
Inc. may incur for remedial activities, taking into account the impossibility of reasonably estimating a loss or loss range related to the
eventual aforementioned FFS costs, considering the studies performed by TS, and the estimated costs corresponding to the Removal
Agreement from 2008, as well as other matters related to Passaic River and Newark Bay. This includes the aforementioned associated
legal matters. However, other potentially works may be required, including remedial measures additional to or different from those
taken into account. Additionally, the development of new information, the imposition of penalties or remedial actions, or the outcome
of negotiations related to the mentioned matters differing from the scenarios assessed by YPF Holdings may result in a need by this
company to incur in additional costs higher than the current allowance amount accrued.
Considering the information available to YPF Holdings Inc. as of the date of issuance of these financial statements; the results of
studies and testing phase; as well as the potential liability of the other parties involved in this issue and the possible allocation of the
removal costs; and considering the opinion of our internal and external legal advisors, the management of the Company has not
accrued additional amounts than the mentioned above and that could emerge as a result of the conclusion of the aforementioned
issues and consequently to be reasonably estimated.
3. Other Environmental Administrative Issues unrelated to “Passaic River”
•
Hudson County, New Jersey
Until 1972, Chemicals operated a chromite ore processing plant at Kearny, New Jersey (“Kearny Plant”). According to the DEP,
wastes from these ore processing operations were used as fill material at a number of sites in and near Hudson County. DEP has
identified over 200 sites in Hudson and Essex Counties alleged to contain chromite ore processing residue either from the Kearny
Plant or from plants operated by two other chromium manufacturers.
The DEP, TS and Occidental, as successor to Chemicals, signed an administrative consent order with the DEP in 1990 for
investigation and remediation work at 40 chromite ore sites in Hudson and Essex Counties alleged to be impacted by the Kearny
Plant operations.
TS, on behalf of Occidental, is presently performing the work and funding Occidental’s share of the cost of investigation and
remediation of these sites. In addition, financial assurance has been provided in the amount of US$ 20 million for performance of the
work. The ultimate cost of remediation is uncertain. TS submitted its remedial investigation reports to the DEP in 2001, and the DEP
continues to review the report.
F-79
Additionally, in May 2005, the DEP took two actions in connection with the chrome sites in Hudson and Essex Counties. First, the
DEP issued a directive to Maxus, Occidental and two other chromium manufacturers directing them to arrange for the cleanup of
chromite ore residue at three sites in New Jersey City and the conduct of a study by paying the DEP a total of US$ 20 million. While
YPF Holdings Inc. believes that Maxus is improperly named and there is little or no evidence that Chemicals’ chromite ore residue
was sent to any of these sites, the DEP claims these companies are jointly and severally liable without regard to fault. Second, the
State of New Jersey filed a lawsuit against Occidental and two other entities seeking, among other things, cleanup of various sites
where chromite ore processing residue is allegedly located, recovery of past costs incurred by the state at such sites (including in
excess of US$ 2 million allegedly spent for investigations and studies) and, with respect to certain costs at 18 sites, treble damages.
The DEP claims that the defendants are jointly and severally liable, without regard to fault, for much of the damages alleged. In
February 2008, the parties reached an agreement in principle, for which TS, on behalf of Occidental, agreed to pay US$ 5 million and
perform remediation works in three sites, with a total cost of approximately US$ 2 million, subject to the terms of a Consent
Judgment between and among DEP, Occidental and two other parties, which was published in the New Jersey Register in June 2011,
and became final and effective as of September 2011. Pursuant to the Consent Judgment, the US$ 5 million payment was made in
October 2011 and a master schedule was delivered to DEP for the remediation during a ten-year period, of the three orphan sites plus
the remaining chromite ore sites (approximately 26 sites) under the Kearny ACO. DEP indicated that it could not approve a ten-year
term; consequently, Maxus submitted a revised eight-year schedule which was approved by DEP on March 24, 2013.
On behalf of Occidental, Maxus granted a financial guarantee in an amount of US$ 20 million for the performance of this work.
Currently, TS is performing the work in accordance with the Master Plan, where the outstanding activities are the onset and
completion of extensions work at six sites, the implementation of the planning phase of the remedial action for a minimum of eight
sites, and the preparation and/or presentation of the remedial work plan intended to start them in about seven sites.
In November 2005, several environmental groups sent a notice of intent to sue the owners of the properties adjacent to the former
Kearny Plant (the “adjacent property”), including among others TS, under the Resource Conservation and Recovery Act. The stated
purpose of the lawsuit, if filed, would be to require the noticed parties to carry out measures to abate alleged endangerments to health
and the environment emanating from the Adjacent Property. The parties have entered into an agreement that addresses the concerns
of the environmental groups, and these groups have agreed, not to file suit. After the original agreement expired, the parties entered
into a new Standstill Agreement, effective since March 7, 2013.
In March 2012, the PRG received a Notice of Deficiency (“NOD”) letter from DEP relating to the Hackensack River Study Area
(“HRSA”) Supplemental Remedial Investigation Work Plan (“SRIWP”) that the PRG had submitted to the DEP in January 2009. In
the NOD, DEP seeks to expand the scope of work that would be required in the Hackensack River under the SRIWP to add both
additional sample locations/core segments and parameters.
While the PRG acknowledges that it is required to investigate and prevent chrome releases from certain upland sites into the river, the
PRG contends that it is has no obligation under the governing ACOs and Consent Judgment to investigate chrome contamination in
the river generally. PRG responded with these and other arguments to the NOD, by which asked for its cancellation. Negotiations
between the PRG and the DEP are ongoing.
As of December 31, 2015, there are approximately 608 accrued in connection with the foregoing chrome-related matters. The study
of the levels of chromium has not been finalized, and the DEP is still reviewing the proposed actions. The cost of addressing these
chrome-related matters could increase depending upon the final soil actions, the DEP’s response to TS’s reports and other
developments.
•
Standard Chlorine Chemical Company Superfund Site
In 2013, the Standard Chlorine Site Cooperating Parties Group (including Maxus on behalf of Occidental) entered into a CERCLA
Administrative Order on Consent with EPA. This Consent Order required the Cooperating Parties Group to fund and perform a Site
RI/FFS. The RI was completed during the fourth quarter of 2014 and EPA approved the RI Report in October 2015. The draft FFS
was submitted to EPA during the third quarter of 2015. The Site Cooperating Parties Group received EPA’s initial comments on the
FFS on October 1, 2015. The revised FFS is due to EPA on March 11, 2016.
F-80
As of December 31, 2015, Maxus had reserved 22 for known probable and reliably estimable Site related losses to allow continued
response for this matter on Occidental’s behalf.
•
Painesville, Ohio
In connection with the Chemical’s operation until 1976 of one chromite ore processing plant (“Chrome Plant”), the Ohio
Environmental Protection Agency (“OEPA”) ordered to conduct a RI/FS at the former Painesville’s Plant area. OEPA has divided the
Painesville Work Site into 20 operable units, including operable units related to groundwater. TS has agreed to participate in the
RI/FS as required by the OEPA. TS submitted the remedial investigation report to the OEPA, which was finalized in 2003. TS will
submit required feasibility reports separately. In addition, the OEPA has approved certain work, including the remediation of specific
operable units within the former Painesville Works area and work associated with the development plans (the “Remediation Work”).
The Remediation Work has begun. As the OEPA approves additional projects related to investigation, remediation, or operation and
maintenance activities for each operable unit within the Site, additional amounts will need to be provisioned.
Over fifteen years ago, the former Painesville Works Site was proposed for listing on the national Priority List under the
Comprehensive Environmental Response, Compensation and Liability Act of 1980, as amended (“CERCLA”); however, the EPA has
stated that the site will not be listed so long as it is satisfactorily addressed pursuant to the Director’s Order and OEPA’s programs. As
of the date of issuance of these consolidated financial statements, the site has not been listed.
During the third quarter of 2015 the final remedies for Operable Units 2 and 6 were completed; Ohio EPA approved these remedy
completions in July 2015 and terminated the applicable State Administrative Orders. Also in July 2015, OPEA issued its Preferred
Remedial Plan for OU-5. As of December 31, 2015, the Painesville PRP Group (including Tierra and Maxus on behalf of Occidental)
continues to move forward with the funding and performance of Feasibility Studies for each of the remaining Operable Units and the
performance of individual Operable Unit remedies as they are selected by OPEA. Further, Maxus, on behalf of Occidental, continues
to fund and perform groundwater extraction and treatment, and operation and maintenance activities, as required under the 1983
RCRA Administrative Consent Order.
As of December 31, 2015, the Company has reserved approximately 134 for known probable and reasonably estimable Painesville
Site environmental liabilities.
The scope and nature of any further investigation or remediation that may be required cannot be determined at this time; however, as
the RI/FS progresses, YPF Holdings will continuously assess the condition of the Painesville Works Site and make any required
changes, including additions, to its provision as may be necessary.
•
Other sites - Greens Bayou
Pursuant to settlement agreements with the Port of Houston Authority and other parties, TS and Maxus are participating (on behalf of
Chemicals) in the remediation of property required Chemicals’ former Greens Bayou facility where DDT and certain other chemicals
were manufactured. Additionally, in 2007 the parties have reached an agreement with the Federal and State Natural Resources
Trustees concerning natural resources damages. In 2008, the Final Damage Assessment and Restoration Plan/Environmental
Assessment were approved, specifying the restoration projects to be implemented. During the first semester of 2011, TS negotiated,
on behalf of Occidental, a draft Consent Decree with governmental agencies of the United States and Texas addressing natural
resource damages at the Greens Bayou Site. The Consent Decree was signed by the parties in January 2013 and notice of approval of
the Proposed Consent Agreement was published in the Official Gazette on January 29, 2013. After the publication of the notice a
period of 30 days is opened for comments. Under the agreement, it is agreed to reimburse certain costs incurred by the
aforementioned governmental agencies and conducting two restoration projects for a total amount of US$ 0.8 million. Although the
primary work was largely finished in 2009, some follow-up activities and operation and maintenance remain pending. As of
December 31, 2015, YPF Holdings Inc. has accrued 50 for its estimated share of remediation activities associated with Greens Bayou
facility.
F-81
•
Milwaukee Solvay Site
In June 2005, the EPA designated Maxus as PRP (Potential Responsible Party) at the Milwaukee Solvay Coke & Gas site in
Milwaukee, Wisconsin. The basis for this designation is Maxus alleged status as the successor to Pickands Mather & Co. and
Milwaukee Solvay Coke Co., companies that the EPA has asserted are former owners or operators of such site.
In November 2006, five PRPs, including Maxus, signed a joint agreement of participation and defense that establishes the allocation
of costs for making a RI/FS. Under the agreement Maxus is responsible for a significant part.
In 2007, Maxus signed with four other parties potentially involved, an AOC to conduct RI/FS about contamination in the soil,
groundwater, as well as in the Kinnickinnic River sediments.
On April 25, 2012 EPA made a proposal concerning the scope of future investigations of sediments, which was rejected by the PRP
group.
On June 6, 2012 the PPR Group submitted a proposed Field Sampling Plan (FSP) that included detailed plans for the remaining
upland investigation and a phased approach to the sediment investigation. In July 2012, EPA responded to the FSP requiring
expanded sediment sampling as part of the next phase of the investigation and additional evaluation for the possible presence of
distinct coal and coke layers on parts of the upland portion of the Site. In December 2012, EPA approved the PRP Group’s revised
FSP, and the PRP Group commenced upland and sediment investigation activities. The estimated cost of implementing the field work
associated with the FSP is approximately US$ 0.8 million.
In February 2014, the PRP Group submitted to EPA and the Wisconsin Department of Natural Resources (“WDNR”) a preliminary
study of basic assessment of risk to human health, a preliminary study of ecological risk assessment of upland and an ecological risk
assessment of aquatic life. Currently, they are conducting sediment research activities as approved in the FSP.
In June 2014, the PRP Group submitted to EPA and WDNR the draft Remedial Investigation (“RI”) Report and risk assessment
documents (i.e., Baseline Human Health Risk Assessment, Screening Level Ecological Risk Assessment, and Aquatic Baseline
Ecological Risk Assessment) and a Remedial Action Objectives Technical Memorandum. Comments to the draft RI Report were
received in October 2014. In accordance with the timeline established by the Agencies, in November 2014 the PRP Group submitted
written responses to the EPA/WDNR comments concerning the draft RI and risk assessment documents. The PRP Group received
approval from EPA to defer preparation of responses to the comments on the draft RAOs until after the RI has been approved.
EPA commented on the RI Report in November 2015, and the PRP Group submitted a revised RI Report in December 2015.
YPF Holdings Inc. has accrued 4 as of December 31, 2015 for its estimated share of the costs of the RI/FS. The main outstanding
issue lies in determining the extent of the studies of sediments in the river that may be required. YPF Holdings Inc. lacks sufficient
information to determine additional costs, if any; it might have in respect of this site.
•
Other sites - Black Leaf Chemical Site
In September 2011, Occidental and Exxon Mobil received a liability notice from EPA under the ruling known as 104(e) for the site
called Black Leaf Chemical located at Louisville, Kentucky. Occidental requested that Maxus undertake the defense of this matter by
virtue of the indemnity established in the Stock Purchase Agreement of 1986. Maxus accepted the defense, reserving its rights with
respect to the case and without acknowledging any responsibility, in November 2011. In March 2013, EPA requested Maxus on
behalf of Occidental, and Exxon Mobil to perform specific remedial tasks and to reimburse EPA and the local regulatory authority
certain past costs (estimated between US$ 3 and US$ 5 million).
In September 2014, the Environmental Protection Department of Kentucky (“EPDK”) initiated investigation procedures. In October
2015, the EPDK approved the site characterization report submitted by the cooperation group and required presentation of a
remediation action plan. In January 2016, the cooperation group presented the required remediation action plan. As of December 31,
2015, the Company provisioned its contribution for the estimated site remediation costs.
F-82
•
Tuscaloosa Site
YPF Holdings Inc. has completed the remediation activities at this site and has provisioned 52 for matters related to operation and
maintenance activities as of December 31, 2015.
•
Malone Services Site
Maxus has agreed to defend Occidental, as successor to Chemicals, in respect of the Malone Services Company Superfund site in
Galveston County, Texas. This site is a former waste disposal site where Chemicals is alleged to have sent waste products prior to
September 1986. The potentially responsible parties, including Maxus on behalf of Occidental, formed a PRP Group to finance and
perform an AOC RI/FS. The RI/FS has been completed and the EPA has selected a Final Remedy, the EPA Superfund Division
Director signed the Record of Decision on September 20, 2009. The PRP Group signed a Consent Decree in the second quarter of
2012 which became effective in July, 2012. During 2012, 2013, 2014 and 2015 the PRP Group continued with the design, planning
and remediation phase. As of December 31, 2015 YPF Holdings has accrued 5 in connection with its obligations for this matter.
•
Central Chemical Company Superfund Site (Hagerstown, Maryland)
The Central Chemical PRP Group has been responding to this federal Superfund Site since the early/mid 1990s. The PRP Group
consists of parties who EPA alleges are former Central Chemical Company customers (or who are the legal successors thereof) which
arranged for the disposal of certain CERCLA hazardous substances at the Site. Maxus participates in the PRP Group on behalf of
Occidental. In 1998, the EPA entered into a CERCLA Administrative Order on Consent with certain PRPs to conduct an RI/FS. The
PRP Group, including Maxus, on behalf of Occidental, funded and performed the RI/FS, which was completed in 2007. In 2009 the
EPA issued its Record of Decision which selected the final Site remedy. In 2010, EPA divided the Site into two Operable Units:
“Operable Unit 1” (OU-1) – Site soils, waste and shallow groundwater, and; “Operable Unit 2” (OU-2)—bedrock groundwater. In
September 2012, the EPA issued CERCLA Special Notice Letters to the PRPs, including Occidental, requesting that they fund and
perform the Site OU-1 remedy. In August 2013, the PRP Group members, including Occidental, entered into a CERCLA
Administrative Order on Consent to fund and perform the Remedial Design for Operable Unit 1.
In early 2014, the PRP Group and the EPA began negotiations of a judicial Consent Decree for the funding and performance of the
Remedial Action for Operable Unit No. 1. During the third quarter of 2015, the Central Chemical PRP Group members (including
Maxus on behalf of Occidental) entered into a judicial Consent Decree for the funding and performance of the OU-1 Remedy (the
“OU-1 Consent Decree”). The OU-1 Consent Decree was approved and entered with the court in October 2015. Performance of the
Remedial Action for Operable Unit No. 1 is currently forecasted to occur between 2016 and 2021; and according to EPA, is estimated
to cost approximately US$ 14.2 million. In addition, the EPA may also require the Central Chemical PRP Group to initiate a
Remedial Design/Remedial Action for Operable Unit 2 in 2016 or 2017; which the PRP Group has estimated could cost at least US$
3 million.
As of December 31, 2015, Maxus had reserved 17 for known probable and reliably estimable Site related losses to allow continued
response for this matter on Occidental’s behalf.
•
Other third party sites
Chemicals has also been designated as a PRP with respect to a number of third party sites where hazardous substances from
Chemicals’ plant operations allegedly were disposed or have come to be located. At several of these, Chemicals has no known
relationship. Although PRPs are typically jointly and severally liable for the cost of investigations, cleanups and other response costs,
each has the right of contribution from other PRPs and, as a practical matter, cost sharing by PRPs is usually effected by agreement
among them. As of December 31, 2015, YPF Holdings Inc. has accrued approximately 48 in connection with its estimated share of
costs related to certain sites and the ultimate cost of other sites cannot be estimated at the present time.
F-83
•
Black Lung Benefits Act Liabilities
The Black Lung Benefits Act provides monetary and medical benefits to miners disabled with a lung disease, and also provides
benefits to the dependents of deceased miners if black lung disease caused or contributed to the miner’s death. As a result of the
operations of its coal-mining subsidiaries, YPF Holdings Inc. is required to provide insurance of this benefit to former employees and
their dependents. As of December 31, 2015, YPF Holdings Inc. has accrued 35 in connection with its estimate of these obligations.
4. Other legal proceedings
•
Sale Taxes - Texas
In 2001, the Texas State Controller assessed Maxus approximately US$ 1 million in Texas state sales taxes for the period of
September 1, 1995 through December 31, 1998, plus penalty and interest.
In August 2004, the administrative law judge issued a decision affirming approximately US$ 1 million of such assessment, plus
penalty and interest. YPF Holdings Inc. believes the decision is erroneous, but has paid the revised tax assessment, penalty and
interest (a total of approximately US$ 2 million) under protest. Maxus filed a suit in Texas state court in December 2004 challenging
the administrative decision. The matter will be reviewed by a trial de novo in the court action, additionally, settlement negotiations
are ongoing.
•
Occidental’s claim for past events - Texas
In 2002, Occidental sued Maxus and TS in state court in Dallas, Texas seeking a declaration that Maxus and TS have the obligation
under the agreement pursuant to which Maxus sold Chemicals to Occidental to defend and indemnify Occidental from and against
certain historical obligations of Chemicals, notwithstanding the fact that said agreement contains a twelve-year cut-off for defense
and indemnity obligations with respect to most litigation. TS was dismissed as a party, and the matter was tried in May 2006. The
trial court decided that the twelve-year cut-off period did not apply and entered judgment against Maxus. This decision was affirmed
by the Court of Appeals in February 2008. Maxus has petitioned the Supreme Court of Texas for review. This lawsuit was denied.
Maxus anticipates that Occidental’s costs in the future under the Dallas case will not exceed those incurred in the first semester of
2012. Most of the claims that had been rejected by Maxus based on the twelve-year cut-off period, were related to “Agent Orange”.
With the exception of one Agent Orange claim filed in 2012 and dismissed in 2013. All pending Agent Orange litigation was
dismissed in December 2009, and although it is possible that further claims may be filed by unknown parties in the future, no further
significant liability is anticipated.
•
Turtle Bayou
In March 2005, Maxus agreed to defend Occidental, as successor to Chemicals, in respect of an action seeking the contribution of
costs incurred in connection with the remediation of the Turtle Bayou waste disposal site in Liberty County, Texas. The plaintiffs
alleged that certain wastes attributable to Chemicals found their way to the Turtle Bayou site. Trial for this matter was bifurcated, and
in the liability phase Occidental and other parties were found severally, and not jointly, liable for waste products disposed of at this
site. Trial in the allocation phase of this matter was completed in the second quarter of 2007, and following post judgment motions,
the court entered a decision setting Occidental’s liability at 15.96% of the past and future costs to be incurred by one of the plaintiffs.
Maxus appealed this matter. In June 2010, the Court of Appeals ruled that the District Court had committed errors in the admission of
certain documents, and remanded the case to the District Court for further proceedings. Maxus took the position that the exclusion of
the evidence should reduce Occidental’s allocation by as much as 50%. The District Court issued its Amended Findings of Fact and
Conclusions of Law in January 2011, requiring Maxus to pay, on behalf of Occidental, 15.86% of the past and future costs to be
incurred by one of the plaintiffs. On behalf of Occidental, Maxus presented an appeal in the first semester of 2011. The U.S. Court of
Appeals for the Fifth Circuit affirmed the District Court’s ruling in March 2012. Maxus paid to the plaintiff, on behalf of Occidental,
US$ 2 million in June 2012 covering past costs and US$ 0.9 million in November 2012 to cover the costs incurred by El Paso in
2007-2011. The obligation to pay some future costs is still pending. As of December 31, 2015, YPF Holdings Inc. has accrued 5 in
respect of this matter.
F-84
•
Ruby Mhire:
In May 2008, Ruby Mhire and others (“Mhire”) brought suit against Maxus and other third parties, alleging that various parties
including a predecessor of Maxus had contaminated certain property in Cameron Parish, Louisiana, during oil and gas activities on
the property. Maxus’ predecessor operated on the property from 1969 to 1989. The Mhire plaintiffs have demanded remediation and
other compensation from approximately US$ 159 million to US$ 210 million basing themselves on plaintiff’s experts study. During
June 2012, the parties in the case held a court-ordered mediation. Maxus filed appropriate answers to the complaints. On June 22,
2012, the parties to the case held a mediation requested by the Court to discuss a settlement. In this mediation, two of the five
defendants reached an agreement with the plaintiffs. Plaintiffs did not attain a termination agreement with the three remaining
defendants (Maxus, Chevron and El Paso). In the fourth quarter of 2012 both the discovery process and the depositions were
intensified. In December 2012, Maxus filed an appeal with the intention to obtain a change of forum, alleging that its due process
rights would be adversely affected if the case was heard in Cameron. The Court had contemplated a hearing in February 2013 and a
trial in March 2013. However, the Court suspended litigation in order to allow for the negotiation of an out-of-court settlement
agreement between the parties. On June 2013, Maxus signed an agreement with its plaintiffs, in which Maxus has to make installment
payments over three years, and is required to remediate the site. On July 31, 2013, the Court of Judicial District No. 38 of Cameron,
Louisiana State accepted the Resolution Agreement after receiving the notification of No Objection from the Department of Natural
Resources, Office of Conservation on July 8, 2013. In August 2013, under the Settlement Agreement, Maxus made the initial
payment of US$ 2 million and in December 2013, June 2014 and December 2014 Maxus made payments of US$ 3 million each time.
One last installment payment in the amount of US$ 1 million was made in June 2015. Maxus has no further payment obligation to
plaintiffs under the Settlement Agreement; however, it must still undertake remediation of the site, which is expected to be completed
in 2016.
•
The Bedivere Litigation (Bedivere Insurance Company et al. v Maxus Energy Corporation;
Is an Insurance Declaratory Judgment Action (“Declaratory Action”) which was filed against Maxus in Texas State District Court.
The Plaintiffs are former insurers, or successors thereof, who issued insurance policies to Maxus and its predecessors covering certain
risks associated with oil and gas exploration and production activities in the State of Louisiana (the “Policies”). The underlying
subject matter of the Declaratory Action arises from the alleged claims, and ultimate settlement thereof, asserted against Maxus in the
Ruby Mhire Litigation. The Ruby Mhire Litigation was a Louisiana Oil Field Legacy Liability Lawsuit which was filed in Cameron
Parish, Louisiana in 2008 against numerous oil and gas companies, including Maxus. Maxus settled the Ruby Mhire Litigation during
the summer of 2013. Prior to the filing of the Declaratory Action, Maxus had been engaged in substantive discussions with the claims
administrator for the Plaintiff insurance companies in the Declaratory Action regarding a possible resolution of Maxus claims under
the Policies. On June 18th, 2015, Resolute issued a Denial of Coverage, and without prior notice, filed the Declaratory Action the
next day. Maxus is actively defending the case. As a first step, in October 2015, Maxus requested a change of venue to Harris County,
which was granted by the court.
•
Environmental Contamination Claims in Louisiana:
Maxus is also defending two additional environmental contamination claims brought against it in Louisiana arising from legacy
petroleum exploration and production activities.
The Jumonville Litigation: is a claim brought in 2012 in Port Coupee Parish, Louisiana against Murphy Oil, as Lessee, and Maxus as
successor to Apexco/Natomas, the operator, for environmental contamination caused by the drilling of a deep well in 1976 that was a
dry hole, and which was plugged and abandoned in 1978. The claim against Murphy Oil is a contract claim with a 10-year
prescription period from date of discovery. The claim against Maxus is a tort claim with a 1-year prescription period from date of
discovery. Murphy Oil asserts, without documentary evidence to date, that it probably farmed-out or assigned the lease to Maxus and
that there would have been an indemnity provision in such documentation. Murphy Oil’s position is that Maxus has an obligation to
indemnify it as Maxus’s predecessor was the operator of the well. However, it has produced not documentary evidence of this. In
May 2014, the court severed the plaintiffs’ claims against Maxus and Murphy Oil from its claims against other defendants and set the
trial date for August 2015. In July 2015, Maxus and Plaintiffs entered into a non-binding Settlement Memorandum of Understanding
(MOU) as a first step towards a court-approved settlement of this litigation. Under the terms of the MOU, the litigation is stayed as to
Maxus and Murphy Oil to allow for continued settlement discussions. The MOU contemplates a final settlement consisting of, among
other things, two primary components: 1) a monetary payment(s) made by Maxus to the Plaintiffs, and 2) Maxus’ funding and
performance of a defined limited site remediation project at the Plaintiffs’ property.
F-85
As of December 31, 2015, Maxus and the Plaintiffs continue to make progress towards concluding a final and definitive settlement
agreement. Maxus expects that this matter will be resolved within the monetary amounts previously budgeted and reserved by the
Company. The Company currently forecasts that the Plaintiff’s claims against Maxus in this litigation will be resolved sometime
during the second quarter of 2016. Maxus advices that absent a definitive settlement sharing agreement between Maxus and Murphy,
it is possible that litigation of cross-claims could ensue between Maxus and Murphy Oil to resolve any settlement allocation dispute.
YPF Holdings Inc., including its subsidiaries, is a party to various other lawsuits and environmental situations, the outcomes of which
are not expected to have a material adverse effect on YPF’s financial condition or its future results of operations. YPF Holdings Inc.
provisioned legal contingences and environmental situations that are probable and can be reasonably estimated.
11. CONTINGENT LIABILITIES, CONTINGENT ASSETS, CONTRACTUAL COMMITMENTS, MAIN REGULATIONS
AND OTHERS
a) Contingent liabilities
The Company has the following contingencies and claims, individually significant, that the Company’s management, in
consultation with its external counsels, believes have possible outcome. Based on the information available to the
Company, including the amount of time remaining before trial among others, the results of discovery and the judgment of
internal and external counsel, the Company is unable to estimate the reasonably possible loss or range of loss on certain
matters referred to below:
–
Asociación Superficiarios de la Patagonia (“ASSUPA”): In August 2003, ASSUPA sued 18 companies operating
exploitation concessions and exploration permits in the Neuquén Basin, YPF being one of them, claiming the
remediation of the general environmental damage purportedly caused in the execution of such activities, and
subsidiary constitution of an environmental restoration fund and the implementation of measures to prevent
environmental damages in the future. The plaintiff requested that the Argentine Government, the Federal
Environmental Council (“Consejo Federal de Medio Ambiente”), the provinces of Buenos Aires, La Pampa,
Neuquén, Río Negro and Mendoza and the Ombudsman of the Nation be summoned. It requested, as a preliminary
injunction, that the defendants refrain from carrying out activities affecting the environment. Both the
Ombudsman’s summon as well as the requested preliminary injunction were rejected by the CSJN. YPF has
answered the demand requesting its rejection, opposing failure of the plaintiff and requiring the summon of the
Argentine Government, due to its obligation to indemnify YPF for events and claims previous to January 1, 1991,
according to Law No. 24,145 and Decree No. 546/1993. The CSJN gave the plaintiffs a term to correct the defects
of the complaint. On August 26, 2008, the CSJN decided that such defects had already been corrected and on
February 23, 2009, ordered that certain provinces, the Argentine Government and the Federal Environmental
Council be summoned. Therefore, pending issues were deferred until all third parties impleaded appear before the
court. As of the date of issuance of these consolidated financial statements, the provinces of Río Negro, Buenos
Aires, Neuquén, Mendoza, and the Argentine government have made their presentations, which are not available to
the Company yet. The provinces of Neuquén and La Pampa have claimed lack of jurisdiction, which has been
answered by the plaintiff, and the claim is pending resolution.
On December 13, 2011, the Supreme Court suspended the proceeding for 60 days and ordered YPF and the plaintiff
to present a schedule of the meetings that would take place during such suspension, authorizing the participation of
the remaining parties and third parties. ASSUPA reported the interruption of the negotiations in the claim and the
CSJN declared finalize the 60 days period of suspension property ordered.
F-86
On December 30, 2014 the Supreme Court issued two interlocutory judgments. By the first, it supported the claim
of the Provinces of Neuquén and La Pampa, and declared that all environmental damages related to local and
provincial situations were outside the scope of his original competence, and that only “inter-jurisdictional
situations” (such as the Colorado River basin) would fall under his venue.
By the second judgment, the Court rejected the petition filed by ASSUPA to incorporate Repsol and the directors
who served in YPF until April 2012 as a necessary third party. The Court also rejected precautionary measures and
other proceedings related to such request.
In addition, it should be highlighted that the Company learned about other three court complaints filed by ASSUPA
against:
(i) Concessionaire companies in the San Jorge Gulf basin areas: An attempt was made to give notice of the
complaint to YPF, which was held null and void due to formal defects thereof. Currently, the court has
ordered the suspension of procedural terms;
(ii) Concessionaire companies in the Austral basin areas: In this case, a highly summarized action has been
ordered. In addition, an interim relief has been issued to notify several companies of the existence of the
suit, and for the defendants to contribute certain information. This interim relief has been appealed
against by YPF. On November 2, 2015 YPF was notified of the lawsuit. Following an YPF request, the
court ordered on November 4, 2015 to suspend the procedural time-limits.
(iii) Concessionaire companies in the Northwest basin areas: The action has been submitted to ordinary
proceedings. On December 1, 2014, the Company was notified about the complaint. Currently, the
answering terms have been stayed as a result of a request submitted by the Company. In addition, Pan
American Company has challenged the acting judge without cause, wherefore the file was remitted for
the proceedings to be heard by Salta Federal Court No.2.
–
–
Petersen Energía Inversora, S.A.U and Petersen Energía, S.A.U. (collectively, “Petersen”): On April 8, 2015
Petersen Energía Inversora, S.A.U and Petersen Energía, S.A.U. (jointly, “Petersen”), a former shareholder of YPF,
filed a complaint against the Argentine Republic and YPF with the U.S. District Court for the Southern District of
New York. The litigation is being conducted by the bankruptcy trustee of the aforesaid companies by reason of a
liquidation process pending in a Commercial Court in Spain. The complaint contains claims related to the
expropriation of the controlling interest of Repsol in YPF by the Argentine Republic in 2012, asserting that the
obligation by the Argentine Republic to make a purchase offer to the remaining shareholders would have been
triggered. Claims seem to be mainly grounded on allegations that the expropriation breached contract obligations
contained in the initial public offering and bylaws of YPF and seeks unspecified compensation. The Company filed
a motion to dismiss on September 8, 2015, the date which was set as a result of the extension of the term provided
for by the Court. On the other hand, Petersen filed an objection against YPF’s motion to dismiss. Currently the
parties await the decision of the Court.
As of the date of this annual report, there are no elements held by YPF to quantify the potential impact that this
claim could have on the Company.
Petitions for bankruptcy filed by Pan American Sur S.A., Pan American Fueguina S.A. and Pan American Energy
LLC Sucursal Argentina: On September 18, 2015, Metrogas S.A. was made aware of petitions for bankruptcy, filed
by Pan American Sur S.A., Pan American Fueguina S.A. and Pan American Energy LLC Sucursal Argentina, which
are being heard by Argentine First Instance Court No. 26 in Commercial Matters, Division No. 51 of Buenos Aires
City. As of the date of these consolidated financial statements, Metrogas has not received any notice regarding said
court files, despite of which it shall take all necessary action for an appropriate defense of its rights.
F-87
–
–
–
Dock Sud environmental claims: A group of neighbours of Dock Sud, Province of Buenos Aires, have sued 44
companies, among which YPF is included, the Argentine Government, the Province of Buenos Aires, the City of
Buenos Aires and 14 municipalities, before the CSJN, seeking the remediation and the indemnification of the
environmental collective damage produced in the basin of the Matanza and Riachuelo rivers. Additionally, another
group of neighbours of the Dock Sud area, have filed two other environmental lawsuits, one of them desisted in
relation to YPF, claiming several companies located in that area, among which YPF is included, the Province of
Buenos Aires and several municipalities, for the remediation and the indemnification of the environmental
collective damage of the Dock Sud area and for the individual damage they claim to have suffered. At the moment,
it is not possible to reasonably estimate the outcome of these claims, as long as, if applicable, the corresponding
legal fees and expenses that might result. YPF has the right of indemnity by the Argentine Government for events
and claims previous to January 1, 1991, according to Law No. 24,145 and Decree No. 546/1993.
By means of sentence dated July 8, 2008, the CSJN:
(i) Determined that the Basin Authority (Law No. 26,168) (“ACUMAR”) should be in charge of the execution of
the program of environmental remediation of the basin, being the Argentine Government, the Province of
Buenos Aires and the City of Buenos Aires responsible of its development; delegated in the Federal Court of
First Instance of Quilmes the knowledge of all the matters concerning the execution of the remediation and
reparation; declared that all the litigations related to the execution of the remediation plan will accumulate and
will proceed before this court and established that this process produces that other collective actions that have
for object the environmental remediation of the basin be dismissed (“littispendentia”). YPF has been notified
of certain resolutions issued by ACUMAR, by virtue of which YPF has been requested to present an Industrial
Reconversion Program, in connection with certain installations of YPF. The Program has been presented
although the Resolutions had been appealed by the Company;
(ii) Decided that the proceedings related to the determination of the responsibilities derived from past behaviours
for the reparation of the environmental damage will continue before the CSJN.
Environmental claims in La Plata: YPF is aware of an action that has not been served yet, in which the plaintiff
requests the clean-up of the channel adjacent to the La Plata refinery, the Río Santiago, and other sectors near the
coast line, and, if such remediation is not possible, an indemnification of 500 or an amount to be determined from
the evidence produced in discovery. The claim partially overlaps with the requests made by a group of neighbours
of La Plata refinery on June 29, 1999, described in Note 10 of “La Plata and Quilmes environmental claims”.
Accordingly, YPF considers that if it is served in this proceeding or any other proceeding related to the same subject
matters, the cases should be consolidated to the extent that the claims overlap. The issue has been archived and no
notice has been served of the complaint filed against YPF in 2006. Therefore, this will not be reported in the future.
In addition to the information mentioned above, YPF has entered into an agreement with the OPDS in connection
with the claims of the channels adjacent to the La Plata refinery. See Note 10 “La Plata and Quilmes environmental
claims”.
Environmental claims in Quilmes: YPF has been notified of a complaint filed by neighbours of Quilmes city,
province of Buenos Aires, claiming approximately 421 for compensation for personal damages. Considering the
phase of the trial, the evidence available to the date, and the preliminary judgment of internal and external legal
advisors, YPF is unable to reasonably estimate the possible loss or range of loss related to this complaint.
F-88
–
National Antitrust Protection Board (“CNDC”): On November 17, 2003, Antitrust Board requested explanations,
within the framework of an official investigation pursuant to Article 29 of Law No. 25,156 of Antitrust Protection,
from a group of almost thirty natural gas production companies, YPF among them, with respect to the following items:
(i) the inclusion of clauses purportedly restraining trade in natural gas purchase/sale contracts; and (ii) observations on
gas imports from Bolivia, in particular (a) old expired contract signed by YPF, when it was state-owned, and YPFB
(the Bolivian state-owned oil company), under which YPF allegedly sold Bolivian gas in Argentina at prices below the
purchase price; and (b) the unsuccessful attempts in 2001 by Duke and Distribuidora de Gas del Centro to import gas
into Argentina from Bolivia. On January 12, 2004, YPF submitted explanations in accordance with article 29 of the
Antitrust Law, contending that no antitrust violations had been committed and that there had been no price
discrimination between natural gas sales in the Argentine market and the export market. On January 20, 2006, YPF
received a notification of resolution dated December 2, 2005, whereby the Antitrust Board (i) rejected the “non bis in
idem” petition filed by YPF, on the grounds that ENARGAS was not empowered to resolve the issue when
ENARGAS Resolution No. 1,289 was enacted; and (ii) ordered that the opening of the proceedings be undertaken
pursuant to the provisions of Section 30 of the Antitrust Law. On January 15, 2007, the Antitrust Board charged YPF
and eight other producers with violations of the Antitrust Law. YPF has contested the complaint on the basis that no
violation of the law took place and that the charges are barred by the applicable statute of limitations and has presented
evidence in support of its position. On June 22, 2007, YPF presented to the Antitrust Board, without acknowledging
any conduct in violation of the Antitrust Law, a commitment consistent with article 36 of the Antitrust Law, requiring
to the Antitrust Board to approve the commitment, to suspend the investigation and to file the proceedings. On
December 14, 2007, the Antitrust Board decided to transfer the motion to the Court of Appeals as a consequence of the
appeal presented by YPF against the rejection of the application of the statute of limitations.
In addition, on January 11, 2012, the Argentine Secretariat of Transportation filed with the CNDC a complaint against
five oil companies (including YPF), for alleged abuse of a dominant position regarding bulk sales of diesel fuel to
public bus transportation companies. The alleged conduct consists of selling bulk diesel fuel to public bus
transportation companies at prices higher than the price charged in service stations. According to the provisions of
Article 29 of the Antitrust Law, YPF has submitted appropriate explanations to the CNDC, questioning certain formal
aspects of the complaint, and arguing that YPF has adjusted its behaviour at all times with current regulations and that
it did not set any discrimination or abuse in determining prices.
In addition, YPF is subject to other claims before the Antitrust Board which are related to alleged price discrimination
in sale of fuels. Upon the opinion of Management and its legal advisors, such claims have been considered as possible
contingencies.
–
Additionally, the Company has received other labour, civil and commercial claims and several claims from the AFIP
and from provincial and municipal fiscal authorities, not individually significant, which have not been accrued since
Management, based on the evidence available as of the date of issuance of these consolidated financial statements, has
assessed them to be possible contingencies.
b) Contingent assets
-
La Plata Refinery:
On April 2, 2013, the facilities of YPF in the La Plata refinery were hit by a severe and unprecedented storm, which
caused a fire and consequently affected the Coke A and Topping C units in the refinery. These incidents temporarily
affected the crude processing capacity of the refinery, which had to be stopped entirely. Seven days after the event, the
processing capacity was restored to about 100 mbbl/day through the commissioning of two distillation units (Topping
IV and Topping D). Coke A unit is out of service permanently and Topping C unit was launched back in late May,
after a technical and human effort of great relevance.
Based on the documentation provided to the insurance adjuster appointed by reinsurers, and after their analysis, in
November 2013 YPF requested an advanced payment on account of the total compensation that will result from this
process of US$ 300 million (US$ 227 million for material damage and US$ 73 million for consequential loss). This
advance was accepted, recognized and paid by the reinsurers and, consequently, was recorded in YPF’s statement of
comprehensive income for the year ended on December, 31, 2013. For some subsequent periods, presentations to the
insurers had been submitted. Consequently a second partial payment of US$ 130 million has been request, this
payment was received during the third quarter of 2014. The loss of profit coverage period for this incident continued
until January 16, 2015, and the entire compensation for loss of profits was finally payed in June 2015 upon a final
payment of US$ 185 million.
The total amount received for this loss amounted to US$ 615 million, of which US$ 227 million were related to
property damage and US$ 388 million to loss of profits.
F-89
During the year ended December 31, 2015, the Company has concluded the claim settlement proceedings with the
insurance company and has recorded an income of 523, which were included in the statement of Comprehensive
income, under the captions “revenues” and “Cost of sales”, depending on the nature of the claimed concept.
–
Cerro Divisadero:
On March 21, 2014 a fire incident damaged the facilities of Crude Oil Treatment Plant of Cerro Divisadero in
Mendoza, belonging to the North Mendoza business, located 59 kilometres south from Malargüe city. In the
mentioned facilities crude oil production from the fixed assets located in North Malargüe and South Malargüe was
treated. As a consequence of the incident the facilities were almost completely unusable with the corresponding
production loss.
The incident was reported to the corresponding insurers and reinsurers and upon an analysis of the several technical
options, the Company has selected the facilities reconstruction option and has requested an advance payment of US$
60 million, which was received as of fiscal year end.
In November 2015, the claim settlement proceedings were concluded, with the final settlement amount agreed at
US$ 122 million, of which US$ 45 million were related to property damage and US$ 77 million to production
losses. This amount was accepted by reinsurers, while the remaining balance is pending payment as of the date of
issuance of these consolidated financial statements.
During the year ended December 31, 2015, the Group has recorded a gain of 1,165 in the statement of
comprehensive income under “Other operating results, net” and “Cost of sales”, based on the nature of the item
claimed (property damage and loss of production respectively).
c) Contractual commitments
–
Agreements of extension of concessions
•
Neuquén: On December 28, 2000, through Decree No. 1,252/2000, the Argentine Federal Executive Branch
(the “Federal Executive”) extended for an additional term of 10 years (until November 2027) the concession
for the exploitation of Loma La Lata – Sierra Barrosa area granted to YPF. The extension was granted under
the terms and conditions of the Extension Agreement executed between the Argentine Government, the
Province of Neuquén and YPF on December 5, 2000. Under this agreement, YPF paid US$ 300 million to the
Argentine Government for the extension of the concession mentioned above, which were recorded in “Fixed
Assets” on the balance sheet and committed, among other things, to define a disbursement and investment
program of US$ 8,000 million in the Province of Neuquén from 2000 to 2017 and to pay to the Province of
Neuquén 5% of the net cash flows arising out of the concession during each year of the extension term. The
previously mentioned commitments have been affected by the changes in economic rules established by Public
Emergency Law.
Additionally, in 2008 and 2009, YPF entered into a series of agreements with the Province of Neuquén, to
extend for ten additional years the term of the production concessions on several areas located in that province,
which, as result of the above mentioned agreement, will expire between 2026 and 2027. As a condition for the
extension of these concessions YPF undertook the following commitments, among others, upon the execution
of the agreements: i) to make to the Province total initial payments of US$ 204 million; ii) to pay in cash to the
Province an “Extraordinary Production Royalty” of 3% of the production of the areas involved. In addition, the
parties agreed to make adjustments of up to an additional 3% in the event of an extraordinary income
according to the mechanisms and reference values established in each signed agreement and iii) to carry out
exploration activities in the remaining exploration areas and make certain investments and expenditures in the
production concessions that are the purpose of the agreements in a total amount of US$ 3,512 million until the
expiring date of the concessions.
F-90
On July 24, 2013, in order to make feasible the implementation of a non-conventional hydrocarbons project,
YPF and the Province of Neuquén signed an Agreement under which the Province of Neuquén agreed to
(i) separate from the Loma La Lata – Sierra Barrosa exploitation concession a surface area of 327.5 km2;
(ii) incorporate such separated surface area into the surface area of the Loma Campana exploitation
concession, forming a surface area of 395 km2 and (iii) extend the Loma Campana exploitation concession for
a term of 22 years starting from the date of its expiration (until November 11, 2048).
The commitments made by the Company are as follows: i) payment of US$ 20 million in consideration for the
effect that the separation of surface from the Area Loma La Lata—Loma Campana has on the conventional
production, payable within 15 days of the legislative ratification of the Agreement; (ii) payment of US$
45 million on the Corporate Social Responsibility concept, payable during the years 2013/2014/2015;
(iii) payment of 5% on the investment project profits after taxes, applicable as from December 2027; (iv) 50%
reduction, as from August 2012, of the subsidy applicable to the price of natural gas for the Methanol Plant
according to the terms of the Commitment Act of 1998 signed between the Company and the Province of
Neuquén; (v) the Company undertakes to make an investment of US$ 1 billion within a period of 18 months
beginning on July 16, 2013; and vi) YPF commits to prioritize the recruitment of labor, suppliers and services
based in Neuquén.
The Province of Neuquén also agrees: i) not to apply Extraordinary Income (Windfall Profits) or Extraordinary
Production Taxes and to maintain a 12% rate for hydrocarbon royalties; (ii) to apply a Turnover Tax rate not
higher than 3% to the revenue generated in the Loma Campana concession; and (iii) to set the total sum of US$
1,240 million as the tax base for Stamps Tax purposes. The Agreement was approved by Decree No. 1,208/13
and Law No. 2,867.
•
Mendoza: In April 2011, YPF entered into an agreement with the province of Mendoza to extend for 10 years
the term of certain exploitation concessions (among which is “La Ventana”), and the transportation
concessions located in the province, from the expiration of the original terms of the grant.
By signing the memorandum of agreement, YPF assumed certain commitments within which includes: (i) to
make initial payments to the province of Mendoza in an aggregate amount of approximately US$ 135 million,
on the date specified in the agreement; (ii) to pay the province of Mendoza an “Extraordinary Production
Royalty” of 3% of the production of the areas included in the agreement. In addition, the parties agreed to
make additional adjustments in the event of extraordinary income due to lower export duties or a higher
monthly average price of crude oil and/or natural gas according to a mechanism and reference values
established in the Memorandum of Agreement; (iii) to carry out exploration activities and make certain
investments and expenditures in a total amount of US$ 4,113 million until the expiration of the extended term,
as stipulated in the agreement; and; (iv) to make payments equal to 0.3% of the annual amount paid as
“Extraordinary Production Royalty” intended to the Fortalecimiento Institucional Fund, in order to purchase
equipment and finance training activities, logistics and operational expenses in certain government agencies of
the province of Mendoza specified in the agreement, among others.
•
Santa Cruz: During November, 2012, YPF entered into an agreement with the province of Santa Cruz to
extend for 25 years the term of certain exploitation concessions, from the expiration of their original terms.
By signing the memorandum of agreement, YPF assumed certain commitments within which include: (i) to
make initial payments to the province of Santa Cruz in an aggregate amount of approximately of US$
200 million, on the date specified in the agreement; (ii) to pay the province of Santa Cruz a Production Royalty
of 12% plus an additional of 3% over the production of conventional hydrocarbons; (iii) to pay the province of
Santa Cruz a Production Royalty of 10% over the production of unconventional hydrocarbons; (iv) make
certain investments on the exploitation concessions, as stipulated in the agreement; (v) carry out exploration
activities in the remaining exploration areas; (vi) to contribute with social infrastructure investments within the
province of Santa Cruz in an amount equivalent to 20% of the amount of the extension royalty; (vii) define and
prioritize a remediation plan of environmental liabilities with reasonable technical criteria and the extent of
remediation tasks within the term of the concessions.
F-91
•
Salta: On October 23, 2012, YPF entered into an agreement with the province of Salta to extend for 10 years
the original term of certain exploitation concessions from the expiration of their original terms. YPF and
associated signatory companies (Tecpetrol S.A., Petrobras Argentina S.A., Compañía General de Combustibles
S.A. and Ledesma SAAI) by signing the Memorandum of Agreement took, among others, the following
commitments: (i) conducting in area Aguaragüe, on the dates indicated in the agreement and during the first
two years, the following investments: a minimum amount in development plans, involving the drilling of
development wells (at least 3) and expansion of production facilities and treatment of hydrocarbons of US$
36 million, (ii) YPF and each of the associated signatory companies will recognize for the province a special
extraordinary contribution equal to 25% of the amount corresponding to royalties of 12% referred to in art. 59
and 62 of Law 17,319, (iii) YPF and each of the associated signatory companies will recognize for the
province an additional payment to the special extraordinary contribution, only when conditions of
extraordinary income are verified in the marketing of oil crude production and natural gas from the
concessions, under price increase obtained by each party, from the sum of US$ 90/bbl in the case of crude oil
production and the sum equivalent to 70% of import gas prices, (iv) YPF and each of the associated signatory
companies will pay to the province, and in the proportion that corresponds to each one, a one-time sum of US$
5 million in the concept of bonus extension, (v) YPF and the associated signatory companies undertake to
make investments for a minimum amount of US$ 30 million in additional exploration work to be implemented
in the concessions.
•
•
Chubut – Concessions El Tordillo – La Tapera and Puesto Quiroga: On October 2, 2013, the Province of
Chubut published the law for the approval of the Agreement to Extend the Exploitation Concessions El
Tordillo, La Tapera and Puesto Quiroga, located in the Province of Chubut. YPF holds 12.196% of the
concessions, while Petrobras Argentina S.A. holds 35.67% and Tecpetrol S.A. holds the remaining 52.133%.
The Concessions were extended for a 30 year period counted as from the year 2017. The main terms and
conditions agreed by the Province of Chubut comprise the commitment of the companies belonging to the joint
operation to make the following payments and contributions: (i) paying US$ 18 million as Historical
Remediation Bonus (ii) paying a Compensation Bonus amounting to a fixed 4% over the production of gas and
oil since 2013 (this is calculated as an additional royalty); (iii) covering expenses and investments related to
the protection and conservation of the environment; (iv) maintaining a minimum amount of equipment for
drilling and work-overs in operation; (v) after the first ten years of extension, Petrominera will acquire a 10%
interest in the exploitation Concessions.
Chubut - Restinga Alí, Sarmiento, Campamento Central – Cañadón Perdido, Manantiales Behr and El Trébol
– Escalante: On December 26, 2013, YPF and the Province of Chubut signed an Agreement for the extension
of the original term of the Concessions for the Exploitation of Restinga Alí, Sarmiento, Campamento Central –
Cañadón Perdido, Manantiales Behr and El Trébol. The Extension Agreement was ratified by the Legislature
of the Province of Chubut on January 17, 2014, and by the Company´s Board on February 24, 2014; thus
complying with the conditions precedent established in the Extension Agreement.
The following are the main terms and conditions agreed with the Province of Chubut: YPF holds 100% of the
exploitation concessions, except for the concession Campamento Central – Cañadón Perdido, where ENAP
SIPETROL S.A. holds 50%. A 30-year extension was established for the terms of the exploitation concessions
that expire in the years 2017 (Campamento Central – Cañadón Perdido and El Trébol – Escalante), 2015
(Restinga Alí) and 2016 (Manantiales Behr).
YPF undertook, among others, the following obligations: (i) to pay a Historical Compensation Bonus of US$
30 million; (ii) to pay to the Province of Chubut the Hydrocarbons Compensation Bonus amounting to 3% of
the oil and gas production (calculated as an additional royalty); (iii) to meet a minimum level of investment;
(iv) to maintain a minimum amount of equipment for drilling and work-over under hire and in operation; and
(v) to assign to Petrominera S.E. 41% of YPF´s interest in the exploitation concessions of El Tordillo, La
Tapera and Puesto Quiroga (amounting to 5% of the total concessions) and in the related Joint operations.
F-92
•
•
Tierra del Fuego: the Company has negotiated with the Executive Office of the province of Tierra del Fuego
the terms in order to extend their concessions in such province, having signed, on December 18, 2013, the
Agreement of Extension of concessions of Tierra del Fuego (until November 14, 2027), Los Chorrillos (until
April 18, 2026) and Lago Fuego (until November 6, 2027). On October 10, 2014, Act No. 998 and Act
No. 997 approving the extension agreements were enacted.
Rio Negro: In December 2014, YPF, YSUR Energía Argentina S.R.L., YSUR Petrolera Argentina S.A. entered
into a Renegotiation Agreement with the Province of Rio Negro to extending for 10 years the original term of
the following exploitation concessions as from maturity of their original granting terms: (i) “El Medanito”,
“Barranca de los Loros”, “Señal Picada-Punta Barda”, “Bajo del Piche” where YPF holds 100%, up to
November 14, 2027; (ii) “Los Caldenes” where YPF holds 100%, up to September 19, 2036; (iii) “Estación
Fernandez Oro”, where YSUR Energía Argentina SRL holds 100%, up to August 16, 2026; and (iv) “El
Santiagueño” where YSUR Petrolera Argentina S.A. holds 100%, up to September 6, 2025.
The Renegotiation Agreement was confirmed by the legislature of the Province of Rio Negro by the issuance
of Provincial Law No. 5027 dated December 30, 2014. The companies signing the Renegotiation Agreement
assumed the following commitments, among others: (i) payment of US$ 46 million as Fixed Bonus,
(ii) contributions to social development and institutional strengthening amounting US$ 9,2 million,
(iii) supplementary contributions equivalent to 3% of the monthly oil production, and 3% of the monthly gas
production, (iv) annual contributions for training, research and development, (v) compliance with a minimal
development and investment plan, (vi) investment for the execution of environmental remediation plans.
–
Agreements of project investments
•
Agreements for the development of Loma La Lata Norte and Loma Campana areas:
On July 16, 2013, the Company and subsidiaries of Chevron Corporation (“Chevron”) signed an Investment
Project Agreement (“the Agreement”) with the objective of the joint exploitation of unconventional
hydrocarbons in the province of Neuquén. The Agreement contemplates an expenditure, subject to certain
conditions, of US$ 1,240 million by Chevron for the first phase of work to develop about 20 km2 (the “pilot
project”) (4,942 acres) of the 395 km2 (97,607 acres) corresponding to the area dedicated to the project, located
in the aforementioned province and includes Loma La Lata Norte and Loma Campana areas. This first pilot
project includes the drilling of more than 100 wells.
During September 2013, and upon the fulfillment of certain precedent conditions (among which is the granting
of an extension of the Loma Campana concession maturity until 2048 and the unitization of that area with the
sub-area Loma La Lata Norte), Chevron made the initial payment of US$ 300 million.
On December 10, 2013, the Company and some of its subsidiaries and subsidiaries of Chevron Corporation
successfully completed the pending documents for the closing of the Investment Project Agreement, which
enables the disbursement by Chevron of US$ 940 million, in addition to the US$ 300 million that such
company has already disbursed.
For such purposes, the Company and Chevron made the necessary contracts for the assignment in favor of
Compañía de Hidrocarburo No Convencional S.R.L. (“CHNC”) of 50% of the exploitation concession Loma
Campana (“LC”), and supplementary agreements including the contract for the organization of the Joint
Operation (“JO”) and the Joint Operating Agreement (“JOA”) for the operation of LC, where YPF shall
participate as area operator.
The Company indirectly holds 100% of the capital stock of CHNC, but under the existing contractual
arrangements, it does not make financial or operative decisions relevant to CHNC and does not fund its
activities either. Therefore, the Company is not exposed to any risk or rewards due to its interest in CHNC.
Thus, as required by IFRS, the Company has valued its interest in CHNC at cost, which is not significant, and
has not recorded any profit or loss for such interest for the year ended December 31, 2015.
F-93
During the years 2015, 2014 and 2013, YPF and CHNC have made transactions, among which it is possible to
highlight the purchases of gas and crude oil by YPF for 3,556, 2,311 and 50, respectively. These transactions
will be completed under the general and regulatory market conditions. The net balance as of December 31,
2015 and 2014, is a liability in favor of CHNC of 533 and 837, respectively, while the net balance as of
December 31, 2013, was a receivable in favor of YPF of 1,616.
Considering the rights that Chevron could exercise in the future over CHNC -to access to the 50% of the
concession and supplementary rights- and as a guarantee for such rights and other obligations under the
Investment Project Agreement, a pledge over the shares of a YPF’s affiliate, which is an indirect holder of
YPF’s interest in CHNC, has been made in favor of Chevron.
In this context, and considering that YPF is the LC area operator, the parties have made a Project Obligations,
Indemnities and Guarantee Agreement, by virtue of which the Company makes certain representations and
guarantees in relation to the Investment Project Agreement. This guarantee on the operation and management
of the Project does not include the project’s performance or return on investment, both at the exclusive risk of
Chevron.
Finally, other supplementary agreements and documents related to the Investment Project Agreement have
been signed, including: (a) the agreement for the allocation of certain benefits deriving from Executive Order
No. 929/2013 from YPF to CHNC; (b) terms and conditions for YPF’s acquisition of natural gas and crude oil
pertaining to CHNC for 50% of the interest in the LC area; and (c) certain agreements for the technical
assistance of Chevron to YPF.
During April 2014, YPF and certain of its subsidiaries and subsidiaries of Chevron, have successfully
completed the second phase of the Project Investment Agreement and Chevron has confirmed its decision to
continue with the investment project in unconventional hydrocarbons in the Loma Campana area, thereby
commencing the third phase of such project. The duration of this third phase will encompass the life of the
project, until the expiration of the Loma Campana concession. At the present time, there are 6 drilling
equipments operating in the above mentioned area and more than 18.97 thousand daily barrels of oil equivalent
to the percentage of participation extracted.
•
Agreements for the development of the Chihuído de la Sierra Negra Sudeste – Narambuena area:
During April 2014, YPF and Chevron have signed a new Project Investment Agreement with the objective of
the joint exploration of unconventional hydrocarbons in the Province of Neuquén, within the area Chihuido de
la Sierra Negra Sudeste – Narambuena. The investment will be undertaken exclusively by, and at the sole risk
of, Chevron. The investment will be disbursed in two stages.
To this end, the Company and Chevron entered into the necessary agreements to implement the assignment to
Compañía de Desarrollo No Convencional S.R.L (“CDNC”) of a) a 50% interest in the Narambuena
Exploration Project Area and b) a 7% legal interest in the Exploitation Concession of Chihuído de la Sierra
Negra in Neuquén and Mendoza. However, contractual rights of Chevron are limited to Narambuena Area, as
YPF will hold 100% ownership of the conventional production and reserves outside the Project Area and
Desfiladero Bayo field. On May 29, 2015, the first phase of the Agreement was closed with the perfection of
the relevant assignments. At present, 2 wells have been drilled and completed and 1 is being drilled.
Depending on the results of the exploration activities, both companies foresee to continue with the execution of
a pilot project and the subsequent comprehensive development of the above mentioned area, sharing
investments at 50% each.
The Company indirectly holds a 100% interest in the capital stock of CDNC; however as pursuant to effective
contractual agreements, the Company neither exercises CDNC’s relevant financial and operating decision-
making rights nor funds its activities, the Company is not exposed to risks and benefits for its interest in
CDNC. Therefore, according to IFRS, the Company has valued its interest in CDNC at cost, which is not
significant, and has not recorded any income (loss) for the said interest during the period ended December 31,
2015.
F-94
•
Agreements for the development of El Orejano area:
On September 23, 2013, the Company, Dow Europe Holding B.V. and PBB Polisur S.A., (hereinafter,
collectively, “Dow”) signed an agreement (the “Agreement”), which contemplates an expenditure by both
parties of up to US$ 188 million which will be directed towards the joint exploitation of an unconventional gas
pilot project in the Province of Neuquén, in the area of “El Orejano” of which Dow provided US$ 120 million
by means of a financing agreement convertible into a participation in the project, which contemplates a first
phase of work during which 16 wells will be drilled.
On October 22, 2015, both parties agreed to an Addenda which provides, among other things, for: (i) an
increase in the amount to be disbursed by Dow, by US$ 60 million, totaling US$ 180 million, through a
convertible financing in an interest in the project, for the same purposes and effects than those of the previous
disbursements, and (ii) an extension of the time period during which Dow may exercise the conversion option,
up to December 18, 2015. On October 30, 2015, the Company received the additional amounts committed.
On December 15, 2015, PBB Polisur S.A. exercised the option provided for in the Agreement, whereby YPF
has assigned 50% of its interest in the exploitation concession of “El Orejano” area, which amounts to a total
area of 45km2, in the Province of Neuquén.
As of December 31, 2015, 27 wells are drilled, out of which 18 have been completed.
In addition, the parties have formed a joint operation for the exploration, evaluation, exploitation and
development of hydrocarbons in “El Orejano” area, which will become effective on January 1, 2016 and in
which Dow and YPF have a 50% interest each.
•
Agreements for the development of Rincón del Mangrullo area:
On November 6, 2013, the Company and Petrolera Pampa S.A. (hereinafter “Petrolera Pampa”) signed an
investment agreement under which Petrolera Pampa undertakes to invest US$ 151.5 million in exchange for
50% of the interest in the production of hydrocarbons in the area of Rincón del Mangrullo in the Province of
Neuquén, pertaining to the formation “Formación Mulichinco” (hereinafter the “Area”), where YPF shall be
area operator.
During this first stage, Petrolera Pampa has undertaken to invest US$ 81.5 million for the drilling of 17 wells
and the acquisition and analysis of about 40 km2 of 3D seismic data.
The second phase investment contemplates an investment of US$ 70 million to drill 15 wells.
As of December 31, 2015, the two stages were completed.
On May 26, 2015 a supplementary agreement (the “Amendment”) to the investment agreement dated
November 6, 2013 was signed.
The Amendment establishes an interest of 50% of each of the parties in the entire production, costs and
investments for the development of the Area with retroactive effect from January 1, 2015, excluding from the
agreement only the formations of Vaca Muerta and Quintuco. It should be noted that on July 14, 2015, the
necessary requirements for the effectiveness of the said Amendment were met.
Such investments include surface facilities in the area of US$ 150 million, which include the first expansion
stage of the treatment facilities, bringing the current capacity of 2 to 4 million cubic meters per day to allow
the conditioning and evacuation of future production from the block.
The Amendment also includes the expansion of the investment commitment of Petrolera Pampa in a third
investment phase of US$ 22.5 million, for the drilling of additional wells targeting the Mulichinco Formation.
In addition, the Amendment includes an exploratory program for the Lajas Formation, under which Petrolera
Pampa is committed to an investment of up to US$ 34 million and YPF up to US$ 6 million for the period
2015-2016. Subject to the results obtained in this period, Petrolera Pampa may choose to continue with a
second investment phase in 2017 also for the Lajas Formation, with an additional investment commitment of
US$ 34 million.
F-95
•
Agreements for the development of La Amarga Chica area:
On August 28, 2014, the Company has signed an Agreement with Petronas (E&P) Overseas Ventures Sdn.
Bhd, (hereinafter, “Petronas”) whereby YPF and Petronas agreed on the main terms and conditions to jointly
develop a shale oil pilot project in three annual phases involving a jointly investment of up to US$ 550 million
plus VAT in the La Amarga Chica area, province of Neuquén. Petronas will invest US$ 475 million and YPF
will invest US$ 75 million.
YPF will be the operator of the area and will assign a 50% interest in the concession to Petronas E&P
Argentina S.A. (hereinafter “PEPASA”).
Dated December 10, 2014 the Company and PEPASA, a Petronas affiliate, entered into an Investment Project
Agreement for the joint exploitation of unconventional hydrocarbons in La Amarga Chica area in the Province
of Neuquén. It should be noted that on May 10, 2015, the conditions required for the entry into force of that
Pilot Plan in 2015 were complied with. The Agreement also provides that both companies will assess the
expansion of the strategic association to other exploration areas with potential for unconventional resources.
Likewise, the Parties signed the following supplementary agreements to the Investment Agreement:
(a) Assignment Agreement for the assignment of 50% of the concession on the La Amarga Chica area;
(b) Joint Operation formation contract; (c) Joint Operating Agreement; (d) Assignment Guarantee Agreement;
(e) First Option Agreement for trading crude oil; and (f) Assignment of Rights on Hydrocarbon Export
Agreement.
Additionally, Petronas has granted a payment guarantee for certain financial obligations assumed by PEPASA
under the Investment Agreement.
Once contributions of each annual phase are made, PEPASA would be entitled to opt-out of the joint
development agreement upon surrender of its participation in the concession and the settlement of liabilities as
of the date of opt-out (without access to the 50% of the net production value of drilled wells until exercise of
the opt-out options).
Upon full compliance with the parties’ commitments, each party will contribute 50% to the work schedule and
cost budget based on the investment agreement.
The Investment Agreement provides that during the three phases of the Pilot Plan a 3D seismic acquisition and
processing program will be completed, covering the whole concession area, 35 wells will be drilled with the
Vaca Muerta formation as objective (including vertical and horizontal wells), and a series of surface
installations will be built with the purpose of evacuating the area production.
As of December 31, 2015, 4 wells of the Pilot Plan have been drilled: 1 vertical and 3 horizontal. Microseismic
studies will be carried out for these 4 wells during the first months of 2016. Therefore, there are no new wells
under production at 2015 year end.
•
Subdivision of Bandurria Block - Neuquén:
On July 16, 2015, the Province of Neuquén, pursuant to executive orders 1536/15 and 1541/15, approved the
subdivision of the Bandurria block (465.5 km2) and awarded 100% of the area known as “Bandurria
Norte” (107 km2) to Wintershall Energía S.A., 100% of the area known as “Bandurria Centro” (130 km2) to
Pan American Energy LLC (Sucursal Argentina) and 100% of the area known as “Bandurria Sur” (228.5 km2)
to YPF, awarding to YPF an Unconventional Hydrocarbons Exploitation Concession in Bandurria Sur area, for
a 35-year term, with a commitment to develop a pilot plan to be completed in 3 years with a related investment
of US$ 360 million.
F-96
•
Granting of exploitation concession for Lindero Atravesado block – Neuquén:
On July 10, 2015, the Province of Neuquén agreed to award to both partners, Pan American Energy LLC
(Sucursal Argentina) and YPF, pro rata their interests (62.5% and 37.5%, respectively) in the “Lindero
Atravesado” joint venture, the right to an Unconventional Hydrocarbons Exploitation Concession for a 35-year
term, pursuant to the provisions of sections 27 bis, 35(b) and related sections of Act 17.319, as amended by
Act 27.007. As a condition to the award of the above mentioned concession rights, concession holders have
agreed to carry out an Unconventional Tight Gas Pilot program within 4 years, beginning on January 1, 2015,
with an investment of US$ 590 million. On July 16, 2015, an agreement in this respect was approved by
Executive Order 1540/15 of the Neuquén Province.
•
Extension of the Joint Operation Agreement for the Magallanes Area:
On November 17, 2014, ENAP SIPETROL ARGENTINA S.A. (“ENAP”) made to YPF, and YPF accepted,
an offer whereby ENAP’s rights and obligations under the Magallanes area Joint Operation Agreement were
extended until the concession termination, with ENAP keeping 50% interest and continuing as Operator. The
area concession includes three jurisdictions: Santa Cruz, Estado Nacional and Tierra del Fuego (as of the date
of these financial statements, the concessions of the two first-named have been extended). In consideration for
such extension, ENAP agreed to pay to YPF, or invest in the Joint Venture on behalf and on account of YPF,
US$ 100 million, subject to certain conditions. The Agreement further provides for the obligation to agree on a
so-called “Incremental Project” by September 15, 2015. The Incremental Project was approved by an operating
committee on September 10, 2015, and its approval was ratified by YPF on October 20, 2015. Notwithstanding
the foregoing, ENAP is entitled to withdraw at any time from the Incremental Project, without right to
compensation or reimbursement therefor, including the Consideration and any royalties as may have been paid
until termination.
–
Contractual commitments: The Group has signed contracts by means of which it has committed to buy certain
products and services, and to sell natural gas, liquefied petroleum gas and other products. Some of the mentioned
contracts include penalty clauses that stipulate compensations for a breach of the obligation to receive, deliver or
transport the product object of the contract. The anticipated estimated losses for contracts in progress, if any,
considering the compensations mentioned above, have been charged to the income of the year in which they were
identified.
In this order, the Group has renegotiated certain natural gas export contracts, and has agreed, between others, to
limit compensations only in case of interruptions and/or suspension of deliveries from any cause, except physical
force majeure. Also, the Group has agreed to make investments and export gas to temporarily import certain final
products. As of the date of issuance of these financial statements, the Group is fulfilling the agreed commitments
mentioned above. To the extent that the Group does not comply with such agreements, we could be subject to
significant claims, subject to the defences that the Group might have.
The Group under certain trade agreements has undertaken the obligation with third parties to buy goods and services
(such as liquefied petroleum gas, electricity, gas, oil and steam) that as of December 31, 2015 amounted to about
37,116. In addition, it has exploratory, investment and expense commitments until the termination of some of its
concessions for 287,238 as of December 31, 2015, including commitments for the extension of concessions
mentioned in previous paragraphs.
F-97
d) Main regulations and other:
–
New Hydrocarbon Law:
Dated October 31, 2014 the Argentine Republic Official Gazette published the text of Law No. 27,007, amending
the Hydrocarbon Law No. 17,319. The most relevant aspects of the new law are as follows:
•
As regards exploration permits, it distinguishes between those with conventional and unconventional
objectives, and between explorations in the continental shelf and in territorial waters, establishing the
respective terms for each type.
•
As regards concessions, three types of concessions are provided, namely, conventional exploitation,
unconventional exploitation, and exploitation in the continental shelf and territorial waters, establishing the
respective terms for each type.
•
•
The terms for hydrocarbon transportation concessions were adjusted in order to comply with the exploitation
concessions terms.
As regards royalties, a maximum of 12% is established, which may reach 18% in the case of granted
extensions, where the law also establishes the payment of an extension bond for a maximum amount equal to
the amount resulting from multiplying the remaining proven reserves at the end of effective term of the
concession by 2% of the average basin price applicable to the respective hydrocarbons over the 2 years
preceding the time on which the extension was granted.
•
The extension of the Investment Promotion Regime for the Exploitation of Hydrocarbons (Decree
No. 929/2013) is established for projects representing a direct investment in foreign currency of at least
250 million dollars, increasing the benefits for other type of projects.
•
Reversion and transfer of hydrocarbon exploitation permits and concessions in national offshore areas is
established when no association contracts subscribed with ENARSA to the National Secretariat of Energy
exist.
–
Natural gas regulatory requirements:
In addition to the regulations that affect the natural gas market mentioned in “Natural gas market” (Note 10), on
June 14, 2007, Resolution No. 599/2007 of the Secretariat of Energy was published in the Official Gazette (the
“Resolution”). This Resolution approved an agreement with natural gas producers regarding the natural gas supply
to the domestic market during the period 2007 through 2011 (the “Agreement 2007-2011”). The purpose of this
Agreement 2007-2011 is to guarantee the normal supply of the natural gas domestic market during the period 2007
through 2011, considering the domestic market demand registered during 2006 plus the growth of residential and
small commercial customer’s consumption (the “Priority Demand”). According to the Resolution, the producers that
have signed the Agreement 2007-2011 commit to supply a part of the Priority Demand according to certain
percentage determined for each producer based upon its share of production for the 36 months period prior to April
2004. In case of shortage to supply Priority Demand, natural gas exports of producers that did not sign the
Agreement 2007-2011 will be the first to be called upon in order to satisfy such mentioned shortage. The Agreement
2007-2011 also establishes terms of effectiveness and pricing provisions for the Priority Demand consumption.
Considering that the Resolution anticipates the continuity of the regulatory mechanisms that affect the exports, YPF
has appealed the Resolution and has expressly stated that the execution of the Agreement 2007-2011 does not mean
any recognition by YPF of the validity of that Resolution. On June 22, 2007, the National Direction of
Hydrocarbons notified that the Agreement 2007-2011 reached the sufficient level of subscription. On January 5,
2012, the Official Gazette published Resolution of the Secretariat of Energy No. 172 which temporarily extends the
rules and criteria established by Resolution No. 599/07, until new legislation replaces the Resolution previously
mentioned. This Resolution was appealed on February 17, 2012 by filing a motion for reconsideration with the
Secretariat of Energy.
F-98
Additionally, on October 4, 2010, the Official Gazette published ENARGAS Resolution No. 1410/2010 that
approves the procedure which sets new rules for natural gas dispatch applicable to all participants in the natural gas
industry, imposing new and more severe regulations to the producers’ availability of natural gas (“Procedimiento
para Solicitudes, Confirmaciones y Control de Gas”). By virtue of these procedures, distributors remain able to
request all the natural gas necessary to cover the Priority Demand even in the case of natural gas volumes that
exceed those that the Secretariat of Energy would have allocated by virtue of the Agreement ratified by the
Resolution No. 599/07. Producers are obligated to confirm all the natural gas requested by distributors to supply the
Priority Demand. The producers’ shares in such volumes follow the allocation criterion established by the
Agreement 2007-2011. It is not possible to predict the estimated demand of the Argentine market that must be
satisfied by the producers, whether or not the producer signed the Agreement 2007-2011. Once the Priority Demand
has been supplied, the volumes requested by the rest of the segments must be confirmed, leaving the exports last in
order of priority. In case the programming do not yield sustainable results, with respect to the objective of
maintaining the equilibrium and preserving the operation of the transportation and distribution systems, the
necessary reprogramming and redirections will take place. In case the producer’s confirmations are of a lower
volume than requested, the transporters will be in charge of making confirmations adequate by redirecting natural
gas until the volume required by distributors according to Priority Demand is completed. This greater volume will
have to be withdrawn from the confirmations made by that producer to other clients. If the producer would not have
confirmed natural gas to other clients from the same basin, the lacking volume will be requested to the rest of the
natural gas producers. Therefore, this procedure imposes a supply obligation that is jointly liable for all producers in
case any producer supplies natural gas in a deficient way. YPF has challenged the validity of Resolution
No. 1,410/2010.
On November 27, 2008 through Executive Decree No. 2067/08, a trust fund was created to finance imports of
natural gas for its injection in the national gas pipeline system when necessary to satisfy the domestic demand. The
trust fund is financed through the following mechanisms: (i) diverse tariff charges paid by users of transportation
services and regularly distributed, gas consumers receiving gas directly from producers, and companies processing
natural gas; (ii) special credit programs that may be agreed upon with national or international organizations; and
(iii) specific contributions assessed by the Secretariat of Energy on the participants in the natural gas industry. This
Decree has been object of diverse judiciary claims, and judges from all over the country have issued precautionary
measures for suspension of its effects, grounded on the violation of the principle of legality on tax matters. On
November 8, 2009, ENARGAS published Resolution No. 1982/11 that adjusted the tariff charges established by
Executive Decree No. 2067/08 to be paid by users as from December 1, 2011.
On November 24, 2011, ENARGAS passed Resolution No. 1991/11, enlarging the number of users obliged to pay
tariff charges, including residential services, natural gas processing, industrial premises and electric power plants,
among others; this has affected the operations of the Company, and has had a significant impact on our joint
subsidiary companies, all of which have filed appeals against the mentioned resolution. For its part, YPF has
challenged these Resolutions and rejected the charge invoice made by Nación Fideicomiso. On April 13, 2012, YPF
obtained a precautionary measure related to El Portón processing plant, suspending the effects of these resolutions
in relation to that plant until a decision on the administrative appeals filed by YPF had been reached.
In November 2012, Law 26,784 was passed which granted legal hierarchy, since such date, to the decisions enacted
by the Executive Power and ENARGAS, in relation to the charge. Dated December 11, 2014 the National Supreme
Court of Justice pronounced the “Alliance” judgment, deciding that the charge created by decree 2067/2008 is a
tariff charge and not a tax, and thus is not subjected to the principle of tax legality. However, the Court left open the
possibility of eventual claims or defenses in cases different from the claims raised in the “Alliance” judgment.
In particular, the application of the above mentioned tariff charge produces an impact so significant in Mega
operations that, if not favorably resolved, Mega could have in the future serious difficulties to continue business. On
October 27, 2015, the Supreme Court of Justice issued a resolution on the motion for protection of constitutional
rights filed by Mega S.A. (period until the enactment of the 2013 Budget Enactment Law No. 26.784) providing that
the charge under “Executive Order 2067/08” was unconstitutional and was not applicable to Mega S.A.
F-99
On April 7, 2014 the Secretariat of Energy published Resolution No. 226/2014, fixing new wellhead prices per basin
for the sale of gas to the Residential and Commercial full service segment and Natural Gas Stations that in a period
of two months/one month: (i) shows a higher than 20% saving compared to the same period of two months/one
month from previous year; and (ii) shows a saving between 5% and 20% compared to the same period of two
months/one month from previous year. Likewise, new prices per basin are fixed for full service users in the Camuzzi
Gas del Sur geographic area, in view of the climate conditions prevailing in the Southern geographic area of our
country.
–
Natural Gas Additional Injection Stimulus Programs:
On December 2012, YPF and other gas producing companies of Argentina agreed with the Planning and Strategic
Coordination Commission of the National Plan of Hydrocarbon Investments (the “Commission”) to establish an
incentive scheme for the Additional Injection (all gas injected by the companies above certain threshold) of natural
gas. On February 14, 2013 Resolution No. 1/2013 of the Commission was published in the Official Gazette. This
Resolution formally creates the “Natural Gas Additional Injection Stimulus Program”.
Under this regulation, gas producing companies were invited to file Projects for increasing Total Natural Gas
Injection (“the projects”) to the Commission, in order to receive an Increased Price of 7.5 US$/MBTU for all gas
injected above certain threshold (Additional Injection). The Projects shall comply with minimum requirements
established in Resolution No. 1/2013, and will be subject to approval consideration by the Commission. The
Projects have a maximum term of five (5) years, renewable at the request of the beneficiary, and subject to the
decision of the Commission. If the beneficiary company, for certain month, does not reach the compromised
production increase of its project, approved by the Commission, it will have to compensate its failure to achieve the
minimum total injection committed in such Project. Resolution No. 60/2013, regulated by Resolution No. 83/2013,
established a similar program for the companies that failed to comply with the requirements of Resolution
No. 1/2013 and those that had failed to register in time under such Resolution. The price to be paid under the
program established in Resolution No. 60/2013 varies between 4 US$/MBtu and 7.5 US$/MBtu, according to the
highest production curve reached by the beneficiary company under the program. Resolution No. 123/2015 was
published in the Official Gazette on July 15, 2015 which approved the Regulations governing procurement, sales
and transfers of areas, assignments of rights and interest under the approved programs.
On September 29, 2015, Resolution 185/2015 was published in the Official Gazette regulating an incentive program
for natural gas injection for the benefit of corporate producers which do not have a previous record of natural gas
injection. The beneficiary companies will receive a compensation resulting from the difference between 7.50
US$/MMBtu and the price received for the sale of the natural gas in the market. Such compensation shall be
received only for natural gas originating in areas whose production rights shall have been acquired from companies
registered with any of the two previous programs and provided that during the period in which the transferor shall
have calculated its “base injection”, according to its programme, the injection of the area operated by the current
beneficiary – transferee– shall have been null.
–
Liquid hydrocarbons regulatory requirements:
Resolution No. 1,679/04 of the Secretariat of Energy reinstalled the registry of diesel and crude oil export
transactions created by Executive Decree No. 645/02, and mandated that producers, sellers, refining companies and
any other market agent that wishes to export diesel or crude oil to register such transaction and to demonstrate that
domestic demand has been satisfied and that they have offered the product to be exported to the domestic market. In
addition, Resolution No. 1,338/06 of the Secretariat of Energy added other petroleum products to the registration
regime created by Executive Decree No. 645/02, including gasoline, fuel oil and its derivatives, diesel, aviation fuel,
asphalts, certain petrochemicals, certain lubricants, coke and petrochemical derivatives. Resolution No. 715/07 of
the Secretariat of Energy empowered the National Refining and Marketing Director to determine the amounts of
diesel to be imported by each company, in specific periods of the year, to compensate exports of products included
under the regime of Resolution No. 1,679/04; the fulfilment of this obligation to import diesel is necessary to obtain
authorization to export the products included under Decree No. 645/02. In addition, certain regulations establish that
exports are subordinated to the supply of the domestic market. In this way, Resolution No. 25/2006 of the
Secretariat of Domestic Commerce, issued on October 11, 2006, imposes on each Argentine refining and/or retail
company the obligation to supply all reasonable diesel fuel demand, by supplying certain minimum volumes (which
at least should be volumes supplied the year before plus the positive correlation between diesel demand and GDP
accumulated from the month reference). The mentioned commercialization should be done without altering or
affecting the normal operation of the diesel market.
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Additionally, Rule No.168/04 requires companies intending to export LPG to first obtain an authorization from the
Secretariat of Energy, by demonstrating that local demand was satisfied or that an offer to sell LPG to local demand
has been made and rejected.
In January 2008, the Secretariat of Domestic Commerce issued Resolution No.14/2008, whereby the refining
companies were instructed to optimize their production in order to obtain maximum volumes according to their
capacity.
On January 26, 2012, the Secretariat of Domestic Commerce issued Resolution No. 6/2012 whereby (i) YPF and
other four oil companies were required to sell diesel oil to public bus transportation companies at a price not higher
than the retail price charged on its service station located, in general terms, nearest to the place of delivery of diesel
fuel to each such transportation company, while maintaining both historic volumes and delivery conditions; and
(ii) it created a price monitoring scheme of both the retail and the bulk markets to be implemented by the CNDC.
YPF has appealed that resolution. On February 16, 2012, YPF filed with the CNDC an appeal against Resolution
No. 6/2012, for submission to the Civil and Commercial Federal Court of Appeals of Buenos Aires city. Meanwhile,
on March 2, 2012, YPF has challenged this Resolution and requested a preliminary injunction against its validity.
YPF’s preliminary injunction has been granted and the effects of the Resolution No. 6/2012 have been temporarily
suspended, until the appeal is judicially solved. Against that preliminary injection, the Argentinian Federal
Government presented an extraordinary federal appeal, which has not yet been served to YPF.
On March 13, 2012, YPF was notified of Resolution No. 17/2012, issued by the Argentine Secretariat of Domestic
Commerce, pursuant to which YPF, Shell Compañía Argentina de Petróleo, S.A. and ESSO Petrolera Argentina
S.R.L were ordered to supply jet fuel for domestic and international air transport at a price net of taxes not to exceed
2.7% of the price net of taxes of medium octane gasoline (not premium) offered at its closest service station to the
relevant airport, while maintaining its existing supply logistics and its usual supply quantities. The abovementioned
resolution benefits companies owning aircraft that operate in the field of commercial passenger or commercial
passenger and cargo aviation which are registered under the Argentine National Aircraft Registry. According to a
later clarification from the Secretary of Domestic Commerce, the beneficiaries of the measure adopted by this
resolution are the following companies: Aerolíneas Argentinas, Andes Líneas Aéreas S.A., Austral – Cielos del Sur,
LAN Argentina S.A. and Sol S.A. Líneas Aéreas. In addition, in said resolution, the Argentine Secretariat of
Domestic Commerce indicated that it considered convenient to implement a price surveillance system to be
implemented by the CNDC. YPF has challenged such resolution, which will be reviewed by a court. The Civil and
Commercial Federal Court granted the appeal filed by YPF with suspensive effect, consequently the effects of
Resolution No. 17/2012 were suspended until the legality or illegality of the Resolution is solved. Subsequently, the
Argentinian Federal Government filed a federal extraordinary appeal, and YPF answered it. To date, the court
granted the extraordinary appeal but has not yet been submitted to the Supreme Court.
On August 31, 2012, YPF was notified of the judgment of the mentioned Court, which declared the nullity of
Resolution No. 17/2012, based on the lack of jurisdiction of the Argentine Secretariat of Domestic Commerce to
issue a measure of that nature.
Decree No. 1,189/2012 of the National Executive Power, dated July 17, 2012, established that the jurisdictions and
entities of the National public Sector included in section 8, subsection a) of Law No. 24,156 (National
Administration, formed by the central administration and the decentralized agencies including the social insurance
institutions) must contract with YPF the provision of fuels and lubricants for the fleet of official cars, boats and
aircrafts, except in those cases which have the prior authorization of the Chief of the Cabinet of Ministers.
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Dated February 3, 2015, the Argentine Republic Official Gazette published the text of Resolution No. 14/2015
passed by the Commission for Planning and Coordination of the Strategy for the National Plan of Investment in
Hydrocarbons that created the Crude Oil Production Promotion Program for 2015 under which beneficiary
companies are awarded an economic compensation, payable in pesos, for an amount equivalent to up to three U.S.
dollars per barrel for the total production of each beneficiary company, provided that its quarterly production of
crude oil is higher or equal to the production taken as basis for such program. Basis production is defined as the total
production of crude oil by beneficiary companies corresponding to the fourth quarter of 2014, expressed in barrels
per day. The beneficiary companies that have met the demands of all refineries authorized to operate in the country
and direct part of their production to the foreign market may receive an additional economic compensation of two or
three U.S. dollars for each barrel of exported crude oil, depending on the level of exported volume achieved.
–
Refining and Petroleum Plus Programs:
Decree No. 2,014/2008 of the Department of Federal Planning, Public Investment and Services of November 25,
2008, created the “Refining Plus” and the “Petroleum Plus” programs to encourage (a) the production of diesel fuel
and gasoline and (b) the production of crude oil and the increase of reserves through new investments in exploration
and production. The programs entitle refining companies that undertake the construction of a new refinery or the
expansion of their refining and/or conversion capacity and production companies that increase their production and
reserves within the scope of the program to receive export duty credits to be applied to exports withholdings. In
order to be eligible for the benefits of both programs, companies’ plans must be approved by the Argentine
Secretariat of Energy.
During February 2012, by Note No. 707/2012, supplemented by Note No. 800/2012, both issued by the Secretariat
of Energy, YPF was notified that the benefits granted under the “Refining and Petroleum Plus” programs had been
temporarily suspended. The effects of the suspension also apply to benefits accrued and not yet redeemed by YPF at
the time of the issuance of the Notes. The reasons alleged for such suspension are that the programs had been
created in a context where domestic prices were lower than prevailing prices and that the objectives of those
programs had already been achieved. On March 16, 2012, YPF has challenged this temporary suspension.
Pursuant to Executive Order No. 1330/15 of July 6, 2015, the Government resolved to render ineffective the
“Petróleo Plus” program, which had been created by Executive Order No. 2,014 of November 25, 2008.
–
Regulatory requirements established by Decree No. 1,277/2012:
On July 25, 2012, the executive decree of Law No. 26,741, Decree No. 1,277/2012, was published, creating the
“Regulation of the Hydrocarbons Sovereignty Regime in the Argentine Republic”. Among other matters, the
mentioned decree establishes: the creation of the National Plan of Investment in Hydrocarbons; the creation of the
Commission for Planning and Coordination of the Strategy for the National Plan of Investment in Hydrocarbons
(the “Commission”), which will elaborate on an annual basis, within the framework of the National Hydrocarbon
Policy, the National Plan of Investment in Hydrocarbons; the National Registry of Investments in Hydrocarbons in
which the companies undertaking activities of exploration, exploitation, refining, transport and commercialization of
hydrocarbons and fuels will have to register; and the obligation for the registered companies to provide their Plan of
Investments every year before September 30, including a detail of quantitative information in relation to the
activities of exploration, exploitation, refining, transport and commercialization of hydrocarbons and fuels
according to each company.
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Additionally, the mentioned companies will have to provide their plans in relation to the maintenance and increase
of hydrocarbons reserves, including: a) an investment in exploration plan; b) an investment plan in primary
hydrocarbons reserves recovery techniques; and c) an investment plan in secondary hydrocarbons reserves recovery
techniques, which will be analyzed by the Commission; the Commission will adopt the promotion and coordination
measures that may consider necessary for the development of new refineries in the National Territory, that may
allow the growth in the local processing capacity in accordance with the aims and requirements of the National Plan
of Investment in Hydrocarbons; in relation to prices, and accordingly to the Decree, for the purpose of granting
reasonable commercial prices, the Commission will determine the criteria that shall govern the operations in the
domestic market. In addition, the Commission will publish reference prices of each of the components of the costs
and the reference prices for the sale of hydrocarbons and fuels, which will allow to cover the production costs
attributable to the activity and to reach a reasonable margin of profit.
Not complying with the dispositions included in the Decree and supplementary rules may result in the following
penalties: fine, admonition, suspension or deregistration from the registry included in section 50 of Law No. 17,319;
the nullity or expiration of the concessions or permits. Moreover, the mentioned Decree abrogates the dispositions
of the Decrees No. 1,055/89, 1,212/89 and 1,589/89 (the “Deregulation Decrees”) which set, among other matters,
the right to the free disposition of hydrocarbon production. On December 29, 2015, the Executive Branch issued
order No. 272/15 resolving the dissolution of the Commission and its Regulations, and also providing that the
powers vested on the Commission were to be exercised by the Ministry of Energy and Mining.
–
Principal rules applicable to Natural Gas distribution:
The Group participates in natural gas distribution through Metrogas, an indirectly controlled company.
The natural gas distribution system is regulated by Law No. 24,076 (the “Gas Act”) that, together with Decree
No. 1.738/92, issued by the Executive Power, others regulatory decrees, the specific bidding rules (“Pliego”), the
Transfer Agreement and the License, establishes the Regulatory Framework for Metrogas’ business. The License,
the Transfer Agreement and the regulations issued pursuant to the Gas Act establish requirements regarding the
quality of service, capital investment, restrictions on transfer and encumbrance on assets, cross-ownership
restrictions among producers, transporters and distributors, and Metrogas stock transfer.
The Gas Act and the License created ENARGAS as regulatory entity to administer and enforce the Gas Act and the
applicable regulations. In this order, the tariffs for the gas distribution service were established by the License and
are regulated by ENARGAS. ENARGAS jurisdiction extends to gas transportation, sale, storage and distribution. Its
mandate under the Gas Law includes consumers’ protection, competition protection in gas offer and demand, and
the promotion of long-term investments in the gas industry.
Gas distribution tariffs have been established in the License and are regulated by ENARGAS.
The Distribution License has authorized Metrogas to provide the gas distribution public service for a 35-year term
(for which Metrogas may request al 10-year period extension at the end thereof subject to approval by ENARGAS)
in its service area.
At the end of the 35 or 45-year period, as the case may be, the Gas Law requires a new competitive bidding to grant
the license, for which, if it has performed its obligations, Metrogas will have the option to equal the best bid made to
the Government by a third party. As a general rule, upon the termination of a License due to completion of its time-
period, Metrogas will be entitled to a consideration equal to the value of the designated assets or to the amount paid
by the winner bidder under a new call for bids, whichever is lower.
On March 26, 2014, within the framework of the process for renegotiating public services contracts provided by
Law No. 25,561 and supplementary regulations, Metrogas signed a Letter of Understanding with the Public Services
Contracts Renegotiation and Analysis Unit (the “UNIREN”) whereby a provisional tariff regime is established for
the collection of higher revenues than those collected under ENARGAS Resolution No. I/2407 issued on
November 27, 2012 which, in turn, had implemented a fixed amount per bill, differentiated by type of customer;
such revenues had to be deposited in a trust created for the performance of the works.
F-103
The new Temporary Agreement, ratified by National Executive Order No. 445/2014 establishes an interim tariff
regime effective as from April 1, 2014, consisting in the readjustment of tariffs and prices and with due regard to the
necessary guidelines for service continuity and common criteria with the other distribution licensees, and to the
tariff regulations, including changes in the gas price at the transportation entry point.
The Temporary Agreement further provides that it will include any transfer resulting from in tax (excluding income
tax) regulations changes, as may be pending resolution, and also includes, among its provisions, a cost monitoring
mechanism based on an exploitation cost and investment structure, as well as price indexes reflecting such costs
which, under given premises, triggers a revision procedure whereby ENARGAS will evaluate the actual extent of
variation in the Licensee’s exploitation costs and investments, and decide if the distribution tariff needs to be
adjusted.
As of December 31, 2015, Metrogas has submitted to ENARGAS three requests to increase its tariffs through the
application of the Cost Monitoring Mechanism set forth in the Temporary Agreement. None of these requests has
resulted in the adjustments of Distribution tariffs to allow for the increased costs afforded by Metrogas. Instead, a
Temporary Financial Assistance has been approved by Energy Secretariat Resolution No. 263/2015.
The Temporary Agreement further provides that between its execution date and December 31, 2015 (expiration date
of the Emergency Act) the National Government, through UNIREN, and the Licenses were required to reach an
agreement related to the modalities, time periods and timing of the execution of the Memorandum of Agreement for
Comprehensive Contractual Renegotiations. On November 3, 2015 an extension of the Emergency Act was
approved until December 31, 2017.
On June 8, 2015 Energy Secretariat Resolution No. 263/2015 was published in the Argentine Official Gazette
stating that the Energy Secretariat had approved a disbursement, as temporary financial assistance payable in ten
subsequent installments, to Metrogas and the rest of natural gas distributors, effective on March 2015, with the
purpose of funding expenses and investments associated with the normal operation of the natural gas distribution
public service through networks and on account of the Comprehensive Tariff Review to be held in due time.
This Resolution provides that its beneficiaries shall use part of the funds received under each monthly installment to
cancel debts due and payable until December 31, 2014 to natural gas producers and, further, that distributors may
not accrue additional debt for natural gas purchases made as of the effective date of the Resolution.
In the case of Metrogas, ENARGAS has provided for an exceptional need of funds for 2015, which is disbursable
on a monthly basis according to a specified schedule between March and December. In addition it has ordered that
Metrogas shall use part of the temporary financial aid to cancel debts to producers payable as of December 31, 2014
in 36 equal and successive monthly installments, plus interest as from January 2015, using the current “Banco
Nación Average Active Interest Rate for Commercial Discount Transactions” (Tasa Activa Promedio del Banco
Nación para Operaciones de Descuentos Comercial) (2.05% monthly), with the installments to be payable from
March 2015.
In addition, ENARGAS stated that distributors shall cancel invoices for gas purchases whose maturity occurs in
2015, providing for cancellation thereof at 30, 60 and 90 days in line with the collection of invoice payments from
their clients.
As of the date of these consolidated financial statements, Metrogas has received seven of the ten installments on
account of temporary economic assistance. In addition, it has executed payment agreements with most producers
under Energy Secretariat Resolution No. 263/2015, subject to the availability of the amounts committed.
The real impact on Metrogas revenue levels and on costs will depend on a variable beyond its control: how users
will reduce gas consumption, which will not only depend on the individual actions taken to achieve such reduction
but also due to climate variables effects between the compared periods.
F-104
Metrogas expects that during next year the financial condition will gradually recover with the implementation of the
Temporary Agreement executed on March 26, 2014 with UNIREN or with a new Complementary Temporary
Agreement. Additionally, a consensus with the National Government is intended to be reached through UNIREN in
reference to the modalities, terms and opportunity of the execution of the Letter of Understanding for the Integral
Contractual Renegotiation, in order to reestablish the economical-financial situation of Metrogas.
Notwithstanding the foregoing, the company may not guarantee that the above mentioned estimates will actually be
implemented or that they will be implemented under the expected terms.
Additionally, if the conditions prevailing as of the date of these financial statements are maintained, the situation
will continue deteriorating; therefore, Metrogas is analysing a series of measures to mitigate the impact of the
financial situation, including, among others: to submit the claims referring to tariff increases (including transfer to
municipal charge tariffs) to the Argentine authorities; to try to keep a strict cash management and expense control;
to request additional capital contributions from shareholders; to modify payment conditions with the main suppliers
and to obtain funding from third parties.
–
Regulatory Framework of the Electric Power Industry in the Argentine Republic:
Legal Framework: Law No. 24,065, passed in 1992 and governed by Executive Order No. 1,398/92, has established
the current basic regulatory framework for the electricity sector (the “Regulatory Framework”). This Regulatory
Framework is supplemented by the regulations of the National Secretariat of Energy (“SE”) for the generation and
marketing of electric power, including the Resolution of the former Secretariat of Electric Energy No. 61/92,
“Procedures for the Scheduling of Operations, Load Dispatch and Price Calculation”, with its supplementary and
amending regulations.
The National Electricity Regulation Agency (“Ente Nacional Regulador de la Electricidad”, “ENRE”) is the agency
that regulates, oversees and controls the electric power industry and, in such capacity, it is responsible for the
enforcement of Law No. 24,065.
The technical dispatch, operation and economic organization of the Argentine Interconnection System (“Sistema
Argentino de Interconexion”, “SADI”) and the Wholesale Electricity Market (“Mercado Eléctrico Mayorista”,
“MEM”) is under the responsibility of CAMMESA. CAMMESA also acts as a collection agency for all MEM
agents.
It is possible to underscore the following main supplementary and amending resolutions of the sector, taking into
consideration the power generation business of YPF Energía Eléctrica S.A.:
•
SE Resolution No. 146/2003: this resolution established the framework within which generators may request
funding for major or extraordinary maintenance works with the goal of maintaining their units available. This
funding may be repaid with the future profits of the generation business, and it may also be repaid in advance.
Against this backdrop, YPF Energía Eléctrica, as the successor of the operations of the Power Plants of
Tucumán and San Miguel de Tucumán, has requested funding for its plan for the maintenance and availability
improvement of the plants in Tucumán, and has offered its Sale Settlements with No Expiration Date to Define
(“Liquidaciones de Venta sin Fecha de Vencimiento a Definir”, “LVFVD”) for the advanced repayment of the
funded amounts.
•
SE Resolution No. 406/2003: this resolution established the mechanism to set collection priorities among
various remunerative items of the power generation plants. This set priorities for the collection of items related
to variable costs and the collection of the power made available to the system, and finally, of amounts related
to generation margins for the sales made in the Spot market as per the curve of contracts with Large Users
registered between May and August 2004. LVFVDs were issued for the last ones and for such cases in which
CAMMESA did not have a certain repayment date.
F-105
•
•
2008-2011 Generators Agreement: On November 25, 2010, the SE and the main electricity generator
companies signed the “Agreement for the Management and Operation of Projects, Increase of Power
Generation Availability and Adjustment of Remuneration for 2008-2011 Generation” (hereinafter, the
“Generators Agreement”). This Generators Agreement was aimed at establishing the framework, conditions
and undertakings that the parties should make to continue with the MEM adjustment process, to enable the
entry of new generation to cover the increase in the demand for energy and power in such market, to determine
a mechanism for the repayment of the consolidated debts of generators incurred between January 1, 2008, and
December 31, 2011, and the acknowledgment of global remuneration for MEM Generator Agents adhering to
the Generators Agreement. The Generators Agreement envisaged an increase in the remuneration for the
“Power Made Available” by the adhering power generators and in the maximum values recognized for variable
maintenance costs and other costs other than fuels. As per this agreement, YPF Energía Eléctrica, as the
successor company in the operation of the plants in “Complejo de Generación El Bracho”, has credits with
CAMMESA.
SE Resolution No. 95/2013: this resolution establishes a new remuneration scheme based on the items
described below and classified in terms of size and type of generation technology used. The defined
remunerative items pertain to: a) remuneration for fixed costs; b) remuneration for variable costs other than
fuel; c) direct additional remuneration; and d) indirect additional remuneration, which shall be allocated to a
trust for the development of electric power infrastructure works. It is necessary to accept the terms and
conditions of the resolution to access such remunerations. YPF Energía Eléctrica has adhered to this system in
August 9, 2013, back-dated to February 1, 2013. Among other matters governed by this resolution, it shall be
stressed that it established that until the SE decides otherwise, generators and large users shall refrain from
making new contracts and/or renewing existing contracts (except for contracts under the framework of SE
Resolution No. 1,281/2006 “Energy Plus” and SE Resolution No. 220/2007, among others) as of the entry into
force of the resolution. Furthermore, it establishes that as from the date of termination of existing contracts,
large users shall begin to make their power purchases through the agency in charge of dispatch (CAMMESA).
Similarly, it establishes that fuel supply contracts shall only be acknowledged as long as they are in force, and
no new contracts may be made and existing contracts may not be renewed as from their termination dates.
•
SE Resolution No. 529/2014: this resolution replaces the remuneration scheme established by SE Resolution
No. 95/2013, increasing the tariff schedule of the 4 remunerative concepts included by that resolution. In
relation to the Fixed Costs establishes an increase related to the availability of each Generator Agent. Also
incorporates a new remuneration scheme of the Non Recurrent Maintenance, which aims to the funding of
mayor maintenance subject to the SE approval. This resolution will be applicable to economic transactions
from February 2014 for generators that had adhered to SE Resolution No. 95/2013.
•
SE Resolution No. 482/2015: this resolution provides adjustments to the compensation scheme set forth in SE
Resolution No. 529/2014, by increasing the tariff schedule of the five concepts provided for therein. In
addition, it introduces a new specific contribution scheme known as “Resources for 2015-2018
FONINVEMEM Investments” (Recursos para Inversiones del FONINVEMEM 2015-2018) to be allocated to
generators participating in the investment projects approved or to be approved by the Energy Secretariat, and a
new incentive scheme for the Production of Energy and Operating Efficiency for the relevant generator agents
therein included. The provisions of this resolution are retroactively applied to financial transactions made as of
February 2015 for those generators who have adhered to SE Resolution No. 95/2013.
•
Executive Order No. 134/2015: in the light of the current electrical system condition, the National Executive
has declared a Federal Electric Sector Emergency until December 31, 2017. This executive order instructs the
Ministry of Energy and Mining to prepare and implement an action plan relative to the electric energy
generation, transportation and distribution segments in order to adjust the quality and safety of energy supply
and warrant the provision of the electricity in appropriate technical and economic conditions.
F-106
–
–
Other regulatory requirements:
Investment Promotion Regime for the Exploitation of Hydrocarbons - Decree No. 929/2013:
Decree No. 929/2013 provides the creation of an Investment Promotion Regime for the Exploitation of
Hydrocarbons (the “Promotional Regime”), both conventional and unconventional, which will apply throughout the
territory of the Republic of Argentina. Inclusion in the Promotional Regime may be applied for by subjects
registered with the Hydrocarbon Investments National Register and holding hydrocarbon exploration permits and/or
exploitation concessions and/or any third party associated and together with, such holders, provided they file with
the Strategic Planning and Coordination Commission of the Hydrocarbon Investments Nation Plan created by
Executive Order No.1.277/12 a “Hydrocarbon Exploitation Investment Project (“Proyecto de Inversión para la
Explotación de Hidrocarburos”) entailing a direct investment in foreign currency of at least US$ 1.000 million,
computed as of the filing of the Hydrocarbon Exploitation Investment Project to be invested during the first five
years of the Project (this amount was amended by the subsequent Law No. 27,007).
Among the benefits to subjects comprised by the Promotional Regime, the following are highlighted: i) they will be
entitled, subject to the terms of Law No. 17.319 and as from the fifth successive year of actual execution of their
respective “Hydrocarbon Exploitation Investment Projects”, to freely sell to foreign markets 20% of their
production of liquid and gaseous hydrocarbons produced under the said Projects, with a 0% rate for export duties,
should these be otherwise applicable; ii) they will be entitled to free availability of 100% of any foreign currency
obtained from export of the hydrocarbons mentioned in the preceding item, provided that the approved
“Hydrocarbon Exploitation Investment Project” implies the entry of foreign currency to the Argentine market of at
least US$ 1,000 million and as mentioned hereinabove; iii) it is provided that, during periods where national
production is not enough to meet domestic supply needs under the terms of section 6 of Law No. 17.319, subjects
included In the Promotional Regime shall be entitled, as from the fifth year from approval and execution of their
respective “Hydrocarbon Exploitation Investment Projects”, to obtain, in compensation for the percentage of liquid
and gaseous hydrocarbons produced under such Projects available for export as mentioned herein above, an export
price of not less than the reference export price, for whose determination the incidence of export duties otherwise
applicable will not be computed.
In addition, the Executive Order creates the institute of “Unconventional Hydrocarbon Exploitation”, consisting in
the extraction of liquid and/or gaseous hydrocarbons through unconventional stimulation techniques applied in
fields located in shale gas or shale oil, tight sands, tight gas and tight oil, and coal bed methane geological rock
formations and/or characterized, generally, by the presence of low- permeability rocks. In connection therewith, it
has been provided that subjects holding hydrocarbon exploration permits and/or exploitation concessions included
in the Promotional Regime will be entitled to apply for an “Uncoventional Hydrocarbon Exploitation Concession”.
In addition, holders of “Unconventional Hydrocarbon Exploitation Concessions” who in turn are holders of an
adjacent pre-existing exploitation concession, may apply for the merging of both areas into a sole unconventional
area, provided that due evidence is given of the geological continuity of the relevant areas.
–
Repatriation of foreign exchange:
During October, 2011, Decree No. 1,722/2011 was published and became effective as from such date. The
mentioned decree provides that total export collections from operations by producers of crude oil or its derivatives,
natural gas and liquefied gas, and companies which aim to develop mining projects, must be liquidated in the single
and free-exchange market in accordance with the provisions of Article No. 1 of Decree No. 2,581 of April 10, 1964
(see Decree No. 929/2013 above).
–
Price Information Regime
By Resolution No. 29/2014, the Secretariat of Commerce approved a Price Information Regime whereby all
companies producing supplies and final goods with total annual sales in the domestic market exceeding the amount
of 183 during 2013 must submit to the Secretariat a monthly report of current prices of all their products.
The same obligation falls upon all companies distributing and/or marketing supplies and final goods with total
annual sales in the domestic market exceeding the amount of 250 in the same year.
F-107
Likewise, Provision No. 6/2014 of the Under-Secretariat of Domestic Commerce created the Price Information
Regime Information System (“SIRIP”) that will be available at the web site http://www.mecon.gov.ar/comercio
interior.
–
New CNV Regulatory Framework
Through Resolution No. 622/2013 dated September 5, 2013, the Argentine Securities Commission (Comisión
Nacional de Valores – “CNV”) approved the Regulations (N.T. 2013) applicable to companies subject to this
agency control, as provided for by the Capital Market Act No. 26,831, and Regulatory Decree No. 1,023 dated
August 1, 2013. This Resolution superseded the former CNV Regulations (N.T. 2001 as amended) and the General
Resolutions No. 615/2013 and No. 621/2013, as from the effective date of the Regulations (N.T. 2013).
–
New Argentine Civil and Commercial Code:
On August 1, 2015, the new Federal Civil and Commercial Code became effective. These new regulations, in
addition to merging the Civil and Commercial Codes introduce details several news and amendments relative to
Capacity, Obligations, Contracts, Contractual and Precontractual Civil Liability, Ownership, Co-ownership,
Business Companies and Lapsing, among other legal institutes.
–
Transactions in the Forward Rosario Market (“ROFEX”):
As mentioned in Note 15.a) ii, YPF is licensed to operate as own settlement and clearance agent at the ROFEX. In
this sense, during October 2015 YPF has acquired in ROFEX forward agreements whose underlying asset is the
U.S. Dollar, with maturities occurring between February and May 2016.
12. BALANCES AND TRANSACTIONS WITH RELATED PARTIES
The Group enters into operations and transactions with related parties according to general market conditions, which are part of the
normal operation of the Group with respect to their purpose and conditions.
The information detailed in the tables below shows the balances with joint ventures and affiliated companies as of December 31,
2015, 2014 and 2013 and transactions with the mentioned parties for the fiscal years ended December 31, 2015, 2014 and 2013.
F-108
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9
Additionally, in the normal course of business, and taking into consideration that YPF is the main oil and gas company in Argentina,
the Group´s client/suppliers portfolio encompasses both private sector entities as well as national, provincial and municipal public
sector entities. As required by IAS 24 “Related party disclosures”, among the major transactions above mentioned the most important
are:
•
CAMMESA: the provision of fuel oil, which is destined to thermal power plants, and selling and purchases of energy (the
operations of sale and purchase for fiscal year ended on December 31, 2015 amounted to 12,079 and 1,460, respectively,
and on December 31, 2014 amounted to 7,816 and 1,121, respectively, while the net balance as of December 31, 2015,
2014 and 2013 was credit 1,960, 1,010 and 455 respectively);
•
ENARSA: rendering of regasification service in the regasification projects of liquified natural gas in Escobar and Bahía
Blanca and the purchase of natural gas, imported by ENARSA from the Republic of Bolivia and crude oil (the operations
for the fiscal year ended December 31, 2015, amounted to 1,635 and 1,141, respectively, and on December 31, 2014
amounted to 1,507 and 476, respectively, and on December 31, 2013 amounted to 1,015 and 1,107, respectively; while the
net balance as of December 31, 2015 was debt 135, and December 31, 2014 and 2013 was a credit of 192 and 430,
respectively);
•
Aerolíneas Argentinas S.A. and Austral Líneas Aéreas Cielos del Sur S.A.: the provision of jet fuel (the operations for the
fiscal year ended on December 31, 2015, 2014 and 2013, amounted to 2,178, 2,676 and 1,495, respectively, while the net
balance as of December 31, 2015, 2014 and 2013 was credit of 255, 183 and 104, respectively);
•
Ministry of Energy and Mining: the benefits of the incentive scheme for the Additional Injection of natural gas (the
operations for the for the fiscal year ended on December 31, 2015, 2014 and 2013, amounted to 12,345, 7,762 and 4,289
respectively, while the net balance as of December 31, 2015, 2014 and 2013 was credit 9,859, 3,390 and 1,787,
respectively) and for the crude oil production incentive program (the operations for the fiscal year ended on December 31,
2015 amounted to 1,988, all of them outstanding as of the closing date of this period);
•
•
•
Argentine Secretariat of Domestic Commerce: the compensation for providing gas oil to public transport of passengers at a
differential price (operations for the fiscal year ended on December 31, 2015, 2014 and 2013, amounted to 3,746, 3,763
and 2,208, respectively, while the net balance for the fiscal year ended on December 31, 2015, 2014 and 2013 was credit
412, 244 and 116, respectively);
Energy Secretariat: temporary economic assistance to Metrogas (the operations for the fiscal year ended on December 31,
2015 amounted to 711, while the net balance as of December 31, 2015 was credit 149);
Industry Secretariat: incentive for domestic manufacturing of capital goods, for the benefit of A-Evangelista S.A. (the
operations for the fiscal year ended on December 31, 2015, 2014 and 2013, amounted to 621, 233 and 169 respectively,
while the net balance as of December 31, 2015, 2014 and 2013 was credit 27, 15 and 11, respectively).
Such transactions are generally based on medium-term agreements and are provided according to general market or regulatory
conditions, as applicable.
Additionally, the Group has entered into certain financing and insurance transactions with entities related to the national public sector,
as defined in IAS 24. Such transactions consist of certain financial transactions that are described in Note 6.j) of these financial
statements, and transactions with Nación Seguros S.A. related to certain insurance policies contracts, and in connection therewith, to
the reimbursement from the insurance coverage for the incident mentioned in Note 11.b.
Furthermore, in relation to the investment agreement signed between YPF and Chevron subsidiaries, YPF has an indirect non-
controlling interest in CHNC with which YPF carries out transactions in connection with the above mentioned investment agreement
(see Note 11.c).
F-110
The table below discloses the compensation for the Company’s key management personnel, including members of the Board of
Directors and vice presidents (managers with executive functions appointed by the Board of Directors), for the fiscal year ended
December 31, 2015, 2014 and 2013:
Short-term employee benefits (2)
Share-based benefits
Post-retirement benefits
Termination benefits
2015 (1)
158
40
6
5
209
2014 (1)
112
48
4
—
164
2013 (1)
67
29
3
—
99
Includes the compensation for YPF’s key management personnel which developed their functions during the mentioned periods.
(1)
(2) Does not include Social Security contributions for 55, 57 and 29.
13. EMPLOYEE BENEFIT PLANS AND SHARE-BASED PAYMENTS
Note 1.b.10 describes the main characteristics and accounting treatment for benefit plans implemented by the Group. The charges
recognized during the fiscal year ended on December 31, 2015, 2014 and 2013 are as follows.
i. Retirement plan:
The total charges recognized under the Retirement Plan amounted to approximately 60, 49 and 42 for the years ended
December 31, 2015, 2014 and 2013, respectively.
ii. Performance Bonus Programs and Performance evaluation:
The amount charged to expense related to the Performance Bonus Programs was 1,020, 781 and 466 for the years ended
December 31, 2015, 2014 and 2013, respectively.
iii. Share-based benefit plan :
During the fiscal year ended December 31, 2015, 2014 and 2013, the Company has repurchased 382,985, 634,204 and
1,232,362 treasury shares for an amount of 120, 200 and 120, respectively, in order to comply with the share-based plans. The
cost of such repurchases is reflected in the shareholders’ equity under the name of “Treasury shares acquisition cost”, while the
face value and the adjustment resulting from the monetary restatement carried out in accordance with the Previous Accounting
Principles have been reclassified from the accounts “Subscribed Capital” and “Capital Adjustment” to the accounts “Treasury
shares” and “Treasury shares comprehensive adjustment” respectively.
The amount charged to expense in relation with the share-based plans, which are disclosed according to their nature, amounted
to 124, 80 and 43 for the fiscal years ended December 31 2015, 2014 and 2013, respectively.
Information related to the evolution of the quantity of shares, of the plans at the end of the years ended on December 31, 2015,
2014 and 2013 is as follows:
Plan 2013-2015
Amount at the beginning of the year
- Granted
- Settled
- Expired
Amount at end of year(1)
Expense recognized during the year
Fair value of shares on grant date (in dollars)
2015
2014
2013
695,015 1,289,841
—
(563,754)
(31,072)
695,015
53
14.75
—
(503,535)
(2,987)
188,493
34
14.75
—
1,769,015
(479,174)
—
1,289,841
43
14.75
(1) The average remaining life of the plan is 7 months as of December 31, 2015, between 10 and 22 months as of December 31,
2014 and between 10 and 34 months as of December 31, 2013.
F-111
Plan 2014-2016
Amount at the beginning of the year
- Granted
- Settled
- Expired
Amount at end of year (1)
Expense recognized during the year
Fair value of shares on grant date (in dollars)
2015
2014
356,054 —
— 356,054
(118,927) —
(2,997) —
234,130 356,054
27
53
33.41 33.41
(1) The average remaining life of the plan is between 10 and 22 months as of December 31, 2015 and between 10 and 30 months as
of December 31, 2014.
Plan 2015-2017
Amount at the beginning of the year
- Granted
- Settled
- Expired
Amount at end of year (1)
Expense recognized during the year
Fair value of shares on grant date (in dollars)
2015
—
619,060
(888)
(16,093)
602,079
37
19.31
(1) The average remaining life of the plan is between 7 and 31 months as of December 31, 2015.
iv. Pension Plans and other Post-retirement and Post-employment benefits of YPF Holdings Inc.:
Following is disclosed the information about pension plans and other obligations of YPF Holdings Inc. The last actuarial
evaluation for the plans mentioned above was made as of December 31, 2015.
Defined-benefit obligations
Present value of obligations
Fair value of assets
Deferred actuarial losses
Recognized net liabilities
Changes in the fair value of the defined-benefit obligations
Liabilities at the beginning of the year
Translation differences
Service costs
Interest costs
Actuarial gains
Benefits paid, settlements and amendments
Liabilities at the end of the year
Changes in the fair value of the plan assets
Fair value of assets at the beginning of the year
Employer and employees contributions
2015
279
—
—
279
2014
221
—
—
221
2013
190
—
—
190
2015
221
73
—
10
(6)
(19)
279
2014
190
81
—
5
(25)
(30)
221
2013
152
57
—
3
(6)
(16)
190
2015
—
19
2014
—
30
2013
—
16
Benefits paid and settlements
Total recognized as expense of the year
(19)
—
(30)
—
(16)
—
Amounts recognized in the Statement of Comprehensive Income
Service costs
Interest costs
Gains (Losses) on settlements and amendments
Total recognized as expense of the year
F-112
(Loss) Income
2015
—
(10)
—
(10)
2014
—
(5)
—
(5)
2013
—
(3)
—
(3)
Amounts recognized in Other Comprehensive Income
Actuarial gains, net
Total recognized in Other Comprehensive Income
Actuarial assumptions
Discount rate
Expected return on assets
Expected increase on salaries
(Loss) Income
2015
6
6
2014
25
25
2013
6
6
2015
5%
2014
5% 3.25 – 3.9%
2013
N/A N/A
N/A N/A
N/A
N/A
Expected employer’s contributions and estimated future benefit payments for the outstanding plans are as follows:
Expected employer’s contributions during 2016
Estimated future benefit payments are as follows:
-2017
-2018
-2019
-2020
-2021 – 2025
27
26
25
24
22
90
The weighted average duration used in the estimation of future payments was between 6.8 and 7.4.
YPF Holdings Inc. has performed a sensitivity analysis related to variations of 1% in the discount rate and in the trend of medical
costs for the mentioned plans, without having, such changes, a significant effect in the liability recognized or net income for the fiscal
year.
For additional information about other existing benefit plans, see Note 1.b.10.
14. OPERATING LEASES
As of December 31, 2015 the main agreements in which the Group is a lessee are:
•
Lease of facilities equipment and production equipment in fields, and natural gas compression equipment units under
agreements with an average three-year effective term with a renewal option of one additional year, for which contingent
installments are computed based on a unit of use rate (pesos per hour/day of use).
•
•
Lease of vessels and barges for hydrocarbon transportation under agreements with an average effective term of 5 years for
which contingent installments are computed based on a unit of use rate (pesos per hour/day of use).
Leases of lands for the installation and operation of service stations under agreements with an average term of
approximately 10 years, for which contingent installments are computed on the basis of a rate by unit of estimate fuel
sales.
Charges for the above mentioned agreements for fiscal years ended December 31, 2015, 2014 and 2013 amounted to approximately
7,364, 5,438 and 3,520, respectively, with 746, 1,737 and 1,493 corresponding to minimum payments, and 6,618, 3,701 and 3,027 to
contingent installments They have been allocated to “Lease of property and equipment and Contract for works and services”.
As of December 31, 2015, future estimate payments related to these agreements are as shown below
Future estimate payments
Up to 1
year
7,929
From 1 to 5
years
14,120
Following the sixth
year
332
F-113
15. INFORMATION REQUIRED BY REGULATORY AUTHORITIES
a) CNV General Resolution No. 622
I.
Pursuant to section 1, Chapter III, Title IV of such resolution, there follows a detail of the notes to the consolidated financial
statements containing information required under the Resolution in the form of exhibits.
Exhibit A – Fixed Assets
Exhibit B – Intangible assets
Note 6.b) Fixed Assets
Note 6.a) Intangible assets
Exhibit C – Investments in companies
Note 16 Investments in companies
Exhibit D – Other investments
Exhibit E – Provisions
Note 5 Financial instrument by category
Note 6.f) Trade receivables
Note 6.e) Other receivables
Note 6.c) Investments in companies
Note 6.b) Fixed Assets
Note 6.h) Provisions
Exhibit F – Cost of goods sold and services rendered
Note 6.m) Cost of sales
Exhibit G – Assets and liabilities in foreign currency
Note 18 Assets and liabilities in currencies other than the
Argentine peso
II. On March 18, 2015, the Company was registered with the CNV under the category “Settlement and Clearing Agent and Trading
Agent—Own account”, record No. 549. Considering the Company’s business, and the CNV Rules and its Interpretative
Criterion No. 55, the Company shall not, under any circumstance, offer brokerage services to third parties for transactions in
markets under the jurisdiction of the CNV and also it shall not open operating accounts to third parties to issue orders and trade
in markets under the jurisdiction of the CNV.
Besides, in accordance with the provisions of Section VI, Chapter II, Title VII of the CNV Rules and its Interpretative Criterion
No. 55, the Company’s equity exceeds the minimum required equity under such rules, which is 15, while the minimum required
counterparty capital, which is 3, is comprised of 11,618,762 units of the mutual fund known as Fondo Común de Inversión
Compass Ahorro—Clase B, with settlement upon redemption in 24 hours; the Company’s units total value as of December 31,
2015 amounted to 19.
b) Required Information by General Resolution No. 629
Due to General Resolution No. 629 of the CNV, the Company informs that supporting documentation of Company’s operations,
which is not in Company’s headquarters, is stored in the following companies:
–
–
Adea S.A. located in Barn 3 – Route 36, Km. 31.5 – Florencio Varela – Province of Buenos Aires.
File S.R.L., located in Panamericana and R.S. Peña – Blanco Escalada – Luján de Cuyo –Province of Mendoza.
F-114
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17. JOINT OPERATION AND OTHER EXPLORATION AND PRODUCTION AGREEMENTS
As of December 31, 2015, the main exploration and production joint operations and other agreements in which the Group participates
are the following:
Name and Location
Acambuco
Salta
Aguada Pichana
Neuquén
Aguaragüe
Salta
CAM-2/A SUR
Tierra del Fuego
Campamento Central / Cañadón Perdido
Chubut
Consorcio CNQ 7/A
La Pampa y Mendoza
El Tordillo
Chubut
La Tapera y Puesto Quiroga
Chubut
Lindero Atravesado
Neuquén
Llancanelo
Mendoza
Magallanes
Santa Cruz, Tierra del Fuego y Plataforma
Continental Nacional
Palmar Largo
Formosa y Salta
Loma Campana
Neuquén y Mendoza
Ramos
Salta
Rincón del Mangrullo
Neuquén
San Roque
Neuquén
Tierra del Fuego
Tierra del Fuego
Yacimiento La Ventana – Río Tunuyán
Mendoza
Zampal Oeste
Mendoza
Narambuena
Neuquén
La Amarga Chica
Neuquén
Neptuno
U.S.A.
Ownership Interest
Operator
22.50%
Pan American Energy LLC
27.27%
Total Austral S.A.
53.00%
Tecpetrol S.A.
50.00%
Enap Sipetrol Argentina S.A.
50.00%
YPF S.A.
50.00%
Pluspetrol Energy S.A.
12.20%
Tecpetrol S.A.
12.20%
Tecpetrol S.A.
37.50%
Pan American Energy LLC
51.00%
YPF S.A.
50.00%
Enap Sipetrol Argentina S.A.
30.00%
Pluspetrol S.A.
50.00%
YPF S.A.
42.00%
Pluspetrol Energy S.A.
50.00%
YPF S.A.
34.11%
Total Austral S.A.
100.00%
Petrolera L.F. Company S.R.L.
70.00%
YPF S.A.
70.00%
YPF S.A.
50.00%
YPF S.A.
50.00%
YPF S.A.
15.00%
BHPB Pet (Deepwater) Inc.
F-117
18. ASSETS AND LIABILITIES IN CURRENCIES OTHER THAN THE ARGENTINE PESO
2015
2014
2013
Amount in
currencies
other than
the
Argentine
peso
Exchange
rate (1)
Total
Amount in
currencies
other than
the
Argentine
peso
Exchange
rate (1)
Total
Amount in
currencies
other than
the
Argentine
peso
Exchange
rate (1)
Total
46 12.94
3.31
10
595
33
73
6
8.45
3.2
617
19
319
4
6.48 2,067
11
2.77
— — —
628
5
3.2
16 — — —
2,078
652
307 12.94 3,973
339
0.02
50
3.31
16,971
15
407 12.94 5,267
84
23
1
13
— — —
6 14.07
3.31
7
0.02
27
0.11
119
502
1,009 12.94 13,056
10
0.02
— — —
13
22,829
23,457
3.31
4
341
11,043
24
473
3
3
4,344
10.26
3.2
0.01
263
8,688
21
8.45 2,881
110
0.01
77
3.2
502
8.45 3,997
31
3
10 —
1,087
43
6.48 1,704
87
0.01
58
2.77
—
6.48 3,253
27
8.96
—
11
— — — — — —
11
— — —
—
6.48 4,205
2
0.01
2
0.31
11
2.77
9,371
11,449
647
8.45 5,467
— — —
— — —
— — —
12,616
13,268
649
189
6
4
0.31
0.01
34
2,774 13.04 36,173
2,785
8.55 23,812
2,095
6.52 13,660
— — —
— — —
16
6.52
104
4,403 13.04 57,417
13
3.35
4
2,845
6.52 12,910
— — — — — —
8.55 24,325
1,980
— — —
— — —
1
6.52
7
37 13.04
482
— — —
94,085
55
470
8.55
— — —
48,607
60
8
6.52
0.35
391
3
27,075
80 13.04 1,043
177
8.55 1,513
123
6.52
802
6
1,077
3.31
0.02
20
22
— — — — — —
— — — — — —
1,543 13.04 20,121
117
3.35
35
919
16
8.55 7,860
51
3.2
985
13
6.52 6,421
36
2.79
7 13.04
3.35
2
0.02
423
91
7
8
3
2
13
6
— — — — — —
6.52
2.79
8.55
3.2
26
6
2
2
Noncurrent Assets
Other receivables
US Dollar
Real
Trade receivables
Real
Total noncurrent assets
Current Assets
Trade receivables
US Dollar
Chilean peso
Real
Other receivables
US Dollar
Euro
Real
Chilean peso
Yens
Uruguayan pesos
Cash and cash equivalents
US Dollar
Chilean peso
Uruguayan pesos
Real
Total current assets
Total assets
Noncurrent Liabilities
Provisions
US Dollar
Taxes payable
US Dollar
Loans
US Dollar
Real
Salaries and social security
US Dollar
Accounts payable
US Dollar
Uruguayan pesos
Total noncurrent liabilities
Current Liabilities
Provisions
US Dollar
Taxes payable
Real
Chilean peso
Loans
US Dollar
Real
Salaries and social security
US Dollar
Real
Chilean peso
Uruguayan pesos
Accounts payable
US Dollar
Euro
Chilean peso
Real
Yens
Uruguayan pesos
Bolivian pesos
Total current liabilities
Total liabilities
— — —
— — —
10
0.35
4
1,283
14
29
26 14.21
0.02
3.35
0.11
1,877 13.04 24,476
369
26
47
3
— — —
— — —
46,350
140,435
1,776
186
6,629
6
8.55 17,228
248
10.41
64
0.01
35
3.2
6.52 11,580
2,015
9 1,674
24
66
6,387
11
17
— — — — — —
9
— — —
— — —
22
20,650
27,031
47,725
75,638
0.01
2.79
0.35
0.96
27
23
(1) Exchange rates in pesos as of December 31 2015, 2014 and 2013 according to Banco Nación Argentina.
F-118
19. SUBSEQUENT EVENTS
–
–
Pursuant to Administrative Decision No. 1/2016, published on January 8, 2016 in the Argentine Official Gazette, the
Executive Branch granted a 10-year concession extension for hydrocarbon exploitation in the Magallanes area, held by
YPF and belonging to Marina Austral Basin, as from November 14, 2017. The extension was granted for the portion under
the National Government’s concession jurisdiction, according to Section 35 of Hydrocarbons Law No. 17,139.
On January 14, 2016 YPF entered into two Agreements (the “Agreements”) with American Energy – Acquisitions LLC
(“AEAQ”), an affiliate of American Energy Partners (“AELP”) whereby YPF and AEAQ agreed on the main terms and
conditions for (i) the joint development of a shale oil and gas pilot in Bajada de Añelo area and (ii) the exploratory
delineation in the southern region of Cerro Arena area, both located in the Province of Neuquén.
The Agreements provide for an exclusivity period for the negotiation and execution of several final agreements, whose effectiveness
shall be subject to the fulfillment of precedent conditions.
As of the date of the issuance of these consolidated financial statements, there are no other significant subsequent events that require
adjustments or disclosure in the financial statements of the Group as of December 31, 2015 which were not already considered in
such consolidated financial statements according to IFRS.
These financial statements were approved by the Board of Directors’ meeting and authorized to be issued on March 3, 2016 and will
be considered by the next annual Shareholders’ meeting. In addition for purpose of its presentation to the Securities and Exchange
Commission of the United States of America, the Note 20 “Supplemental information on Oil and Gas producing activities
(unaudited)” has been included.
20. SUPPLEMENTAL INFORMATION ON OIL AND GAS PRODUCING ACTIVITIES (UNAUDITED)
The following information is presented in accordance with ASC No. 932 “Extractive Activities – Oil and Gas”, as amended by ASU
2010 – 03 “Oil and Gas Reserves. Estimation and Disclosures”, issued by FASB in January 2010.
Oil and gas reserves
Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be
estimated with reasonable certainty to be economically producible (from a given date forward, from known reservoirs, and under
existing economic conditions, operating methods and government regulations) prior to the time at which contracts providing the right
to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic
methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be
reasonably certain that it will commence the project within reasonable time. In some cases, substantial investments in new wells and
related facilities may be required to recover proved reserves.
Information on net proved reserves as of December 31, 2015, 2014 and 2013 was calculated in accordance with the SEC rules and
Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 932, as amended. Accordingly, crude
oil prices used to determine reserves were calculated for each month, for crude oils of different quality produced by the Company.
Consequently, for calculation of our net proved reserves as of December 31, 2015 the Company considered the realized prices for
crude oil in the domestic market (which are higher than those that had prevailed in the international market), taking into account the
unweighted average price for each month within the twelve-month period ended December 31, 2015. Additionally, since there are no
benchmark market natural gas prices available in Argentina, the Company used average realized gas prices during the year to
determine its gas reserves.
Notwithstanding the foregoing, commodity prices declined significantly since 2014. See “Item 3. Key Information—Risk Factors—
Risks Relating to the Argentine Oil and Gas Business and Our Business— Our oil and natural gas reserves are estimates, and —Risks
Relating to the Argentine Oil and Gas Business and Our Business— Our reserves and production are likely to decline.”
F-119
Net reserves are defined as that portion of the gross reserves attributable to the interest of YPF after deducting interests owned by
third parties. In determining net reserves, the Company excludes from its reported reserves royalties due to others, whether payable in
cash or in kind, where the royalty owner has a direct interest in the underlying production and is able to make lifting and sales
arrangements independently. By contrast, to the extent that royalty payments required to be made to a third party, whether payable in
cash or in kind, are a financial obligation, or are substantially equivalent to a production or severance tax, the related reserves are not
excluded from the reported reserves despite the fact that such payments are referred to as “royalties” under local rules. The same
methodology is followed in reporting our production amounts.
Gas reserves exclude the gaseous equivalent of liquids expected to be removed from the gas on concessions and leases, at field
facilities and at gas processing plants. These liquids are included in net proved reserves of natural gas liquids.
Technology used in establishing proved reserves additions in 2015
Company’s estimated proved reserves are based on estimates generated through the integration of available and appropriate data,
utilizing well-established technologies that have been demonstrated in the field to yield repeatable and consistent results. Data used in
these integrated assessments include information obtained directly from the subsurface via wellbore, such as well logs, reservoir core
samples, fluid samples, static and dynamic pressure information, production test data, and surveillance and performance information.
The data utilized also include subsurface information obtained through indirect measurements, including high quality 2-D and 3-D-
seismic data, calibrated with available well control. Where applicable, geological outcrops information was also utilized. The tools
used to interpret and integrate all these data included both proprietary and commercial software for reservoir modeling, simulation
and data analysis. In some circumstances, where appropriate analog reservoir models are available, reservoir parameters from these
analog models were used to increase the reliability of our reserves estimates.
F-120
Changes in Company’s Estimated Net Proved Reserves
The table below sets forth information regarding changes in Company’s net proved reserves during 2015, 2014 and 2013, by
hydrocarbon product.
Oil and Condensate
Worldwide Argentina
Other
foreign Worldwide
Argentina
Other
foreign Worldwide Argentina
Other
foreign
(Millions of barrels)
2015
2014
2013
Consolidated entities
At January 1,
Developed
Undeveloped
Revisions of previous
estimates (1)
Extensions and discoveries
Improved recovery
Purchase of minerals in place
Sale of minerals in place
Production for the year (2)
At December 31, (3)
Developed
Undeveloped
Equity-accounted entities
At January 1,
Developed
Undeveloped
Revisions of previous
estimates (1)
Extensions and discoveries
Improved recovery
Purchase of minerals in place
Sale of minerals in place
Production for the year (2)
At December 31, (3)
Developed
Undeveloped
601
447
154
1
600
1
446
154 —
31
*
31
44 —
44
23 —
23
— — —
(*) —
(*)
(91)
1
607
(*)
(91)
608
440
168
439
1
168 —
— — —
— — —
— — —
— — —
— — —
— — —
— — —
— — —
— — —
— — —
— — —
— — —
552
422
130
74
40
16
17
(9)
(89)
601
447
154
—
—
—
—
—
—
—
—
—
—
—
—
1
551
1
421
130 —
73
1
40 —
16 —
17 —
(9) —
(*)
1
(89)
600
446
1
154 —
— —
— —
— —
— —
— —
— —
— —
— —
— —
— —
— —
— —
521
397
124
83
26
11
1
(5)
(84)
552
422
130
520
397
123
1
*
*
83
*
26 —
11 —
1 —
(5) —
(*)
(84)
1
551
421
1
130 —
*
*
* —
* —
— — —
— — —
— — —
— — —
— — —
(*) —
(*) —
— — —
(*)
(*)
— — —
— — —
Oil and Condensate
Worldwide Argentina
Other
foreign Worldwide Argentina
(Millions of barrels)
Other
foreign Worldwide Argentina
Other
foreign
2015
2014
2013
Consolidated and Equity-
accounted entities
At January 1,
Developed
Undeveloped
Total
At December 31,
Developed
Undeveloped
Total
447
154
601
440
168
608
446
1
154 —
1
600
439
1
168 —
1
607
422
130
552
447
154
601
421
1
130 —
1
551
446
1
154 —
1
600
397
124
521
422
130
552
397
123
520
*
*
1
421
1
130 —
1
551
Not material (less than 1)
*
(1) Revisions in estimates of reserves are performed at least once a year. Revision of oil and gas reserves is considered
prospectively in the calculation of depreciation.
(2) Crude oil production for the years 2015, 2014 and 2013 includes an estimated approximately 13, 13 and 12 mmbbl, respectively,
in respect of royalty payments which are a financial obligation, or are substantially equivalent to a production or similar tax.
Equity-accounted entities production of crude oil in respect of royalty payments which are a financial obligation, or are
substantially equivalent to a production or similar tax, is not material.
(3) Proved crude oil reserves of consolidated entities as of December 31, 2015, 2014 and 2013 include an estimated approximately
88, 91 and 82 mmbbl, respectively, in respect of royalty payments which, as described above, are a financial obligation, or are
substantially equivalent to a production or similar tax. Proved crude oil reserves of equity–accounted entities in respect of
royalty payments which are a financial obligation, or are substantially equivalent to a production or similar tax, are not material.
F-121
Natural Gas Liquids
Worldwide
Argentina
2015
Other
foreign Worldwide
2014
Argentina
(Millions of barrels)
Other
foreign Worldwide Argentina
Other
foreign
2013
Consolidated entities
At January 1,
Developed
Undeveloped
Revisions of previous
estimates (1)
Extensions and discoveries
Improved recovery
Purchase of minerals in
place
Sale of minerals in place
Production for the year (2)
At December 31, (3)
Developed
Undeveloped
Equity-accounted entities
At January 1,
Developed
Undeveloped
Revisions of previous
estimates (1)
Extensions and discoveries
Improved recovery
Purchase of minerals in
place
Sale of minerals in place (4)
Production for the year (2)
At December 31, (3)
Developed
Undeveloped
73
53
20
9
10
—
—
(3)
(18)
71
56
15
—
—
—
—
—
—
—
—
—
—
—
—
73
53
20
—
—
—
9
10
—
—
—
—
—
(3)
(18)
71
56
15
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
76
55
21
2
13
—
*
(*)
(18)
73
53
20
—
—
—
—
—
—
—
—
—
—
—
—
76 —
55 —
21 —
2 —
13 —
— —
* —
(*) —
(18) —
73 —
53 —
20 —
69
56
13
22
3
*
1
(2)
(18)
76
55
21
69 —
56 —
13 —
22 —
3 —
* —
1 —
(2) —
(18) —
76 —
55 —
21 —
— —
— —
— —
1
1
—
1 —
1 —
— —
— —
— —
— —
—
—
—
— —
— —
— —
— —
— —
— —
— —
— —
— —
—
(1)
(*)
—
—
—
— —
(1) —
(*) —
— —
— —
— —
Natural Gas Liquids
Worldwide Argentina
Other
foreign Worldwide Argentina
(Millions of barrels)
Other
foreign Worldwide Argentina
Other
foreign
2015
2014
2013
Consolidated and
Equity-accounted
entities
At January 1,
Developed
Undeveloped
Total
At December 31,
Developed
Undeveloped
Total
53
20
73
56
15
71
53
20
73
—
—
—
56
15
71
—
—
—
55
21
76
53
20
73
55 —
21 —
76 —
53 —
20 —
73 —
57
13
70
55
21
76
57 —
13 —
70 —
55 —
21 —
76 —
Not material (less than 1)
*
(1) Revisions in estimates of reserves are performed at least once a year. Revision of oil and gas reserves is considered
prospectively in the calculation of depreciation.
(2) Natural gas liquids production for the years 2015, 2014 and 2013 includes an estimated approximately 2, 2 and 3 mmbbl,
respectively in respect of royalty payments which are a financial obligation, or are substantially equivalent to a production or
similar tax. Equity-accounted entities production of natural gas liquids in respect of royalty payments which are a financial
obligation, or are substantially equivalent to a production or similar tax, is not material.
(3) Proved natural gas liquids reserves of consolidated entities as of December 31, 2015, 2014 and 2013 include an estimated
approximately 14, 11 and 11 mmbbl, respectively, in respect of royalty payments which, as described above, are a financial
obligation, or are substantially equivalent to a production or similar tax. Proved natural gas liquids reserves of equity–accounted
entities in respect of royalty payments which are a financial obligation, or are substantially equivalent to a production or similar
tax, are not material.
In 2013, approximately 1 mmbbl was transferred to Consolidated Entities as a result of YPF Energía Eléctrica working interest
on Ramos Field. These rights were previously owned by former Pluspetrol Energy and thus disclosed under Equity-accounted
Entities reserves.
(4)
F-122
Natural gas
Worldwide
Argentina
Other
foreign
Worldwide
Argentina
Other
foreign Worldwide Argentina
Other
foreign
(Billions of standard cubic feet)
2015
2014
2013
Consolidated entities
At January 1,
Developed
Undeveloped
Revisions of previous
estimates (1)
Extensions and discoveries
Improved recovery
Purchase of minerals in place
Sale of minerals in place
Production for the year (2)
At December 31, (3) (4)
Developed
Undeveloped
Equity-accounted entities
At January 1,
Developed
Undeveloped
Revisions of previous
estimates (1)
Extensions and discoveries
Improved recovery
Purchase of minerals in place
Sale of minerals in place (5)
Production for the year (2)
At December 31, (3)
Developed
Undeveloped
Natural gas
Consolidated and Equity-
accounted entities
At January 1,
Developed
Undeveloped
Total
At December 31,
Developed
Undeveloped
Total
3,016
2,267
749
3,011
2,262
5
5
749 —
174
520
1
—
(70)
(569)
3,072
2,210
862
174
*
520 —
1 —
— —
(70) —
(569)
3,067
2,205
(*)
5
5
862 —
—
—
—
— —
— —
— —
—
—
—
—
—
—
—
—
—
— —
— —
— —
— —
— —
— —
— —
— —
— —
2,558
1,938
620
444
421
1
315
(176)
(547)
3,016
2,267
749
—
—
—
—
—
—
—
—
—
—
—
—
2,555
1,935
3
3
620 —
441
3
421 —
1 —
315 —
(176) —
(1)
(546)
5
3,011
5
2,262
749 —
2,186 2,183
1,810 1,807
3
3
376 —
376
564
1
565
179 —
179
2 —
2
73 —
73
(10) —
(10)
(1)
(437)
(436)
3
2,558 2,555
3
1,938 1,935
620 —
620
— —
— —
— —
36 —
36
36
36 —
— — —
— —
— —
— —
— —
— —
— —
— —
— —
— —
— — —
— — —
— — —
— — —
(31) —
(31)
(5) —
(5)
— — —
— — —
— — —
2015
2014
2013
Worldwide Argentina
Other
foreign Worldwide Argentina
Other
foreign Worldwide Argentina
Other
foreign
(Billions of standard cubic feet)
2,267 2,262
749
5
749 —
5
3,016 3,011
2,210 2,205
862
5
862 —
5
3,072 3,067
1,938
620
2,558
2,267
749
3,016
1,935
3
620 —
3
2,555
2,262
5
749 —
5
3,011
1,846 1,844
376
2
376 —
2
2,222 2,220
1,938 1,935
620
3
620 —
3
2,558 2,555
Not material (less than 1)
*
(1) Revisions in estimates of reserves are performed at least once a year. Revision of natural gas reserves is considered
prospectively in the calculation of depreciation.
(2) Natural gas production for the years 2015, 2014 and 2013 includes an estimated approximately 58, 60 and 47 bcf, respectively,
in respect of royalty payments which are a financial obligation, or are substantially equivalent to a production or similar tax.
Equity-accounted entities production of natural gas in respect of royalty payments which are a financial obligation, or are
substantially equivalent to a production or similar tax, is not material.
(3) Proved natural gas reserves of consolidated entities as of December 31, 2015, 2014 and 2013 include an estimated
approximately 329, 324, and 285 bcf respectively, in respect of royalty payments which, as described above, are a financial
obligation, or are substantially equivalent to a production or similar tax. Proved natural gas reserves of equity-accounted entities
in respect of royalty payments which are a financial obligation, or are substantially equivalent to a production or similar tax, are
not material.
(4) Proved natural gas reserves of consolidated entities and Equity accounted entities as of December 31, 2015, 2014 and 2013
(5)
include an estimated of approximately 635, 554 and 376 bcf respectively, which is consumed as fuel at the field.
In 2013, approximately 31 bcf were transferred to Consolidated Entities as a result of YPF Energía Eléctrica working interest on
Ramos Field. These rights were previously owned by former Pluspetrol Energy and thus disclosed under Equity-accounted
Entities reserves.
F-123
Oil equivalent (1)
Worldwide
Argentina
Other
foreign Worldwide
Argentina
Other
foreign
(Millions of barrels of oil equivalent)
Worldwide Argentina
Other
foreign
2015
2014
2013
Consolidated entities
At January 1,
Developed
Undeveloped
Revisions of previous
estimates (2)
Extensions and discoveries
Improved recovery
Purchase of minerals in place
Sale of minerals in place
Production for the year (3)
At December 31, (4)
Developed
Undeveloped
Equity-accounted entities
At January 1,
Developed
Undeveloped
Revisions of previous
estimates (2)
Extensions and discoveries
Improved recovery
Purchase of minerals in place
Sale of minerals in place (5)
Production for the year (3)
At December 31, (4)
Developed
Undeveloped
1,212
905
307
2
1,210
903
2
307 —
71
147
23
—
(16)
(211)
1,226
889
337
70
1
147 —
23 —
— —
(16) —
(1)
(210)
1,224
2
2
887
337 —
—
—
—
— —
— —
— —
—
—
—
—
—
—
—
—
—
— —
— —
— —
— —
— —
— —
— —
— —
— —
1,083
822
261
155
129
17
74
(42)
(204)
1,212
905
307
—
—
—
—
—
—
—
—
—
—
—
—
1
1,082
821
1
261 —
979
776
203
1
978
775
1
203 —
154
2
129 —
17 —
74 —
(42) —
(204)
(*)
1,210
2
2
903
307 —
— —
— —
— —
— —
— —
— —
— —
— —
— —
— —
— —
— —
205
1
61 —
11 —
15 —
(9) —
206
61
11
15
(9)
(180)
(179)
(*)
1,083 1,082
1
1
821
261 —
822
261
8
8
8 —
8 —
— — —
— — —
— — —
— — —
— — —
(7) —
(1) —
— — —
— — —
— — —
(7)
(1)
Oil equivalent (1)
Worldwide Argentina
Other
foreign Worldwide Argentina
Other
foreign Worldwide Argentina
Other
foreign
(Millions of barrels of oil equivalent)
2015
2014
2013
Consolidated and Equity-
accounted entities
At January 1,
Developed
Undeveloped
Total
At December 31,
Developed
Undeveloped
Total
1,212 1,210
905
307
889
337
903
2
307 —
2
887
2
337 —
2
822
261
1,083
821
1
261 —
1
1,082
905
307
1,212
903
2
307 —
2
1,210
1,226 1,224
783
203
987
822
261
782
1
203 —
1
986
821
1
261 —
1
1,083 1,082
Not material (less than 1)
*
(1) Volumes of natural gas have been converted to barrels of oil equivalent at 5,615 cubic feet per barrel.
(2) Revisions in estimates of reserves are performed at least once a year. Revision of crude oil, natural gas liquids and natural gas
reserves are considered prospectively in the calculation of depreciation.
(3) Barrel of oil equivalent production of consolidated entities for the years 2015, 2014 and 2013 includes an estimated
approximately 26, 27 and 23 mmboe, respectively, in respect of royalty payments which, as described above, are a financial
obligation, or are substantially equivalent to a production or similar tax. Barrel of oil equivalent production of equity-accounted
entities in respect of royalty payments which are a financial obligation, or are substantially equivalent to a production or similar
tax, are not material.
(4) Proved oil equivalent reserves of consolidated entities as of December 31, 2015, 2014 and 2013 include an estimated
approximately 176, 160 and 144 mmboe, respectively, in respect of royalty payments which, as described above, are a financial
obligation, or are substantially equivalent to a production or similar tax. Proved oil equivalent reserves of equity-accounted
entities in respect of royalty payments which are a financial obligation, or are substantially equivalent to a production or similar
tax, are not material.
In 2013, approximately 6.5 mmboe were transferred to Consolidated Entities as a result of YPF Energía Eléctrica working
interest on Ramos Field. These rights were previously owned by former Pluspetrol Energy and thus disclosed under Equity-
accounted Entities reserves.
(5)
The paragraphs below explain in further detail the most significant changes in our proved reserves during 2015, 2014 and 2013.
F-124
Changes in our estimated proved reserves during 2015
a) Revisions of previous estimates
During 2015, the Company’s proved reserves were revised upwards by 31 mmbbl of crude oil, 9 mmbbl of NGL and 174 bcf of
natural gas.
The main revisions to proved reserves were due to the following:
–
–
Total liquids and gas production performance was better than expected, resulting in a 56 mmboe (29.3 mmbbl of crude oil,
5.7 mmbbl of NGL and 117 bcf of natural gas) addition to proved developed reserves. The most significant additions were
for the Lindero Atravesado, CNQ 7A, Loma La Lata Central, Chihuido La Salina, Manantiales Behr, San Roque, Aguada
Pichana, Barranca Baya and Loma La Lata Norte fields. Main fields which performed below expectations were Al Norte
de La Dorsal and Tierra del Fuego Fracción B, resulting in these cases in a proved reserves reduction.
In the Loma La Lata field, scheduled compression projects and its production forecasts were reviewed according to the
reservoir’s current performance and the available compression technology. This revision resulted in a 21 mmboe (4.3
mmbbl of crude oil, 3.5 mmbbl of NGL and 72 bcf of natural gas) addition to proved reserves for the Sierras Blancas gas
formation.
– Mainly as a result of the impact of lower average oil prices in 2015 on economics, 21 mmboe (9.4 mmbbl of crude oil and
64.6 bcf of natural gas) of proved reserves were removed. This price reduction primarily affected reserves in the
Magallanes, Restinga Alí, Barrancas, El Portón, El Tordillo, Aguada Pichana, Loma Campana and Cañadón Perdido fields.
–
–
17 mmboe (8.8 mmbbl of crude oil and 47.4 bcf of natural gas) of proved reserve were added as a result of feasibility
studies performed to include new projects pursuant to field development plans, mainly in the Tierra del Fuego Fracción B,
Barranca Baya, Escalante, Volcán Auca Mahuida, and Seco León fields.
Net production results and forecasts from certain new wells were lower than expected, resulting in a 10 mmboe (2 mmbbl
of crude oil, 1.8 mmbbl of NGL and 36.1 bcf of natural gas) reduction in proved reserves. The reductions were in the
Loma La Lata Norte, Loma La Lata Central, Aguada Toledo Sierra Barrosa, Manantiales Behr, Rincón del Mangrullo and
Acambuco fields.
b) Extensions and discoveries
Wells drilled in unproved reserves and resource areas added 147 mmboe of proved reserves, 44 mmbbl of crude oil, 10 mmbbl of
NGL and 520 bcf of natural gas.
–
–
–
–
In the Lindero Atravesado field, 33 mmboe (0.1 mmbbl of crude oil and 182.1 bcf of natural gas), made up of 12 mmboe
of proved developed reserves and 21 mmboe of proved undeveloped reserves, were added as a result of gas wells drilled
and due to the development plan for the Lajas tight gas formation in the area.
Drilling activities and development plans in the Aguada Toledo-Sierra Barrosa field resulted in a 22 mmboe (123 bcf of
natural gas) addition of proved reserves, of which 8 mmboe were from proved developed and 14 mmboe were from proved
undeveloped reserves. The main contributions came from the Lajas tight gas formation.
The results of new gas wells in the Estación Fernandez Oro field as well as new scheduled wells resulted in an addition of
17 mmboe (5.3 mmbbl of crude oil, 2.2 mmbbl of NGL and 53.2 bcf of natural gas) of proved reserves, most of which, 16
mmboe, were in accordance with the new field development plan.
14 mmboe (0.6 mmbbl of crude oil, 2.8 mmbbl of NGL and 61.5 bcf of natural gas) of proved reserves were added as a
result of wells drilled and scheduled to be drilled in the Rincón del Mangrullo area. Reserves contributions came from the
Mulichinco tight gas formation.
F-125
–
–
During 2015, drilling activities continued in Loma Campana and Loma La Lata Norte fields for the Vaca Muerta formation
development, adding 12 mmboe (10.1 mmbbl of crude oil, 0.9 mmbbl of NGL and 4.9 bcf of natural gas) and 11 mmboe
(5.8 mmbbl of crude oil, 2.5 mmbbl of NGL and 12.6 bcf of natural gas) of proved reserves, respectively. From these total,
drilled wells contributed with proved reserve volumes of 4 mmboe in the Loma Campana field and 4 mmboe in the Loma
La Lata Norte field, and new scheduled wells added 8 mmboe and 7 mmboe of proved undeveloped reserves, respectively.
In the Golfo San Jorge basin, 12 mmboe of proved reserves, of which 8.4 mmbbl were crude oil and 18 bcf were gas, were
added as a result of new extension wells drilled and new locations added to the development plan. The main contributions
came from the Seco León, Manantiales Behr, Barranca Baya and Los Perales fields.
c) Improved recovery
23 mmbbl of proved reserves of crude oil were added mainly due to new projects and positive production response, including:
–
–
–
In the Golfo San Jorge basin, 12.9 mmbbl of secondary recovery reserves of crude oil were added as a result of new
projects and better than expected production response from existing projects. The primary additions were from the Los
Perales, Manantiales Behr, Seco León, El Trébol and Las Heras fields.
In the Neuquina basin, 6.2 mmbbl of proved reserves of crude oil were added, of which 3.2 mmbbl were proved developed
and 3.0 mmbbl were proved undeveloped, as a result of ongoing secondary recovery projects development and the addition
of new projects. The main undeveloped reserve contributions were from the CNQ 7A, Punta Barda and Puesto Hernandez
fields, whereas the Señal Picada and Chihuido de la Sierra Negra fields provided the main contributions of proved
developed reserves.
Also in the Neuquina basin, a total of 1.7 mmbbl of proved undeveloped reserves of crude oil were deducted as a result of
changes in secondary recovery project development plan.
d) Sales and acquisitions
As a result of sales and acquisitions, proved reserves declined by 16.3 mmboe (0.6 mmbbl of crude oil, 3.3 mmbbl of NGL and 69.9
bcf of natural gas), of which 8.2 mmboe was proved developed and 8.1 mmboe was proved undeveloped. This reduction in reserves
was mainly related to a modification in the joint venture agreement in the Rincón del Mangrullo field, which resulted in a reduction
of 7 mmboe of proved developed reserves and 8 mmboe of proved undeveloped reserves. Additionally, in the El Orejano field, a new
joint venture resulted in a reduction of 1.5 mmboe of proved developed reserves.
Changes in our estimated proved reserves during 2014
a) Revisions of previous estimates
During 2014, the Company’s proved reserves were revised upwards by 74 million barrels (“mmbbl”) of crude oil, 2 million barrels
(“mmbbl”) of natural gas liquids, and 444 billion cubic feet (“bcf”) of natural gas.
The main revisions to proved reserves have been due to the following:
–
–
The term of concession contracts was extended for several operated and non-operated fields located in Rio Negro and
Tierra del Fuego provinces. As a result, approximately 75 mmboe of proved reserves (25.3 mmbbl of crude oil, 1.8 mmbbl
of NGL and 268.7 bcf of natural gas) were added. Fields included in this contract are: Tierra del Fuego, Los Chorrillos,
Lago Fuego, Estación Fernandez Oro, Señal Picada, El Medanito, Punta Barda, Bajo del Piche and El Santiagueño.
Existing development plans were revised and new development plans were finalized for recently acquired fields through
the acquisition of the Apache Group assets in the Neuquina and Austral Basins. As a result, a total of 29 mmboe of proved
undeveloped reserves (5.2 mmbbl of crude oil, 1.1 mmbbl of NGL and 126.4 bcf of natural gas) were added mainly in the
Estación Fernández Oro gas field.
F-126
–
–
–
–
In the Golfo San Jorge Basin, a net volume of 7.0 mmboe of proved developed reserves (7.9 mmbbl of crude oil and a
decrease of 4.6 bcf of natural gas) was added as a result of better than expected production and revised production
forecasts. The main contributors to this increase were the Los Perales (6.4 mmboe), Barranca Baya (3.7 mmboe) and Zona
Central-Bella Vista Este (1.8 mmboe) fields, while the Seco Leon (a decrease of 2.3 mmboe) and Cañadón Yatel (a
decrease of 1.0 mmboe) fields performed lower than expected.
In the Neuquina Basin, 23.8 mmboe of proved reserves (10.9 mmbbl of crude oil and 73 bcf of natural gas) were added as
a result of fields performing above forecast. The contributors to the increase were the Chihuido La Salina (4.1 mmboe),
Puesto Hernandez (3.9 mmboe), Chihuido Sierra Negra (3.0 mmboe), Lindero Atravesado (2.8 mmboe), Aguada Pichana
(2.5 mmboe), and Loma La Lata Central (2.1 mmboe). The decrease was from the Loma La Lata Norte (a decrease of 1.9
mmboe).
A total of 9.2 mmboe of proved reserves (6.1 mmbbl of crude oil and 17.7 bcf of natural gas) was added due to feasibility
studies performed to include new projects to the field development plans, mainly in the Volcan Auca Mahuida (1.9
mmboe), Aguada Toledo-Sierra Barrosa (1.9 mmboe), Seco León (1.7 mmboe) and Los Perales (1.5 mmboe) fields.
Net results from certain new wells were lower than expected, resulting in a 6.0 mmboe reduction of proved reserves
(reductions of 2.2 mmbbl of crude oil, 2.0 mmbbl of NGL and 10.1 bcf of natural gas). The main reductions were in the
Rincón del Mangrullo, Loma La Lata Central, Manantiales Behr, Vizcacheras and Cañadón Yatel fields.
b) Extensions and discoveries
Wells drilled in unproved reserve areas added approximately 129 mmboe of proved reserves (40 mmbbl of crude oil, 13 mmbbl of
NGL and 421 bcf of natural gas).
–
–
–
–
A total of approximately 32.3 mmboe of proved reserves (1.2 mmbbl of crude oil, 6.9 mmbbl of NGL and 135.7 bcf of
natural gas) were added as a result of wells drilled and scheduled to be drilled in the Rincón del Mangrullo area,
Mulichinco Tight Gas formation.
Drilling activities and development plans in the Aguada Toledo-Sierra Barrosa field resulted in a total addition of
approximately 27.9 mmboe of proved reserves (1.2 mmbbl of crude oil and 149.9 bcf of natural gas). Main contributions
came from the Lajas Tight Gas formation (22.8 mmboe) and the Lotena formation (2.8 mmboe).
A total of 23.4 mmboe (11.8 mmbbl of crude oil, 5.6 mmbbl of NGL and 33.3 bcf of natural gas) of unconventional proved
reserves were added as a result of wells drilled in areas with unproved reserves and additional well locations scheduled to
be drilled in Loma La Lata Norte (Loma La Lata fields in the Vaca Muerta formation).
In the Golfo San Jorge Basin, 17.9 mmboe of proved reserves (13.3 mmboe of crude oil and 26.2 bcf of natural gas) were
added as a result of new extension wells drilled and new locations added to the development plan. The main contributors
were the Manantiales Behr, Barranca Baya, Cañadón Yatel and Restinga Ali fields.
c) Improved recovery
A total of approximately 17 mmboe of proved reserves were added mainly due to new projects and positive production response,
including:
–
–
In the San Jorge Basin, 15.7 mmbbl of secondary recovery reserves of crude oil were added as a result of new projects and
improved production response of existing projects. The main additions were from the Manantiales Behr, El Trebol,
Escalante, Barranca Baya and Los Perales fields.
In the Neuquina Basin, in the Puesto Hernandez field, proved undeveloped secondary recovery reserves were reduced by
4.5 mmbbl of crude oil, due to changes in workover and drilling scheduled activities in accordance with a new project
strategy.
F-127
–
This was partially offset by a total of 3.3 mmbbl of proved reserves of crude oil added as a result of production response in
the CNQ7 and CNQ7A secondary recovery projects.
d) Sales and acquisitions
–
–
During 2014, additional gas and oil fields were acquired in the Neuquina Basin (13 fields) and the Austral Basin (2 fields).
See Note 2 to the Audited Consolidated Financial Statements. As a result, 69.3 mmboe of proved reserves were added
(13.8 mmbbl of crude oil, 0.6 mmbbl of NGL and 308 bcf of natural gas), most of which are from operated fields.
On November 17, 2014, we entered into an agreement to extend the joint venture contract with ENAP Sipetrol Argentina
S.A. in the Magallanes area, until the concession contract expires which was previously extended (portion located in Santa
Cruz) exclusively by us during 2012. This resulted in a 28.9 mmboe reduction (reductions of 3.9 mmbbl of crude oil and
140.0 bcf of natural gas) of proved reserves in this area because YPF’s working interest in these fields was reduced.
Changes in our estimated proved reserves during 2013
a) Revisions of previous estimates
During 2013, the Company’s proved reserves were revised upwards by 106 mmbbl of crude oil, condensate, and NGL, and 564 bcf of
natural gas.
The main revisions to proved reserves have been due to the following:
–
–
–
–
–
–
–
–
–
The term of concession contracts was extended for several operated and non-operated fields located in Chubut Province.
Because of this, approximately 43 mmbbl of proved crude oil reserves and 15 bcf of proved natural gas reserves were
added in the Manantiales Behr, El Trebol, Escalante, Zona Central—Bella Vista, Cañadón Perdido, El Tordillo, La Tapera
and Sarmiento fields.
In the Magallanes field, approximately 36 mmboe (9 mmbbl of crude oil and 150 bcf of natural gas) of proved developed
reserves were added as a result of better than expected production and revised expected production until the expiration of
the concession contract.
A total of 8 mmbbl of liquids and 84 bcf of natural gas proved developed reserves were added in Loma La Lata Central
(southern part of Loma La Lata field), mainly because of new projects, revision of existing projects, and a higher than
forecasted production performance.
In the Golfo San Jorge Basin, Los Perales and Seco León fields, 12 mmboe of proved developed reserves (10.6 mmbbl of
crude oil and 8.2 bcf of natural gas) were added because of an improved production performance.
A total of 9 mmbbl of liquids and 122 bcf of gas proved reserves were added in the El Porton, Chihuido de la Salina,
Chihuido de la Salina Sur and Filo Morado fields in relation with production response, workovers activity and project
revision in accordance with updated field response.
In the Rincón del Mangrullo field approximately 6 mmbbl of liquids proved reserves, and 74 bcf of mainly proved
undeveloped natural gas reserves were added because of additional drilling activity planned for 2014.
The Chihuido de la Sierra Negra field added approximately 7 mmbbl of crude oil and 3 bcf of natural gas proved
developed reserves due to better than expected production performance.
Production rates did not behave as expected in the Aguada Pichana, Puesto Hernández, Aguada Toledo—Sierra Barrosa
and Barrancas fields. Proved developed reserves were reduced by 8.8 mmboe based on this new information.
New wells drilled during 2013 in several operated areas did not perform as expected. Because of this, proved reserves were
reduced by 6 mmbbl of NGL and 4 bcf of natural gas mainly in the Barranca Baya, Loma La Lata Norte, Loma Campana,
Cerro Fortunoso, and Vizcacheras fields.
F-128
b) Extensions and discoveries
Wells drilled in unproved reserve areas added approximately 61 mmboe of proved reserves (179 bcf of natural gas and 29 mmbbl of
crude oil).
–
–
–
–
–
A total of approximately 27.5 mmboe of proved reserves were added as a result of wells drilled and scheduled to be drilled
during 2014 in the Aguada Toledo—Sierra Barrosa field. The main contributions came from the Lajas Tight Gas formation
(15.9 mmboe) and the Lotena formation (7.9 mmboe).
Unconventional proved developed oil reserves for a total of 10.6 mmboe were added as a consequence of 57 new wells
drilled in unproved reserve and resource areas of the Loma La Lata Norte (Loma La Lata fields) in the Vaca Muerta
formation.
In the Loma Campana field, unconventional proved developed oil reserves for a total of 4.0 mmboe were added related to
22 new wells drilled in unproved reserves and resources areas.
In the Golfo San Jorge Basin, extensions drilled in the Seco León field (25 new wells) allowed the addition of
approximately 2.8 mmboe of proved reserves, mainly crude oil.
Also in the Golfo San Jorge Basin, 37 new extension wells drilled in the Barranca Baya field added 2.6 mmboe of mainly
crude oil reserves.
c) Improved recovery
A total of approximately 11.5 mmboe of proved oil reserves have been added due to positive production response, new production
and injection wells, and from workovers, performed as part of the improved recovery projects, including:
–
–
–
In the Neuquina Basin, Aguada Toledo—Sierra Barrosa field, approximately 6.3 mmboe of oil reserves were added as a
result of new scheduled secondary recovery projects, extension projects, and new wells drilled in the area.
In the San Jorge Basin, Manantiales Behr and El Trebol fields, 3.4 mmboe of secondary recovery reserves were added as a
result of recovery factor improvements based on new drilling and project optimization.
In the Neuquina Basin in Cerro Fortunoso field, proved undeveloped reserves were reduced by approximately 3.7 mmboe
because of observed changes in the behavior of a secondary recovery pilot project.
d) Sales and acquisitions
–
–
–
The acquisition of a 23% working interest in the Aguarague and San Antonio Sur fields of the Noroeste Basin resulted in
the addition of approximately 8.9 mmboe of proved reserves. YPF’s working interest in this field is currently 53%.
The execution of a contract for a joint venture project for the development and operation of the Loma Campana and Loma
La Lata Norte (North of Loma La Lata) fields resulted in an 8.8 mmboe reduction in proved reserves of Vaca Muerta and
Quintuco formations. As part of this agreement, YPF’s working interest in these fields changed from 100% to 50%.
Approximately 6.5 mmboe were transferred to Consolidated Entities as a result of YPF Energía Eléctrica’s working
interest in the Ramos field. These rights were previously owned by Pluspetrol Energy and are thus disclosed under Equity-
Accounted Entities reserves.
F-129
Capitalized costs
The following tables set forth capitalized costs, along with the related accumulated depreciation and allowances as of December 31,
2015, 2014 and 2013:
Consolidated capitalized costs
Proved oil and gas properties
Mineral property, wells and
2015
Other
foreign Worldwide
Argentina
2014
Other
foreign Worldwide Argentina
2013
Other
foreign Worldwide
Argentina
related equipment
451,900 4,312 456,212
Support equipment and facilities 16,920 — 16,920
45,715 — 45,715
Drilling and work in progress
Unproved oil and gas properties
6,924
Total capitalized costs
521,008 4,763 525,771
Accumulated depreciation and
6,473
451
260,759
2,763
11,037 —
26,903 —
84
3,587
2,847
302,286
263,522 177,058 1,869
7,601 —
11,037
8,998 —
26,903
83
4,577
3,671
305,133 198,234 1,952
178,927
7,601
8,998
4,660
200,186
valuation allowances
Net capitalized costs
(327,579) (3,811) (331,390) (192,010) (2,308) (194,318) (133,558) (1,676) (135,234)
64,952
193,429
110,815 64,676
952 194,381
110,276
539
276
There is no Company’s share in equity method investees’ capitalized costs during the years ended December 31, 2015, 2014 and
2013.
Costs incurred
The following tables set forth the costs incurred for oil and gas producing activities during the years ended December 31, 2015, 2014
and 2013:
2015
Other
foreign Worldwide Argentina
2014
Other
foreign Worldwide Argentina
2013
Other
foreign Worldwide
Argentina
Consolidated costs incurred
Acquisition of unproved properties — —
2,784 —
—
5,719 —
—
— —
Acquisition of proved properties
189
3,170
4,469
4,029 440
Exploration costs
182
84 44,837 37,615
44,753
Development costs
371
48,782 524 49,306 49,288
Total costs incurred
2,784 — —
78 —
5,719
57
3,359 1,626
15
37,797 26,160
72
49,659 27,864
—
78
1,683
26,175
27,936
There is no Company’s share in equity method investees’ costs incurred during the years ended December 31, 2015, 2014 and 2013.
Results of operations from oil and gas producing activities
The following tables include only the revenues and expenses directly associated with oil and gas producing activities. It does not
include any allocation of the interest costs or corporate overhead and, therefore, is not necessarily indicative of the contribution to net
earnings of the oil and gas operations.
F-130
Differences between these tables and the amounts shown in Note 4, “Segment Information”, for the exploration and production
business unit, relate to additional operations that do not arise from those properties held by the Company.
Consolidated results of operations
Net sales to unaffiliated parties
Net intersegment sales
Total net revenues
Production costs
Exploration expenses
Depreciation and expense for valuation
allowances
Other
Pre-tax income from producing
activities
Income tax expense
Results of oil and gas producing
activities
2015
Other
foreign Worldwide Argentina
2014
Other
foreign Worldwide Argentina
2013
Other
foreign Worldwide
Argentina
13,812 197 14,009
64,191 — 64,191
78,003 197 78,200
(89) (44,044)
(43,955)
(2,469)
(2,342) (127)
(25,222) (322) (25,544)
(457)
(401)
(56)
6,823
361
62,093 —
361
68,916
(81)
(37,193)
(173)
(1,712)
7,184 2,751 276
62,093 38,908 —
69,277 41,659 276
(55)
(37,274) (24,938)
(59)
(770)
(1,885)
3,027
38,908
41,935
(24,993)
(829)
(17,067)
(1,296)
(113)
48
(17,180) (9,464) (135)
(715) —
(1,248)
(9,599)
(715)
6,083 (397)
79
(2,114)
5,686
(2,035)
11,648
(3,777)
42
(38)
11,690 5,772
(3,815) (1,997)
27
(22)
5,799
(2,019)
3,969 (318)
3,651
7,871
4
7,875 3,775
5
3,780
There is no Company’s share in equity method investees’ results of operations during the years ended December 31, 2015, 2014 and
2013.
Standardized measure of discounted future net cash flows
The standardized measure is calculated as the excess of future cash inflows from proved reserves less future costs of producing and
developing the reserves, future income taxes and a discount factor. Future cash inflows represent the revenues that would be received
from production of year-end proved reserve quantities assuming the future production would be sold at the prices used for reserves
estimates as of year-end (the “average price”). Accordingly, crude oil prices used to determine reserves were calculated each month,
for crude oils of different quality produced by the Company.
For the year ended December 31, 2015, the Company considered the realized prices for crude oil in the domestic market (which are
higher than those that had prevailed in the international market), taking into account the unweighted average price for each month
within the twelve-month period ended December 31, 2015.
Additionally, since there are no benchmark market natural gas prices available in Argentina, the Company used average realized gas
prices during the year ended December 31, 2015.
Future production costs include the estimated expenditures related to production of the proved reserves plus any production taxes
without consideration of future inflation. Future development costs include the estimated costs of drilling development wells and
installation of production facilities, plus the net costs associated with dismantling and abandonment of wells, assuming year-end costs
continue without consideration of future inflation. Future income taxes were determined by applying statutory rates to future cash
inflows less future production costs and less tax depreciation of the properties involved. The present value was determined by
applying a discount rate of 10% per year to the annual future net cash flows.
The future cash inflows and outflows in foreign currency have been remeasured at the selling exchange rate of Argentine pesos 13.01
as of December 31, 2015.
The standardized measure does not purport to be an estimate of the fair market value of the Company’s proved reserves. An estimate
of fair value would also take into account, among other things, the expected recovery of reserves in excess of proved reserves,
anticipated changes in future prices and costs and a discount factor representative of the time value of money and the risks inherent in
producing oil and gas.
F-131
Consolidated standardized measure
of discounted future net cash flows
Future cash inflows (1)
Future production costs (1)
Future development costs
Future income tax expenses
10% annual discount for estimated
2015
Other
foreign Worldwide Argentina
Argentina
670,085 589 670,674
513,786
(395,119) (331) (395,450) (252,073)
(71,617)
(116,524)
(37,454)
(30,724)
(10) (116,534)
(70) (30,794)
2014
Other
foreign Worldwide Argentina
2013
Other
foreign Worldwide
514,430 357,749 641
644
358,390
(228) (252,301) (185,727) (151) (185,879)
(49,344)
(25,553)
(71,691) (49,164) (180)
(37,570) (25,403) (150)
(74)
(116)
timing of cash flows
(30,075)
(56) (30,131)
(53,403)
(82)
(53,485) (35,935)
(54)
(35,989)
Standardized measure of discounted
future net cash flows
97,643 122 97,765
99,239
144
99,383 61,520 106
61,626
(1) Does not include amounts corresponding to volumes consumed or flared in operation.
There is no Company’s share in equity method investees’ standardized measure of discounted future net cash flows during the years
ended December 31, 2015, 2014 and 2013.
Changes in the standardized measure of discounted future net cash flows
The following table reflects the changes in standardized measure of discounted future net cash flows for the years ended December
31, 2015, 2014 and 2013:
Beginning of year
Sales and transfers, net of production
costs
Net change in sales and transfer prices,
net of future production costs
Changes in reserves and production rates
(timing)
Net changes for extensions, discoveries
and improved recovery
Net change due to purchases and sales of
minerals in place
Changes in estimated future development
and abandonment costs
Development costs incurred during the
year that reduced future development
costs
Accretion of discount
Net change in income taxes
Others(2)
End of year
2015
2014
2013
Company’s
share in
equity
method
investees
Consolidated
—
61,626
Company’s
share in
equity
method
investees Consolidated
40,562
—
Consolidated
99,382
(52,321)
—
(29,426)
—
(20,402)
(80,809)
—
(651)
—
3,174
3,748
—
14,588
—
21,996
30,956
—
18,423
—
6,963
—
—
7,294
—
—
(28,225)
—
(13,134)
—
(11,012)
Company’s
share in
equity
method
investees
194
—
—
—
—
—
—
24,475
13,646
35,409
51,504
97,765
—
—
—
—
—
12,128
7,069
2,567
18,899
99,383
—
—
—
—
—
7,544
4,592
(5,284)
13,493
61,626
—
—
—
(194)(1)
—
(1)
(2)
In 2013, approximately 194 were transferred to Consolidated Entities as a result of YPF Energĺa Eléctrica’s working interest on
Ramos Field. These discounted future net cash flows were previously owned by former Pluspetrol Energy and thus disclosed
under Company’s share in equity method investees.
It corresponds mainly to changes in exchange rates during each year presented.
F-132
Exhibit 12.1
I, Miguel Galuccio, certify that:
1. I have reviewed this annual report on Form 20-F of YPF S.A.;
302 CERTIFICATION
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact
necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with
respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all
material respects the financial condition, results of operations and cash flows of the company as of, and for, the periods presented in
this report;
4. The company’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures
(as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act
Rules 13a-15(f) and 15d-15(f)) for the company and have:
(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our
supervision, to ensure that material information relating to the company, including its consolidated subsidiaries, is made known to us
by others within those entities, particularly during the period in which this report is being prepared;
(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed
under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial
statements for external purposes in accordance with generally accepted accounting principles;
(c) Evaluated the effectiveness of the company’s disclosure controls and procedures and presented in this report our conclusions
about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such
evaluation; and
(d) Disclosed in this report any change in the company’s internal control over financial reporting that occurred during the period
covered by the annual report that has materially affected, or is reasonably likely to materially affect, the company’s internal control
over financial reporting; and
5. The company’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over
financial reporting, to the company’s auditors and the audit committee of the company’s board of directors (or persons performing the
equivalent functions):
(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which
are reasonably likely to adversely affect the company’s ability to record, process, summarize and report financial information; and
(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the company’s
internal control over financial reporting.
Date: March 17, 2016.
/s/ Miguel Galuccio
Miguel Galuccio
Chief Executive Officer
Exhibit 12.2
I, Daniel González, certify that:
1. I have reviewed this annual report on Form 20-F of YPF S.A.;
302 CERTIFICATION
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact
necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with
respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all
material respects the financial condition, results of operations and cash flows of the company as of, and for, the periods presented in
this report;
4. The company’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures
(as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act
Rules 13a-15(f) and 15d-15(f)) for the company and have:
(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our
supervision, to ensure that material information relating to the company, including its consolidated subsidiaries, is made known to us
by others within those entities, particularly during the period in which this report is being prepared;
(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed
under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial
statements for external purposes in accordance with generally accepted accounting principles;
(c) Evaluated the effectiveness of the company’s disclosure controls and procedures and presented in this report our conclusions
about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such
evaluation; and
(d) Disclosed in this report any change in the company’s internal control over financial reporting that occurred during the period
covered by the annual report that has materially affected, or is reasonably likely to materially affect, the company’s internal control
over financial reporting; and
5. The company’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over
financial reporting, to the company’s auditors and the audit committee of the company’s board of directors (or persons performing the
equivalent functions):
(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which
are reasonably likely to adversely affect the company’s ability to record, process, summarize and report financial information; and
(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the company’s
internal control over financial reporting.
Date: March 17, 2016.
/s/ Daniel González
Daniel González
Chief Financial Officer
906 CERTIFICATION
Exhibit 13.1
The certification set forth below is being submitted in connection with the Annual Report on Form 20-F for the year ended
December 31, 2015 (the “report”) for the purpose of complying with Rule 13a-14(b) or Rule 15d-14(b) of the Securities Exchange
Act of 1934 (the “Exchange Act”) and Section 1350 of Chapter 63 of Title 18 of the United States Code.
Miguel Galuccio, the Chief Executive Officer and Daniel González, the Chief Financial Officer of YPF S.A., each certifies that, to
the best of their knowledge:
1. the report fully complies with the requirements of Section 13(a) or 15(d) of the Exchange Act; and
2. the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of
YPF S.A.
Date: March 17, 2016.
/s/ Miguel Galuccio
Miguel Galuccio
Chief Executive Officer
/s/ Daniel González
Daniel González
Chief Financial Officer
Exhibit 23.1
DeGolyer and MacNaughton
5001 Spring Valley Road
Suite 800 East
Dallas, Texas 75244
March 10, 2016
YPF Sociedad Anónima
Macacha Güemes 515
C1106BKK Buenos Aires
Argentina
Ladies and Gentlemen:
We hereby consent to the references to DeGolyer and MacNaughton and to the inclusion of our third-party letter report
dated January 25, 2016, as set forth under the sections “Item 4. Information on the Company–Exploration and Production Overview–
Oil and Gas Reserves,” and “Item 19. Exhibits,” and as Exhibit 99.1 in YPF Sociedad Anónima’s (YPF S.A.) report on Form 20-F for
the year ended December 31, 2015, to be filed with the United States Securities and Exchange Commission (SEC).
Our third-party letter report dated January 25, 2016, contains our independent estimates of the proved oil, separator gas,
and oil-equivalent reserves audited as of December 31, 2015, of certain selected properties in the United States in which YPF S.A.
has represented that it holds interests.
Very truly yours,
/s/ DeGolyer and MacNaughton
DeGOLYER and MacNAUGHTON
Texas Registered Engineering Firm F-716
Exhibit 23.2
ihs.com
SUITE 800 SUN LIFE PLAZA EAST TOWER 112 - 4TH AVENUE SW CALGARY, AB T2P 0H3 • 403 213 4200 • 1 800 625 2488
March 11, 2016
YPF S.A.
Macacha Guemes 515
Ciudad Autonoma de Buenos Aires
Buenos Aires, Argentina
Ladies and Gentlemen:
CONSENT OF INDEPENDENT ENGINEERS
We hereby consent to the references to IHS Global Canada Limited and to the inclusion of our third-party letter report dated
February 17, 2016, as set forth under the sections “Item 4. Information on the Company–Exploration and Production Overview–Oil
and Gas Reserves,” “Item 19. Exhibits,” and as Exhibit 99.1 in YPF Sociedad Anónima’s (YPF S.A.) report on Form 20-F for the
year ended December 31, 2015, to be filed with the United States Securities and Exchange Commission (SEC).
Our third-party letter report dated February 17, 2016, contains our independent estimates of the proved crude oil and natural gas
reserves audited as of December 31, 2015, of certain selected properties in Argentina in which YPF S.A. holds interests.
Yours truly,
IHS GLOBAL CANADA LIMITED
Jason Wilhelm, P. Eng.
Senior Principal Engineer, Consulting
Exhibit 99.1(a)
DeGolyer and MacNaughton
5001 Spring Valley Road
Suite 800 East
Dallas, Texas 75244
January 25, 2016
Maxus Energy Corporation
10333 Richmond Avenue
Suite 1050
Houston, Texas 77042
Ladies and Gentlemen:
Pursuant to your request, we have conducted a reserves audit of the net proved oil and gas reserves, as of December 31,
2015, of certain properties that Maxus Energy Corporation (Maxus), an indirect wholly owned subsidiary of YPF S.A. (YPF) for the
purposes of YPF’s disclosure of reserves pursuant to the requirements of Item 1202 of Regulation S–K and inclusion of this report as
an exhibit to YPF’s filings with the United States Securities and Exchange Commission (SEC), has represented that it owns. This
evaluation was completed on January 25, 2016. The properties evaluated consist of working interests located offshore in the Gulf of
Mexico. Maxus has represented that these properties account for 55 percent on a net equivalent barrel basis of Maxus’ net proved
reserves of assets they can account for as of December 31, 2015, and that the net proved reserves estimates have been prepared in
accordance with the reserves definitions of Rules 4–10(a) (1)–(32) of Regulation S–X of the SEC of the United States. We have
reviewed information provided to us by Maxus that it represents to be Maxus’ estimates of the net reserves, as of December 31, 2015,
for the same properties as those which we evaluated.
Reserves estimates included herein are expressed as net reserves as represented by Maxus. Gross reserves are defined as
the total estimated petroleum to be produced from these properties after December 31, 2015. Net reserves are defined as that portion
of the gross reserves attributable to the interests owned by Maxus after deducting all interests owned by others.
2
DeGolyer and MacNaughton
Estimates of oil and gas should be regarded only as estimates that may change as further production history and additional
information become available. Not only are such reserves estimates based on that information which is currently available, but such
estimates are also subject to the uncertainties inherent in the application of judgmental factors in interpreting such information.
Data used in this audit were obtained from reviews with Maxus personnel, from Maxus’ files, from records on file with the
appropriate regulatory agencies, and from public sources. In the preparation of this report we have relied, without independent
verification, upon such information furnished by Maxus with respect to property interests, production from such properties, current
costs of operation and development, current prices for production, agreements relating to current and future operations and sale of
production, and various other information and data that were accepted as represented. A field examination of the properties was not
considered necessary for the purposes of this report.
Methodology and Procedures
Estimates of reserves were prepared by the use of appropriate geologic, petroleum engineering, and evaluation principles
and techniques that are in accordance with practices generally recognized by the petroleum industry as presented in the publication of
the Society of Petroleum Engineers entitled “Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves
Information (Revision as of February 19, 2007).” The method or combination of methods used in the analysis of each reservoir was
tempered by experience with similar reservoirs, stage of development, quality and completeness of basic data, and production history.
Based on the current stage of field development, production performance, the development plans provided by Maxus, and
the analyses of areas offsetting existing wells with test or production data, reserves were classified as proved.
An analysis of reservoir performance, including production rate, water-cut, and gas-oil ratio behavior, was used in the
estimation of reserves.
For depletion-type reservoirs or those whose performance disclosed a reliable decline in producing-rate trends or other
diagnostic characteristics, reserves were estimated by the application of appropriate decline curves or other performance
relationships. In the analyses of production-decline curves, reserves were estimated only to the limits of economic production.
3
DeGolyer and MacNaughton
In certain cases, when the previously named methods could not be used, reserves were estimated by analogy with similar
wells or reservoirs for which more complete data were available.
Gas quantities estimated herein are expressed as separator gas. Separator gas is the gas remaining after field separation but
prior to gas processing and shrinkage for fuel use or flare. Gas reserves are expressed at a temperature base of 60 degrees Fahrenheit
and at a pressure base of 14.73 pounds per square inch absolute. Gas quantities included herein are expressed in thousands of cubic
feet (Mcf). Oil reserves estimated herein are those to be recovered by conventional lease separation. Oil reserves estimates included
herein are expressed in terms of barrels (bbl) representing 42 United States gallons per barrel.
Definition of Reserves
Petroleum reserves estimated by Maxus and by us included in this report are classified as proved. Only proved reserves
have been evaluated for this report. Reserves classifications used by Maxus and by us in this report are in accordance with the
reserves definitions of Rules 4–10(a) (1)–(32) of Regulation S–X of the SEC. Reserves are judged to be economically producible in
future years from known reservoirs under existing economic and operating conditions and assuming continuation of current
regulatory practices using conventional production methods and equipment. In the analyses of production-decline curves, reserves
were estimated only to the limit of economic rates of production under existing economic and operating conditions using prices and
costs consistent with the effective date of this report, including consideration of changes in existing prices provided only by
contractual arrangements but not including escalations based upon future conditions. The petroleum reserves are classified as follows:
Proved oil and gas reserves – Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of
geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given
date forward, from known reservoirs, and under existing economic conditions, operating methods, and government
regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that
renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The
project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence
the project within a reasonable time.
DeGolyer and MacNaughton
4
(i) The area of the reservoir considered as proved includes:
(A) The area identified by drilling and limited by fluid contacts, if any, and (B) Adjacent undrilled portions of the
reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically
producible oil or gas on the basis of available geoscience and engineering data.
(ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known
hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable
technology establishes a lower contact with reasonable certainty.
(iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the
potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of
the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher
contact with reasonable certainty.
(iv) Reserves which can be produced economically through application of improved recovery techniques (including,
but not limited to, fluid injection) are included in the proved classification when:
(A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the
reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other
evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the
project or program was based; and (B) The project has been approved for development by all necessary parties and
entities, including governmental entities.
(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be
determined. The price shall be the average price during the 12-month period prior to the ending date of the period
covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each
month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon
future conditions.
DeGolyer and MacNaughton
5
Developed oil and gas reserves – Developed oil and gas reserves are reserves of any category that can be expected to be
recovered:
(i) Through existing wells with existing equipment and operating methods or in which the cost of the required
equipment is relatively minor compared to the cost of a new well; and
(ii) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the
extraction is by means not involving a well.
Undeveloped oil and gas reserves – Undeveloped oil and gas reserves are reserves of any category that are expected to be
recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for
recompletion.
(i) Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are
reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes
reasonable certainty of economic producibility at greater distances.
(ii) Undrilled locations can be classified as having undeveloped reserves only if a development plan has been
adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances justify a
longer time.
(iii) Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an
application of fluid injection or other improved recovery technique is contemplated, unless such techniques have
been proved effective by actual projects in the same reservoir or an analogous reservoir, as defined in [section
210.4–10 (a) Definitions], or by other evidence using reliable technology establishing reasonable certainty.
6
DeGolyer and MacNaughton
Primary Economic Assumptions
The following economic assumptions were used for estimating existing and future prices and costs:
Oil Prices
Maxus has represented that the oil prices were based on a reference price, calculated as the unweighted arithmetic
average of the first-day-of-the-month price for each month within the 12-month period prior to the end of the
reporting period, unless prices are defined by contractual arrangements. Maxus supplied differentials to a West
Texas Intermediate reference price of $50.16 per barrel and the prices were held constant thereafter. The volume-
weighted average price attributable to estimated proved reserves was $47.97 per barrel of oil.
Gas Prices
Maxus has represented that the gas prices were based on a reference price, calculated as the unweighted arithmetic
average of the first-day-of-the-month price for each month within the 12-month period prior to the end of the
reporting period, unless prices are defined by contractual arrangements. The gas prices were calculated for each
property using differentials to the Henry Hub reference price of $2.64 per million British thermal units (MMBtu)
furnished by Maxus and held constant thereafter. The volume-weighted average price attributable to estimated
proved reserves was $2.769 per thousand cubic feet of gas.
Operating Expenses, Capital Costs, and Abandonment Costs
Operating expenses, capital costs, and abandonment costs, based on information provided by Maxus, were used in
estimating future expenditures required to operate the properties. In certain cases, future costs, either higher or lower
than existing costs, may have been used because of anticipated changes in operating conditions. These costs were
not escalated for inflation.
While the oil and gas industry may be subject to regulatory changes from time to time that could affect an industry
participant’s ability to recover its oil and gas reserves, we are not aware of any such governmental actions which would restrict the
recovery of the December 31, 2015, estimated oil and gas reserves.
DeGolyer and MacNaughton
Maxus has represented that its estimated net proved reserves attributable to the reviewed properties are based on the
definition of proved reserves of the SEC. Maxus represents that its estimates of the net proved reserves attributable to these
properties, which represent 55 percent of Maxus’ reserves on a net equivalent basis, are as follows, expressed in thousands of barrels
(Mbbl), millions of cubic feet (MMcf), and thousands of barrels of oil equivalent (Mboe):
7
Properties reviewed by
DeGolyer and MacNaughton
Proved Developed
Proved Undeveloped
Total Proved
Estimated by Maxus
Net Proved Reserves
as of
December 31, 2015
Oil
(Mbbl)
1,292
0
Separator
Gas
(MMcf)
1,147
0
1,292
1,147
Oil
Equivalent
(Mboe)
1,496
0
1,496
Note: Gas is converted to oil equivalent using an energy equivalent factor of 5,615 cubic feet of gas per 1 barrel of oil equivalent.
Our estimates of Maxus’ net proved reserves attributable to the reviewed properties are based on the definition of proved
reserves of the SEC and are as follows, expressed in thousands of barrels (Mbbl), millions of cubic feet (MMcf), and thousands of
barrels of oil equivalent (Mboe):
Estimated by DeGolyer and MacNaughton
Net Proved Reserves
as of
December 31, 2015
Separator
Gas
(MMcf)
Oil
Equivalent
(Mboe)
Oil
(Mbbl)
Proved Developed
Proved Undeveloped
Total Proved
1,211
0
1,211
939
0
939
1,378
0
1,378
Note: Gas is converted to oil equivalent using an energy equivalent factor of 5,615 cubic feet of gas per 1 barrel of oil equivalent.
In our opinion, the information relating to estimated proved reserves of oil and gas contained in this report has been
prepared in accordance with Paragraphs 932-235-50-4, 932-235-50-6, 932-235-50-7, and 932-235-50-9 of the Accounting Standards
Update 932-235-50, Extractive Industries – Oil and Gas (Topic 932): Oil and Gas Reserve Estimation and Disclosures
(January 2010) of the Financial Accounting Standards Board and Rules 4–10(a) (1)–(32) of Regulation S–X and Rules 302(b), 1201,
and 1202(a) (1), (2), (3), (4), (8)(i), (ii), and (v)–(x) of Regulation S–K of the Securities and Exchange Commission; provided,
however, that estimates of proved developed and proved undeveloped reserves are not presented at the beginning of the year.
DeGolyer and MacNaughton
To the extent the above-enumerated rules, regulations, and statements require determinations of an accounting or legal
nature, we, as engineers, are necessarily unable to express an opinion as to whether the above-described information is in accordance
therewith or sufficient therefor.
In comparing the detailed net proved reserves estimates prepared by us and by Maxus, we have found differences, both
positive and negative, resulting in an aggregate difference of 7.9 percent when compared on the basis of net equivalent barrels. It is
our opinion that the net proved reserves estimates prepared by Maxus on the properties reviewed by us and referred to above, when
compared on the basis of net equivalent barrels, in aggregate, are reasonable.
8
DeGolyer and MacNaughton
DeGolyer and MacNaughton is an independent petroleum engineering consulting firm that has been providing petroleum
consulting services throughout the world since 1936. Our fees were not contingent on the results of our evaluation. This letter report
has been prepared at the request of Maxus. DeGolyer and MacNaughton has used all assumptions, data, procedures, and methods that
it considers necessary and appropriate to prepare this report.
9
[SEAL]
Submitted,
/s/ DeGolyer and MacNaughton
DeGOLYER and MacNAUGHTON
Texas Registered Engineering Firm F-716
/s/ Paul J. Szatkowski
Paul J. Szatkowski, P.E.
Senior Vice President
DeGolyer and MacNaughton
DeGolyer and MacNaughton
CERTIFICATE of QUALIFICATION
I, Paul J. Szatkowski, Petroleum Engineer with DeGolyer and MacNaughton, 5001 Spring Valley Road, Suite 800 East, Dallas,
Texas, 75244 U.S.A., hereby certify:
1.
2.
[SEAL]
That I am a Senior Vice President with DeGolyer and MacNaughton, which company did prepare the letter report
addressed to Maxus dated January 25, 2016, and that I, as Senior Vice President, was responsible for the preparation of this
letter report.
That I attended Texas A&M University, and that I graduated with a Bachelor of Science degree in Petroleum Engineering
in the year 1974; that I am a Registered Professional Engineer in the State of Texas; that I am a member of the
International Society of Petroleum Engineers and the American Association of Petroleum Geologists; and that I have in
excess of 41 years of experience in oil and gas reservoir studies and reserves evaluations.
/s/ Paul J. Szatkowski
Paul J. Szatkowski, P.E.
Senior Vice President
DeGolyer and MacNaughton
Exhibit 99.1(b)
SEC
RESERVES AUDIT OF CERTAIN
P&NG INTERESTS OF
YPF S.A.
AS OF DECEMBER 31, 2015
PREPARED FOR:
YPF S.A.
Prepared by:
IHS Global Canada Limited
Suite 800 Sun Life Plaza East Tower
112 – 4th Avenue S.W.
Calgary, Alberta T2P 0H3
SUITE 800 SUN LIFE PLAZA EAST TOWER 112 - 4TH AVENUE SW CALGARY, AB T2P 0H3 • 403 213 4200 • 1 800 625 2488
ihs.com
February 17, 2016
Mr. Javier Sanagua
Auditor de Reservas, YPF S.A.
Macacha Guemes 515
Ciudad Autonoma de Buenos Aires
Buenos Aires, Argentina
Re:
SEC Reserves Audit of Certain P&NG Interests of YPF S.A.
In Argentina as of December 31, 2015
Dear Mr. Javier Sanagua:
This reserve statement has been prepared by IHS Global Canada Limited (IHS) and issued on February 22,
2016 at the request of YPF S.A. (YPF), operator of certain assets in the Cuyo, Neuquina, and San Jorge
Basins in Argentina. YPF holds a 100% working interest in these properties with the exception of those
described below.
Properties
Rio Tunuyan
Zampal Oeste
Bajo Del Toro
La Amarga Chica
Llancanelo
Loma Campana
Loma La Lata Norte
Rincón Del Mangrullo
Cañadón Perdido
Working Interest (%)
70
90
46.8
50
51
50
50
50
50
IHS has conducted an independent audit examination as of December 31, 2015, of the hydrocarbon liquid and
natural gas proved reserves for 38 properties in the Cuyo, San Jorge and Neuquina Basins. This report is
intended for inclusion in YPF’s filings (20-F, F-3) with the United States Securities and Exchange Commission.
On the basis of technical and other information made available to us concerning these properties, we hereby
provide the summary of total gross reserves in the table below.
IHS GLOBAL CANADA LIMITED
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
Summary of Remaining Hydrocarbon Volumes
Proved
Developed Producing
Developed Non-Producing
Undeveloped
Total Proved
Liquids
(103m3)
Gas
(106m3)
22163.3
21977.6
47.5
140.5
9229.8
8222.8
31440.6
30340.9
Hydrocarbon liquid volumes represent crude oil, condensate, gasoline and NGL estimated to be recovered
during field separation and plant processing and are reported in thousands (103) of stock tank cubic meters.
Natural gas volumes represent expected gas sales, and are reported in million (106) standard cubic meters (at
standard conditions of 15 degrees Celsius and 1 atmosphere). The volumes have not been reduced for fuel
usage in the field. Based on the assumption that Argentine royalties are a financial obligation or substantially
equivalent to a production or similar tax, royalties payable to the provinces have not been deducted from the
reported volumes.
Gas reserves sales volumes are based on firm and existing gas contracts, or on the reasonable expectation
that any such existing gas sales contracts will be renewed on similar terms in the future.
The following tables contain the gross reserves for each property.
[3]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
TOTAL LIQUID HYDROCARBONS
Entity
Cuyo
Ceferino
Rio Tunuyan
Zampal Oeste*
GROSS LIQUID HYDROCARBONS (103 m3)
PDP
(CDEP)
PDNP
(CDNP)
PUD
(CND)
3.5
109.8
0.0
0.0
0.0
0.0
0.0
0.0
0.0
TP
3.5
109.8
0.0
Total Cuyo 113.3
0.0
0.0
113.3
Neuquina
Bajada De Añelo*
Bajo Del Piche
Bajo Del Toro
Bandurria
Cañadón Amarillo
Cerro Bandera No Operada
Cerro Hamaca
Cerro Mollar Norte
El Medanito
El Orejano
La Amarga Chica
Llancanelo
Loma Alta Sur
Loma Campana
Loma De La Mina
Loma La Lata Central
Loma La Lata Norte
Los Cavaos
Octógono
Pampa Palauco
0.0
139.2
7.0
24.5
396.7
419.3
279.0
41.4
347.9
106.2
24.5
280.1
348.8
1662.2
124.6
4425.4
5468.8
334.5
323.0
175.9
Piedras Negras-Señal Lomita
0.0
Puesto Molina
Puesto Molina Norte
Punta Barda
Puntilla Del Huincan*
Rincón Del Mangrullo
Señal Cerro Bayo
296.3
4.3
282.0
0.0
975.3
774.7
0.0
1.1
0.0
0.0
0.0
0.0
0.0
1.6
0.0
0.0
0.0
0.0
26.4
0.0
0.0
0.0
0.0
18.4
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
320.4
23.3
190.8
0.0
0.0
0.0
0.0
373.2
170.3
1486.7
9.1
1297.3
1001.4
0.0
102.2
0.0
0.0
43.8
17.8
285.0
0.0
738.2
0.0
0.0
140.3
7.0
24.5
717.2
442.6
469.8
43.0
347.9
106.2
24.5
653.3
545.5
3148.9
133.7
5722.5
6470.2
352.9
425.2
175.9
0.0
340.1
22.1
567.0
0.0
1713.4
774.7
Total Neuquina 17261.6
47.5
6059.5
23368.4
San Jorge
Cañadón Perdido*
Cañadón Vasco
0.0
83.7
Cerro Piedra-Cerro Guadal Norte
164.0
El Cordón
El Destino
El Trébol
Escalante
Pico Truncado
216.7
397.0
2408.5
895.8
622.7
Total San Jorge 4788.4
GRAND TOTAL
22163.3
*YPF has not assigned any reserves to these fields
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
47.5
0.0
113.4
48.3
500.5
229.6
1009.3
910.8
358.4
3170.3
9229.8
0.0
197.2
212.3
717.2
626.5
3417.8
1806.6
981.1
7958.7
31440.4
[4]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
NATURAL GAS VOLUMES
GROSS GAS (106m3)
PDP
(CDEP)
PDNP
(CDNP)
PUD
(CND)
TP
Entity
Cuyo
Ceferino
Rio Tunuyan
Zampal Oeste*
0.0
1.1
0.0
Total Cuyo
1.1
Neuquina
Bajada De Añelo*
Bajo Del Piche
Bajo Del Toro
Bandurria
Cañadón Amarillo
Cerro Bandera No Operada
Cerro Hamaca
Cerro Mollar Norte
El Medanito
El Orejano
La Ama rga Chica
Llancanelo
Loma Alta Sur
Loma Campana
Loma De La Mina
0.0
36.7
0.0
1.5
62.5
223.6
12.6
0.0
46.2
361.9
0.0
0.0
0.0
174.2
23.7
Loma La Lata Central
Loma La Lata Norte
13110.9
2814.4
Los Cavaos
Octógono
Pampa Palauco
Piedras Negras-Señal Lomita
Puesto Molina
Puesto Molina Norte
Punta Barda
Puntilla Del Huincan*
165.7
387.2
0.0
563.6
21.4
0.0
5.3
0.0
Rincón De l Mangrullo
3374.5
Señal Cerro Bayo
88.9
0.0
0.0
0.0
0.0
0.0
10.3
0.0
0.0
6.3
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.6
0.0
0.0
0.0
0.0
0.0
123.3
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
226.6
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
155.8
1.7
4170.3
457.2
0.0
349.7
0.0
0.0
55.1
0.0
12.1
0.0
2555.8
0.0
0.0
1.1
0.0
1.1
0.0
47.0
0.0
1.5
295.4
223.6
12.6
0.0
46.2
361.9
0.0
0.0
0.6
330.0
25.4
17281.2
3271.6
165.7
860.2
0.0
563.6
76.5
0.0
17.4
0.0
5930.3
88.9
Total Neuquina 21474.8
140.5
7984.3
29599.6
San Jorge
Cañadón Perdido*
Cañadón Vasco
Cerro Piedra-Cerro Guadal Norte
El Cordón
El Destino
El Trébol
Escalante
Pico Truncado
0.0
67.8
69.5
46.3
39.6
91.3
76.7
110.5
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
13.0
26.5
0.0
10.1
66.7
102.5
19.7
0.0
80.8
96.0
46.3
49.7
158.0
179.2
130.2
Total San Jorge
501.7
0.0
238.5
740.2
GRAND TOTAL
21977.6
140.5
8222.8
30340.9
*YPF has not assigned any reserves to these fields
[5]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
GROSS OIL (103m3)
PDP
(CDEP)
PDNP
(CDNP)
PUD
(CND)
TP
OIL VOLUMES
Entity
Cuyo
Ceferino
Rio Tunuyan
Zampal Oeste*
3.5
109.8
0.0
Total Cuyo
113.3
Neuquina
Bajada De Añelo*
Bajo Del Piche
Bajo Del Toro
Bandurria
Cañadón Amarillo
Cerro Bandera No Operada
Cerro Hamaca
Cerro Mollar Norte
El Medanito
El Orejano
La Ama rga Chica
Llancanelo
Loma Alta Sur
Loma Campana
Loma De La Mina
Loma La Lata Central
0.0
139.0
7.0
23.3
396.7
412.9
279.0
41.4
347.9
0.0
24.5
280.1
348.8
1476.7
124.6
28.2
Loma La Lata Norte
3403.4
Los Cavaos
Octógono
Pampa Palauco
Piedras Negras-Señal Lomita
Puesto Molina
Puesto Molina Norte
Punta Barda
Puntilla Del Huincan*
Rincón De l Mangrullo
Señal Cerro Bayo
292.9
323.0
175.9
0.0
296.3
4.3
282.0
0.0
0.0
774.7
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
1.6
0.0
0.0
0.0
0.0
26.4
0.0
0.0
0.0
0.0
18.4
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
320.4
23.3
190.8
0.0
0.0
0.0
0.0
373.2
170.3
1320.8
9.1
0.0
644.9
0.0
102.2
0.0
0.0
43.8
17.8
285.0
0.0
0.0
0.0
3.5
109.8
0.0
113.3
0.0
139.0
7.0
23.3
717.2
436.2
469.8
43.0
347.9
0.0
24.5
653.3
545.5
2797.5
133.7
28.2
4048.3
311.3
425.2
175.9
0.0
340.1
22.1
567.0
0.0
0.0
774.7
Total Neuquina 9482.6
46.4
3501.6
13030.7
San Jorge
Cañadón Perdido*
Cañadón Vasco
Cerro Piedra-Cerro Guadal Norte
El Cordón
El Destino
El Trébol
Escalante
Pico Truncado
0.0
83.7
164.0
216.7
397.0
2408.5
895.8
622.7
Total San Jorge 4788.4
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
113.4
48.3
500.5
229.6
1009.3
910.8
358.4
3170.3
0.0
197.2
212.3
717.2
626.5
3417.8
1806.6
981.1
7958.7
GRAND TOTAL
14384.3
46.4
6671.9
21102.7
*YPF has not assigned any reserves to these fields
[6]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CONDENSATE VOLUMES
GROSS CONDENSATE (103m3)
PDP
(CDEP)
PDNP
(CDNP)
PUD
(CND)
TP
Entity
Cuyo
Ceferino
Rio Tunuyan
Zampal Oeste*
0.0
0.0
0.0
Total Cuyo
0.0
Neuquina
Bajada De Añelo*
Bajo Del Piche
Bajo Del Toro
Bandurria
Cañadón Amarillo
Cerro Bandera No Operada
Cerro Hamaca
Cerro Mollar Norte
El Medanito
El Orejano
La Amarga Chica
Llancanelo
Loma Alta Sur
Loma Campana
Loma De La Mina
0.0
0.2
0.0
0.0
0.0
6.4
0.0
0.0
0.0
1.1
0.0
0.0
0.0
0.0
0.0
Loma La Lata Central
Loma La Lata Norte
1093.3
132.1
Los Cavaos
Octógono
Pampa Palauco
Piedras Ne gras-Seña l Lomita
Puesto Molina
Puesto Molina Norte
Punta Barda
Puntilla Del Huincan*
Rincón Del Mangrullo
Señal Cerro Bayo
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
96.4
0.0
0.0
0.0
0.0
0.0
0.0
1.1
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
289.9
16.6
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
73.0
0.0
0.0
0.0
0.0
0.0
0.0
1.3
0.0
0.0
0.0
6.4
0.0
0.0
0.0
1.1
0.0
0.0
0.0
0.0
0.0
1383.2
148.7
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
169.4
0.0
Total Neuquina 1329.5
1.1
379.5
1710.1
San Jorge
Cañadón Perdido*
Cañadón Vasco
Cerro Piedra-Cerro Guadal Norte
El Cordón
El Destino
El Trébol
Escalante
Pico Truncado
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Total San Jorge
0.0
GRAND TOTAL
1329.5
*YPF has not assigned any reserves to these fields
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
1.1
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
379.5
1710.1
[7]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
GROSS NGL (103m3)
PDP
(CDEP)
PDNP
(CDNP)
PUD
(CND)
TP
NGL VOLUMES
Entity
Cuyo
Ceferino
Rio Tunuyan
Zampal Oeste*
0.0
0.0
0.0
Total Cuyo
0.0
Neuquina
Bajada De Añelo*
Bajo Del Piche
Bajo Del Toro
Bandurria
Cañadón Amarillo
Cerro Bandera No Operada
Cerro Hamaca
Cerro Mollar Norte
El Medanito
El Orejano
La Amarga Chica
Llancanelo
Loma Alta Sur
Loma Campana
Loma De La Mina
Loma La Lata Central
Loma La Lata Norte
Los Cavaos
Octógono
Pampa Palauco
Piedras Negras-Seña l Lomita
Puesto Molina
Puesto Molina Norte
Punta Barda
Puntilla Del Huincan*
0.0
0.0
0.0
1.2
0.0
0.0
0.0
0.0
0.0
105.1
0.0
0.0
0.0
185.5
0.0
3023.8
1904.0
41.6
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Rincón Del Mangrullo
809.9
Señal Cerro Bayo
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
165.9
0.0
922.0
335.8
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
1.2
0.0
0.0
0.0
0.0
0.0
105.1
0.0
0.0
0.0
351.4
0.0
3945.8
2239.8
41.6
0.0
0.0
0.0
0.0
0.0
0.0
0.0
612.9
0.0
1422.8
0.0
Total Neuquina 6071.1
0.0
2036.6
8107.7
San Jorge
Cañadón Perdido*
Cañadón Vasco
Cerro Piedra-Cerro Guadal Norte
El Cordón
El Destino
El Trébol
Escalante
Pico Truncado
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Total San Jorge
0.0
GRAND TOTAL
6071.1
*YPF has not assigned any reserves to these fields
[8]
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
2036.6
8107.7
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
GASOLINE VOLUMES
GROSS GASOLINE (103m3)
PDP
(CDEP)
PDNP
(CDNP)
PUD
(CND)
TP
Entity
Cuyo
Ceferino
Rio Tunuyan
Zampal Oeste*
0.0
0.0
0.0
Total Cuyo
0.0
Neuquina
Bajada De Añelo*
Bajo Del Piche
Bajo Del Toro
Bandurria
Cañadón Amarillo
Cerro Bandera No Operada
Cerro Hamaca
Cerro Mollar Norte
El Medanito
El Orejano
La Ama rga Chica
Llancanelo
Loma Alta Sur
Loma Campana
Loma De La Mina
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Loma La Lata Central
280.1
Loma La Lata Norte
Los Cavaos
Octógono
Pampa Palauco
Piedras Negras-Señal Lomita
Puesto Molina
Puesto Molina Norte
Punta Barda
Puntilla Del Huincan*
Rincón De l Mangrullo
Señal Cerro Bayo
29.3
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
69.0
0.0
Total Neuquina 378.4
San Jorge
Cañadón Perdido*
Cañadón Vasco
Cerro Piedra-Cerro Guadal Norte
El Cordón
El Destino
El Trébol
Escalante
Pico Truncado
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Total San Jorge
0.0
GRAND TOTAL
378.4
*YPF has not assigned any reserves to these fields
[9]
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
85.4
4.1
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
52.3
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
365.5
33.4
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
121.2
0.0
141.8
520.1
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
141.8
520.1
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
It is our understanding that the Proved reserves estimated in this report as of December 31, 2015 constitute
approximately 26.8% of YPF’s Proved reserves. It is also our understanding that the Proved Undeveloped
reserves estimated in this report constitute approximately 27.8% of all YPF’s Proved Undeveloped reserves as
of December 31, 2015. These proportions are on a barrel oil equivalent (BOE) basis. IHS cannot directly verify
this statement as it was not requested to review YPF’s other oil and gas assets. Our study was completed on
February 17, 2016.
IHS’ audit of the YPF gross reserve estimates was based on decline curve analysis to extrapolate the
production of existing wells or generate type curves to estimate future production from the locations proposed
by YPF. Geological information, material balance, fluid laboratory tests, reservoir simulations, field
deliverability forecasts and other pertinent information was also used to assess the reserves estimates and the
classification/categorization of the proposed development plans.
This audit examination was based on gross reserve estimates and other information provided by YPF to IHS
through December 2015 and included such tests, procedures and adjustments as were considered necessary
under the circumstances to prepare the report. All questions that arose during the course of the audit process
were resolved to our satisfaction. There were no significant differences between IHS and YPF reserve
estimates.
The reserves tolerances, in respect to YPF reserves, are as follows:
•
7% or 10 million of oil equivalent barrels to Proved reserves (1P).
YPF is subject to extensive regulations relating to the oil and gas industry in Argentina which include specific
natural gas market regulations as well as hydrocarbon export taxes, all of which affect the realized prices of oil
and other products in the domestic market under certain circumstances. In addition, domestic prices for oil and
gas and its related by-products have demonstrated in recent years they do not follow international prices (both
in the down and upside), also considering the domestic economic variables which affect Argentina such as
labor costs, labor unions, political, economic and social constraints, among others. Accordingly, crude oil
prices used to determine reserves are set for crude oils of different quality produced by YPF, considering the
realized prices for crude oils of such quality in the domestic market.
[10]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
Additionally, a significant portion of the Argentine gas market is regulated. Natural gas prices for the
residential and power generation markets, as well as natural gas for vehicles, are regulated by the
government. Natural gas prices for industrial consumers are negotiated by market participants on a private
basis. As a result, there are no benchmark natural gas market prices available in Argentina. IHS reviewed and
accepted the prices used by YPF in estimating the reserves in Argentina.
Considering the mentioned decoupling between domestic and international oil and gas prices, and that
domestic crude oil sales prices in 2015 (and during the first months of 2016 until the date of this report) were
above the theoretical export parity price set by Law 26,732 (as a result of export taxes), YPF does not modify
prices for crude oil, condensate and gasoline until 2017 when export taxes expire according to current law.
The economic tests for the December 31, 2015 reserve volumes were based on realized crude oil,
condensate, NGL and average gas sales prices as shown in the following table, as provided by YPF. A prior
twelve-month average realized price for Medanito oil of US$ 75.03/BBL serves as the foundation for the oil,
condensate and gasoline price.
Cuyo
Ceferino
Rio Tunuyan
Zampal Oeste*
Neuquina
Bajada De Añelo*
Bajo Del Piche
Bajo Del Toro
Bandurria
Bandurria Sur
Cañadón Amarillo
Cerro Bandera No Operada
Cerro Hamaca
Cerro Mollar Norte
El Medanito
El Orejano
Crude Oil
Condensate
(US$/BBL)
NGL
(US$/BBL)
Natural Gas
(US$/MMBTU)
62.31
62.31
-
74.61
75.03
74.61
-
74.61
73.48
74.61
75.03
59.01
75.03
74.61
-
-
-
-
-
-
-
73.06
-
-
-
-
-
73.06
-
3.20
-
-
3.20
-
-
7.50
-
3.20
-
-
3.20
7.50
* YPF has not assigned any reserves to these fields
[11]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
Crude Oil
Condensate
NGL
(US$/BBL)
(US$/BBL)
Natural Gas
(US$/MMBTU)
Neuquina - cont’d. -
La Amarga Chica
Llancanelo
Loma Alta Sur
Loma Campana
Loma De La Mina
Loma La Lata Central
Loma La Lata Norte
Los Cavaos
Octógono
Pampa Palauco
Piedras Negras-Señal Lomita
Puesto Molina
Puesto Molina Norte
Punta Barda
Puntilla del Huincan*
Rincón del Mangrullo
Señal Cerro Bayo
San Jorge
Cañadón Perdido*
Cañadón Vasco
Cerro Piedra-Cerro Guadal Norte
El Cordón
El Destino
El Trébol
Escalante
Pico Truncado
74.61
59.01
59.01
74.61
59.01
74.61
74.61
59.01
74.61
59.01
75.03
73.48
73.48
75.03
-
74.61
75.03
61.21
62.21
62.21
62.21
62.21
61.21
61.21
62.21
-
-
-
73.06
-
73.06
73.06
73.06
-
-
-
-
-
-
-
73.06
-
-
-
-
-
-
-
-
-
-
-
-
7.50
-
7.50
7.50
3.20
3.20
-
3.20
-
-
3.20
-
7.50
-
-
-
5.83
5.83
-
5.83
5.83
-
* YPF has not assigned any reserves to these fields
Future capital costs were derived from development program forecasts prepared by YPF for the fields which
were summarized in economic summary tables that were provided for the reserve audit. Recent historical
operating expense data were utilized as the basis for operating cost projections and was incorporated by YPF
in their economic summary tables. IHS has determined that YPF has projected sufficient capital investments
and operating expenses to economically produce the projected volumes.
IHS has reviewed the gross estimates of total remaining recoverable hydrocarbon liquid and gas volumes at
December 31, 2015 based on information available as at December 31, 2015.
[12]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
It is IHS’ opinion that the estimates of total gross remaining recoverable hydrocarbon liquid and gas volumes
at December 31, 2015, evaluated as at December 31, 2015 are, in the aggregate, reasonable and the
reserves categorization is appropriate and consistent with the definitions for reserves set out in 17-CFR Part
210 Rule 4-10(a) of Regulation S-X of the United States Securities and Exchange Commission (as set out in
Appendix II). IHS concludes that the methodologies employed by YPF in the determination of the volume
estimates are appropriate and that the quality of the data relied upon, the depth and thoroughness of the
estimation process is adequate.
IHS is not aware of any potential changes in regulations applicable to these fields that could affect the ability
of YPF to produce the estimated reserves.
This assessment has been conducted based on IHS’ understanding of YPF’s petroleum property rights as
represented by YPF’s management. IHS is not in a position to attest to property title, financial interest
relationships or encumbrances thereon for any part of the appraised properties or interests.
There are numerous uncertainties inherent in estimating reserves and resources, and in projecting future
production, development expenditures, operating expenses and cash flows. Oil and gas reserve engineering
and resource assessment must be recognized as a subjective process of estimating subsurface
accumulations of oil and gas that cannot be measured in an exact way. Estimates of oil and gas reserves or
resources prepared by other parties may differ, perhaps materially, from those contained within this report.
The accuracy of any reserve or resource estimate is a function of the quality of the available data and of
engineering and geological interpretation. Results of drilling, testing and production that post-date the
preparation of the estimates may justify revisions, some or all of which may be material. Accordingly, reserve
and resource estimates are often different from the quantities of oil and gas that are ultimately recovered, and
the timing and cost of those volumes that are recovered may vary from that assumed.
For this assignment, IHS served as independent reserve auditors. The firm’s officers and employees have no
direct or indirect interest holdings in the properties evaluated. IHS’ remuneration was not in any way
contingent on reported reserve estimates. The qualifications of the technical person primarily responsible for
overseeing this audit and staff members involved in the audit are included in this report.
This report has been prepared at the request of YPF regarding assets it holds in Argentina and is for inclusion
in YPF’s filings with the United States Securities and Exchange Commission.
[13]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
YPF will obtain IHS’ prior written or email approval for the use with third parties and context of the use with
third parties of any results, statements or opinions expressed by IHS to YPF, which are attributed to IHS. Such
requirement of approval shall include, but not be confined to, statements or references in documents of a
public or semi-public nature such as loan agreements, prospectuses, reserve statements, websites, press
releases, etc.
Yours truly,
IHS Global Canada Limited
Dale Struksnes, B. Comm., CMA, C.E.T.
Director, Consulting
Jason Wilhelm, P. Eng.
Senior Principal Engineer, Consulting
[14]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
TABLE OF CONTENTS
LETTER OF TRANSMITTAL
TABLE OF CONTENTS
CERTIFICATES OF QUALIFICATION
LIMITATIONS OF REPORT
RESERVE DEFINITIONS
STANDARD OIL INDUSTRY TERMS AND ABBREVIATIONS
[15]
Page
2
15
16
33
35
38
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Maria Tjoa, E.I.T.
I, Maria Tjoa, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation dated
February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Dalhousie, Halifax, Nova Scotia with a Bachelor in Engineering in
Electrical with Computer Engineering, in 2003. I am an engineer-in-training and have in excess of 9 years
experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Maria Tjoa, E.I.T.
Senior Engineer - Consulting
[16]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Carmen M. Bujor, P. Eng.
I, Carmen M. Bujor, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation
dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Bucharest, Romania with a B.Sc. in Chemical Engineering in 1986, and
have in excess of 19 years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Carmen M. Bujor
Principal Engineer - Consulting
[17]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Robert V. Coles
I, Robert V. Coles, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation
dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the Technical University of Nova Scotia with a Bachelor of Engineering (Mining
Engineering) in 1981 and have in excess of 34 years experience in reservoir engineering, business
development and property evaluation the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Robert V. Coles
Principal Engineer - Consulting
[18]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Dale Struksnes, B. Comm, CMA, C.E.T.
I, Dale Struksnes, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation
dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the Southern Alberta Institute of Technology with an Honours Diploma in Petroleum
Technology in 1988 and have in excess of 27 years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Dale Struksnes
Director - Consulting
[19]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Robert Henderson, P. Eng.
I, Robert Henderson, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation
dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Alberta with a B.Sc. in Mining Engineering in 1984 and have in excess of
29 years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Robert Henderson, P. Eng.
Senior Principal Engineer - Consulting
[20]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Jared Ponto, E.I.T.
I, Jared Ponto, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation dated
February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Alberta with a B.Sc. in Petroleum Engineering in 2012 and have in
excess of 3 years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Jared Ponto, E.I.T.
Principal Engineer - Consulting
[21]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Kristina Epp, P.Eng.
I, Kristina Epp, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation dated
February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Alberta with a B.Sc. in Petroleum Engineering in 2008 and have in
excess of 7 years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Kristina Epp, P.Eng.
Principal Engineer - Consulting
[22]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Ivan Olea, M.Sc.
I, Ivan Olea, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation dated
February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Calgary with a M.Sc. in Mechanical Engineering in 2006, from the
National Autonomous University of Mexico with a B.Sc. in Petroleum Engineering in 2002 and have in
excess of 12 years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Ivan Olea, M.Sc.
Senior Engineer - Consulting
[23]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Mohammad Tavallali, Ph.D., P.Eng.
I, Mohammad Tavallali, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG
evaluation dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Calgary with a Ph.D. in Petroleum Engineering in 2012, Tarbiat Modares
University in Tehran with a M.Sc. in Chemical and Petroleum Engineering in 2004, from the Abadan
Institute of Technology in Iran with a B.Sc. in Chemical Engineering in 2001 and have in excess of 11
years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Mohammad Tavallali, Ph.D., P.Eng.
Senior Engineer - Consulting
[24]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Zhongdong (Don) Xu, P.Eng.
I, Zhongdong (Don) Xu, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG
evaluation dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the China University of Petroleum with a B.Sc. in Reservoir Engineering in 1991 and have
in excess of 24 years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Zhongdong (Don) Xu, P.Eng.
Principal Engineer - Consulting
[25]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
José Inciarte, P.Eng.
I, José Inciarte, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation
dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the Instituto Universitario Santiago Mariño, Cabimas, Venezuela, with a B.Sc. in
Petroleum Engineering in 2002 and have in excess of 9 years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
José Inciarte, P.Eng.
Principal Engineer - Consulting
[26]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Hamed Tabatabaie, Ph.D., P.Eng.
I, Hamed Tabatabaie, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG
evaluation dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Calgary with a Ph.D. in Petroleum Engineering in 2014 and have in
excess of 3 years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Hamed Tabatabaie, Ph.D., P.Eng.
Principal Engineer - Consulting
[27]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Jason K. Wilhelm, P. Eng.
I, Jason K. Wilhelm, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation
dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Saskatchewan with a B.Sc. in Chemical Engineering in 1996 and have in
excess of 19 years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Jason K. Wilhelm, P. Eng.
Senior Principal Engineer - Consulting
[28]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Norbert K. Alwast, P. Geol.
I, Norbert K. Alwast, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation
dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Calgary with a B.Sc. in Geology in 1986. I have in excess of 29 years
experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Norbert K. Alwast, P. Geol.
Senior Principal Geologist - Consulting
[29]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Michael G. Muirhead, P. Geol.
I, Michael G. Muirhead, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG
evaluation dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of British Columbia with a B.Sc. in Geology. I completed my degree in 1991
and have in excess of 24 years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Michael G. Muirhead, P. Geol.
Principal Geologist - Consulting
[30]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
John B. Hughes, P. Geol.
I, John B. Hughes, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation
dated February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Calgary with a B.Sc. in Geology in 1972 and have in excess of 43 years
experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
John B. Hughes, P. Geol.
Senior Principal Geologist - Consulting
[31]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
CERTIFICATE OF QUALIFICATION
Lisa Dean, P. Geol.
I, Lisa Dean, an employee of IHS Global Canada Limited, and co-author of the SEC P&NG evaluation dated
February 17, 2016 prepared for YPF S.A., do hereby certify that:
• I graduated from the University of Calgary with a B.Sc. in Earth Sciences in 1992 and have in excess of 23
years experience in the Petroleum Industry.
• I have no interest, directly or indirectly, in YPF S.A. nor in the properties evaluated, nor do I expect to
obtain any interest, directly or indirectly in the Company, or the properties evaluated, nor in the securities of
the Company.
• A personal field inspection of the properties was not made; however, such an inspection was not
considered necessary in view of public information and records, the files of YPF S.A., and the appropriate
regulatory authorities.
Lisa Dean, P.Geol.
Director - Geosciences
[32]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
LIMITATIONS OF REPORT
All factual data supplied by or obtained from the files of YPF S.A., were accepted as correct.
A field inspection was not considered necessary by IHS Global Canada Limited.
It should be understood that our audit does not constitute a complete reserves study. In the conduct of our
examination, we have not independently verified the accuracy and completeness of all the information and
data furnished by your Company with respect to ownership interest or oil and gas production. We have,
however, specifically identified to you the information and data upon which we relied. Furthermore, if in the
course of our examination, something came to our attention that brought into question the validity or
sufficiency of any of the information or data, we did not rely on that information or data until we had
satisfactorily resolved our questions or independently verified it.
The analyses, interpretations and opinions expressed in this report reflect the best judgement of IHS Global
Canada Limited. Due to the inherent risks associated with the petroleum business, IHS Global Canada Limited
assumes no responsibility and makes no warranty whatsoever in connection with the information, analyses,
interpretations and opinions presented herein.
The IHS reports and information referenced herein (the “IHS Materials”) have been prepared for the exclusive
use of YPF S.A. and for the information and assistance of its independent public accountants and financial
lenders in connection with their review of, and report upon, the financial statements of your company. They
are the copyrighted property of IHS Global Canada Limited (“IHS”) and represent data, research, opinions or
viewpoints published by IHS, and are not representations of fact. The IHS Materials speak as of the original
publication date thereof (and not as of the date of this document). The information and opinions expressed in
the IHS Materials are subject to change without notice and IHS has no duty or responsibility to update the IHS
Materials. Moreover, while the IHS Materials reproduced herein are from sources considered reliable, the
accuracy and completeness thereof are not warranted, nor are the opinions and analyses which are based
upon it. To the extent permitted by law, IHS shall not be liable for any errors or omissions or any loss, damage
or expense incurred by reliance on the IHS Materials or any statement contained herein, or resulting from any
omission.
[33]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
No portion of the IHS Materials may be reproduced, reused, or otherwise distributed in any form without the
prior written consent of IHS. Content reproduced or redistributed with IHS’ permission must display IHS’ legal
notices and attributions of authorship. IHS and the IHS globe design are trademarks of IHS. Other trademarks
appearing in the IHS Materials are the property of IHS or their respective owners.”
[34]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
U.S. SECURITIES AND EXCHANGE COMMISSION (SEC)
MODERNIZATION OF OIL AND GAS REPORTING
As requested by YPF S.A., the Proved Reserve definition used in this report is in accordance with the Reserve Definitions
of Rules 210-4-10(a) of Regulation S-X of the Securities Exchange Commission (SEC) as amended by the SEC
“Modernization of Oil and Gas Reporting – Final Rule” published January 14, 2009.
SEC DEFINITIONS FOR OIL AND GAS RESERVES
Proved oil and gas reserves – Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of
geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a
given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government
regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that
renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation.
The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will
commence the project within a reasonable time.
(i)
The area of the reservoir considered as proved includes:
(A) The area identified by drilling and limited by fluid contacts, if any, and
(B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous
with it and to contain economically producible oil or gas on the basis of available geoscience and engineering
data.
(ii)
In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known
hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and
reliable technology establishes a lower contact with reasonable certainty.
(iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the
potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher
portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish
the higher contact with reasonable certainty.
(iv) Reserves which can be produced economically through application of improved recovery techniques (including,
but not limited to, fluid injection) are included in the proved classification when:
(A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the
reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other
evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which
the project or program was based; and
(B) The project has been approved for development by all necessary parties and entities, including
governmental entities.
(v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be
determined. The price shall be the average price during the 12-month period prior to the ending date of the
period covered by the report, determined as an unweighted arithmetic average of the first- day-of-the-month
price for each month within such period, unless prices are defined by contractual arrangements, excluding
escalations based upon future conditions.
Probable oil and gas reserves – Probable reserves are those additional reserves that are less certain to be recovered
than proved reserves but which, together with proved reserves, are as likely as not to be recovered.
[35]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
(i) When deterministic methods are used, it is as likely as not that actual remaining quantities recovered will
exceed the sum of estimated proved plus probable reserves. When probabilistic methods are used, there
should be at least a 50% probability that the actual quantities recovered will equal or exceed the proved plus
probable reserves estimates.
(ii) Probable reserves may be assigned to areas of a reservoir adjacent to proved reserves where data control or
interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or
productivity does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that
are structurally higher than the proved area if these areas are in communication with the proved reservoir.
(iii) Probable reserves estimates also include potential incremental quantities associated with a greater percentage
recovery of the hydrocarbons in place than assumed for proved reserves.
(iv) See also guidelines in paragraphs (iv) and (vi) of the definition of possible reserves.
Possible oil and gas reserves – Possible reserves are those additional reserves that are less certain to be recovered
than probable reserves.
(i) When deterministic methods are used, the total quantities ultimately recovered from a project have a low
probability of exceeding proved plus probable plus possible reserves. When probabilistic methods are used,
there should be at least a 10% probability that the total quantities ultimately recovered will equal or exceed the
proved plus probable plus possible reserves estimates.
(ii) Possible reserves may be assigned to areas of a reservoir adjacent to probable reserves where data control
and interpretations of available data are progressively less certain. Frequently, this will be in areas where
geoscience and engineering data are unable to define clearly the area and vertical limits of commercial
production from the reservoir by a defined project.
(iii) Possible reserves also include incremental quantities associated with a greater percentage recovery of the
hydrocarbons in place than the recovery quantities assumed for probable reserves.
(iv) The proved plus probable and proved plus probable plus possible reserves estimates must be based on
reasonable alternative technical and commercial interpretations within the reservoir or subject project that are
clearly documented, including comparisons to results in successful similar projects.
(v) Possible reserves may be assigned where geoscience and engineering data identify directly adjacent portions
of a reservoir within the same accumulation that may be separated from proved areas by faults with
displacement less than formation thickness or other geological discontinuities and that have not been
penetrated by a wellbore, and the registrant believes that such adjacent portions are in communication with the
known (proved) reservoir. Possible reserves may be assigned to areas that are structurally higher or lower than
the proved area if these areas are in communication with the proved reservoir.
(vi) Pursuant to paragraph (iii) of the proved oil and gas definition, where direct observation has defined a highest
known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves should be
assigned in the structurally higher portions of the reservoir above the HKO only if the higher contact can be
established with reasonable certainty through reliable technology. Portions of the reservoir that do not meet this
reasonable certainty criterion may be assigned as probable and possible oil or gas based on reservoir fluid
properties and pressure gradient interpretations.
Developed oil and gas reserves – Developed oil and gas reserves are reserves of any category that can be expected to
be recovered:
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SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
(i)
Through existing wells with existing equipment and operating methods or in which the cost of the required
equipment is relatively minor compared to the cost of a new well; and
(ii) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the
extraction is by means not involving a well.
Undeveloped oil and gas reserves – Undeveloped oil and gas reserves are reserves of any category that are expected
to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is
required for recompletion.
(i) Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are
reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes
reasonable certainty of economic producibility at greater distances.
(ii) Undrilled locations can be classified as having undeveloped reserves only if a development plan has been
adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances
justify a longer time.
(iii) Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an
application of fluid injection or other improved recovery technique is contemplated, unless such techniques
have been proved effective by actual projects in the same reservoir or an analogous reservoir, as defined in
[section 210.4–10 (a) Definitions], or by other evidence using reliable technology establishing reasonable
certainty.
[37]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
STANDARD OIL INDUSTRY TERMS AND ABBREVIATIONS
oAPI
B
BBL
/BBL
BSCF or BCF
or BCFD
Bm3
BHP
BPD
BOE
BOEPD
BOPD
BWPD
BTU
Cp
Deg C
Deg F
DST
E&P
EOR
EUR
FDP
Ft
G&A
GIP
GJ
GOR
GWC
IRR
k
KB
km
LKG
LKH
LKO
LNG
m
M
m3
MCF or MSCF
MMCF or MMSCF
m3/d
mD
MD
Mean
Median
MFT
Mm3
Mm3/d
Degrees API (American Petroleum Institute)
Billion (109)
Barrels
per barrel
Billion standard cubic feet BSCFD
Billion standard cubic feet per day
Billion cubic metres
Bottomhole pressure
Barrels per day
Barrels of oil equivalent @ xxx MSCF/BBL
Barrels of oil equivalent per day@ xxx MSCF/BBL
Barrels of oil per day
Barrels of water per day
British Thermal Units
Centipoise (a measure of viscosity)
Degrees Celsius
Degrees Fahrenheit
Drillstem Test
Exploration and Production
Enhanced Oil Recovery
Estimated Ultimate Recovery
Field Development Plan
Foot/feet
General and Administrative Costs
Gas Initially In-Place
Gigajoules (one billion Joules)
Gas/Oil Ratio
Gas/Water Contact
Internal Rate of Return
Permeability
Kelly Bushing
Kilometres
Last Known Gas
Last Known Hydrocarbons
Last Known Oil
Liquefied Natural Gas
Metres
Thousand
Cubic Metres
Thousand Standard Cubic Feet
Million Standard Cubic Feet
Cubic Metres per day
Measure of Permeability in millidarcies
Measured Depth
Arithmetic average of a set of numbers
Middle value in a set of values
Multi Formation Tester
Thousand Cubic Metres
Thousand Cubic Metres per day
[38]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
STANDARD OIL INDUSTRY TERMS AND ABBREVIATIONS
Page 2 of 3
MM
MMBBL
MMBTU
Mode
MSCFD
MMSCFD
NGL
NPV
OPEX
OWC
Pa
P&A
psi
psia
psig
PVT
P10
P50
P90
Rf
RT
Rw
SCAL
CF or SCF
CFD or SCFD
SL
so
SPE
SPEE
ss
STB
STOIIP
sw
T
TD
TSCF or TCF
TOC
TVD
TVDss
US$
WC
WI
WTI
2D
3D
4D
%
Million
Millions of Barrels
Millions of British Thermal Units
Value that exists most frequently in a set of values = most likely
Thousand Standard Cubic Feet per day
Million Standard Cubic Feet per day
Natural Gas Liquids
Net Present Value
Operating Expenditure
Oil/Water Contact
Pascals (metric measurement of pressure)
Plugged and Abandoned
Pounds per Square Inch
Pounds per Square Inch Absolute
Pounds per Square Inch Gauge
Pressure Volume Temperature
10% Probability
50% Probability
90% Probability
Recovery Factor
Rotary Table
Resistivity of Water
Special Core Analysis
Standard Cubic Feet
Standard Cubic Feet per day
Straight Line (for depreciation)
Oil Saturation
Society of Petroleum Engineers
Society of Petroleum Evaluation Engineers
Subsea
Stock Tank Barrel
Stock Tank Oil Initially in-place
Water Saturation
Tonnes
Total Depth
Trillion Standard Cubic Feet
Total Organic Carbon
True Vertical Depth
True Vertical Depth Subsea
United States Dollar
Watercut
Working Interest
West Texas Intermediate
Two Dimensional
Three Dimensional
Four Dimensional
Percentage
[39]
SEC Reserves Audit of Certain P&NG Interests of YPF S.A. in Argentina as of December 31, 2015
STANDARD OIL INDUSTRY TERMS AND ABBREVIATIONS
Page 3 of 3
Reserve Classifications
PDP
PDNP
PO
PR
PUD
TP
TPP
TPPP
1P
2P
3P
Proved Developed Producing
Proved Developed Non-Producing
Possible
Probable
Proved Undeveloped
Proved
Total Proved Plus Probable
Total Proved Plus Probable Plus Possible
Proved Reserves
Proved Plus Probable Reserves
Proved Plus Probable Plus Possible Reserves
[40]