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, 2013
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) 5441-5531
Facsimile Number: (011-54-11) 5441-2113
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, 2013 was:
Class A Shares
Class B Shares
Class C Shares
3,764
7,624
40,422
Class D Shares
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:2)
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
No
⌧
(cid:2)
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:2)
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
(cid:2)
the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes
No
(cid:2)
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:2)
Non-accelerated filer
(cid:2)
Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:
(cid:2)
U.S. GAAP
International Financial Reporting Standards as issued by the
International Accounting Standards Board:
⌧
(cid:2)
Other
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
No
⌧
(cid: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
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 Income Statement
Factors Affecting Our Operations
Critical Accounting Policies
Principal Income Statement Line Items
Results of Operations
Liquidity and Capital Resources
Off-Balance Sheet Arrangements
Research and Development, Patents and Licenses, etc.
ITEM 6. Directors, Senior Management and Employees
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
2
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150
ITEM 9. The Offer and Listing
Shares and ADSs
Argentine Securities Market
ITEM 10. Additional Information
Capital Stock
Memorandum and Articles of Association
Directors
Foreign Investment Legislation
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
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
3
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169
169
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177
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 balance
sheets as of December 31, 2013, 2012 and 2011, YPF’s audited consolidated statements of comprehensive income for the years ended
December 31, 2013, 2012 and 2011, YPF’s audited consolidated statements of cash flows for the years ended December 31, 2013,
2012 and 2011, YPF’s audited consolidated statements of changes in shareholders’ equity for the years ended December 31, 2013,
2012 and 2011, 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, 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 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” below 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.
4
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, and natural gas liquids (“NGL”).
“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 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.
Abbreviations:
“bbl”
“bcf”
“bcm”
“boe”
“boe/d”
“cm”
“dam 3”
“GWh”
“HP”
“km”
“km2”
“liquids”
“LNG”
“LPG”
“m”
“m3”
“mbbl/d”
“mcf”
“mcm”
“mboe/d”
“mm”
“mmbbl”
Barrels.
Billion cubic feet.
Billion cubic meters.
Barrels of oil equivalent.
Barrels of oil equivalent per day.
Cubic meters.
Dekameters cubic (thousand cubic meters).
Gigawatt hours.
Horsepower.
Kilometers.
Square kilometers.
Crude oil, condensate and natural gas liquids.
Liquefied natural gas.
Liquefied petroleum gas.
Thousand.
Cubic meter
Thousand barrels per day.
Thousand cubic feet.
Thousand cubic meters.
Thousand barrels of oil equivalent per day.
Million.
Million barrels.
5
“mmboe”
“mmboe/d”
“mmBtu”
“mmcf”
“mmcf/d”
“mmcm/d”
“mtn”
“MW”
“psi”
“WTI”
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 per day.
Thousand tons.
Megawatts.
Pound per square inch.
West Texas Intermediate.
6
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”).
On March 20, 2009, the Argentine Federation of Professional Councils in Economic Sciences (“FACPCE”) approved Technical
Resolution No. 26 on the “Adoption of the International Financial Reporting Standards (IFRS) of the International Accounting
Standards Board (IASB)”. Such resolution was approved by the Argentine National Securities Commission (“CNV”) through General
Resolution No. 562/09 on December 29, 2009 (modified by General Resolution No. 576/10 on July 1, 2010), with respect to certain
publicly-traded entities subject to Law No. 26,831. Compliance with such rules was mandatory for YPF for the fiscal year which
began on January 1, 2012, with transition date of January 1, 2011.
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, 2013 have been translated into U.S. dollars at the exchange rate quoted by the Argentine Central Bank (Banco Central
de la República Argentina or “Central Bank”) on December 31, 2013 of Ps.6.52 to U.S.$1.00, unless otherwise specified. The
exchange rate quoted by the Central Bank on March 25, 2014 was Ps 8.00 to U.S.$1.00. The U.S. dollar equivalent information
should not be construed to imply that the peso amounts represent, or could have been or could be converted into U.S. dollars at such
rates or any other rate. See “—Exchange Rates.”
7
The financial data contained in this annual report as of December 31, 2013, 2012 and 2011 and for the years then ended has been
derived from our Audited Consolidated Financial Statements included in this annual report. See Note 14 to the Audited Consolidated
Financial Statements.
Consolidated Statement of Comprehensive Income
Data(1) :
Revenues(2)
Gross profit
Administrative expenses
Selling expenses
Exploration expenses
Other income/(expense), net
Operating income
Income/(Loss) on long-term investments
Interest expense
Other financial income/(expense), net
Income from sale of long-term investments
Reversal/(impairment) of other current assets
Income before income tax
Income tax
Deferred tax
Net income
Total other Comprehensive income
Total Comprehensive income
Earnings per share and per ADS(4)
Dividends per share and per ADS(4) (in pesos)
Dividends per share and per ADS(4)(5) (in U.S. dollars)
Consolidated Balance Sheet Data(1):
Cash
Working capital(3)
Total assets
Total debt(6)
Shareholders’ equity(7)
Other Consolidated Financial Data:
Fixed assets depreciation
Cash used in fixed asset acquisitions
2013
(in millions of
U.S.$, except for
per share and
per ADS data)
As of and for the year ended December 31,
2011
2012
2013
(in millions of pesos, except
for per share and per ADS data)
13,825
3,305
(412)
(1,161)
(127)
108
1,712
54
(588)
1,023
—
—
2,201
(436)
(985)
779
1,846
2,625
2.00
n.a.
n.a.
1,644
262
20,803
4,893
7,401
1,754
4,240
90,113
21,542
(2,686)
(7,571)
(829)
704
11,160
353
(3,833)
6,668
—
—
14,348
(2,844)
(6,425)
5,079
12,031
17,110
13.05
0.83
0.13
10,713
1,706
135,595
31,890
48,240
67,174
16,907
(2,232)
(5,662)
(582)
(528)
7,903
114
(1,557)
2,105
—
—
8,565
(2,720)
(1,943)
3,902
4,241
8,143
9.92
0.77
0.16
4,747
(2,582)
79,949
17,104
31,260
56,211
15,068
(1,822)
(5,438)
(574)
(46)
7,188
685
(1,045)
758
—
—
7,586
(2,495)
(646)
4,445
1,852
6,297
11.30
14.15
3.39
1,112
(7,750)
60,990
12,198
23,420
11,433
27,639
8,281
16,403
6,499
12,156
(1) The consolidated financial statements reflect the effect of the application of the functional and reporting currency. See Note
1.b.1) to the Audited Consolidated Financial Statements.
(2) Revenues are net to us after 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 2.k) 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.16) to the Audited Consolidated Financial Statements.
(3) Working Capital consists of Total Current Assets minus Total Current Liabilities as of December 31, 2013, December 31, 2012
(4)
and December 31, 2011.
Information has been calculated based on 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 payment.
(6) Total loans includes non-current loans of Ps. 23,076 million, Ps.12,100 million and Ps.4,435 million as of December 31, 2013,
2012 and 2011, respectively, and current loans of Ps. 8,814 million, Ps.5,004 million and Ps.7,763 million as of December 31,
2013, 2012 and 2011, respectively. See “Financial Risk Management–Liquidity Risk” in Note 1.d) to the Audited Consolidated
Financial Statements.
8
(7) Our subscribed capital as of December 31, 2013 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 additionally “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
assigned as a result of our employee compensation plans.
Exchange Rates
From April 1, 1991 until the end of 2001, the Convertibility Law (Law No. 23,928) established a fixed exchange rate under
which the Central Bank was obligated 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, or the “Public Emergency Law”),
formally putting an end to the Convertibility Law regime and abandoning over 10 years of U.S. dollar-peso parity. The Public
Emergency Law, which has been extended until December 31, 2015 by Law 26,896, 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 Argentine peso has recently been subject to devaluation (approximately 23% during January 2014). The Argentine
government is analyzing certain measures in response to such devaluation and the impact on the rest of the economy, including
inflation. See “Risks 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,
2009
2010
2011
2012
2013
Month
September 2013
October 2013
November 2013
December 2013
January 2014
February 2014
March 2014 (2)
Source: Central Bank
Low
High
Average
(pesos per U.S. dollar)
Period End
3.45
3.79
3.97
4.30
4.92
5.68
5.80
5.92
6.15
6.54
7.76
7.87
3.85
3.99
4.30
4.92
6.52
5.79
5.91
6.14
6.52
8.02
8.02
7.97
3.75(1)
3.92(1)
4.15(1)
4.58(1)
5.54(1)
5.74(1)
5.85(1)
6.01(1)
6.32(1)
7.10(1)
7.86(1)
7.90(1)
3.80
3.98
4.30
4.92
6.52
5.79
5.91
6.14
6.52
8.02
7.88
7.97
(1) Represents the average of the exchange rates on the last day of each month during the period.
(2) Through March 21, 2014.
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.
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.
9
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. Since January 2003, the Central Bank has gradually eased these restrictions
and expanded the list of transfers of funds abroad that do not require its prior authorization (including the transfer of funds to pay
dividends). 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. Under the exchange regulations currently in force, restrictions exist in
respect of the repatriation of funds or investments by non-Argentine residents. For instance, subject only to limited exceptions, 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 a limit of U.S.$500,000 per person per calendar month. In order to repatriate such funds abroad, non-Argentine residents
also are required to demonstrate that the funds used to make the investment in the Class D shares were transferred to Argentina at
least 365 days before the proposed repatriation. 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.
During 2012, additional foreign exchange regulations were imposed on purchases of foreign currency and transfers of foreign
currency abroad. Such regulations include the requirement for financial institutions to inform in advance and obtain approval from the
Central Bank with respect to any foreign exchange transaction to be entered into through the foreign exchange market. See “—Risk
Factors—Risks Relating to Argentina—We are subject to exchange and capital controls.”
The risks and uncertainties described below are not the only risks and uncertainties that we face. Additional risks and uncertainties
that are unknown to us or that we currently think are immaterial also may impair our business operations or our ability to make
payments on the notes and under other existing or future indebtedness.
Risk Factors
Risks Relating to Argentina
The Argentine federal government will control the Company according to domestic energy policies in accordance with Law 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, such occurrence 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.
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. Since the most recent crisis of 2001 and 2002, Argentina’s gross
domestic product, or GDP, grew at an average annual real rate of approximately 8.5% from 2003 to 2008, although the growth rate
decelerated to 0.9% in 2009 as a result of the global financial crisis, but recovered in 2010 and 2011, growing at an annual real rate of
approximately 9%, according to preliminary official data. In 2012, the Argentine economy experienced a slowdown with GDP
increasing at a rate of 1.9% on an annualized basis compared to the preceding year. 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 for 2013
was revised from 4.9% to 3%. 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. In addition, the Argentine peso has recently been subject to devaluation
(approximately 23% during January 2014). 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.
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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;
levels of consumer consumption and foreign and domestic investment and financing; and
the rate of inflation.
The Argentine peso has recently been subject to devaluation (approximately 23% during January 2014). The Argentine
government is analyzing certain measures in response to such devaluation and the impact on the rest of the economy, including
inflation. In addition, Argentina has confronted inflationary pressures. According to inflation data published by the National Statistics
Institute (Instituto Nacional de Estadística y Censos, 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; the wholesale price index increased 8.8%, 10.3%, 14.5%, 12.7%
13.1% and 14.7% , respectively. However, certain private sector analysts usually quoted by the government opposition, based on
methodologies being questioned by the Argentine government on the basis of the lack of technical support, believe that actual
inflation was significantly higher than that reflected in INDEC reports according to the methodology prevailing for such reports until
December 2013. In 2014, the Argentine government established a new consumer price index (“IPCNU”) which more broadly reflects
consumer prices by considering price information from the 24 provinces of the country, divided into six regions. According to the
IPCNU, inflation for each of January and February 2014 was 3.7% and 3.4%, respectively. Increased rates of inflation in Argentina
could increase our cost of operation, and may negatively impact our results of operations and financial condition. There can be no
assurance that inflation rates will not be higher in the future.
In addition, Argentina’s economy is vulnerable to adverse developments affecting its principal trading partners. A significant
decline in the economic growth of any of Argentina’s major trading partners, such as Brazil, 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 depreciation 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.
Furthermore, in 2005, Argentina successfully restructured a substantial portion of its bond indebtedness and settled all of its debt
with the IMF. In June 2010, Argentina completed the renegotiation of approximately 67% of the defaulted bonds that were not
swapped in 2005. As a result of the 2005 and 2010 debt swaps, approximately 91% of the bond indebtedness on which Argentina had
defaulted in 2002 was restructured. Certain bondholders did not participate in the restructuring and instead sued Argentina for
payment. In late October 2012, the United States Court of Appeals for the Second Circuit rejected an appeal by Argentina concerning
payments allegedly due on bonds that had not been the subject of the swaps in 2005 and 2010. On November 21, 2012, the United
States District Court for the Southern District of New York ordered Argentina to make a deposit of U.S.$1,330 million for payment to
the holdout bondholders. Argentina appealed the District Court’s November 21 order to the Second Circuit Court of Appeals, which
granted Argentina’s request for a stay of the order. On March 19, 2013, Argentina submitted to the Second Circuit a proposed
payment plan for holdout bondholders. That proposal was rejected by the plaintiff holdout bondholders on April 19, 2013. 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 Supreme Court of the United States.
On September 3, 2013, the District Court granted plaintiff holdout bondholders’ requests for discovery from Argentina and
certain financial institutions concerning, among other things, Argentina’s assets and the relationship between Argentina and YPF. In
January 2014, the United States Supreme Court accepted an appeal by Argentina concerning the permissible scope of discovery into
its assets. Litigation initiated by holdout bondholders has resulted, and may result, in material judgments against Argentina and could
result in attachments of or injunctions relating to assets of or deemed owned by Argentina. Such attachments or injunctions could
have a material adverse effect on the country’s economy and also affect our ability to access international financing or repay our
obligations.
For additional information related to the evolution of the Argentine economy see “Item 5 – Operating and Financial Review and
Prospects—Macroeconomic Conditions.”
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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.
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. Resolution
394/2007 of the Ministry of Economy and Production, published on November 16, 2007, amended the export duties on crude oil and
other crude derivative products imposed in previous years. In addition, the Resolution No. 1/2013 from the Ministry of Economy,
published on January 3, 2013, modified the reference and floor prices. The regime provides that when the WTI international price
exceeds the reference price, which is fixed at U.S.$80/barrel, the producer shall be allowed to collect at U.S.$70/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 will apply. If such price is under U.S.$45/barrel, the applicable export tax is to be
determined by the Argentine government within a term of 90 business days. The withholding rate determined as indicated above also
currently applies to diesel fuel, gasoline and other crude derivative products. In addition, the calculation procedure described above also
applies to other petroleum products and lubricants based upon different withholding rates, reference prices and prices allowed to
producers. See “Item 4. Information on the Company—Regulatory Framework and Relationship with the Argentine Government—
Market Regulation.” With respect to natural gas products, Resolution No. 127/2008 of the Ministry of Economy and Production
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. Resolution No. 127/2008 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/m3 for propane, U.S.$393/m3 for butane and U.S.$363/m3 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/m3 for propane, U.S.$271/m3 for butane and U.S.$250/m3 for blends
of the two), with the remainder being withheld by the Argentine government as an export tax. The imposition of these export taxes has
adversely affected our results of operations.
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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 which 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 to allow importers access to the foreign exchange market for the payment of
such imported products and services.
We cannot assure you that these taxes and import regulations will not continue or be increased in the future or that other new taxes or
import regulations will not be imposed.
We may be exposed to fluctuations in foreign exchange rates.
Our results of operations are exposed to currency fluctuation 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 and may
do so in the future. In addition, the Argentine peso has recently been subject to devaluation (approximately 23% during January 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.
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, 2013 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 restrictions have been imposed which restrict
purchases of foreign currency and transfers of foreign currency abroad. Such restrictions include the requirement for financial institutions to
inform in advance and obtain approval from the Argentine Central Bank with respect to any foreign exchange transaction to be entered into
through the foreign exchange market with the exception of payments related to foreign debt previously liquidated in the domestic market.
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”.
There can be no assurances regarding future modifications to exchange and capital controls. Exchange and capital controls could
adversely affect our financial condition or results of operations and our ability to meet our foreign currency obligations and execute our
financing 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.
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Moreover, recent regulatory and policy developments in Argentina, including the enactment of the Expropriation Law, have led
to considerable volatility in the market price of our shares and ADSs. 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
securities. As a result of the foregoing, we cannot assure you that factors previously mentioned may not affect our financial condition
and/or results of operations (See “Item 4. Information on the Company—History and Development of YPF.”)
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 pass higher domestic taxes, increases in production costs, or increases in international prices of
crude oil and other hydrocarbon fuels and exchange rate fluctuations through to domestic prices, or to increase local prices
(See “Limitations on local pricing in Argentina may adversely affect our results of operations” below);
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;
legislation and regulatory initiatives relating to hydraulic stimulation and other drilling activities for non-conventional 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 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.”
In January 2007, Law No. 26,197 was enacted, which, in accordance with Article 124 of the National Constitution, provided that
Argentine provinces shall be the owners of the hydrocarbon reservoirs located within their territories. Pursuant to the law, the
Argentine Congress is charged with enacting laws and regulations aimed at developing mineral resources within Argentina, while the
provincial governments are responsible for enforcing these laws and administering hydrocarbon fields that fall within the territories of
their respective provinces. Certain provincial governments, however, have construed the provisions of Law No. 26,197 and Article
124 to empower the provinces to enact their own regulations concerning exploration and production of oil and gas within their
territories. There can be no assurance that regulations or taxes (including royalties) enacted or administered by the provinces will not
conflict with federal law, and such taxes or regulations may adversely affect our operations and financial condition.
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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 frequently lagged
substantially behind prevailing international and regional market prices for such products, and our ability to increase prices has been limited.
Likewise, the prices at which we sell natural gas in Argentina (particularly to the residential sector) are subject to government regulations and
currently are substantially below regional market prices for natural gas. The prices that we are able to obtain for our hydrocarbon products affect,
among others, 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”. 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 a period of six months (subsequently extended until
November 24, 2013), which shall not exceed the highest outstanding price as of April 9, 2013 in each of the regions identified in the Annex of the
Resolution. We cannot assure you that we will be able to increase the domestic prices of our products, and 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.
In addition, in July 2012, pursuant to the Expropriation Law, the Argentine government created the “Regulation of the Hydrocarbons
Sovereignty Regime in the Argentine Republic” and established a planning and coordination commission for the sector (the “Hydrocarbons
Commission”). The Hydrocarbons Commission consists of representatives of the federal government, and its objective is to address certain market
asymmetries in the oil and gas sector. The goals of the Hydrocarbons Commission are mainly to guarantee adequate investment by oil and gas
companies to:
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improve the level of oil and gas reserves,
expand oil refining capabilities, and
maintain an adequate supply of fuel at reasonable prices.
For the purpose of granting reasonable commercial prices, the Hydrocarbons Commission will determine the criteria that shall govern the
operations in the domestic market. The Hydrocarbons Commission has the power to publish reference prices for oil and gas, which will be adjusted
to cover the production costs attributable to the activity and to reach a reasonable margin of profit, monitor oil and gas prices charged by private
companies and supervise and ensure investment in the oil sector. Each company within the sector must be registered in the Registro Nacional de
Inversiones Hidrocarburíferas (National Hydrocarbons Investments Registry) and must submit an annual investment plan for approval by the
Hydrocarbons Commission. Non-compliance with this requirement may result in several sanctions, including termination of the authorization to
exploit hydrocarbon reserves and operate within the sector. For more information, please see “See “Item 4. Information on the Company—
Regulatory Framework and Relationship with the Argentine Government—Market Regulation —Regulation of the Hydrocarbons Sovereignty
Regime in the Argentine Republic—Decree No. 1,277/2012.”
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 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 fuel must also first demonstrate that the local
demand of diesel fuel is duly satisfied. Because domestic diesel fuel production does not currently satisfy Argentine domestic consumption needs,
we have been prevented since 2005 from selling diesel fuel production in the export market, and are obliged to sell in the local market at prevailing
domestic prices.
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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 fuel or other products and, accordingly, our results of operations.
Oil and gas prices could affect our business.
We budget capital expenditures related to exploration, development, refining and distribution activities by taking into account,
among other things, market prices for our hydrocarbon products. In the event that 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 nonconventional resources, and also with evolution
of the economy, our ability to improve our hydrocarbon recovery rates, find new reserves and carry out certain of our other capital
expenditure plans are likely to be adversely affected, which in turn would have an adverse effect on our results of operations.
Our reserves and production are likely to decline.
Most of our 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. As a result of
increased development and exploration activity in 2013, during 2013 our production increased by approximately 1.7%, on a boe/d basis.
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 non-conventional oil and gas reserves, such as shale
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 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.
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 and/or impairment charges, which would reduce earnings and shareholders’ equity.
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
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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 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.
Our business plan includes future drilling activities for non-conventional 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 strategic 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. 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.
The Hydrocarbons Law provides for oil and gas concessions to remain in effect for 25 years as from the date of their award, and further
provides for the concession term to be extended for up to 10 additional years, subject to terms and conditions approved by the grantor at the
time of the extension. 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 the extension, any concessionaire and permit holder must have complied with its obligations under the
Hydrocarbons Law and the terms of the particular concession or permit, including evidence of payment of taxes and royalties, the supply of
the necessary technology, equipment and labor force and compliance with various environmental, investment and development obligations.
Under the Hydrocarbons Law, non-compliance with these obligations and standards 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. The expiration of part of
our concessions which represent approximately 1.9% of our proved reserves as of December 31, 2013 occurs in 2017. In addition, our
concessions in certain provinces in Argentina have been extended as of the date of this annual report (see “Item 4. Information on the
Company—Regulatory Framework and Relationship with the Argentine Government — Exploration and Production—Extension of
Exploitation Concessions in the province of Neuquén,” “—
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Extension of Exploitation Concessions in the province of Mendoza,” “—Extension of Exploitation Concessions in the province of Santa
Cruz,” “—Negotiation of Extension of Concessions in the province of Tierra del Fuego,” and “—Extension of Concessions in the province of
Chubut”). We cannot provide assurances that concessions will be extended or that additional investment, royalty payment or other
requirements will not be imposed on us in order to obtain extensions as of the date of expiration of them. 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.
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, which are typically auctioned by governmental
authorities, especially those areas with the most attractive crude oil and natural gas reserves. Some provinces of Argentina, including La
Pampa, Neuquén and Chubut, have created provincial government-owned companies to develop activities in the oil and gas industry. 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
100% 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.”
In particular, remediation alternatives for Passaic River contamination have been undergoing investigation and analysis by the
Environmental Protection Agency (the “EPA”) of the United States and other parties for many years. Tierra, a subsidiary of YPF Holdings has
been working on behalf of Occidental on various studies and conducting certain remediation activities as discussed further below. In June
2007, the EPA released a draft Focused Feasibility Study (the “FFS”) that outlines several alternatives for remedial action in the lower eight
miles of the Passaic River. These alternatives ranged from no action (which would result in comparatively low cost) to extensive dredging and
capping (which, according to the draft FFS, the EPA estimated could cost from U.S.$0.9 billion to U.S.$2.3 billion), and are all described by
the EPA as involving proven technologies that could be carried out in the near term, without extensive research. Tierra, in conjunction with
the other members of the Cooperating Parties Group (as defined below), submitted comments on the draft FFS to the EPA, as did a number of
other interested parties. Additionally, on September 18, 2012, the EPA described the new alternatives it is considering in the revised FFS,
which is reportedly now expected to be released to the public soon. The EPA stated that the FFS will set forth four alternatives which could
cost from U.S.$8.6 million to U.S.$3.4 billion. Based on the information available to us as of the date of this annual report, considering the
potential final proposal, the results of the studies and discoveries to be produced, the several potential responsible parties involved in the
matter, and the consequent potential allocation of removal costs, and also considering the opinion of external legal advisors, it is not possible
to reasonably estimate a loss or range of losses on these outstanding matters on this time. Therefore, no reserve has been accrued for this
litigation by YPF Holdings Inc. Depending on the final proposal released and approved by the EPA regarding the FFS, and the potential
assignment of responsibility to YPF Holdings for such remediation, our financial condition and result of operations could negatively be
affected. See “Item 8. Financial Information—Legal Proceedings—YPF Holdings.”
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 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
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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.
Additionally, following the enactment of the Expropriation Law, the Spanish company Repsol, which had a significant portion of its
shares subject to expropriation, commenced legal proceedings against the Argentine government before New York and the International
Center for Settlement of Investment Disputes (ICSID) arbitral tribunal. Additionally, Repsol has filed other claims against us in Argentina,
New York and Madrid courts. Repsol has also made public its intention to contest the validity of agreements that we may enter into with
third parties related to the exploitation and exploration of unconventional oil reserves in the Vaca Muerta formation. On February 25, 2014,
the Board of Directors of Repsol approved the text agreed to by the Argentine Ministry of Economy and Finance and Repsol’s management
to reach an “Amicable Settlement and Compromise of Expropriation” whereby Repsol would agree to accept a payment of U.S.$ 5 billion in
Argentine sovereign bonds as 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, such agreement remains subject to the ratification of Repsol’s General Shareholders’ Meeting
and the Argentine Congress. This agreement, which is public, is subject to certain conditions, and investors should carefully read it in order
to make their own assessment. In addition, on February 27, 2014, YPF and Repsol executed an arrangement (the “Arrangement”) whereby,
mainly, the parties reciprocally agreed to withdraw, subject to certain exclusions, all present and future actions and/or claims based on causes
occurring prior to the Arrangement derived from the declaration of public interest and subjection to expropriation of YPF shares owned by
Repsol pursuant to the Expropriation Law, the intervention, temporary takeover of public utility-declared shares and management of YPF.
Likewise, the parties have 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 subject to certain conditions. The Arrangement will become fully effective on the day following to the date on
which Repsol notifies YPF that the Agreement signed between Repsol and the Argentine Republic becomes effective. If such effectiveness
does not occur on or prior to May 7, 2014, or at a later date as the parties may agree in writing, the Arrangement shall not be enforced and
shall become void, and the parties shall retain all of the rights preexisting at the date of their signature, and the Arrangement shall not create
any liability for either party. Thus, we cannot give any assurance that the withdrawals contemplated by the Arrangement will occur, and
accordingly, we can give no assurance that actions taken by Repsol will not disrupt our business efforts, including any exploitation and
exploration agreements we may seek to enter into, or that Repsol will not continue to litigate the issues related to the expropriation of its
shares.
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.
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 disrupted refinery systems and caused 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 6 tanks, 4 of which are for processing and 2 are for
dispatch of treated crude oil, concentrates the production of 10 fields in the Malargue area, which constitutes a daily production of
approximately 9,200 barrels of oil and represents 3.8% of the oil production of YPF. As of the date of this annual report, the fire has been
completely extinguished and maintenance works have commenced to reinitiate operations of the surrounding facilities, which had been
preventatively shut down due to the risk of being affected, and to work on reestablishing production. The technical personnel of the company
are currently defining the plan for the total resumption of activities in the coming days. In addition we are in the process of gathering the
necessary information to make a claim under our existing insurance coverage.
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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 “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 July 17, 2012 our Shareholder’s meeting approved a dividend of Ps.303 million (Ps.0.77 per share or ADS) which was paid
during November 2012. In 2013, our Board of Directors in its meeting held on March 11, 2013 approved a proposal to the
Shareholders of a Ps.326 million dividend to be paid during 2013 (Ps.0.83 per share or ADS). Such proposal was approved at the
Shareholder’s meeting which was held on April 30, 2013 and was paid during August 2013. Notwithstanding the foregoing, our
ability to pay, maintain or increase dividends is based on many factors, including but not limited to 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.
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, have led to considerable volatility in the market price of
our shares and ADSs. For example, the price of our ADSs closed at U.S.$54.58 on January 5, 2011, and fell to a low of U.S.$9.57 on
November 16, 2012. In 2013, the price recovered to a high closing price of U.S.$34.17 on December 23, but subsequently fell to
U.S.$21.85 on February 3, 2014. 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.
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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 the Emergency Law (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.
The Argentine government has recently tightened U.S. dollar exchange regulations.
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.
Repsol owns ADSs representing approximately 11.86% of our capital stock (See “Item 7. Major Shareholders and Related Party
Transactions”). Sales of a substantial number of Class D shares or ADSs by Repsol or any other present or future significant
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.
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, or “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.
21
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 depreciation 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 an unlimited 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 2013, we had consolidated revenues of
Ps.90,113 million (U.S.$13,825 million) and consolidated net income of Ps.5,079 million (U.S.$779 million). Due to decreased export
volumes, the portion of our revenues derived from exports has decreased steadily in recent years. Exports accounted for 13.3%, 11.5% and
14.2%, of our consolidated net sales revenues in 2013, 2012 and 2011, 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.
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
22
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 to the activities previously mentioned, on March 12, 2014, we acquired 100% of the stake 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 Rio 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, produce a total of approximately 46,800 boe/d, and have an important infrastructure of pipelines and facilities,
employing around 350 employees. In addition, certain assets have potential for exploration and development in the Vaca Muerta
formation. YPF also entered into a transfer of assets agreement with Pluspetrol S.A. (“Pluspetrol”) whereby it transferred, in
exchange for U.S.$217 million, a stake 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.
The financial data contained in this annual report as of December 31, 2013, 2012 and 2011 and for the years then ended has been
derived from our Audited Consolidated Financial Statements included in this annual report. See Note 14 to the Audited Consolidated
Financial Statements.
Upstream Operations
•
As of December 31, 2013, we held interests in more than 90 oil and gas fields in Argentina. According to the Argentine
Secretariat of Energy, in 2013 these assets accounted for approximately 44% of the country’s total production of crude oil,
excluding natural gas liquids, and approximately 36% of its total natural gas production, including natural gas liquids, in
2013, according to information provided by the Argentine Secretariat of Energy.
•
We had proved reserves, as estimated as of December 31, 2013, of approximately 628 mmbbl of oil, including condensates
and natural gas liquids, and approximately 2,558 bcf of gas, representing aggregate reserves of approximately 1,083
mmboe as of such date, compared to approximately 590 mmbbl of oil, including condensates and natural gas liquids, and
approximately 2,186 bcf of gas, representing aggregate reserves of approximately 979 mmboe as of December 31, 2012.
•
In 2013, we produced approximately 102 mmbbl of oil (approximately 279 mbbl/d), including condensates and natural gas
liquids, and approximately 437 bcf of gas (approximately 1,197 mmcf/d), representing a total production of approximately
180 mmboe (approximately 493 mboe/d), compared to approximately 101 mmbbl of oil (275 mbbl/d), including
condensates and natural gas liquids, and approximately 432 bcf of gas (1,179 mmcf/d) in 2012.
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 additionally “—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, 2013 consisted of 1,542 YPF-
branded service stations, of which we own 111 directly and through our 100% subsidiary Operadora de Estaciones de
Servicios S.A. (“OPESSA”), and we estimate we held approximately 34.1% 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.
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In addition, see Note 11.c “—Investment Project Agreements” to the Audited Consolidated Financial Statements for a description of
the transaction we entered into with Chevron.
24
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, 2013.
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 2012 production, according to the 2013 edition of the BP Statistical Review of World Energy, published in June
2013.
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In response to the economic crisis of 2001 and 2002, the Argentine government, pursuant to the Public Emergency Law (Law
No. 25,561), 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 fuel. 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.
After declining during the economic crisis of 2001 and 2002, Argentina’s GDP grew at an average annual real rate of
approximately 8.5% from 2003 to 2008, although the growth rate decelerated to 0.9% in 2009 as a result of the global financial crisis.
In 2010 and 2011, Argentina’s GDP grew at an annual real rate of approximately 9.0%. In 2012 Argentina’s GDP experienced a
slowdown, with GDP increasing at a rate of 1.9% on an annualized basis compared to the preceding year. 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 for 2013 was revised from 4.9% to 3%. Driven by this 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). Argentine
natural gas consumption grew at average annual rate of approximately 5.0% during the period 2003-2011, 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 fuel 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 fuel, and increased imports of gas (including NGL). In 2003, Argentina’s net exports of diesel fuel
amounted to approximately 1,349 mcm, while in 2013 its net imports of diesel fuel amounted to approximately 2,427 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 fuel in Argentina exceeds domestic production. In addition, 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 fuel sales. On May 3, 2012, the Expropriation Law was passed by 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. 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, Law No. 24,145 (referred to as 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.
26
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 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 expropriation between 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 which 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.” Additionally, see “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.
Furthermore, on April 16, 2012, the Company was notified, through a notarial certification, of Decree No. 530/12 of the National
Executive Office , which provides for the Intervention of YPF for a period of thirty days (which was then extended to our next Shareholders
meeting to be held on June 4, 2012 at which the composition of our Board of Directors was determined), with the aim of securing the
continuity of its business and the preservation of its assets and capital, securing the provision of fuel and the satisfaction of the country’s
needs, and guaranteeing that the goals of the Expropriation Law are met. See “—Regulatory Framework and Relationship with the Argentine
Government—The Expropriation Law.” In accordance with Article 3 of Decree No. 530/2012, the powers conferred by YPF’s by-laws on the
Board and/or the President of the Company have been temporarily granted to the Intervenor. On May 7, 2012, through Decree No. 676/2012
of the National Executive Office, Mr. Miguel Matías Galuccio was appointed General Manager of the Company during the Intervention. At
our general shareholders’ meeting, on June 4, 2012, our shareholders appointed the new members of our Board of Directors. See “Item 6.
Directors, Senior Management and Employees—Management of the Company.”
On August 30, 2012, we approved and announced the Strategic Plan 2013-2017 establishing the basis of our development for
the years to come. Such plan 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) the development of unconventional resources, which we see as a unique
opportunity because a) the expectation related to the existence of large volumes of unconventional resources in Argentina according to
estimations of leading reports on global energy resources, b) we currently possess a relevant participation in terms of exploration and
exploitation rights on the acreage in which such resources could be located, and c) we believe we can integrate a portfolio of projects with
high production potential; (ii) the re-launch of conventional and unconventional exploration initiatives in existing wells and expansion to new
wells, including offshore; (iii) an increase in capital and operating expenditures in mature areas with expected higher return and efficiency
potential (through investment in improvements, increased use of new perforation machinery and well intervention); (iv) a return to active
production of natural gas to accompany our oil production; and (v) an increase in production of refined products through an enhancement of
the refining capacity (including improving and increasing our installed capacity and upgrading and converting our refineries). The previously
mentioned 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.
27
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.
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 transferred from Exploration and Production to
Refining and Marketing at transfer prices established by us, which generally seek to approximate Argentine market prices.
We have recently 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. Accordingly, the Company has adjusted comparative information for the years 2012 and 2011 to reflect this
reorganization.
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, pretrochemical 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 segment, including corporate
administration costs and assets, environmental matters related to YPF Holdings, Inc (“YPF Holdings”) (see Note 3 to our Audited
Consolidated Financial Statements) and certain construction activities, mainly related to the oil and gas industry, through our
subsidiary A-Evangelista S.A. and its subsidiaries.
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
two exploratory areas in Uruguay and Chile (see “—Exploration and Production—Principal properties—International properties”).
Additionally, we market lubricants and specialties in Brazil and Chile and carry out some construction activities related to the oil and
gas industry in Uruguay, Bolivia, Brazil and Peru, through our 100% owned company A-Evangelista S.A. and its subsidiaries.
28
The following table sets forth revenues and operating income for each of our lines of business for the years ended December 31,
2013, 2012 and 2011:
Revenues(1)
Exploration and production(2)
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)
Exploration and production
Downstream
Corporate and other
Consolidation adjustments
Total operating income
For the Year Ended December 31,
2011
2012
2013
(in millions of pesos)
3,851
38,846
42,697
1,135
30,179
31,314
269
23,401
23,670
85,624
1,147
86,771
65,047
1,069
66,116
54.636
848
55,484
638
2,285
2,923
(42,278)
90,113
992
1,243
2,235
(32,491)
67,174
1,306
651
1,957
(24,900)
56,211
6,324
6,721
(1,522)
(363)
11,160
5,730
4,095
(2,492)
570
7,903
4,067
5,466
(1,714)
(631)
7,188
(1) Revenues are net to us after payment of a fuel transfer tax and turnover tax. Custom duties on exports are included in Selling
expenses. 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 in determining revenues. See “Item 4. Information on the Company-Exploration and Production-Oil and gas
production, production prices and production costs” and Note 2 (f) to the Audited Consolidated Financial Statements.
Includes exploration costs in Argentina, Guyana and the United States and production operations in Argentina and the
United States.
Intersegment revenues of crude oil to Refining and Marketing are recorded at transfer prices that reflect our estimates of
Argentine market prices.
(2)
(3)
Exploration and Production Overview
Our project 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 project 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
additionally “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 2013, our oil production in Argentina increased by 2.19% and our
gas production in Argentina increased by 1.45%, in each case compared to our production in 2012. Moreover, our oil and gas
production in Argentina from areas we operated in December 2013 increased by 6.31% and 17.63%, respectively, compared to our
production in December 2012. This increase reflects the intensive work we do in the fields which we operate both conventional and
unconventional hydrocarbons.
29
Meeting the challenge of the mature oil and gas fields
Most of our oil and gas producing fields in Argentina are mature, which requires us to assume 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 well infill and extension of secondary recovery and tertiary recovery testing.
We are fully dedicated to 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 flooding in mature reservoirs in both the Golfo de San Jorge and Neuquén basins.
Continuous comprehensive 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 in other
regions of the world have already reached 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 additionally “Item 3. Key
Information—Risk Factors.”
In addition, we recently finalized certain agreement related to the acquisition 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 “Area”).
The Area is an exploitation concession located in the Provinces of Neuquén and Mendoza. YPF is the holder of the
concession until 2027. YPF will own 100% of the participation in the Puesto Hernández area, becoming the operator
of the concession. Puesto Hernández currently produces over 10,000 barrels a day of light crude oil (Medanito
quality). The transaction was completed for the amount of U.S.$40.7 million. By becoming the operator of the Area,
we expect we will be able to accelerate our investment plans to optimize the Area’s production potential until 2027.
•
On March 12, 2014, we acquired 100% of the stake of Apache Overseas lnc. and Apache International Finance II
S.a.r.l. (together with their affiliates, “Apache”) in certain foreign companies that control Argentine companies that
are the owners of assets located in Argentina, including 28 concessions (23 operated and 5 non-operated) in
Neuquina Basin (in the provinces of Neuquén and Rio Negro), 7 concessions in Tierra del Fuego, and a significant
conventional resource base. Pursuant to this transaction, YPF acquired control of all of the assets of the Apache
Corporation in Argentina. The price paid for the transaction includes U.S.$ 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, produce a total of
approximately 46,800 boe/d, and have an important infrastructure of pipelines and facilities, employing around 350
employees. In addition, certain assets have potential for exploration and development in the Vaca Muerta formation.
YPF also entered into a transfer of assets agreement with Pluspetrol S.A. (“Pluspetrol”) whereby it transferred, in
exchange for U.S.$217 million, a stake in certain assets related to those acquired from Apache located in the
Province of Neuquén, with the objective of jointly exploring and developing the Vaca Muerta formation. At
March 12, 2014 YPF has made the payment of the transaction giving terminating the operation.
•
On February 7, 2014, YPF acquired Potasio Rio Colorado S.A.’s 50% interest in the joint operation contract
“Segment 5 Loma La Lata—Sierra Barrosa” (known as the “Lajas” formation) signed by YPF and Potasio Rio
Coloroado S.A. for the exploitation of the Lajas formation concession area (the “Area”). The Area is an exploitation
concession, located in the Province of Neuquén. YPF is the holder of the concession, which expires in 2027.
Exploitation of the Area was conducted under the aforementioned joint operation contract. The terms of the joint
operation contract provided that it would expire upon the earlier of the expiration of the concession or the early
termination of any agreement or contract that granted the right to continue exploiting the area. As a result of the
termination of the joint operation contract, YPF will own 100% interest in the Area. The consideration for the
transaction was U.S.$ 25 million.
30
Staying the Path of Unconventional Resources
We have committed significant technical resources and experience to tap the potential of our unconventional hydrocarbon assets.
Through the more than 100 unconventional wells drilled this year (most of which were drilled in Loma Campana concession, which
we jointly control with Chevron as detailed below), we clearly showed leadership in this area and expressed our commitment to the
objective of growing our production and reserves through the development of unconventional resources.
During 2013, we launched the first shale oil cluster development in Loma Campana field, in association with Chevron, and the
first shale gas pilot program in El Orejano field, in association with Dow Chemical, while continuing to delineate the potential of the
Vaca Muerta formation in the Neuquina Basin. The map below describes each of these projects.
Vaca Muerta Formation
(1) “Loma Campana”: On July 16, 2013, YPF and Chevron signed an investment project agreement with the objective of 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”) (4942 acres) of the 395 km2 (97.607 acres) corresponding to the
area dedicated to the project. This first pilot project includes the drilling of more than 100 wells. Together with what has already been invested
by YPF in the area, this new investment will result in a total investment of 1500 million dollars in the pilot project. In a second stage, after
completion of the pilot project, both companies expect to continue with the development of the area, sharing investments 50% each. For
additional information see “Note 11.c –Investment Project Agreements” to the Audited Consolidated Financial Statements.
(2) “El Orejano” Area: On September 23, 2013, YPF and Dow Europe Holding B.V. and PBB Polisur SA signed an agreement that includes
a disbursement by both parties up to U.S.$188 million dollars 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 contemplates a first phase of work during which 16 wells will be
drilled.
31
The agreements with Chevron and Dow Chemical constitute significant steps towards the development of our vast
unconventional resources, but the corresponding areas still represent only a fraction of our unconventional acreage.
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 economies of scale and increasing
well productivity through better subsurface understanding of this resource play.
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 additionally “Item 3. Key Information—
Risk Factors.”
Main properties
Our production is concentrated in Argentina and our domestic operations are subject to numerous risks (See “Item 3. Key
Information—Risk Factors.”).
The following table sets forth information with regard to our developed and undeveloped acreage by geographic area as of
December 31, 2013:
As of December 31, 2013
Developed(1)
Undeveloped(2)
Gross(3)
Net(4)
Gross(3)
Net(4)
South America
Argentina
Rest of South America(5)
North America(6)
Total
1,508
1,508
—
17
(thousands of acres)
1,002 53,960
1,002 44,967
— 8,993
138
2.6
1,525 1,004.6
54,098
33,155
25,743
7,412
74.8
33,229.80
(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.
(3) A “gross acre” is an acre in which we own a working interest.
(4)
(5) Relates to Uruguay, Colombia, Paraguay, and Chile. In the case of Paraguay, YPF non-developed surface totaled of
“Net” acreage equals gross acreage after deducting third party interests.
3,825 thousand acres as of December 31, 2013, and is connected to an exploration permit granted to YPF through Resolution
1703 of the Ministry of Public Works and Communications of Paraguay. The permit expired on September 16, 2012 and a
request for a 1 year extension was presented before the Ministry of Public Works and Communications. As of the date of this
annual report, the extension request is pending. In the case of Uruguay, YPF’s undeveloped acreage includes mining areas and a
permit for exploratory drilling. This permit relates to an area of 2,397 thousand acres and was awarded entirely to YPF in March
2012. Related to Colombia, YPF has requested approval from the application authority (“ANH”), for the farm-out of its total
working interest in COR 12 and COR 33 blocks. YPF and its partners informed ANH the decision to relinquish COR 14 block.
(6) Relates only to the United States’ Gulf of Mexico.
As of December 31, 2013, none of our exploratory undeveloped acreage was subject to exploration permits that will expire in
2014 in accordance with Law 17,319. However, as a result of the expiration in 2014 of the first, second or third exploration terms of
certain of our exploration permits, we would be required to relinquish a fixed portion of the acreage related to each such expiring
permit, as set forth in Law 17,319, 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). If no such discoveries are made in 2014, we would be required to relinquish approximately
12 thousand square kilometers of exploratory undeveloped acreage (approximately 16% of our 78 thousand square kilometers of net
exploratory undeveloped acreage as of December 31, 2013) during 2014. We are entitled to decide, according to our best interest,
which portions of each of the exploration permits to keep, within the required relinquishment percentage. Therefore, the areas to be
relinquished consist usually of acreage where drilling has not been successful and that 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.
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 2013
edition of the BP Statistical Review of World Energy, published in June 2013. 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 line with the Plan
32
Exploratorio Argentina (the “Argentine Exploratory Plan”). The total surface of the continent represents approximately 408 million
acres and the total offshore surface includes 194 million acres on the South Atlantic shelf within the 200 meter-deep 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,
2013:
Wells(1)(2)
Oil
Gas
Basin
Onshore
Neuquina
Golfo San Jorge
Cuyana
Noroeste
Austral
Offshore
Total
Net
Gross Net
Gross
11,836 10,917 902 617
3,928 3,341 759 541
43
6,949 6,811 45
720 — —
18
15
10
921 627
816
7 47
19
37 51
124
— — 19
10,917
11,836
(1)
In addition to productive oil and gas wells located in Argentina, we have interests in oil wells located in the United States
(7 gross wells and approximately 1 net well, as of December 31, 2013).
(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, 2013, we held 142 exploration permits and production concessions in Argentina. We directly operate 100 of
them, including 42 exploration permits and 58 production concessions.
•
Exploration permits. As of December 31, 2013, we held 52 exploration permits in Argentina, 48 of which were onshore
exploration permits and 4 of which were offshore exploration permits. We had 100% ownership of three onshore permits,
and our participating interests in the remainder varied between 45% 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, 2013, we had 90 production concessions in Argentina. We had a 100%
ownership interest in 50 production concessions, and our participating interests in the remaining 40 production concessions
varied between 12.2% and 98%.
In addition, we have 23 crude oil treatment plants and 5 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 “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, 2013, most of which are mature:
Areas (1)
Loma La Lata Central
Magallanes (3)
Los Perales
Aguada Toledo - Sierra
Barrosa
Seco León
El Portón
Chihuido Sierra Negra
San Roque
Barranca Baya
Manantiales Behr
Interest
%
Production 2013
Oil (2)
(mmbbl)
Gas
Proved Reserves as of
December 31, 2013
Gas
(mmcf)
BOE
(mmboe)
Oil (2)
(mmbbl)
(mmcf)
100% 7,520 95,907 40,909 732,405 171,347
884 14,165 16,462 298,732 69,664
Basin /Location
Neuquina
Austral
100% 5,625 12,730 56,071 64,483 67,555 Golfo San Jorge
88%
100% 2,218 30,716 14,000 220,502 53,270
Neuquina
100% 4,244 4,185 43,976 22,544 47,991 Golfo San Jorge
Neuquina
100% 2,710 24,546 17,183 132,908 40,853
Neuquina
8,751 35,339
100% 5,160 1,437 33,780
Neuquina
34% 2,118 29,433 8,812 130,601 32,071
100% 4,862 1,020 30,043
5,528 31,027 Golfo San Jorge
100% 6,911 5,029 27,055 15,247 29,770 Golfo San Jorge
Development
Stage of the area
Mature Field
Mature Field
Mature Field
Mature Field
Mature Field
Mature Field
Mature Field
Mature Field
Mature Field
Mature Field
Puesto Hernández (4)
Acambuco
Loma La Lata Norte (5)
Vizcacheras
Chihuido La Salina
Lomas del Cuy
El Trébol
Rincón del Mangrullo
CNQ 7A
La Ventana Central (6)
Tierra del Fuego
Aguada Pichana
Desfiladero Bayo
Aguaragüe
Cañadón Yatel
0 26,792
0 26,792
89% 2,384
23%
274 11,421 1,997 124,403 24,152
75% 3,558 13,618 9,686 72,692 22,632
100% 3,056
2,398 21,855
300 21,428
100% 3,890 29,952 10,684 62,089 21,742
100% 2,477 1,351 19,133
467 19,606
100% 2,086
296 5,795 73,960 18,967
4
100%
682 17,544
50% 4,591 1,408 17,423
2,544 17,122
91% 1,339
174 16,669
30%
587 11,709 3,133 76,916 16,831
27% 1,509 26,952 4,263 70,380 16,798
1,127 16,773
282 7,552 2,467 79,703 16,661
Cuyana
Neuquina
9,077 20,749 Golfo San Jorge
2,788 20,102 Golfo San Jorge
Neuquina
Neuquina
Cuyana
Austral
Neuquina
Neuquina
Noroeste
100% 1,662 8,163 7,909 41,272 15,259 Golfo San Jorge
Mature Field
Neuquina
Noroeste
Mature Field
Neuquina Mature/New Field
Mature Field
Mature Field
Mature Field
Mature Field
New Field
Mature Field
Mature Field
Mature Field
Mature Field
Mature Field
Mature Field
Mature Field
100% 2,537
187 16,572
53%
33
Includes Condensate and Natural Gas Liquids.
(1) Exploitation areas.
(2)
(3) Working Interest is 50% until 2016, and 100% from 2017 until the expiration of the concession.
(4) As of December 31, 2013, working interest is 62% until 2016, and 100% from 2017 until the expiration of the concession. See
additionally “—Meeting the challenge of the mature oil and gas fields.”
(5) Working Interest is 100% in the Sierras Blancas Formation (Mature Field) and 50% in the Vaca Muerta and Quintuco
Formations (New Field).
(6) Working Interest is 69.6% for crude oil and 60% for gas liquids and gas until 2016, and 100% from 2017 until the expiration of
the concession.
Approximately 84% of our proved oil reserves in Argentina are concentrated in the Neuquina (44%) and Golfo San Jorge
(40%) basins, and approximately 92% of our proved gas reserves in Argentina are concentrated in the Neuquina (66%), Austral
(15%) and Noroeste (11%) basins.
Joint ventures and contractual arrangements in Argentina
As of December 31, 2013, we participated in 43 exploration and 25 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 12.2%
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, 2013, see Note 6 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.
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.
34
Information on net proved reserves as of December 31, 2013, 2012 and 2011 was calculated in accordance with the SEC rules
and FASB’s ASC 932, as amended. Accordingly, crude oil prices used to determine reserves were calculated at the beginning of each
month, for crude oils of different quality produced by the Company. The Company considered the realized prices for crude oil in the
domestic market taking into account the effect of exports taxes as in effect as of each of the corresponding years (until 2016, in
accordance with Law No. 26,732). For the years beyond the mentioned periods, the Company considered the unweighted average
price of the first-day-of-the-month for each month within the twelve-month period ended December 31, 2013, 2012 and 2011,
respectively, which refers to the WTI prices adjusted by each different quality produced by the Company. 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.
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 crude oil and natural gas liquids.
Technology used in establishing proved reserves additions
YPF’s estimated proved reserves as of December 31, 2013, 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, surface
geological 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.
For further information on the estimation process of our proved reserves, see “—Internal controls on reserves and reserves
audits.”
Net Proved Developed and Undeveloped Reserves as of December 31, 2013
The following table sets forth our estimated net proved developed and undeveloped reserves of crude oil and natural gas at
December 31, 2013.
Proved Developed Reserves
Consolidated Entities
South America
Argentina
North America
United States
Total Consolidated Entities (6)
Equity-Accounted Entities (10)
South America
Argentina
North America
United States
Total Equity-Accounted Entities
Total Proved Developed Reserves (7)
Oil (1)
(mmbbl)
Natural Gas
(bcf)
Total (2)
(mmboe)
476
1
477
—
—
—
477
1,935
3
1,938
821
1
822
—
—
—
—
1,938
—
—
822
35
Proved Undeveloped Reserves
Consolidated Entities
South America
Argentina
North America
United States
Total Consolidated Entities (8)
Equity-Accounted Entities (10)
South America
Argentina
North America
United States
Total Equity-Accounted Entities
Total Proved Undeveloped Reserves (9)
Total Proved Reserves (2)(3)
Consolidated Entities
Developed Reserves
Undeveloped Reserves
Total Consolidated Entities (4)
Equity-accounted entities (10)
Developed Reserves
Undeveloped Reserves
Total Equity-Accounted Entities
Total Proved Reserves (5)
Oil (1)
(mmbbl)
Natural Gas
(bcf)
Total (2)
(mmboe)
151
—
151
—
—
—
151
620
—
620
261
—
261
—
—
—
—
620
—
—
261
Oil (1)
(mmbbl)
Natural Gas
(bcf)
Total (2)
(mmboe)
477
151
628
—
—
—
628
1,938
620
2,558
—
—
—
2,558
822
261
1,083
—
—
—
1,083
Not material (less than 1)
Includes crude oil, condensate and natural gas liquids.
*
(1)
(2) Volumes of natural gas in the table above and elsewhere in this annual report have been converted to boe at 5.615 mcf per
barrel.
(3) Proved oil reserves of consolidated entities include an estimated approximately 93 mmbbl of crude oil, condensate and natural
gas liquids in respect of royalty payments which, as described above, are a financial obligation, or are substantially equivalent to
a production or similar tax. Proved reserves of natural gas of consolidated entities include an estimated approximately 285 bcf of
natural gas in respect of such payments. Equity-accounted entities’ reserves in respect of royalty payments which are a financial
obligation, or are substantially equivalent to a production or similar tax, are not material.
Includes natural gas liquids of 76, 70 and 74 as of December 31 2013, 2012 and 2011 for Consolidated Entities.
Includes natural gas liquids of 76, 70 and 74 as of December 31 2013, 2012 and 2011 for Consolidated and Equity-accounted
Entities.
Includes natural gas liquids of 55, 56 and 58 as of December 31 2013, 2012 and 2011 for Consolidated Entities.
Includes natural gas liquids of 55, 56 and 58 as of December 31 2013, 2012 and 2011 for Consolidated and Equity-accounted
Entities.
Includes natural gas liquids of 21, 13 and 14 as of December 31 2013, 2012 and 2011 for Consolidated Entities.
Includes natural gas liquids of 21, 13 and 14 as of December 31 2013, 2012 and 2011 for Consolidated and Equity-accounted
Entities.
(4)
(5)
(6)
(7)
(8)
(9)
(10) As of December 31, 2013 we have no Equity Accounted Entities with reserves. See Note 13 to the Audited Consolidated
Financial Statements – Business Combination – YPF Energía Eléctrica S.A.
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 million barrels (“mmbbl”) of crude oil, condensate,
and natural gas liquids, and 564 billion cubic feet (“bcf”) of natural gas.
36
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 oil reserves and 15 bcf of proved 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 oil and 150 bcf of 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 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 oil and 8.2 bcf of 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 gas reserves were added because of additional drilling activity planned for 2014.
The Chihuido de la Sierra Negra field added approximately 7 mmbbl of oil and 3 bcf of 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 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 in 6 mmbbl of liquids and 4 bcf of gas mainly in the Barranca Baya, Loma La Lata Norte, Loma
Campana, Cerro Fortunoso, and Vizcacheras fields.
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
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 oil.
Also in the Golfo San Jorge Basin, 37 new extension wells drilled in the Barranca Baya Field added 2.6 mmboe of
mainly 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.
37
•
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.
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 gas and oil development projects, which added approximately 83 mmboe of proved
undeveloped reserves. The main contributions came 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) that
resulted in an 8 mmboe addition of proved undeveloped reserves, mainly from scheduled proved undeveloped projects and
which will not require additional investment.
•
New improved recovery projects, adding 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.
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 7 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.
38
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 Control Direction (RCD) is separate and independent from the Exploration and Production segment. RCD’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 RCD are
to ensure that YPF’s proved reserves estimates and disclosure are in compliance with the rules of the SEC, the Financial
Accounting Standards Board (FASB), and the Sarbanes-Oxley Act, and to review annual changes in reserves estimates and
the reporting of YPF’s proved reserves. The RCD is responsible for preparing the information to be publicly disclosed
concerning YPF’s reported proved reserves of crude oil, condensate, natural gas liquids, and natural gas. In addition, the
RCD is also responsible for providing training to personnel involved in the reserves estimation and reporting process
within YPF. The RCD 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 RCD 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 RCD are registered
with or affiliated to the relevant professional bodies in their fields of expertise.
(b) The Reserves Control Director, head of the RCD since January 2013, who is responsible for overseeing the preparation of
the reserves estimates and reserves audits conducted by third party engineers. The current director has over 17 years of
experience in geology and geophysics, reserves estimates, project development, finance and general accounting regulation.
Over the past six years, he has been Regional Director responsible for the operation and development of YPF’s operated
fields at Cuyana and North of Neuquina Basins, in western Argentina. He holds a degree in geology from Universidad
Nacional de Tucumán, and postgraduate courses at IAE Universidad Austral. Consistent with our internal control system
requirements, the Reserves Control Director’s compensation is not affected by changes in reported reserves.
(c) A quarterly internal review by the RCD of changes in proved reserves submitted by the Exploration and Production
business unit and associated with properties where technical, operational or commercial issues have arisen.
(d) The Quality Reserve Coordinator (QRC), who is a professional assigned at 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 10 years of practical experience in petroleum engineering or petroleum production geology, with at least five
years of such experience in charge of the estimate and evaluation of reserves information, 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.
39
(f) Our Internal Audit Team, which examines the effectiveness of YPF’s financial controls, designed to ensure the reliability of reporting
and safeguarding of all the assets and examining 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 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.
In 2013, IHS Global Canada Inc. audited areas non operated and operated by YPF in the Neuquina, Golfo San Jorge and Cuyana basins and
DeGolyer and MacNaughton audited non operated areas in the United States. These audits were performed as of September 30, 2013, with the
exception of Manantiales Behr, Restinga Alí, Río Mayo, Sarmiento, and Zona Central-Bella Vista which was audited as of December 31, 2013.
Audited fields as of September 30, 2013 contain in aggregate, according to our estimates, 281.2 mmboe proved reserves (102.2 mmboe of which
were proved undeveloped reserves) as of such date, which represented approximately 25.5% of our proved reserves and 38.6% of our proved
undeveloped reserves as of September 30, 2013. In addition, the Manantiales Behr, Restinga Alí, Río Mayo, Sarmiento, and Zona Central-Bella
Vista Fields, which were audited as of December 31, 2013, contain in aggregate, according to our estimates, 37.6 mmboe proved reserves (3.9
mmboe of which were proved undeveloped reserves) as of such date, which represented approximately 3.5% of our proved reserves and 1.5% of
our proved undeveloped reserves as of December 31, 2013. A copy of the related reserves audit reports are filed as Exhibits 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, 2013. 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 different to proved reserves that are not included in this
annual report, which contains estimates of proved reserves consistent with the SEC’s guidance; 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 oil (including crude oil, condensate and natural gas liquids) and gas production on an as sold and daily 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.
Oil production (1)(2)
Consolidated Entities
South America
Argentina
North America
United States
Total Consolidated Entities
Equity-Accounted Entities
South America
Argentina
Total Equity-Accounted Entities
Total Oil Production (3)
40
2013
2012
2011
(mbbl/d)
279
274
272
1
280
1
275
1
273
1
1
281
1
1
276
1
1
274
Natural gas production (2)
Consolidated Entities
South America
Argentina
North America
United States
Total Consolidated Entities
Equity-Accounted Entities
South America
Argentina
Total Equity-Accounted Entities
Total Natural Gas Production (4)(5)
Oil equivalent production (2)(6)
Consolidated Entities
Oil
Natural gas
Equity-Accounted Entities
Oil
Natural gas
Total Oil Equivalent Production
2013
2012
2011
(mmcf/d)
1,018
1,001
1,049
2
1,020
2
1,003
3
1,052
14
14
1,034
26
26
1,029
38
38
1,090
2013
2012
2011
(mboe/d)
280
182
275
179
273
187
1
2
465
1
5
459
—
7
467
Not material (less than 1)
Includes crude oil, condensate and natural gas liquids.
*
(1)
(2) Loma La Lata Central and Loma La Lata Norte (southern and northern parts of Loma La Lata Field) in Argentina contain
approximately 18% of our total proved reserves expressed on an oil equivalent barrel basis. Oil production in these fields was
11, 15 and 15 mmbbl for the years ended December 31, 2013, 2012 and 2011 respectively. Natural gas production in the Loma
La Lata field was 110, 159 and 182 bcf for the years ended December 31, 2013, 2012 and 2011 respectively.
(3) Oil production for the years 2013, 2012 and 2011 includes an estimated approximately 15, 13 and 12 mmbbl, respectively, of
crude oil, condensate and natural gas liquids 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, condensate and natural gas liquids
in respect of royalty payment 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 2013, 2012 and 2011 includes an estimated approximately 47, 48 and 48 bcf, respectively,
of natural gas 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 operation and inventory changes (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 such amounts).
(6) Volumes of natural gas been converted to an oil equivalent basis at 5.615 mcf 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.
41
The following table sets forth the average production costs and average sales price by geographic area for 2013, 2012, and 2011:
Production costs and sales price
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 natural gas sales price
Year ended December 31, 2012
Lifting costs
Local taxes and similar payments(1)
Transportation and other costs
Average production costs
Average oil sales price
Average natural gas sales price
Year ended December 31, 2011
Lifting costs
Local taxes and similar payments(1)
Transportation and other costs
Average production costs
Average oil sales price
Average natural gas sales price
Total
Argentina
(Ps./boe)
88.02
5.55
19.89
113.46
393.62
72.39
88.02
5.58
19.88
113.48
392.77
72.37
66.22
3.24
19.50
88.97
288.71
54.78
48.24
2.03
15.25
65.52
245.86
55.24
65.89
3.26
19.51
88.66
317.11
60.33
48.24
2.04
15.23
65.51
244.69
55.21
United
States
88.52
—
21.96
110.48
541.74
108.12
65.09
—
17.54
82.63
466.75
92.12
48.93
—
18.07
67
412.19
111.74
(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.32.77 per boe, Ps.25.10 per boe and Ps.19.50 per
boe per boe for the years ended December 31, 2013, 2012 and 2011, respectively.
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(1)
Gross wells drilled(2)
Exploratory
Productive
Oil
Gas
Dry
Total
Development
Productive
Oil
Gas
Dry
Total
Net wells drilled(3)
Exploratory
Productive
Oil
Gas
Dry
Total
For the Year Ended December 31,
2013
2012
2011
38
30
8
3
41
728
664
64
2
730
29
25
4
3
32
33
27
6
5
38
468
455
13
2
470
24
21
3
4
28
18
17
1
4
22
553
529
24
8
561
15
14
1
2
17
Development
Productive
Oil
Gas
Dry
Total
679
624
55
2
681
441
430
11
1
442
494
485
9
8
502
(1)
“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 exploratory well which was abandoned due to technical reasons in
2011; and nine development wells during the last four years, seven of which were productive. In 2012, we completed a side-
track of an off-shore development well not in production for technical reasons and a successful workover of an off-shore
development well.
42
(2)
(3)
“Gross” wells include all wells in which we have an interest.
“Net” wells equals gross wells after deducting third-party interests. In addition to wells drilled in Argentina, “net” wells drilled
in North America round to one well.
Exploration & Production Activity in Argentina
During 2013, our main exploratory and development activities in Argentina have had the following principal focus:
1. Operated Areas - Exploratory Activities
During 2013, our main exploratory activities in Argentina were principally focused on:
1.1. Onshore:
•
Unconventional oil and gas:
We continued with the regional exploration of the Vaca Muerta formation, oriented towards the characterization of
productivity of the shale oil, wet gas and dry gas in different areas of the basin.
•
Shale oil:
Neuquina Basin. Exploration continued along the shale oil strip, in an attempt to define intermediate control points of
productivity, all while complying with the contractual commitments of the exploratory JOAs (“Joint Operation Agreements”) of
the 2nd and 3rd bidding rounds in the province of Neuquén.
Positive results were obtained in La Amarga Chica.x-4, La Caverna.x-4 and La Caverna.e-6 (Bandurria block) and
Meseta Buena Esperanza.x-2002 (operated by Apache Corporation) wells. These results, together with the positive results of the
Narambuena.x-8, San Roque.xp-1008 and San Roque.xp-1010 (operated by Total S.A.) wells confirmed the productivity of the
Vaca Muerta formation at various points of the basin.
Golfo San Jorge Basin. During 2013, the El Trebol xp-914 well was drilled to initiate exploration of the Neocomian
play, the most western area of the Golfo San Jorge basin. The exploration of the Neocomian play is expected to be completed
during 2014.
•
Shale gas:
Neuquina Basin. During 2013, we continued with the regional definition in the shale gas strip area. Positive results
were obtained in the following wells: Cerro Arena.x-5, Las Tacanas.x-1, Pampa de las Yeguas I.x-1 (operated by us) and
Aguada Pichana.e-1007, Pampa de las Yeguas II.x-1 (operated by Total S.A.). Data integration is in progress to define sweet
spot distribution.
43
•
Tight gas:
Neuquina Basin. Exploration of the Basin Center Gas System play started with the Lajas Este.x-1 well and is expected
to yield results in the first half of 2014.
•
Conventional oil and gas:
•
Productive basins
Chachahuén Block: The evaluation of this block’s potential is ongoing. In 2013, 5 wells were drilled targeting
reservoirs related to the Neuquen and Malargue groups (a unit that consists of more than one formation). Additionally, the
Chachahuén Sur.xp-44 well was drilled, with positive results in the Rayoso and Mulichinco formations.
Based on the results obtained since 2011, the Chachahuen Sur Exploitation block was defined, and was approved by the
authorities of the Province of Mendoza in late 2013. We have designed a development plan for this block.
Llancanello R Block: The exploration of this heavy oil field in the south of the Llancanelo block started with drilling
three study wells (targeting reservoirs related to the Neuquen group), where positive results were achieved.
Puesto Cortadera Block: Two exploration wells targeting gas reservoirs related to the Rayoso, Los Molles and
Precuyano formations, were drilled. Positive results were achieved in the Los Molles formation and negative results were achieved
in the Rayoso and Precuyano formations.
Other blocks in the Neuquina Basin: Additionally, during 2013 four exploratory wells were drilled with positive results:
•
•
•
•
Cerro Hamaca, La Ollada.x-1 positive in Rayoso formation (oil)
EL Manzano, Mirador del Valle.x-1 positive in Neuquen group (oil)
Loma de la Mina, Los Pajaritos.x-1 positive in Huitrin formation (oil)
Octógono Fiscal, Campamento.xp-491 positive in Los Molles formation (oil)
Golfo San Jorge basin: We restarted exploration activity targeting conventional oil and gas reservoirs in the Golfo San
Jorge basin by drilling the nine wells described below:
•
Chubut province: In the Restinga Ali and Manantiales Behr blocks, 5 exploratory wells were drilled to
evaluate gas from the Salamanca formation. As of December 31, 2013, positive results were achieved in the
Grimbeek Este.x-2 well, while the remaining wells were pending completion.
•
Santa Cruz province: In the C° Piedra-C°Guadal Norte, Barranca Yankowsky and Los Monos blocks, four
exploratory wells were drilled to evaluate oil and gas from the Bajo Barreal and Castillo formations, with
the following results:
•
•
•
Estancia Zabala.x-5 (C° Piedra-C°Guadal Norte block) positive,
Barranca Yankowsky Oeste.x-3 negative,
Puesto Osorio.x-2 (Los Monos) and C° Piedra Oriental.x-1 (C° Piedra-C° Guadal Norte) were
pending completion as of December 31, 2013.
•
Shallow gas workovers: In order to investigate several conventional shallow gas reservoirs, fifteen
workovers were conducted (12 in the Golfo San Jorge basin and 3 in the Neuquina basin). The encouraging
results obtained from these workovers allowed us to define development plans for some of the
corresponding shallow gas reservoirs.
•
Bordering areas:
Los Tordillos Oeste Block: Starting with the analysis of the 3D seismic data obtained during the last quarter of
2010, the location of two exploratory wells was established in the Los Tordillos Oeste block, (located in the province of
Mendoza), in association with Sinopec Argentina (formerly Occidental Exploration and Production Inc.), with YPF and
Sinopec Argentina each holding a 50% working interest in the project. During 2013, the environmental resolution authorizing
the drilling of both wells was obtained. The wells are expected to be drilled during 2014.
Gan Gan (CCA-1) block: In early 2013, Wintershall Energía (holder of a 25% working interest in the project)
informed us (as holder of a 75% working interest in, and operator of, the project) that Wintershall Energia intended to
withdraw from the JV. We informed the Chubut province authorities of our intention to proceed with activities in the second
exploratory period. The main goal is to define the remaining potential by finishing field studies and modeling.
44
CGSJ V/A block: We (as holder of a 75% working interest in the project) and Wintershall Energía (as holder of a 25%
working interest in the project) informed the Chubut province authorities of our decision to relinquish the block due the lack of
exploration potential.
Bolsón del Oeste block: Inside the Bolsón del Oeste block (in the province of La Rioja), entirely operated by us, the
Guandacol es-1 well was drilled in order to evaluate the sediment column from the Tertiary and Paleozoic ages. Although the
well was drilled to a final depth of 3700 meters, the well’s objective could not be achieved. We decided not to continue with the
third exploratory period and, as a result, the block was relinquished to the province.
1.2. Offshore:
•
Shallow Waters. The evaluation of the E2 block continues (currently operated by ENAP Sipetrol, with a working interest
of 33%, and in which we and Energía Argentina S.A. (“ENARSA”) each also hold a 33% working interest), in search of
new exploration opportunities. We, along with our partners, are currently conducting the regional studies necessary to
support new exploration opportunities. Also, YPF is evaluating the remaining area of the Austral basin.
•
Deep Waters. We are currently participating in three blocks:
•
•
•
CAA-46. The last exploration period in respect of this block expired in April 2013. We are evaluating alternatives to
propose to Secretaria de Energía (“SEN”) to continue exploring the area.
E-1. We hold a 35% working interest in this Colorado basin block, while ENARSA, Petrobras Argentina and
Petrouruguay have 35%, 25% and 5% working interests, respectively. To complete the evaluation of the block a new
2D seismic survey was scheduled for 2014.
E3. We hold a 30% working interest in this Colorado basin block, while ENARSA and Petrobras Argentina each
holds a 35% working interest. During 2013, geological and geophysical studies were carried out in order to define
the location of a 2D seismic survey. The seismic acquisition is expected to be conducted in 2014.
2. Operated Areas - Development activities
During 2013 our main development activities in Argentina were principally focused on:
2.1. Neuquén - Río Negro:
During 2013, our development activities were focused on gas development in addition to oil development, including a massive
development plan for tight sand gas from the Lajas formation.
In the Octógono field, an oil development project on basement formation was executed by drilling 14 exploitation wells.
Although the Octógono field is the oldest field in the Neuquina basin, this oil development project increased the oil production of the
field over 10 times compared to the field’s production before the implementation of the project, to 270 m3/d of oil.
As part of our strategy to maximize oil production, we continued working on secondary recovery efforts for the Aguada Toledo
– Sierra Barrosa field, with the addition of 39 wells and 3 water injectors. Additionally, we built new facilities and renovated old ones
in order to increase the injection and product evacuation capacity of the Aguada Toledo – Sierra Barrosa field. By the end of 2014, we
expect to double the daily volume of water injection. Finally, there have been advancements with respect to Aguada Toledo – Sierra
Barrosa field in the plan for the development of tight gas from the Lajas formation. As of December 31, 2013, 17 wells were put into
production with 9 additional wells pending completion. The advancements in the plan for development of tight gas from the Lajas
formation resulted in over 2 Mm3/d of natural gas production in December 2013.
45
Neuquen YPF Concession
1 AGUADA DE CASTRO; 2 AGUADA PICHANA;3
APON I (LA BANDA I); 4 APON II (LA BANDA
II); 5 BAJADA DE AÑELO; 6 BAJO DEL TORO; 7
BANDURRIA; 8 BUTA RANQUIL I; 9 BUTA
RANQUIL II; 10 CERRO ARENA; 11 CERRO
AVISPA; 12 CERRO BANDERA; 13 CERRO
HAMACA; 14 CERRO LAS MINAS; 15 CERRO
PARTIDO; 16 CHAPUA ESTE; 17 CHASQUIVIL;18
CHIHUIDO DE LA SALINA SUR; 19 CHIHUIDO
DE LA SIERRA NEGRA; 20 CORRALERA; 21
DON RUIZ; 22 EL OREJANO; 23 EL PORTON; 24
FILO MORADO; 25 LA AMARGA CHICA; 26 LA
RIBERA I; 27LA RIBERA II; 28 LAS MANADAS
(CALANDRIA MORA): 29 LAS TACANAS; 30
LINDERO ATRAVESADO; 31 LOMA AMARILLA;
32 LOMA CAMPANA; 33 LOMA DEL MOJON; 34
LOMA DEL MOLLE; 35 LOMA LA LATA -
SIERRA BARROSA; 36 LOS CANDELEROS; 37
MATA MORA; 38 MESETA BUENA ESPERANZA;
39 OCTOGONO; 40 PAMPA DE LAS YEGUAS I;
41 PAMPA DE LAS YEGUAS II; 42 PASO DE LAS
BARDAS NORTE; 43 PORTEZUELO MINAS; 44
PUESTO CORTADERA (PIEDRA CHENQUE); 45
PUESTO HERNANDEZ; 46 RINCON DEL
MANGRULLO; 47 RIO BARRANCAS; 48
SALINAS DEL HUITRIN; 49 SAN ROQUE; 50
SANTO DOMINGO I; 51 SANTO DOMINGO II; 52
SEÑAL CERRO BAYO; 53 SEÑAL PICADA -
PUNTA BARDA; 54 VOLCAN AUCA MAHUIDA.
The Lajas tight gas project was originally a joint venture (referred to herein by its Spanish-language acronym as a “UTE”)
between us and Potasio Rio Colorado. Potasio Rio Colorado subsequently announced its withdrawal from the UTE, which triggered
our right to continue the project at our own risk. See “Item 4. Information on the Company— Exploration and Production
Overview— Meeting the challenge of the mature oil and gas fields.” In order to continue with analysis of the power of tight gas from
the Lajas formation in other areas, wells were drilled in the El Triángulo and El Cordón fields during 2013. We are in process of
evaluating the productivity of these fields.
In the Loma de la Lata field, which is our largest gas producing field, we have made improvements to our facilities to continue
with the low pressure operation project. In addition, compression at the Loma de la Lata field was increased by adding 138 new
compressors. Moreover, a plunger lift installation program was implemented to improve the field’s production. During 2013, infill
wells were drilled and completed according to expected results, continuing with the development of the Sierras Blancas formation.
Additionally, in order to continue with the development of other productive formations of the field, a well to the Lotena formation
was drilled and is pending completion.
46
During 2013, the activities related to enhanced oil recovery projects continued in the Chihuido de la Sierra Negra field. An integrated
reservoir study and laboratory test were completed during 2013 and a single well chemical tracer test is scheduled to be performed during
first quarter 2014. This test will be defined by one workover and the drilling of eight wells (four producers and four injectors). Also, we plan
to evaluate new opportunities in this field by drilling three appraisal wells to the west of the main field along with a workover plan to the
west and to deeper horizons.
Continuing with the appraisal of the Centenario formation in the Volcan Auca Mahuida field, three new wells were completed during
2013, with an average oil production of 270 bpd per well. In 2014, we expect that eight new wells will be drilled and seven workover
operations will be undertaken.
The discovery of the Cerro Hamaca Noroeste field in late 2012 resulted in a drilling campaign of four appraisal wells and two
exploitation wells during the second half of 2013. The new field is located in the Cerro Hamaca block and is operated by us, with a 100%
working interest in the project. Monthly oil production of the block increased by 47%, up to 786 bopd in January 2014 compared to
September 2013. Nine new exploitation wells have been planned for 2014. Water injection is scheduled to begin in 2015.
In Piedras Negras, a gas field located in the province of Neuquén, we drilled one new well in order to supply gas to the existing power
station located in Señal Picada. In addition, a new power station is scheduled to be installed in Piedras Negras during the first quarter of
2014. This new plant would enable us to supply Señal Picada and Punta Barda fields with electricity, without having to purchase power on
the open market. During 2014, we plan to continue our efforts to delineate the gas accumulation in the Piedras Negras field.
Rio Negro YPF Concession
During 2013, we continued with the optimization of existing waterflooding projects in the Señal Picada field, located in the province of
Río Negro. Sixteen new wells were drilled and workovers in existing wells were also performed. We also increased water injection in the
Señal Picada field by renovating certain of our facilities. We also started an infill project in the Punta Barda field with nine wells drilled and
eleven workovers in 2013. This project resulted in a 28% increase in monthly oil production in December 2013 compared to September
2013.
47
2.2. Mendoza Norte:
During 2013, we worked to improve the waterflooding project in the Barrancas area of the Conglomerado Rojo Inferior
formation by drilling nine new wells (6 producers and 3 injectors), reconditioning 17 existing wells, undertaking 17 workovers and
launching a nano spheres injection pilot project. The nano spheres injection technique consists of injecting polyacrylamide in order to
improve the area of sweep toward the producing wells, thereby increasing the oil recovery factor.
In the Vizcacheras field, 20 new development wells were drilled targeting the Papagayos and Barrancas formations. The
workover activity (18 wells) was focused on primary recovery from the Papagayos formation.
In the Llancanelo field, three wells were drilled, which facilitated our collection of updated production information, and enabled
us to evaluate and analyze the field’s production based on updated static and dynamic models.
In the Valle de Rio Grande field, three wells were drilled and five workovers were performed, principally targeting the Vaca
Muerta formation.
Mendoza Norte YPF
Concession
2.3. Mendoza Sur:
During 2013, we drilled one well and two workovers were performed in the lower Troncoso member of the Huitrin formation in
the Chihuido de la Salina South field, while one horizontal well was drilled in the Chihuido de la Salina South Central field.
48
In the Filo Morado oil field, workover activities were focused on four repairs. Additionally, an advanced well was drilled to
investigate the potential of the Vaca Muerta and Agrio fractured reservoirs.
In the Ruca Carmelo field, two development wells were drilled in the Troncoso formation of the Rincon de Correa field.
Additionally, we gathered data to evaluate the potential for oil in the Mulichinco formation.
In the Porton field, 11 workovers were completed, incorporating the production of the lower Troncoso formation and expanding
productivity by means of new pricks and stimulation of horizontal wells using coil tubing equipment.
In the Desfiladero Bayo field, three infill wells were drilled in the Rayoso, Troncoso bottom and Agrio formations to keep the field
in compliance with the level of injection required by our plan of development. In addition, 36 workovers were completed to that end.
Twenty six new development wells were drilled in the Chachahuen South field in the Rayoso formation, and three advanced wells
were drilled with positive results in the North and East portions of the field.
We continued with the development of the North block in the Cañadon Amarillo field, with two new wells drilled, and conducted
twelve workovers.
Mendoza Sur YPF Concession
49
2.4. Chubut
In the Manantiales Behr concession, our main projects included the La Carolina, El Alba and Grimbeek fields. During 2013,
sixty five wells were drilled, with good results. Additionally, seventy five workovers were completed with very positive results.
Furthermore, operations at the Myburg V water treatment plant were started up in early 2013.
The polymer injection pilot project at the Grimbeek field started with a standard waterflooding and is currently in an advanced
stage. We expect to initiate polymer injection when secondary oil recovery is stabilized, which we expect to occur during the first half
of 2014. We expect to continue to develop the entire Manantiales Behr area by expanding our waterflooding efforts and using
enhanced oil recovery methods.
Chubut YPF Concession
We also experienced growth in the production of our other hydrocarbon assets in the province of Chubut. Oil production from
the El Trébol – Escalante area increased by approximately 10% during 2013 compared to 2012 due to waterflooding optimization and
discovery of certain small sweet spots on deeper structures. Oil production from the Zona Central – Cañadón Perdido concession
increased by nearly 30% during 2013 compared to 2012, primarily as a result of the positive results of the Bella Vista Sur primary
project. Additionally, our concession of the Restinga Alí block was reactivated with very promising development prospects.
50
Overall, our oil production from the province of Chubut grew to historic levels, with an almost 7% increase in oil production in
2013 compared to 2012.
Recently, our board of Directors approved the “Agreement for the Implementation of a Commitment of Activity and Investment
in Hydrocarbon Areas in the Province of Chubut” with the Province of Chubut (the “Extension Agreement”) with the objective of
extending the original term of the exploitation concessions identified below, starting from the expiration of their original granted
terms.
The Extension Agreement signed by YPF and the Province of Chubut establishes, among others, the following terms:
•
•
Concessions included: Restinga Alí, Sarmiento, Campamento Central – Cañadón Perdido, Manantiales Behr
and El Trébol – Escalante.
Extension of the concessions: The exploitation concessions that would have expired in 2017 (Campamiento
Central – Cañadón Perdido y El Trébol – Escalante), 2015 (Restinga Alí) and 2016 (Manantiales Behr) are
extended by a term of 30 years.
By signing the Extension Agreement YPF assumed, among others, the following commitments: (i) pay an Extension Bond of
U.S.$30 million; (ii) pay to the Province of Chubut the Compensation Bond for the Sustainable Development of Hydrocarbons in
accordance with the provisions of Arts. 16 and 69 to 73 of Law XVII – 102 of the Province of Chubut, equivalent to 3% of the
wellhead value defined in accordance with the provisions of articles 59 and 62 of Law 17.319 and the complementary rules;
(iii) comply with a minimum investment commitment in the concessions covered by the Extension Agreement during period of 2018
to 2027, inclusive; (iv) maintain a minimum number of drilling and work-over rigs contracted and active during the period of 2014 to
2018, inclusive; and (v) make contributions to the municipality of Comodoro Rivadavia for projects developed within the area.
ENAP Sipetrol S.A., in its capacity as co-owner of the Campamento Central – Cañadón Perdido exploitation concession (it owns
50% of the concession) signed the Extension Agreement in order to ratify and agree to assume its portion of the commitments in such
exploitation concession.
2.5. Santa Cruz
During 2013, nineteen integrated development projects across five major development areas were implemented in the province
of Santa Cruz (Las Heras, El Guadal, Los Perales, Pico Truncado and Cañadon Seco), comprising a total portfolio of twenty six
projects. The principal integrated projects include the following reserve areas: Cañadón Escondida, Cerro Grande, Cerro Piedra, Seco
León y Los Perales, where 246 wells (241 oil wells and five injectors) were drilled and we conducted workovers of 377 wells and
associated facilities.
The main objectives of these integrated projects are:
•
•
•
•
•
•
The comprehensive development of the areas through the drilling of new wells.
Acquiring the necessary information with electrical logs, rotated plugs and well testing.
Increasing the recovery factor with new enhanced oil recovery projects.
Increasing the vertical and areal sweep efficiency.
Extending horizontal and vertical limits with new appraisal and exploration wells.
The provision of development support through the appropriate surface facilities.
51
Santa Cruz YPF Concession
During 2014, we expect to continue with these projects and to increase our portfolio of primary and secondary recovery projects.
3.
Non-operated areas
In June 2013, we acquired the 23% working interest previously held by Mobil Argentina S.A. in the Aguaragüe joint venture. As a
result of such acquisition, we currently hold a 53% working interest in the joint venture.
In the CNQ 7A block, operated by Petro Andina Resources Argentina SA and in which we hold a 50% working interest, activity
during 2013 principally consisted of drilling in edge zones by completing the design development. In addition, we have made significant
progress with a polymer injection pilot project, and expect alkalines-surfactants-polymers project testing to begin in 2014.
In the Rio Negro Norte - La Yesera concession, operated by Chevron and in which we hold a 35% working interest, a well in the
Western Latigo formation was drilled and put into production in October 2013 with a production of 110 m3/d (approximately 692 boe/d)
of oil and a reduction of 10% in usage of water. The drilling of this new well enabled us to reevaluate our model for this reservoir, and
we have developed new drilling targets for this concession for 2014.
In the Aguada Pichana - San Roque concession, operated by Total S.A. and in which we hold a 27.27% working interest, five tight
natural gas wells were drilled during 2013. The positive results of this project enabled us to target new tight gas sands in the middle of
the Mulichinco formation.
In Aguada Pichana, we began drilling the pilot project of 12 shale gas wells so as to evaluate the productive potential of shale gas
in the Vaca Muerta formation. In Aguada San Roque, two wells were drilled also to evaluate the productive potential of shale oil in the
Vaca Muerta formation.
In the Lindero Atravesado concession, operated by Pan American Energy LLC and in which we hold a 37.5% working interest,
thirty nine wells were drilled and are currently in production. This is a tight gas reservoir project targeting the Lajas formation. The
project also includes building the corresponding field facilities.
52
In December 2013, we signed an agreement with the Executive office of the province of Tierra del Fuego in order to extend our
concessions in that province, in the CA-7 Los Chorrillos areas, operated by Petrolera Lago Fuego (Apache Corporation) and in which we hold a
30% working interest. The final agreement has been approved by the respective parties and is pending the approval of the provincial legislature.
See “—Regulatory Framework and Relationship with the Argentine Government—Negotiation of Extension of Concessions in the province of
Tierra del Fuego.”
Properties and E&P Activities in rest of the world
1.
United States.
During 2013, Maxus relinquished a total of 20 blocks, including 3 to the U.S. federal government and 17 to Murphy Oil.
As of December 31, 2013, we had mineral rights in 27 blocks in the United States territorial waters in the Gulf of Mexico, comprised of 24
exploratory blocks, with a net surface area of 557 square kilometers, and three development blocks, with a net surface area of 69.93 square
kilometers. Our U.S. subsidiaries’ net proved reserves in these properties as of December 31, 2013 were 1.165 mmboe. Our U.S. subsidiaries’ net
hydrocarbon production in these properties for 2013 was 0.593 mmboe.
The Neptune Field is located approximately 120 miles from the Louisiana coast within the deepwater region of the Central Gulf of Mexico.
The unitized field area comprises Atwater Valley Blocks 574, 575 and 618. 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 Woodside
Petroleum Ltd (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 located in Green Canyon Block 613 within 4,230 feet of water. Production began on July 8,
2008. The platform supports seven sub-sea development wells which are tied back to the TLP via a subsea gathering system.
In addition, YPF Holdings has entered into various operating agreements and capital commitments associated with the exploration and
development of its oil and gas properties. Such contractual, financial and/or 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 along 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 8 exploratory wells. During December 2013, seismic acquisition began in the San Sebastian block.
3.
Colombia.
Blocks COR12, COR14 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, or “ANH”). Our working interest in these blocks ranges from
55% to 60%. The net acreage relating to our working interest in the blocks is 890 km2. We have requested approval from the ANH to farm out
our working interest in the COR 12 and COR 33 blocks. Also during 2013, we and our partners informed the ANH of our decision to relinquish
the COR 14 block.
4.
Paraguay.
In September 2011, we were awarded 100% of the Manduvira exploration permit. The area covers a surface of 15,475 km2 and is located in
the eastern area of Paraguay, within the scope of the Chacoparaná basin. Our main goal in this project is to explore non-conventional resources.
In September 2012, the one-year exploration period established by the Manduvira exploration permit expired. We requested a one-year extension
of the exploration period from the Ministry of Public Works and Communications in order to finalize our initial exploration. In late 2013, the
one-year extension was approved
5.
Peru.
The process for completing the award of the rights to explore in Blocks 180, 182, 184 y 176 was never completed by Perupetro (the
enforcement authority for this bid) and the parties to the consortium formed for such purpose decided to relinquish their rights to continue
participating in the process. Said relinquishment was communicated and accepted by Perupetro during 2013.
53
6.
Uruguay
6.1
Deep Water Offshore– Punta del Este basin:
•
•
Area 3: We (40% working interest) act as operator, in partnership with Petrobras Uruguay (40% working interest) and Galp
(20% working interest). Exploration is in the first geological and geophysical evaluation stage. The main leads were
defined. In the last quarter of 2013, 2000 km2 of 3D seismic data acquisition was performed.
Area 4: We (40% working interest) and Petrobras Uruguay (40% working interest), act as operator, together with Galp
(20% working interest). Exploration is in the first geological and geophysical evaluation stage.
6.2
Onshore:
In March 2012, the Arapey exploration permit was awarded in its entirety to us. The block has a surface area of 9,700 km2. Our main
goal in this project is to explore unconventional resources. During 2012, 1,600 km2 of 2D seismic data was re-processed, in addition to field
visits and geochemical, biostratography and sedimentology studies. Currently, a seismic interpretation study is being conducted and a
gravimetry and magnetometry model is being built.
Additional information on our present activities
The following table shows the number of wells in the process of being drilled as of December 31, 2013.
Number of wells in the process of being drilled
Argentina
Rest of South America
North America
Total
Delivery commitments
As of December 31, 2013
Net
Gross
80
—
0
80
78
—
0
78
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, 2013, we were not contractually committed to deliver material quantities of crude oil in the
future.
As of December 31, 2013, we were contractually committed to deliver 24.711 mmcm (or 873 bcf) of natural gas in the future, without
considering export interruptible supply contracts, of which approximately 13.762, mmcm (or 486 bcf) will have to be delivered in the period
from 2014 through 2016. According to our estimates as of December 31, 2013, 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 internal 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.
174 million, Ps. 212 million and Ps. 88 million have been recorded in 2013, 2012 and 2011, 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, according to which we were compelled 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 the 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, 2013, supply requirements under the
Agreement 2007-2011 (which we were compelled to enter into and which was approved by a resolution
54
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 approves the
“Procedimiento para Solicitudes, Confirmaciones y Control de 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 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, on August 30, 2012, we
approved and announced the Strategic Plan 2013-2017 establishing the basis of our development for the years to come. Such plan intends to
reaffirm our commitment to creating a new model for 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) the development of unconventional resources, which we see as a unique
opportunity because a) the expectation related to the existence of large volumes of unconventional resources in Argentina according to
estimates of leading reports on global energy resources, b) we currently possess a relevant participation in terms of exploration and
exploitation rights on the acreage in which such resources could be located, and c) we believe we can integrate a portfolio of projects with
high production potential; (ii) the re-launch of conventional and unconventional exploration initiatives in existing wells and expansion to new
wells, including offshore; (iii) an increase in capital and operating expenditures in mature areas with expected higher return and efficiency
potential (through investment in improvements, increased use of new perforation machinery and well intervention); (iv) a return to active
production of natural gas to accompany our oil production; and (v) an increase in production of refined products through an enhancement of
the refining capacity (including improving and increasing our installed capacity and upgrading and converting our refineries). The previously
mentioned 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.
Natural gas supply contracts
The Argentine government has established regulations for both the export and internal natural gas markets which have affected
Argentine producers’ ability to export natural gas under their contracts. 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). Pursuant to instructions from the Argentine government, deliveries were
interrupted from 2007. In connection with these contracts, the Company has renegotiated them and has agreed to make investments, and
export gas to temporarily import certain final products, subject to approval by the relevant government authorities, which have been recently
obtained. As of the date of this annual report, the Company is fulfilling the agreed commitments mentioned above. To the extent that the
Company does not comply with such agreements, we could be subject to significant claims, subject to the defenses that the Company might
have.
We currently have several supply contracts with Chilean electricity producers (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)),
including:
•
•
a 15-year contract (signed in 1998) to provide 63 mmcf/d (or 1.78 mmcm/d) to the San Isidro Electricity Company (Endesa) in
Quillota, Chile (all of this plant’s natural gas needs);
a 15-year contract (signed in 1999) to supply 20% of the natural gas requirements of the electricity company, Colbun
(approximately 11 mmcf/d or 0.3 mmcm/d); and
55
•
a 15-year contract (signed in 2003) to supply 35 mmcf/d (or 1 mmcm/d) to Gas Valpo, a distributor of natural gas in Chile.
The contracts with Colbun and Gas Valpo have been modified and became interruptible supply contracts.
We also 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 (Neuquén, Argentina) with Chile, which was modified to become an interruptible supply
contract.
Finally, we also 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 have been modified, becoming 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 (see “—The Argentine natural gas market,” below), 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 “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,” we have been forced to reduce the export volumes authorized to be provided under the
relevant agreements and permits as shown in the chart below:
Year
2011
2012
2013
Maximum
Contracted
Volumes
(MCV)(1)
(mmcm)
6,120.4
6,137.2
6,120.4
Restricted
Volumes(2)
(mmcm)
2,785.3
2,728.4
1,828.3
Percentage
of
Restricted
Volumes
vs. MCV
45.5%
44.5%
29.9%
(1) Reflects the maximum quantities committed under our natural gas export contracts. Includes all of our natural gas export contracts
pursuant to which natural gas is exported to Chile.
(2) Reflects the volume of contracted quantities of natural gas for export that were not delivered.
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 1,697 bcf (or 47.9944 bcm) in 2013. We estimate that the number of users connected to distribution systems
throughout Argentina amounted to approximately 8,2 million as of October 31, 2013. The domestic natural gas market has grown over recent
years, driven by the forces of economic growth in Argentina.
In 2013, we sold approximately 46% of our natural gas to local residential distribution companies, approximately 7% to Compressed
Natural Gas end users, approximately 38% to industrial users (including our affiliates Mega and Profertil) and power plants, less than 1% in
exports to foreign markets (Chile) and 8% was consumed in YPF downstream operations. Sales are affected by increased consumption by
residential consumers during winter months (June-August). During 2013, approximately 80% of our natural gas sales were produced in the
Neuquina basin. In 2013, our domestic natural gas sales volumes were 8% lower than those in 2012, See “Item 5. Operating and Financial
Review and Prospects—Factors Affecting Our Operations—Relative maturity of our oil and gas assets.”
The Argentine government has taken a number of steps aimed at satisfying domestic natural gas demand, including pricing and export
regulations and 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 us, 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
56
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 are situated in the Neuquina basin (approximately 66% as of December 31, 2013),
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. The Framework Agreement between the Bolivian and the Argentine governments (executed on
June 29, 2006) provides for natural gas imports from Bolivia to Argentina to be managed by ENARSA. In May 2010, we accepted the offer
made by ENARSA for the sale to us of a minimum amount of 2.5 mmcm/d (or 88.28 mmcf/d) of natural gas obtained by ENARSA from the
Republic of Bolivia through initially May 1, 2011 and then extended through May 1, 2013
In April 2013, quantity and price conditions were renegotiated with ENARSA. According to the new conditions, which are set to expire
in May 1st, 2014, ENARSA undertook to sell us a minimum amount of 1.5 mmcm/d (or 52.97 mmcf/d) of natural gas during the winter of
2013 and 1.0 mmcm/d (or 35.31 mmcf/d) of natural gas during the summer of 2013 and 2014, at fixed seasonal prices. The offer also
establishes an additional quantity of up to 2.5 mmcm/d (or 88.3 mmcf/d).
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 such Agreement was extended to October 2018.
Since beginning its operations, the vessel referred to above has converted liquefied natural gas (LNG) into its gaseous state (natural gas)
in an approximate amount of 11,12 bcm (or 392,7 bcf), which has been injected into a pipeline which feeds the Argentine national network.
Most of this volume was supplied during the peak demand period, i.e., winter. In 2013, natural gas injected into the network amounted to
approximately 3,31bcm (or 116,8 bcf).
In June 2011, YPF, acting as the operator of the UTE Escobar (a joint venture formed by YPF and ENARSA), finalized the construction
of a new LNG Regasification Terminal (“LNG Escobar”), which is 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 beginning its operations the total volume injected into the network
by this vessel was 6,51 bcm (or 229,9 bcf). In 2013 natural gas injected into the network amounted to approximately 2.72 bcm (or 96,2 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.
57
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 2013, 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 fuel, 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.
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 2013, our crude oil production,
substantially all of which was destined to our refineries, represented approximately 80.4% of the total crude oil processed by our
refineries. 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, 2013, 2012 and 2011:
Throughput crude
Throughput Feedstock
Throughput crude/Feedstock(1)
Production
Diesel fuel
Motor Gasoline
Petrochemical naphtha
Jet fuel
Base oils
For the Year Ended December 31,
2012
2011
2013
(mmboe)
105.4
3.0
108.4
101.4
4.1
105.5
103.8
3.1
107
38.8
23.1
5.7
6.1
1.0
41.5
23.1
6.9
6.6
1.3
43.5
22.7
8.1
6.4
1.2
58
For the Year Ended December 31,
2013
2012
2011
Fuel oil
Coke
LPG
Asphalt
(thousands of tons)
1,295
916
589
195
1,338
803
607
198
991
897
620
195
During 2013, our global refinery utilization reached 86.9%, compared to 90.2% in 2012, both calculated over a nominal capacity
of 319.5 mboe/d. See below for a description of certain considerations related to the incident that affected our refinery in La Plata
during 2013 which limited our processing capacity during certain months of 2013.
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 catalytic cracking units, a coking unit, a coker naphtha hydrotreater unit, a
platforming unit, a gasoline hydrotreater, two diesel fuel hydrofinishing units, an isomerization unit, an FCC (fluid cracking catalysts)
naphtha splitter and desulfuration unit, and a lubricants complex. 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 2013, the refinery processed
approximately 147 mbbl/d. The capacity utilization rate at the La Plata refinery for 2013 was 77.6%. As mentioned below, capacity
utilization was affected by the shut down of the Coke A unit. In 2012, the refinery processed approximately 165 mbbl/d. The capacity
utilization rate at the La Plata refinery for 2012 was 87.5%. The crude oil processed at the La Plata refinery comes mainly from our
own production in the Neuquina and Golfo San Jorge basins, representing 81.6% of the total crude oil processed. Crude oil supplies
for the La Plata refinery are transported from the Neuquina basin by pipeline and from the Golfo San Jorge basin by vessel, in each
case to Puerto Rosales, and then by pipeline from Puerto Rosales to the refinery.
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 disrupted refinery systems and caused 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 order to increase the conversion capacity, a new Coke A facility is already under construction and is expected to be
commissioned by 2015. The capacity of the new unit will be 1,160 bbl of fresh feed per hour. This feed will come from the bottoms
of the Topping and Vacuum Units, providing the refinery with an increase in crude processing capacity. The production of the new
facility will be a component for the blend to be used in the production of diesel fuel, motor gasoline; and coke.
In June 2012, we started up a new Gasoil Hydrotreater Unit (HTG “B”) and in November 2012 we finished a revamp of the
former Gasoil Hydrotreater Unit (HTG “A”), seeking to comply with Resolution 478/09, which requires that diesel fuel that will be
sold in large cities be produced with a maximum level of sulphur of 500 parts per million.
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 catalytic cracking unit, a platforming unit, a
Methyl TerButil Eter (“MTBE”) unit, an isomerization unit, an alkylation unit, a naphtha splitter, a hydrocracking unit, a naphtha
hydrotreater unit and two gasoil hydrotreating units. During 2013, the refinery processed approximately 106.4 mbbl/d. During 2013,
the capacity utilization rate was 7.0% higher than in 2012. During 2012, the refinery processed approximately 99.4 mbbl/d. Because
of its location in the western province of Mendoza and its proximity to significant distribution terminals owned by us, the Luján de
Cuyo refinery has become the primary facility responsible for providing the central 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 79.1% of the crude oil processed at the Luján de Cuyo refinery in 2013 (and 83.5% of the
crude oil processed in this refinery in 2012) 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.
59
In order to comply with government regulations on sulfur specifications for fuels, in June 2013, the Luján de Cuyo refinery started up a
new naphtha Hydrotreater Unit (HTN II) and in July 2013, started up a new gasoil Hydrotreater Unit (HDS III).
The Plaza Huincul refinery, located near the town of Plaza Huincul in the province of Neuquén, has an installed capacity of 25,000
boe/d. During 2013, the refinery processed approximately 24.6 mbbl/d. In this period, the capacity utilization rate was 98.3%. During 2012,
the refinery processed approximately 23.5 mbbl/d. In this period, the capacity utilization rate was 94.1%. The only products currently
produced at the refinery are gasoline, diesel fuel 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 La Plata refinery for further processing. The Plaza Huincul refinery receives its crude supplies from the Neuquina basin by
pipeline. Crude oil processed at the Plaza Huincul refinery is mostly produced by us. In 2013, 22.6% of the refinery’s crude supplies were
purchased from third parties, while in 2012, such purchases reached 18.5% 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 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. The refineries maintain their systems under
continuous improvement and revision by authorized organizations.
Logistic 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(3)
Daily
Capacity
(boe/d)
85,200
316,000
106,000
120,700
232,000
114,000
(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 operated the Argentine portion of the pipeline, and a 18%
interest in Oleoducto Transandino Chile S.A., which operated the Chilean portion of the pipeline.
(3) This pipeline ceased operating on December 29, 2005.
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. (“Axion,” previously ESSO, a former subsidiary of ExxonMobil which was recently acquired by Bridas Corporation)
refinery in Campana (168 km), in the province of Buenos Aires.
60
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 them 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.
Between 2010 and 2013, we completed the construction of tanks and facilities for the reception and blending of ethanol in the storage
plants of Luján de Cuyo, Monte Cristo, La Matanza, San Lorenzo and Barranqueras, in order to facilitate compliance with the new specifications
for gasoline set forth by Law 26,093. YPF is currently blending ethanol in the Luján de Cuyo, Monte Cristo, San Lorenzo, La Plata, Junín, Plaza
Huincul, Barranqueras and La Matanza storage plants.
In 1998, our logistic activities were certified under ISO (International Organization for Standardization) 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.
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, fuel oil, LPG, light naphtha and virgin naphtha.
This Division’s export sales are made principally to Brazil and the rest of South America. Sales to international customers for the years
2013 and 2012 totaled Ps.3,792 million and Ps.3,297 million, respectively, 10% and 45% of which, respectively, represented sales of refined
products and 57% and 55% of which, respectively, represented sales of marine fuels. On a volume basis, in 2013 and 2012 sales to international
customers consisted of 0.9 mmbbl and 3.3 mmbbl of refined products, respectively, and 4.11 mmbbl and 3.94 mmbbl of marine fuels,
respectively. Domestic sales of crude oil totaled Ps.1,020 million and Ps.561 million or 2.5 mmbbl and 1.7 mmbbl in 2013 and 2012,
respectively. Domestic sales of marine fuels totaled Ps.771 million and Ps.1080 million or 1.2 mmbbl and 1.3 mmbbl in 2013 and 2012,
respectively. In addition, imports of high and low sulfur diesel fuel have increased, totaling 7.8 mmbbl in 2013.
Marketing division
Our Marketing Division, markets gasoline, diesel fuel, LPG and other petroleum products throughout the country and countries in the
region. We supply all of the fuel market segments: retail, agriculture and industry, including transport. During 2013, we continued to hold a
leading position in the sale of the highest quality naphtha (grade 3) “N-Premium” and in the sale of our standard quality naphtha “Super”,
reaching a market share, according to our estimates, of 58.7% and 54.3% as of December 31, 2013 (compared with 61,3% and 53.1% in 2012),
respectively. Our sales volume for N-Premiun was 1,147 mcm in 2013 (2.4% higher than in 2012) and 3,307 mcm for Super in 2013 (12.2%
higher than in 2012).
With respect to diesel fuel, according to our own estimates, as of December 2013 our market share was 57.7% (57.9% in 2012), with an
increase in our share of low sulphur content products. Along with D-Euro (10 ppm), for which sales volume was 886 mcm in 2013, our product
D-500 (500 ppm) reached a volume of 1887 mcm compared to approximately 968 mcm in 2012, both fuels representing 36.4% of the total diesel
fuel sales of the division. The strategy of promoting D-Euro allowed us to allocate a larger portion of our Ultradiesel fuel to the industry,
transport and agriculture market segments, adequately supplying the market and minimizing the imports of D-Euro.
With respect to lubricants, we market our products through the three segments of the domestic market: retail, agriculture and industry. Our
three manufacturing plants located in the CIE produce YPF’s lubricant, asphalt and paraffin lines of products. Our line of automotive lubricants,
including mono-grade, multi-grade and oil, has received approvals and recommendations from leading global automotive manufacturers (Ford,
Volkswagen, GM, Porsche and Scania).
Concerning LPG, we are engaged in the wholesale business, which encompasses LPG storage, logistics and commercialization to the
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 which are used in the manufacturing of aerosols.
With regard to the international market, in addition to the sale of lubricants in Brazil which began at the end of 2010, during 2013 we
decreased the commercialization in Chile of lubricants and aviation fuels, mainly as a result of the incident that affected our refinery in La Plata,
as mentioned above, which limited the product availability, reaching a volume of 10.8 mcm (-7.2% vs 2012) and 145,6 mcm (+ 1.43% vs 2012)
respectively. Moreover, we currently market lubricants through exclusive distributors in four other countries outside Argentina (Uruguay,
Paraguay, Bolivia and Ecuador).
61
Retail
As of December 31, 2013, the Retail Division’s sales network in Argentina included 1,542 retail service stations (compared to
1,535 at December 31, 2012), of which 111 are directly owned by us, and the remaining 1,431 are affiliated service stations.
OPESSA, our wholly-owned subsidiary, operates actively 174 of our retail service stations, 89 of which are directly owned by us, 26
of which are leased to ACA (Automóvil Club Argentino), and 59 of which are leased to independent owners.
According to our latest internal estimates, as of December 31, 2013, we were the main retailer in Argentina, with 34.1% of the
country’s gasoline service stations, followed by Shell, Axion, Petrobras and Oil with shares of 14.5%, 10.8%, 6.4% and 6.3%,
respectively. During 2013, our market share in diesel fuel and gasoline, marketed in all segments, remainde flat at 56.45%, according
to our analysis of data provided by the Argentine Secretariat of Energy.
The “Red XXI” program, released in October 1997, has significantly improved operational efficiency in service stations. This
program provides us with online performance data for each active station and connects most of our network of service stations. As of
December 31, 2013, 1,280 stations were linked to the Red XXI network system.
Our convenience stores, “Full YPF” and “Full Express YPF”, included 386 and 95 point of sales as of December 31, 2013,
respectively. Also, fuel sales are complemented by a modern oil change service, provide by our “YPF Boxes,” with 256 points of
sales. Additionally, we have a marketing loyalty program called “Serviclub” with more than 500.000 card members.
In order to maintain unified standardsa YPF service station operation manual was developed to be implemented in all of our
affiliated service stations, in 2013. The main objective of this model is to promote self-management of our service stations. The
model is being implemented in stages, starting with 458 service stations throughout the country in 2013 and, and is expected to
continue in 2014 with the rest of our service stations.
As of December 31, 2013, 15 modular systems were implemented in remote locations without supply alternatives (Mencue, Las
Coloradas, El Huecu, Canalejas, for example). These so-called Social Supply Modules (MAS) have minimal environmental impact
and an innovative and technological appearance, using alternative energy and requiring a minimum investment with low operating
costs.
Agriculture
Through the Agriculture Division we sell diesel fuel, fertilizers, lubricants, agrochemicals, and ensiling bags (“silobolsa”),
among other products, directly or through a network of 104 wholesaler bases (9 owned by YPF), offering an extensive portfolio to the
agriculture producer and delivering products to the consumption site. As an option we accept as payment different types of grains,
especially soybean, some of which are processed by third party companies to obtain meal and oil that we then sell mainly to the
external market. In 2013, revenue from such exports amounted to U.S.$383 million. Although we encountered irregular market
conditions in 2013, with serious draughts in the central and northern regions of Argentina affecting demand for fertilizers and
agrochemicals, we received approximately 967,000 tons of grains (oilseed and cereal), primarily soy, a 23% increase compared to
2012. In addition, part of the oil produced from processing soybeans is used for the production of fatty acid methyl esters (“FAME”),
a product which is used internally for the production of commercial grade diesel fuel, in accordance with local regulations. Oil
produced from processing soybeans provides approximately 11% of YPF’s FAME needs.
Industry
This Division supplies the entire domestic industrial and transportation (ground and air) sectors, directly (over 5,500 customers)
or through a network of 37 wholesale bases. We offer a broad portfolio of products and services tailor-made according to the needs of
our customers. This portfolio includes products such as fuels (diesel, gasoline, fuel oil, Jet A-1), lubricants, coal, asphalts, paraffin’s
and derivatives (sulfur, CO2, decanted oil, aromatic extract) and services such as “ YPF Road Card” (fleet management service for
the transportation sector), “Expert Service” (certified quality and quantity of bulk lubricants), “Service & Quality” (technical pre—
and-post-sales services, training and quality product control) and “Supply solution at customer facilities” (plant operation services and
associated logistics).
Our vision as a strategic partner in the industry is to integrate the value chain by promoting energy solutions. In line with this,
we have begun to develop a commercial network to meet the needs of road freight transport, energy supply contracts and lubricants to
mining companies and energy supply projects in industrial clusters.
Lubricants and Specialties
During 2013, our lubricants sales decreased by approximately 11.7% by volume compared to 2012. Sales to domestic markets
decreased by 4.1%, while sales to export markets decreased by 35.9% from 37.7 mcm in 2012 to 24.1 mcm in 2013. Sales of asphalts
and paraffins decreased by 4.8% and 11.2% respectively, compared to 2012.
We export to two main groups. First, to our fully-owned companies in Brazil and Chile, where sales volume decreased by 51%
compared to the previous year in Brazil, and by 26% in Chile. On the other hand, we export to our distributor network located in
Bolivia, Uruguay, Paraguay and Ecuador, in which sales volume decreased by 26% compared to 2012.
62
Our lubricants and specialties unit has followed a strategy of differentiation, allowing it to achieve and maintain the leading position in
the Argentinean market. Our market share as of December 31, 2013 was approximately 39.2%, compared to 42.2% as of December 31, 2012,
according to our analysis of data provided by the Argentine Secretariat of Energy. As indicated above, our line of automotive lubricants has
received approvals and recommendations from leading global automotive manufacturers (Ford, Volkswagen, GM, Porsche and Scania).
With respect to lubricants, the performance of the high-end light and heavy products represented by “Elaion” and “Extravida”
respectively, were approximately the same in 2013 compared with the previous year (with 40.890 mcm in 2013 compared to 40.894 mcm in
2012).
Sales of our most important Elaion brand (automotive) in 2013 amounted to 12.983m3, a 5% increase compared to 2012.
Sales of the Elaion Moto (used for motorcycles) products (which started to be commercialized across the entire distributor and
specialized products network in 2012) increased by 22.5% in 2013 compared to 2012.
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
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 and such market is supplied by YPF Gas S.A. (we sold
approximately 37% of our LPG production in 2013 to YPF Gas S.A.), which is not a YPF company.
We are the largest LPG producer in Argentina with sales in 2013 reaching approximately 593 mtn (compared with 566 mtn in 2012), of
which approximately 432 mtn were sold in the domestic market (compared to 472 mtn in 2012). Our principal clients in the domestic market
are companies that sell LPG in bottled or in bulk packing to end-consumers and the networks that distribute LPG to households in some
regions. Additionally, exports in 2013 reached approximately 161 mtn, compared to 94 mtn in 2012, the main destinations being Chile,
Paraguay and Bolivia. The transport 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.1,298 million and Ps.1,015 million in 2013 and 2012,
respectively.
The LPG division obtains LPG from natural gas processing plants and from our refineries and petrochemical plant. We produced 524
mtn of LPG in 2013 (not including LPG destined for petrochemical usage), and also purchased LPG from third parties, as detailed in the
following table:
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 & Petrochemical Plants(2)
LPG purchased from joint ventures:(3)
LPG purchased from unrelated parties
Total
Purchase
(tons)
2013
20,938
127,904
7,972
156,814
223,279
118,470
25,349
367,098
14,992
40,502
579,406
(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 308 mtn of LPG in 2013.
63
Chemicals
Petrochemicals are produced at our petrochemical complexes 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.
Our petrochemical production operations in the CIE are closely integrated with our refining activities (La Plata refinery). This
close integration allows for a flexible supply of feedstock, the efficient use of byproducts (such as hydrogen) and the supply of
aromatics to increase gasoline octane levels.
The main petrochemical products and production capacity per year are as follows:
CIE:
Aromatics
BTX (Benzene, Toluene, Mixed Xylenes)
Paraxylene
Orthoxylene
Cyclohexane
Solvents
Olefins Derivatives
MTBE
Butene I
Oxoalcohols
TAME
LAB/LAS
LAB
LAS
Polybutenes
PIB
Maleic
Maleic Anhydride
Plaza Huincul:
Methanol
Capacity
(tons per year)
386.500
38,000
25,000
95,000
66,100
60,000
25,000
35,000
105,000
52,000
25,000
26,000
17,500
411,000
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 units.
We also use high carbon dioxide-content natural gas in our methanol production, allowing us to keep our methanol plant
working at 50% of its production capacity during the winter period.
The raw materials for petrochemical production in the CIE, including virgin naphtha, propane, butane and kerosene, are supplied
mainly by the La Plata refinery.
In 2013 and 2012, 71.1 % and 80.8%, respectively, of our petrochemicals sales (including propylene) were made in the domestic
market. Petrochemical exports are destined to Mercosur countries, the rest of Latin America, Europe and the United States. The
increase in exports in 2013 was due to products sold in Brazil, especially Solvente B.
We also participate in the fertilizer business, directly and through Profertil, our 50%-owned subsidiary. Profertil is a joint
venture with Agrium (a worldwide leader in fertilizers), that started operations in 2001. Profertil has a production facility in Bahía
Blanca which produces 1.1 million tons of urea and 750 thousand tons of ammonia per year. In addition, Profertil commercializes
other nutrients and special blends prepared land to optimize land performance.
The CIE was certified under ISO 9001 in 1996 and recertified in 2013 (version 2008). The La Plata petrochemical plant was
certified under ISO 14001 in 2001 and last recertified ( version 2004 ) , in 2013.The plant was also certified under OHSAS 18001 in
2005 and last recertified in 2013 ( version 2007). 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 laboratory of our Ensenada petrochemical plant was
certified under ISO 17025 (version 2005), in 2005 and recertified in 2013.
64
The certification of our petrochemical business covers the following processes:
•
•
•
Refining process of crude oil and production of gas and liquid fuels, lubricant base stocks 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/commercial
control, commercialization and post-sale service of petrochemical products.
Our Methanol plant was certified under ISO 9001 (version 2000) in December 2001, and last recertified in August 2012 (version
2008). The Methanol plant was also certified under ISO 14001 in July 1998 with the Plaza Huincul Refinery, and last recertified in
August 2012 (version 2004), and it was also certified under OHSAS 18001 in December 2008, and last recertified in August 2012
(version 2007).
During 2010, YPF initiated the construction of a new continuous catalytic reforming unit (CCR) in the CIE Complex in
Ensenada. Our total investment was U.S.$453.1 million . Start up was in the third quarter of 2013. The new production from this unit
is satisfying the growing demand of high octane gasoline in the local market, while at the same time the CCR is providing hydrogen
to the new hydrotreater unit in our La Plata refinery.
Other investments and activities
Natural gas liquids
We participated in the development of Mega to increase its ability to separate liquid petroleum products from natural gas. Mega
allowed YPF, through the fractionation of gas liquids, to increase production at the Loma La Lata gas field by approximately 5.0
mmcm/d (or 176.5 mmcf/d) in 2001.
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 natural gas liquids fractionation plant, which produces ethane, propane, butane and natural gasoline. This plant is located
in the city of Bahía Blanca in the province of Buenos Aires.
A pipeline that links both plants and that transports natural gas liquids.
Transportation, storage and port facilities in the proximity of the fractionation plant.
Mega commenced operations at the beginning of 2001. Mega’s maximum annual production capacity is 1.35 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 by the company. On August 14, 2012, the Argentine Judicial Court issued
a first instance ruling in favor of Mega, declaring the unconstitutionality of Decree No. 2067/08 and ENARGAS’ resolutions
No. 1982/11 and 1991/11. Such ruling was appealed by both the ENARGAS and the Ministry of Planning. On June 18, 2013 the
Federal Administrative Court of Appeals ruled in favor of Mega. Such ruling was appealed by both the ENARGAS and the Ministry
of Planning before the Supreme Court. On February 25, 2013 Mega filed a petition for declaratory relief, petitioning the court to
declare the unconstitutionality of Articles 53 and 54 of the General State Budget Law of 2013 that included in the provisions of Law
26,095 the fee created by Decree No. 2067/08 and ENARGAS resolutions No. 1982/2011 and 1991/2011. If such actions are not
resolved in favor of Mega, this fee could significantly and adversely affect Mega’s ability to continue operating. The Audited
Consolidated Financial Statements included elsewhere in this annual report do not include any impairment of assets to be accrued if
Mega were to cease its activity.
Electricity market – generation
The Argentine Electricity Market
Argentina´s overall power generation was 3.53% higher in 2013 than 2012 according to Compañía Administradora del Mercado
Mayorísta Eléctrico S.A. (CAMMESA). In 2013, 63.9% of Argentina’s power generation came from thermal power plants, 31% from
hydroelectric power plants, 4.4% from nuclear power plants, 0.2% from spot imports from Uruguay and Paraguay and the balance
from unconventional sources such as wind and solar power.
65
Thermal power plants consumed 2,548,701 m3 of diesel oil (a 39.49% increase compared to 2012), 2,022,053 tn of fuel oil (a 29.30%
decrease compared to 2012) and 13,571,018 dam3 of natural gas (a 3.3% decrease compared to 2012).
The average electricity production cost was 280.13 Ps./MWh, a 7% increase compared to 2012, while the annual average marginal cost
of production was 809.83 Ps./MWh, a 15.6% increase compared to 2012.
In 2013, a new rule titled 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.
YPF in Power Generation
We participate in three power generation plants with an aggregate installed capacity of 1,622 megawatts (“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 2013, YPF EE generated 4,504 GWh with its two combined cycles. Central Térmica Tucuman’s production was 2,133 GWh, and
Central Termica San Miguel de Tucumán’s production was 2,371 Gwh. Additionally, Central Dock Sud generated 4,902 GWh. The energy
produced by YPF EE and Central Dock Sud (9,406 GWh in total) represented 7.22 % of Argentina´s electricity generation in 2013.
The energy produced by Central Térmica Tucumán was 12.7% lower in 2013 compared to 2012 due to a serious failure inside the TG-01
unit on May 28. Maintenance works to restore the plant’s availability were finished on November 28 and were successful.
Energy produced by Central Térmica San Miguel de Tucumán in 2013 increased by 5% compared to 2012 despite a hot gas path
inspection in unit TG-01 in November and December of 2013.
In August, 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 2013 increased by 24.6 % compared to 2012, primarily because planned major maintenance
activities were carried out in Central Dock Sud’s generation facilities.
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;
Chihuido de la Sierra Negra power plant (40 MW); and
the power plant located at the Plaza Huincul refinery (40 MW).
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 2013, Metrogas distributed approximately 19.5
mmcm (689 mmcf) of natural gas per day to 2.3 million customers in comparison with approximately 20.4 mmcm (or 720mmcf) of natural gas
per day distributed to 2.3 million customers in 2012. During May 2013, the Company, through its subsidiary YPF Inversora Energética S.A.
took control of GASA (the 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 (See Note 13 to the
Audited Consolidated Financial Statements).
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GASA’s debt issues. 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 haircut 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%.
On August 22, 2012, the intervening court ratified the GASA agreement. The court protection proceedings will be finalized once
the court issues a final declaration confirming that the terms of the agreement have been fulfilled.
Under the terms of the debt restructuring proposal, GASA will 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 will become due and payable only if the
New Class A Notes are accelerated as a result of the occurrence of an event of default on or before December 2015. If an event of
default does not occur prior to December 2015, the New Class B Notes will be automatically cancelled.
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 June 13, 2013, GASA’s Board of Directors decided to approve the capitalization of 100% of accrued interest to be paid on
June 15, 2013 in respect of the new notes issued on March 15, 2013, and the issuance of additional bonds to effect the capitalization.
GASA has received the relevant regulatory authorizations and on July 15, 2013 it issued Additional Negotiable Obligations Class A-L
for U.S.$1,167,480 and Class A-U for U.S.$29,632 for the capitalization of such accrued interest.
On July 12, 2013, the relevant court ordered the termination of the reorganization proceedings of GASA.
On October 9, 2013, GASA’s Board of Directors decided to approve the capitalization of 100% of accrued interest to be paid on
December 15, 2013 in respect of the new notes issued on March 15, 2013, and the issuance of additional bonds to effect the
capitalization. The Company has received the relevant regulatory authorizations and on January 14, 2014 it issued Additional
Negotiable Obligations Class A-L for U.S.$2,336,009 and Class A-U for U.S.$59,296 for the capitalization of such accrued interest.
Metrogas debt reorganization. Given the adverse business conditions, Metrogas decided to file a voluntary reorganization
petition (“concurso preventivo”) in June 2010.On the same date, Metrogas was notified of the Resolution No. I-1260 dictated 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 haircut 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 the Bankruptcy Law, where the company’s proposal was
unanimously approved. On July 13, 2012, Metrogas informed the Judge that it considered that had obtained the legal majorities
established in the Article 45 of the Bankruptcy Law 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.
Under the terms of the debt restructuring proposal, Metrogas would 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 will become due and payable only if the
New Class A Notes are accelerated as a result of the occurrence of an event of default on or before December 2015. If an event of
default does not occur prior to December 2015, the New Class B Notes will be automatically cancelled.
In compliance with the reorganization proceeding, 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.
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
Argentine 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.
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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.$704,581
On May 31, 2013, ENARGAS published Resolution ENRG I-2,587/13 providing for the termination of the ENARGAS intervention
in Metrogas.
On September 9, 2013, Metrogas made a formal presentation in connection with the reorganization proceedings requesting that the
court formally declare the completion of the proceedings.
On October 9, 2013, the Metrogas Board of Directors decided by a majority of votes to capitalize 50% of the portion subject to
capitalization of accrued interest payable on December 31, 2013 and to issue Additional Negotiable Obligations to effect the
capitalization.
On January 29, 2014, Metrogas issued:
•
Negotiable Obligations of Capitalization:
Additional Series A-L: U.S.$ 3.516.500
Additional Series A-U: U.S.$ 371.456
On 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 Sect. 59 of the Argentine Bankruptcy Law.
Metrogas tariff issues: In January 2002, pursuant to the Public Emergency Law, the tariffs that Metrogas charges to his 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 pesification. In February 2002, the Government issued Executive Order No. 293, which entrusted the Ministry of
Economy with the renegotiation of public utility licenses and created a Committee for the Renegotiation of Contracts for Public Works
and Services (“CRC”).
On July 3, 2003, by means of Executive Order No. 311/03, the “Unit for the Renegotiation and Analysis of Utility
Contracts” (“UNIREN”) was created, aiming at giving advice during the renegotiation process of public works and services contracts and
developing a regulatory framework common to all public services. The UNIREN continues the renegotiation process developed by the
previous CRC.
The Emergency Law, which was originally schedule to be terminated in December 2003, was consecutively extended up to
December 31, 2013 (currently extended until December 31, 2015). 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 the ENARGAS published the
resolution No. 2,407/12 that authorizes Metrogas, following the terms of the temporary agreement previously mentioned, 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. The resolution also states that the revenue charged by the company is to be
deposited in a trust, and the funds collected are to be used for infrastructure investments, connection works, repowering, expansion and
technology upgrades of the gas distribution system as well as any other cost associated with supply of gas distribution to customers.
Metrogas needs to submit for approval of the execution committee (a regulatory committee created by Resolution 2407/12), a
consolidation and expansion investment plan that expresses both physically and financially the details of such plan, which is to be aligned
with the goals set in the trust’s contract between Metrogas and Nación Fideicomisos S.A. (“NAFISA”).
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Metrogas has been invoicing this new tariff charge since December 3, 2012.
On March 27, 2013, Metrogas received, from the Execution Committee, the notification of approval of the Consolidation and
Expansion Investment Plan submitted on February 1, 2013.
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
Our R&D projects and activities are related to the entire hydrocarbons 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. In 2013, approximately U.S.$16 million was allocated to R&D activities, 21% of which
corresponded to cooperation with external technology centers. In order to support these R&D activities, we invested U.S.$4.5 million
in new laboratory equipment.
Twelve important research and development projects are being partially subsidized by ANPCYC (a technology funding
organization of the Argentine government). Uncertainty about what the main technologies in the future will be, prospective R&D
results and business cycles led us to develop a technology plan that supports YPF’s business strategy. The focus of the plan includes
hydrocarbons, the natural gas value chain, oil refining and oil derivatives and petrochemicals, the future diversification of energy
uses, biofuels production and electricity generation.
R&D efforts were focused on the exploration and exploitation of unconventional resources, where our most important
challenges required the development and application of very specific technologies, including design and development of simulation
modeling, specific software, measuring equipment, fluid and materials design for optimizing perforation, hydraulic stimulation and
production in our oilfields.
To optimize production of mature fields, we focused on the development of enhanced oil recovery technologies in order to
increase recovery of oil from mature fields, 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 were mainly focused on the development of new products with higher added
value, such as special solvents, fertilizers and several agricultural products.
As of December 2013, our R&D projects portfolio consisted of 90 projects; 49 of which are under execution; 18 have been
under technical-economic feasibility evaluation since December 31, 2013 and 23 of which are short-term high impact projects (Quick
Wins).
At the end of 2013, YPF created YPF Tecnología S.A. (YPF holds an equity stake of 51% and CONICET, a state-owned
research and development organization, holds an equity stake of 49%). The Board of Directors of YPF Tecnología consists of 3
directors appointed by YPF and 2 directors appointed by CONICET; additionally, the Chairman and the General Manager of YPF
Tecnología are appointed by YPF. All lines of research and development carried out in YPF Tecnología will be in line with the needs
of YPF.
For operation of YPF Tecnología, 5 hectares on the farm belonging to the National University of La Plata were acquired, and a
12,000 m2 building is planned for construction, with an estimated investment of U.S.$ 48 million (approximately U.S.$ 25 million
relates to YPF’working interest). Completion of the work is expected in July 2015.
We expect that about 250 professionals will work in the new building, and their main goal is to acquire knowledge, to work in
research and development about unconventional fields and secondary and tertiary oil recovery from mature fields. Additionally,
development of alternative energies such as marine, geothermal, wind and solar energy, among others, will be part of their objectives.
All of these activities will be supported by a staff of over 6,000 researchers and doctors from different areas of science, available to
the CONICET through agreements with different universities and institutes of research and development.
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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.”
In this new context, several measures to promote the development of the industry have 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.$/7.5 mmbtu for such additional production. . Producers who account for more than 70 % of the total natural gas production in
the country participate in the program through contracts with the Argentine government. In late 2013, the Argentine government
launched a similar program aimed at second tier producers (mid and small sized oil and gas companies with less diversified portfolios),
to further promote the development of indigenous natural gas resources. Still another measure to promote de 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. YPF believes that the
new measures have helped attract strategic partners for the development of its unconventional resource base, such as Chevron and Dow
Chemical, who in turn increase the number of participants in the market, thus causing the market to become more dynamic in the long
term.
In our Refining and Marketing and Chemicals businesses, we face competition from several major international oil companies,
such as Axion (previously ESSO, a former subsidiary of ExxonMobil which was recently 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.
We operate in a dynamic market in the Argentine downstream industry and the crude oil and natural gas production industry.
Crude oil and most refined products prices are subject to international supply and demand and, in certain cases, to Argentine regulations;
accordingly, prices may fluctuate for a variety of reasons. On April 10, 2013, Resolution 35/2013 of the Argentine Secretariat of
Domestic Commerce determined a maximum prices for fuel at all service stations for period of six months, which would not exceed the
highest outstanding price as of April 9, 2013 in each of the regions identified in the Annex of the Resolution. See “—Regulatory
Framework and Relationship with the Argentine Government.” Changes in the domestic and international prices of crude oil and refined
products have a 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 could affect our level of capital
expenditures.”
On May 3, 2012, the Expropriation Law was passed by 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. See “—Regulatory Framework and Relationship with the Argentine Government—The Expropriation Law.”
It is expected that the Argentine government’s actions taken to promote the industry along with the competitive responses of
different players during 2013 have further strengthened the competitive nature of our industry and fostered a positive business
environment. Nevertheless, we cannot assure you that all the actions and measures previously mentioned will be taken by the Argentine
government and players in our industry.
As mentioned before, the Argentine peso has recently been subject to devaluation (approximately 23% during January 2014). The
Argentine government is analyzing certain measures in response to such devaluation and the impact on the rest of the economy,
including inflation. As discussed under the section “Risk Factors,” devaluation may adversely affect our business and results of
operations. Similar implications may apply to our competitors, thus creating several competitive tensions beyond our control.
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
70
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 diesel fuels. In the La Plata Refinery, a new ultra-low sulphur diesel fuel desulphuration
plant (HTGB) was started up during 2012. In Luján de Cuyo refinery, new HDS III (diesel desulphuration) and HTN II (gasoline
desulphuration) 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.
First stage projects related to biofuels, such as the addition of bioethanol to gasoline and FAME to diesel fuel, 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 fuel and to improve the related biofuel logistics. A new
facility for FAME blending was started up in 2013 in the Montecristo terminal. 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 2013, 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 CCR unit which involved an investment of U.S.$453 million. The plant uses the latest worldwide
technology to perform chemical processes and improvements in productivity, safety and environmental standards. Additionally, the
plant produces aromatics that can be used as octane enhancers for gasoline and automotive applications, as well as increases hydrogen
production to feed the fuel hydrogenation processes to increase fuel quality and reduce sulfur content, further reducing the
environmental impact of internal combustion engines.
We also continue construction of a new Coker Unit at La Plata refinery which will involve an investment of approximately
U.S.$ 790 million, replacing the one that was recently severely damaged in the incident 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 by 2015.
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.
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.
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 facilities.
With respect to climate change, YPF has:
•
committed to active promotion of identification and pursuit of opportunities to reduce greenhouse gas emissions in our
operations; intensifying the execution of internal projects for the obtention of 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;
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•
obtained in December 2010 the approval of United Nations 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 2013 the La Plata
project reduced CO2e emissions by 79.150 tons;
•
obtained in December 2011 the approval of United Nations for an industrial project developed by YPF in Argentina defined as a
Clean Development Mechanism (CDM) at the Luján de Cuyo refinery. During 2013 the project reduced CO2e emissions by
9,820 tons;
•
secured the approval of the CDM project: YPF developed a new methodology, which was approved by United Nations in 2007
under the name of AM0055 “Baseline and Monitoring Methodology for the recovery and utilization of waste gas in refinery
facilities”. At the moment, 5 CDM projects in the world (Argentine, China, and Egypt) are being developed applying this
methodology designed by YPF; and
•
undertaken and verify third-party GHG (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 May 2013, the verification
process inventory of greenhouse gases in the La Plata complex and the Luján de Cuyo refinery was completed. A 2013
inventory check, ending in the first half of 2014, is planned.
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.
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.
On average, this technique uses water (99.5% can be recycled), additives (0.5%) and sand (to keep the cracks opened). 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 (cosmetics), potassium carbonate (detergents), guar gum (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. An example would be the development of unconventional resources in the Neuquina basin, which would
consume only 0.1% of the flow of the Neuquén rivers within a given year. This accounts for much lower volumes than those used for
agricultural and human consumption in the province.
The water handling process complies with all applicable environmental regulations. The policies for the use, treatment and reuse
of the water are rigorous and detailed controls are carried out by the environmental authorities at both the provincial and national
level.
The Vaca Muerta formation if 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 “—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.”
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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% subsidiary of YPF. See “—Regulatory Framework and Relationship with the Argentine Government—U.S. Environmental
Regulations.”
In 1995 YPF acquired Maxus Energy Corporation (“Maxus”), a U.S. corporation headquartered in Dallas, Texas. In connection
with the sale of Diamond Shamrock Chemicals Company (“Chemicals Company”) to a subsidiary of Occidental Petroleum
Corporation (“Occidental”) in 1986, Maxus had agreed to indemnify Chemicals 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” below for a description of environmental matters in
connection with YPF Holdings.
Offshore Operations
All of the offshore fields in which we have a working interest have in place a Health, Safety, Environmental and Community
(“HSEC”) management plan to address risks associated with the project. In addition, all drilling projects that we operate or in which
we have a working interest have in place an Emergency Response Plan (“ERP”), including response plans for oil spills.
The HSEC management plans in place include ERPs for an oil spill or leak, and these ERPs are regularly assessed for adequacy
in light of available information and technical developments. We review our HSEC management plans for our drilling projects on a
regular basis to seek to ensure that appropriate measures are in place for every phase of the project.
Neptune
Under the Neptune Joint Operating Agreement, the operator of the field is required to maintain an HSEC 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 HSEC 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 HSEC management plan for Neptune, which is maintained by the operator of the field, includes the following critical
elements and procedures:
•
•
•
•
•
•
•
•
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
Emergency Shutdown (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:
•
•
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, HSEC, 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.
•
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.
•
•
Crisis Management Team (CMT)—Operator Response (Levels 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 HSEC 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 and/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, 2013,
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—Principal 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, 2013, 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.$1,500 million per incident, 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 –
ART) 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
wilful 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 which 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.
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.
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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:
•
•
•
•
Physical loss or damage to owned property and equipment is limited to U.S.$772 million (100%), with deductibles ranging
from U.S.$0.75 million (100%) to U.S.$1.25 million (100%).
Coverage for operator’s extra expenses is subject to a limit of U.S.$250 million (100%) per incident, with a U.S.$1 million
deductible (100%) (U.S.$10 million (100%) in respect of incidents related to windstorms). 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 fire fighting 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 preventor, 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.$32.0 million (15%) with a waiting time of 60 days
Gulf of Mexico windstorm coverage is subject to a limit of U.S.$40 million (for the insured’s interest) with respect to each
and every occurrence and in the aggregate in respect of 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%) each and every
occurrence plus 90 days waiting time in respect of loss of production.
•
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 %) per incident, with a U.S.$5,000
deductible (100%).
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.
Regulatory Framework and Relationship with the Argentine Government
Overview
The Argentine oil and gas industry has been and continues to be subject to certain policies and regulations that have resulted in
domestic prices that are, in some cases, lower than prevailing international market prices, export regulations, 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, and incremental export duties on the volumes of hydrocarbons allowed to be exported. These governmental
pricing and export regulations and tax policies have been implemented in an effort to satisfy increasing domestic market demand.
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 in 2007, 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.
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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, Law No. 24,145, referred to as 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 square kilometers and 50 production
concessions covering approximately 32,560 square kilometers. The Hydrocarbons Law limits to five the number of concessions that may
be held by any one entity, and also limits the total area of exploration permits that may be granted to a single entity. Based on our
interpretation of the law, we were exempted from such limit with regard to the exploration permits and production concessions awarded to
us by the Privatization Law. Nevertheless, the National Department of Economy of Hydrocarbons (Dirección Nacional de Economía de
los Hidrocarburos), applying a restrictive interpretation of Section 25 and 34 of the Hydrocarbons Law, has objected to the award of new
exploration permits and production concessions in which we have a 100% interest. As a result, our ability to acquire 100% of new
exploration permits and/or production concessions has been hindered, although this interpretation has not impeded our ability to acquire
any permits or concessions where an interest is also granted to other parties. 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).
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:
•
•
•
•
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.
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, 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.
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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 nonconventional 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.
Expropriation of shares held by Repsol YPF
For purposes of ensuring the fulfillment of its objectives, the Expropriation Law provides 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. In addition, the Expropriation Law provides 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 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 which 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 National 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 completed proportionately considering the holdings of the Argentine government and provincial governments, and one
Director shall represent the employees of the Company.
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In accordance with Article 16 of the Expropriation Law, the national 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 “Risk Factors—Risks Relating to Argentina—The Argentine federal government will control the Company according to domestic
energy policies in accordance with Law 26,741 (the “Expropriation Law”)” 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, and “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 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
national 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 (Item 1).
Decree No. 530/12
In connection with the Expropriation Law, Decree No. 530/12 of the National Executive Office provided for the temporary intervention of
YPF for a period of thirty days which was extended by Decree 732/12 until our shareholders’ meeting held on June 4, 2012, with the aim of
securing the continuity of its business and the preservation of its assets and capital, securing the provision of fuel and the satisfaction of the
country’s needs, and guaranteeing that the goals of the Expropriation Law are met. In accordance with Article 3 of Decree No. 530/2012, the
powers conferred by YPF’s by-laws on the Board and/or the President of the Company were temporarily granted to Julio M. De Vido (the
“Intervenor”). On May 7, 2012, through Decree No. 676/2012 of the National Executive Office, Mr. Miguel Matías Galuccio was appointed
General Manager of the Company during the Intervention. At our general shareholders’ meeting held on June 4, 2012, our shareholders appointed
new members of our Board of Directors. See “Item 6. Directors, Senior Management and Employees—Management of the Company.”
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 which 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
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 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.
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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 form Decree No. 1212/89 and sections 3
and 5 from Decree No. 1589/89. Decree No. 1277/12 enacted the “Hydrocarbons Sovereignty Regime Rules”, regulating Law
No. 26,741.
This regulation creates a commission, the Commission for Planning and Strategic Coordination of the National Plan of
Hydrocarbons Investments (the “Commission”) which consists of representatives of Secretariat of Economic Policy and Development
Planning, Secretariat of Energy and Argentine Secretariat of Domestic Commerce. This Commission is entrusted with annually
making the National Plan for Hydrocarbons Investments. According to section 6 of Annex I, the aforementioned plan will take into
consideration a complete and integral evaluation of the hydrocarbons sector of Argentina and will establish the criteria and the
desirable goals on matter of investments in exploration, exploitation, refining, transport and commercialization of hydrocarbons.
Decree No. 1277/12 requires 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 is also
responsible for a National Hydrocarbons Investments Registry for all companies performing the activities of exploration, exploitation,
refining, transport and commercialization. All these companies will also need to file an annual plan of investments before the
Commission.
With respect to the refining industry, Decree No. 1277/12 gives the Commission the power to regulate the minimum utilization
rates for primary or secondary refining. It also has 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 is 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 has 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.
Public Emergency
On January 6, 2002, the Argentine Congress enacted Law No. 25,561, the Public Emergency and Foreign Exchange
System Reform Law (“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 National Executive Office the authority to enact all
necessary regulations in order to overcome the economic crisis which Argentina was then facing. The situation of emergency declared
by Law No.25,561 has been extended until December 31, 2015 by Law No.26,896. 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. The following are 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 26,732. See also “—Taxation” below.
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 granted to third parties in connection with the deregulation and demonopolization process
were granted in accordance with procedures specified in Executive Decrees No. 1055/89, 1212/89 and 1589/89 (the “Oil
Deregulation Decrees”), and permits covering areas in which our predecessor company, Yacimientos Petrolíferos Fiscales S.A., was
operating at the date of the Privatization Law and that 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. Each exploration permit may cover only unproved areas not to
exceed 10,000 square kilometers (15,000 square kilometers 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 revert 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.
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 provides that oil and
gas production concessions shall remain in effect for 25 years as from the date of the award of the production concession, in addition
to any remaining exploration term at the date of such award. The Hydrocarbons Law further provides for the concession term to be
extended for up to 10 additional years, subject to terms and conditions approved by the grantor at the time of the extension. 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 12 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. Upon the expiration of the 10-year extension period of the current concessions, the
provinces are entitled to award new concessions or contracts in respect of the relevant blocks.
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” below.
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. A 12% royalty, and an additional 3% royalty in certain concessions for which the expiration has
been extended (see “—Extension of Exploitation Concessions in the province of Neuquén, —Mendoza, —Salta, —Santa Cruz, —
Chubut and —Tierra del Fuego” below), is 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 commercialized.
Notwithstanding the foregoing, in the extension of our concessions in Santa Cruz, we agreed to a 10% royalty (instead of 12%) for
nonconventional 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.
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.
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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 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.
Additionally, Executive Decree No. 1,454/07, dated October 17, 2007, increased the amount of exploration and production surface
fees expressed in Argentine pesos that are payable to the provinces in which the hydrocarbon fields are located or, in the case of
offshore and certain other fields, to the Argentine government.
Exploration permits and production or transportation concessions may be terminated upon any of the following events:
•
•
•
•
•
•
•
•
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 government in the case of reservoirs under
federal jurisdiction (i.e., located on the continental shelf or beyond 12 nautical miles offshore), without compensation to the holder of
the concession.
Certain of our production concessions expire in 2017 (See “—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 provides that applications must be
submitted at least six months 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 establishing 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—Oil and Gas Reserves.”
In March 2007, the Argentine Secretariat of Energy issued Resolution No 407/07 which 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.
In addition, by Resolution 130/2013 of the Ministry of Economy published on April 19, 2013 in the Official Gazette, the
Argentine Oil Fund was created. This fund will manage resources for an amount of up to U.S.$2,000 million, to provide loans or
capital contributions or acquire financial instruments for the implementation of projects of exploration, exploitation, processing and
marketing of hydrocarbons in relation to oil and gas companies in which the Argentine government has interest or the exercise of
economic and political rights. See “Item 5—Operating and Financial Review and Prospects-Liquidity and Capital Resources.”
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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 expires
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 S.A. 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; and
YPF has undertaken: (i) to make initial payments to the province of Mendoza in an aggregate amount of approximately
U.S.$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; (iii) to carry out exploration activities in the
remaining exploration areas and make certain investments and expenditures in a total amount of U.S.$4,113 million until
the expiration of the extended term, as stipulated in the agreement; (iv) to contribute with 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, are extended for a 25-year term; and
YPF has undertaken:
(i) to make initial payments to the province of Santa Cruz in an aggregate amount of approximately of U.S.$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% on the production of
conventional hydrocarbons, and 10% on the production of unconventional hydrocarbons;
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(iii) to carry out exploration activities in the remaining exploration areas and make certain investments and
expenditures on the exploitation concessions, as stipulated in the agreement;
(iv) to contribute with infrastructure investments within the province of Santa Cruz in an amount equivalent to 20%
of the initial payment, and;
(v) 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 and have recently been acquired by us. The final agreement was executed by YPF, Petrolera LF Company S.R.L. and
Petrolera TDF Company S.R.L. on December 18, 2013. The agreement grants an extension of the Tierra del Fuego concession until
November, 2027 and an extension of the Chorrillos concession until November 2026.
Extension of Concessions in the province of Chubut
The Company has obtained the extension of the following concessions in the Province of Chubut:
•
•
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 as from 2017. 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) To make initial payments to the Province of Chubut in an aggregate amount of U.S.$ 18 Million.
(ii) 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
ended in 2017 (Campamento Central – Cañadón Perdido and El Trébol – Escalante), in 2015 (Restinga Alí) and in 2016
(Manantiales Behr).
The following are the main terms and conditions agreed by and between YPF and the Province of Chubut.
(i) To make initial payments to the Province of Chubut in an aggregate amount of U.S.$ 30 million.
(ii) 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).
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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 term of the exploitation
concessions identified below, subject to the approval of the National Executive Office by decree in a sixty-day term.
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 the following:
•
•
•
Concessions involved: exploitation concession on the following areas: Sierras de Aguaragüe, Campo Durán-
Madrejones, La Bolsa and Río Pescado.
Exploitation concession terms, are extended for a 10-year term from the beginning of expiration of the original 25 year
term, thus ending the extension on November 14, 2027.
Commitments: (i) to conduct in 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 U.S.$36 million, (ii) to 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) to recognize for the province an additional payment, when conditions of
extraordinary income are verified in the marketing of crude oil production and natural gas from concessions, when
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.
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, such as it was recently the case (see “—
The Expropriation Law”), 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.”
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Transportation of Liquid Hydrocarbons
The Hydrocarbons Law 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 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.
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 the 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
S.A. 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 fuel 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:
•
•
in the case of crude oil and petroleum products, not lower than that of imported crude oil and petroleum products of similar
quality; and
in the case of natural gas, not less than 35% of the international price per cubic meter of Arabian light oil, 34 API.
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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.
In addition, on May 3, 2012, the Expropriation Law was passed by the Argentine Congress and, on May 7, 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. Furthermore, 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 form Decree No. 1212/89
and sections 3 and 5 from Decree No. 1589/89. Decree No. 1277/12 enacted the “Hydrocarbons Sovereignty Regime Rules,”
regulating Law No. 26,741. This regulation creates the Commission, which among other matters is entitled to publish reference prices
of every component of the costs and sales prices of hydrocarbons and fuels, which should permit covering up production costs and
obtaining a reasonable profit margin. See “The Expropriation Law” and “Decree No. 1277/2012.”
On July 15, 2013 Decree No. 929/2013 was published in the Official Gazette. Decree 929/2013 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 Project.
Beneficiaries to this Promotion Regime shall enjoy the following benefits, among others: i) they shall be entitled, under the terms of
Law No. 17,319, as 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 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) the Decree sets forth that if hydrocarbon production in Argentina is not
enough to cover domestic supply needs in accordance with section 6 of Law No. 17,319, beneficiaries to the Promotion Regime, as
from the fifth anniversary of the start-up of their respective Investment projects, shall be entitled to obtain, in relation to the
aforementioned exportable rate of liquid and gaseous hydrocarbons produced in said Projects, a price not lower than the reference
export price calculated without deducting any export duties that would have been applicable.
Additionally, the Decree created a new type of concession for the “Exploitation of Unconventional Hydrocarbons,” 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. In this respect, 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.
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 Notes. The
reasons alleged for such 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.
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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 Oil was approved by
Executive Decree No. 652/02 and assured the transportation companies their necessary supply of diesel oil 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,
the current price being Ps.2.50 per liter.
In March 2009, Executive Decree No. 1390/09 empowered the Chief of Staff to sign annual agreements extending the diesel oil 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 oil made under the
scheme. Additionally, as of the date of this annual report, agreements for the fiscal years 2012 and 2013 have been executed.
Over the past months, the Argentine Secretariat of Transport has substantially reduced the volumes of diesel oil subsidized under this
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 oil to public bus
transportation companies. The alleged conduct consists of selling bulk diesel oil 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 oil 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
this Resolution and requested a preliminary injunction against its implementation. YPF’s preliminary injunction has been granted and the effects of
the Resolution have been temporarily suspended. See “Item 8. Financial Information—Legal proceedings—Argentina—Non-accrued, possible
contingencies—CNDC investigation.”
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 above mentioned 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 the Resolution 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 judgement regarding its legality. On August 31, 2012 YPF
was notified of the decision of such Court of Appeals who declared the Resolution 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.
The Argentine Secretariat of Energy has issued a series of resolutions affecting the fuel market. 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; and 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 overcosts 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.
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Resolution S.E. No. 1679/04 reinstalled the registry of diesel oil 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 oil 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 oil 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 fuel is necessary to obtain authorization to export the products included under Decree No. 645/02 (crude,
fuel oil, diesel fuel, 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 fuel demand, by supplying certain minimum volumes (established pursuant to the resolution) to their usual
customers, mainly service station operators and distributors.
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.
In addition, an May 3, 2012, the Expropriation Law was enacted 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. Furthermore, 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 form
Decree No. 1212/89 and sections 3 and 5 from Decree No. 1589/89. Decree No. 1277/12 enacted the “Hydrocarbons Sovereignty
Regime Rules,” regulating Law No. 26,741. This regulation creates the Commission, which among other matters is entitled to publish
reference prices of every component of the costs and sales prices of hydrocarbons and fuels, which should permit covering up
production costs and obtaining a reasonable profit margin. See “The Expropriation Law” and “Decree No. 1277/12.”
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.
On December 30, 2013, the Planning and Strategic Coordination Commission of the National Hydrocarbon Investment Plan
(Comisión Nacional de Planificación y Coordinación Estratégica del Plan Nacional de Inversiones Hidrocarburíferas) 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 23.966) and the tax on diesel oil (imposed by Law 26.098),
jointly with other fuels up to a maximum aggregate amount of 7 million m3.
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.
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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 proposal of agreement with natural gas
producers regarding the supply of natural gas to the domestic market during the period 2007 through 2011 (the “Agreement 2007-2011”), giving
such producers a five-business-day term to enter into the Agreement 2007-2011. We executed the Agreement 2007-2011 taking into account that
producers that did not enter into the 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 the Agreement 2007-2011 and will be treated as any producer that has not
entered into the 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 the 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 the
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). The 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.” The Resolution also states that the Agreement 2007-2011 does not prevent
the possible suspension or termination of export permits.
We were compelled to execute the Agreement 2007-2011, among other reasons, in order to mitigate our potential damages. Producers failing
to sign the Agreement 2007-2011 could be penalized and subject to other unfavorable measures by regulatory authorities. However, we expressly
stated that the execution of the 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 the 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 be subject to the 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. 24/07,
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.
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 the Agreement 2007-2011, which was extended by Resolution S.E.
No. 172. On March 23, 2012, Resolution SE 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,
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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 SE 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 approves 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:
•
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 the Agreement 2007-2011 ratified by the Resolution No. 599/07. See
“—Exploration and Production—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 the 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 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, a similar agreement has not been entered into
for 2012.
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 December 2012, YPF and other gas producing companies of Argentina agreed with 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 1/2013 of the
Commission was published in the Official Gazette. This Resolution formally creates the “Natural
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Gas Additional Injection Stimulus Program.” Under this regulation, gas producing companies are invited to file with the Commission
before June 30th, 2013 projects to increase natural gas injection , in order to receive an increased price of 7.5 U.S.$/MBTU 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 (5) 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. On May 23, 2013 the Commission approved the project submitted by
YPF.
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 of 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 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 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 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%.
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 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
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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.
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):
•
•
•
•
•
•
•
•
•
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;
Law No. 25,688 on Environmental Management of Waters;
Law No. 25,670 on the Management and Elimination of Polychlorinated Biphenyls;
Criminal Code; and
Civil 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 is established in relation to 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 works in order to identify potential technical
94
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 Law No. 24,145.
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. We have commenced the development and implementation of a technical and environmental audit plan as required
by this Resolution.
The above 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 (“Maxus”), are subject to the requirements of the following U.S. environmental laws:
•
•
•
•
•
•
•
•
•
Safe Drinking Water Act;
Clean Water Act;
Oil Pollution Act;
Clean Air Act;
Resource Conservation and Recovery Act;
National Environmental Policy Act;
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. 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.
95
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 natural gas liquids 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.
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.
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.
In addition, the calculation procedure described above also applies to other petroleum products and lubricants based upon different
withholding rates, reference prices and prices allowed to producers.
There can be no 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 outside of Argentina up to 70% of foreign currency proceeds we received
from crude oil and gas export sales, but were required to repatriate the remaining 30% through the exchange markets of Argentina.
In July 2002, Argentina’s Attorney General issued an opinion which would have effectively required us to liquidate 100% of our
export receivables in Argentina, instead of the 30% provided in Decree No. 1,589/89 based on the assumption that Decree No. 1,589/89
had been superseded by other decrees (Decree No. 530/91 and 1,606/01) issued by the government. Subsequent to this opinion, however,
the government issued Decree No. 1,912/02 ordering the Central Bank to apply the 70%/30% regime set out in Decree No. 1,589/89.
Nevertheless, the uncertainty generated by the opinion of Argentina’s Attorney General resulted in a legal proceeding described under
“Item 8. Financial Information—Legal proceedings—Argentina—Non-accrued, remote contingencies—Proceedings related to foreign
currency proceeds.”
Decree No. 1722/2011, of October 26, 2011, re-established Decree No. 2581/64 and requires all oil and gas companies (including
YPF), among other entities, to repatriate 100% of their foreign currency export receivables.
96
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.
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. In 2013, we had consolidated revenues of Ps.90,113 million (U.S.$13,825 million) and consolidated net income of
Ps.5,079 million (U.S.$779 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 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.
On March 20, 2009, the Argentine Federation of Professional Councils in Economic Sciences (“FACPCE”) approved Technical
Resolution No. 26 on the “Adoption of the International Financial Reporting Standards (IFRS) of the International Accounting
Standards Board (IASB).” Such resolution was approved by the CNV through General Resolution No. 562/09 on December 29, 2009
(modified by General Resolution No. 576/10 on July 1, 2010), with respect to certain publicly-traded entities subject to Law
No. 17,811. Compliance with such rules was mandatory for YPF for the fiscal year which begun on January 1, 2012, with transition
date of January 1, 2011.
The financial data contained in this annual report as of December 31, 2013, 2012 and 2011 and for the years then ended has been
derived from our Audited Consolidated Financial Statements included in this annual report. See Note 14to the Audited Consolidated
Financial Statements.
Finally, certain oil and gas disclosures are 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 to third parties and intersegment sales, and marketing of crude oil, natural gas, refined products, petrochemicals, electric
power generation and natural gas distribution (“Downstream”). Other activities not falling into the previously described categories are
reported under a separate segment (“Corporate and Other”), principally including corporate administration costs and assets,
environmental matters related to YPF Holdings (see Note 3 to our Audited Consolidated Financial Statements) and construction
activities. See “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.
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Summarized Income Statement
Revenues
Cost of sales
Gross profit
Administrative expenses
Selling expenses
Exploration expenses
(Expense)/Other income, net
Operating income
Income (Loss) on investments in companies
Financial income (expense), net
Net income before income tax
Income tax
Deferred tax
Net income
Total other comprehensive income
Total comprehensive income
Factors Affecting Our Operations
Our operations are affected by a number of factors, including:
For the Year Ended December 31,
2012
2011
2013
(in millions of pesos)
90,113
(68,571)
21,542
(2,686)
(7,571)
(829)
704
11,160
353
2,835
14,348
(2,844)
(6,425)
5,079
12,031
17,110
67,174
(50,267)
16,907
(2,232)
(5,662)
(582)
(528)
7,903
114
548
8,565
(2,720)
(1,943)
3,902
4,241
8,143
56,211
(41,143)
15,068
(1,822)
(5,438)
(574)
(46)
7,188
685
(287)
7,586
(2,495)
(646)
4,445
1,852
6,297
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
the volume of crude oil, oil byproducts and natural gas we produce and sell;
regulation on domestic pricing;
export administration by the Argentine government and domestic supply requirements;
international prices of crude oil and oil products;
our capital expenditures and financing availability for the Company;
cost increases;
domestic market demand for hydrocarbon products;
operational risks, labor strikes and other forms of public protest in the country;
taxes, including export taxes;
regulations 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 business is inherently volatile due to the influence of exogenous factors such as internal demand, market prices, financial
availability for our business plan and the corresponding cost, 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 future financial
condition, results of operations or trends in future periods. See additionally “Item 4. Information on the Company—Regulatory
Framework and Relationship with the Argentine Government—The Expropriation Law.”
Our operating income in 2013 increased by approximately 41 % compared to 2012. This increase was attributable to, among
other things, the increased in diesel oil and gasoline domestic prices and the increase in volumes sold of gasoline and fuel oil. The
aforementioned effects were partially offset by an increase in depreciation of fixed assets, increased prices of crude oil purchased
from third parties, increased volumes of refined products (principally diesel and gasoline) purchased from third parties mainly as a
consequence of the incident suffered by our La Plata refinery (see below), increased royalties (driven mainly by higher prices of crude
oil at the wellhead), 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.
98
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 disrupted refinery systems and caused 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. The Coke A unit has been shut down permanently since the storm, and, after a significant restoration effort,
the Topping C unit resumed operations up to its full nominal capacity in late May 2013. The industrial complex is insured for damage
and loss of profits caused by the incident under our insurance policy. As of December 31, 2013 we have recognized in our result of
operations U.S.$ 300 million relating to the partial compensation of Coke A damages and operational losses for 2013 from our insurance
coverage. (See “Item 4. Information on the Company—Insurance—Argentine Operations”).
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 6 tanks, 4 of which are for processing and 2
are for dispatch of treated crude oil, concentrates the production of 10 fields in the Malargue area, which constitutes a daily production
of approximately 9,200 barrels of oil and represents 3.8% of the oil production of YPF. As of the date of this annual report, the fire has
been completely extinguished and maintenance works have commenced to reinitiate operations of the surrounding facilities, which had
been preventatively shut down due to the risk of being affected, and to work on reestablishing production. The technical personnel of the
company are currently defining the plan for the total resumption of activities in the coming days. In addition we are in the process of
gathering the necessary information to make a claim under our existing insurance coverage.
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. 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, 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 was 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 depreciation 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, according to preliminary
data.
After vigorous growth in 2010 and2011, 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. Although global economic activity increased during the second half of 2013, downward
revisions to growth forecasts in some economies highlight continued fragilities, and downside risks remain. This creates uncertainty
about the future behavior of developed and emerging economies. Locally, among other factors, key agricultural sectors suffered from a
heavy drought, reducing production and Argentine exports. Private consumption remained positive, although growing at a slower pace
than projected.
In this framework, according to the IMF’s estimates, in 2013, global economic growth reached 3%, although the rate of growth or,
in some cases, contraction, varied significantly from region to region. Additionally, according to the IMF, global output is projected to
expand by approximately 3.7% in 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 for 2013 was revised from 4.9% to 3%.
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The official exchange rate of the Argentine peso against the U.S. dollar as of December 31, 2013, was Ps.6.52 per U.S.$1.00,
reflecting an approximate 32.5% depreciation of the peso relative to the U.S. dollar compared to December 31, 2012 (Ps.4.92 per
U.S.$1.00). In addition, the Argentine peso has recently been subject to devaluation (approximately 23% during January 2014). The
Argentine government is analyzing certain measures in response to such devaluation and the impact on the rest of the economy,
including inflation. In this framework, recent negotiations between crude oil producers, refineries and the Argentine government have
led to an informal agreement to pass through the effect of the previously mentioned devaluation to crude oil and refined products
during the coming months in gradual terms, with the objective to mitigate the economic effects in the rest of the Argentine economy.
Argentina has confronted 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; 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 (“IPCNU”) which more broadly reflects consumer prices by considering price information from the 24
provinces of the country, divided into six regions. According to the IPCNU, inflation for January and February 2014 was 3.7% and
3.4%, respectively. See “Item 3. Risk Factors—Risks Relating to Argentina- Our business is largely dependent upon economic
conditions in Argentina.”
During 2013, Argentina’s trade balance was a surplus of approximately U.S.$9,024 million according to preliminary estimates
from INDEC, compared to total exports of approximately U.S.$83,026 million during 2013, which represents a 3% increase
compared to 2012, and total imports were approximately U.S.$74,002, which represents an 8% increase compared to 2012.
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. Nonetheless, the gap between domestic and international prices for certain products has narrowed from time to time as a
result of the increase in domestic fuel prices.
In 2005, Argentina successfully restructured a substantial portion of its sovereign bonds and settled all of its debt with the IMF.
In June 2010, Argentina completed the renegotiation of approximately 67% of the defaulted bonds that were not swapped in 2005. As
a result of the 2005 and 2010 debt swaps, approximately 91% of the bond indebtedness on which Argentina had defaulted in 2002
was restructured. Certain bondholders did not participate in the restructuring and instead sued Argentina for payment. In late October
2012, the United States Court of Appeals for the Second Circuit rejected an appeal by Argentina concerning payments allegedly due
on bonds that had not been the subject of the swaps in 2005 and 2010. On November 21, 2012, the United States District Court for the
Southern District of New York ordered Argentina to make a deposit of U.S.$1,330 million for payment to the holdout bondholders.
Argentina appealed the District Court’s November 21 order to the Second Circuit Court of Appeals, which granted Argentina’s
request for a stay of the order. On March 19, 2013, Argentina submitted to the Second Circuit a proposed payment plan for holdout
bondholders. That proposal was rejected by the plaintiff holdout bondholders on April 19, 2013. 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
Supreme Court of the United States.
On September 3, 2013, the District Court granted plaintiff holdout bondholders’ requests for discovery from Argentina and
certain financial institutions concerning, among other things, Argentina’s assets and the relationship between Argentina and YPF. In
January 2014, the United States Supreme Court accepted an appeal by Argentina concerning the permissible scope of discovery into
its assets. Litigation initiated by holdout bondholders has resulted, and may result, in material judgments against Argentina and could
result in attachments of or injunctions relating to assets of or deemed owned by Argentina. Such attachments or injunctions could
have a material adverse effect on the country’s economy and also affect our ability to access international financing or repay our
obligations.
In connection with the holdout bondholder litigation in New York federal court against the Republic of Argentina (to which YPF
is not a party), the bondholders had 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 the
Republic of Argentina, including YPF. At a hearing on September 3, 2013, the New York judge ruled that this discovery from those
institutions can go forward as to, among others, the accounts of YPF, in order for the bondholders to determine if those documents
might support an argument that YPF is the alter ego of the Republic of Argentina. Notably, the New York courts previously held that
Banco de la Nación Argentina is not an alter ego of Argentina, and a California Magistrate Judge has recently ruled that bondholders’
factual allegations made in support of asset discovery were insufficient to find YPF to be an alter ego of Argentina. YPF is not a
recipient of any such subpoenas and, as such, has no obligation to produce discovery or otherwise participate in discovery.
We cannot predict the evolution of future macroeconomic events, or the effect that they are likely to have on our business,
financial condition and results of operations. See “Item 3. Key Information—Risk Factors—Risks Relating to Argentina”.
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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 production of certain products and companies in our industry, and actions taken by the Argentine regulatory authorities to prioritize
domestic supply, exported volumes of hydrocarbon products, especially natural gas, declined steadily over this period. At the same time, in the
recent years, Argentina has increased its natural gas and refined products imports.
The table below shows Argentina’s total sales, production, exports and imports of crude oil, diesel fuel 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.
Sources: Argentine Secretariat of Energy.
Year Ended December 31,
2012
2011
2013
191.7
13.7
2.6
197.3
21.8
—
208.9
21.7
—
14,490.6
11,680.8
—
2,427.1
14,076.4
11,978.2
—
1,348.7
14,680.2
12,091.5
—
1,994.8
8,579.7
7,609.8
14.0
378.7
7,846.3
7,301.1
—
53.0
7,320.2
6,853.6
1.3
143.0
Policy and regulatory developments in Argentina, including the Expropriation Law
The Argentine oil and gas industry is currently 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 and that have usually been lower than prevailing international market
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; (v) increasingly higher investment and costs expenditure requirements in order to satisfy domestic demand; and (vi) increasingly
higher taxes. 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.
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 affect directly final consumers (See additionally “—Macroeconomic conditions”).
Notwithstanding the foregoing, and for certain products, the Argentine government has implemented from time to time certain price
and investment incentives 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”). 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. 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 fuel in order to satisfy domestic demand, which has increased our operating
costs, as described in “—Cost of sales.”
101
•
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 the
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 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 with the Commission before
June 30th, 2013 projects to increase natural gas injection , in order to receive an increased price of 7.5 U.S.$/MBTU 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 (5) years, renewable at
the request of the company, upon decision of the Commission. If the 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 in the Official Gazette. This Resolution formally creates 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 31st, 2014 projects to increase natural gas injection. Companies which 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 (4) 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 (7.5 U.S.$/MBTU—4 U.S.$/MBTU) depending on the natural gas injection performance of each producer.
•
•
•
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 fuel 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.
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.
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.
During 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. 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, 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
102
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. Additionally, the mentioned
companies 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 it 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 according 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, 1,012/89 and
1,589/89 (the “Deregulation Decrees”) which set, among other matters, the right to the free disposition of hydrocarbon production. 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 the Expropriation Law.”
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.”), net
sale 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.
2013
Year Ended December 31,
2012
(units sold)
2011
Product
Natural gas (mmcm)
Gasoline (mcm)
Fuel oil (mtn)(1)
Petrochemicals (mtn)
27
74
567
281
45
184
544
335
91
290
490
334
(1)
Includes bunker oil sales of 567,544 and 490 mtn for the years 2013, 2012 and 2011, 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 13.3%, 11.5% and 14.2%, of our consolidated revenues in 2013, 2012 and 2011, 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 fuel 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 have surged. 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, as described in “—Declining export volumes,” and reduced the export parity prices.
103
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 other sectors of the Argentine market. Notwithstanding the foregoing, on February 14, 2013
Resolution 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 with the Commission
before June 30th, 2013 projects to increase natural gas injection , in order to receive an increased price of 7.5 U.S.$/MBTU 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 (5) 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.
Critical Accounting Policies
On March 20, 2009, the FACPCE approved the Technical Resolution No. 26 “Adoption of the International Financial Reporting
Standards (IFRS) of the International Accounting Standards Board (IASB).” Such resolution was approved by the CNV through
General Resolution No. 562/09 dated December 29, 2009 (modified by General Resolution No. 576/10 on July 1, 2010), with respect
to certain publicly-traded entities subject to Law No. 17,811. The application of such rules was mandatory for YPF for the fiscal year
which began on January 1, 2012.
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 Note 1.b.8) 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 3 and 11 to the Audited Consolidated Financial
Statements.
Income tax and deferred tax. See Note 10 to the Audited Consolidated Financial Statements.
In addition, for information regarding to our estimation of oil and gas reserves, see “Item 4—.Information on the Company—
Exploration and Production—Oil and Gas reserves.”
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. Custom 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 Note1.b.16 to the Audited Consolidated Financial Statements.
104
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,
2012
2011
2013
(in millions of pesos)
6,006
17,974
32,374
835
(6,922)
50,267
6,992
26,323
42,980
2,227
(9,881)
68,571
3,748
17,679
25,354
368
(6,006)
41,143
(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
Operation 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,
2012
2011
2013
(in millions of pesos)
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
3,229
251
782
590
4,444
208
1,315
7,832
90
1,447
2,555
5,690
212
2,002
1,727
32,374
2,430
247
684
426
3,518
160
943
6,141
61
989
3,006
3,988
88
1,211
1,462
25,354
Our cost of sales accounted for 76.1% and 74.8% of our consolidated revenues in 2013 and 2012, respectively. Our cost of sales
increased by 36.4% from 2012 to 2013, mainly as a result of: increased purchases of crude oil from third parties, driven mainly by the
increased oil price in the domestic market mainly during 2013; increased purchases of refined products (principally gasoline and
diesel) from third parties, mainly as a result of the incident at our La Plata refinery in April 2013; increased royalties, driven mainly
by higher crude oil prices at the wellhead as a result of the foregoing; higher labor costs; higher costs related to the renegotiation of
certain service contracts; and increased depreciation of fixed assets as a result of the higher investment in fixed assets and asset
remeasurement in pesos, as a result of depreciation of the Argentine peso against the U.S. dollar, which is our the functional currency.
Other income/(expense), net
Other income/(expense), net principally includes reserves for pending lawsuits and other claims, provisions for environmental
remediation and provisions for defined benefit pension plans and other post-retirement benefits. For the year ended December 31,
2013, Other income also includes U.S.$ 300 million relating to the partial compensation of Coke A damages and operational losses
for 2013 related to our insurance coverage for the La Plata refinery incident in April 2013 (See additionally Note 11.b to the Audited
Consolidated Financial Statements).
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.
105
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 reameasure 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 10 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, 2013, 2012 and 2011
The following table sets forth certain financial information as a percentage of net revenes for the years indicated.
Year Ended December 31,
2013
2012
2011
Revenues
Cost of sales
Gross Profit
Administrative expenses
Selling expenses
(Expense)/ Other income, net
Exploration expenses
Operating Income
(percentage of revenues)
100.0
(74.8)
25.2
(3.3)
(8.4)
(0.8)
(0.9)
11.8
100.0
(76.1)
23.9
(3.0)
(8.4)
0.8
(0.9)
12.4
100.0
(73.2)
26.8
(3.2)
(9.7)
(0.1)
(1.0)
12.8
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 13.3%, 11.5% and 14.2%, of our consolidated revenues in 2013, 2012 and 2011,
respectively.
Domestic Market
Product
Natural gas
Diesel fuel
Gasoline
Fuel oil
Petrochemicals
2013
Average
price per
unit(1)
(in pesos)
Units sold
Year Ended December 31,
2012
Units sold
Average
price per
unit(1)
(in pesos)
2011
Average
price per
unit(1)
(in pesos)
Units sold
11,092 mmcm 817/mcm 12,176 mmcm 375/mcm 12,170 mmcm 341/mcm
8,546 mcm 2,613/ cm
3,884 mcm 2,400/ cm
353 mtn 1,997/ton
665 mtn 2,669/ton
8,029 mcm 3,409/cm
4,128 mcm 3,000/ cm
736 mtn 2,467/ton
609 mtn 3,210/ton
8,098 mcm 4,277/cm
4,545 mcm 3,895 /cm
734 mtn 2,963 /ton
579 mtn 4,189/ton
(1) Average prices shown are net of applicable domestic fuel transfer taxes payable by consumers.
Export Markets
Product
Natural gas
Gasoline
Fuel oil
Petrochemicals(2)
2013
Year Ended December 31,
2012
2011
Units sold
Average
price per
unit(1)
(in pesos)
Units sold
Average
price per
unit(1)
(in pesos)
Units sold
Average
price per
unit(1)
(in pesos)
27 mmcm 4,540/mcm 45 mmcm 3,096/mcm 91 mmcm 2,115/mcm
74 mcm 5,274/ cm 131 mcm 4,398/ cm 290 mcm 2,730/ cm
567 mtn 3,157/ton 544 mtn 2,777/ton 490 mtn 2,507/ton
281 mtn 5,262/ton 335 mtn 4,521/ton 334 mtn 4,038/ton
(1) Average prices shown are gross of applicable export withholding taxes payable by us.
(2)
Includes exports of refined paraffinic.
106
Revenues
Revenues in 2013 were Ps.90,113 million, which represented a 34.1% increase compared to Ps.67,174 million in 2012. Among
the main causes that contributed to the increase in revenues, we highlight the following:
•
Diesel oil sales revenues increased in 2013 by approximately Ps.7,259 million compared to 2012, which represented an
increase of 27%. In addition, the average price for diesel mix during 2013 increased by approximately 25.4% compared to
2012. This effect was accompanied by a slight increase in sales volumes of approximately 1%. The latter is expressed
primarily in our Eurodiesel and Diesel 500 products at retail segment, partially offset by decreased sales volumes of
Ultradiesel to the retail and transport segments;
•
With respect to the gasoline, during 2013, there was an increase in volumes sold compared to the same period in 2012 of
approximately 10.1% (12.7% if only “unleaded” gasoline is considered). In addition, during 2013, the average price for the
gasoline mix during 2013 increased by approximately 29.8%, compared to 2012. These factors represented a net increase
in gasoline revenues during 2013 of approximately Ps.5,320 million compared to 2012, which represents an increase of
43%;
•
Fuel oil revenues increased in 2013 by approximately Ps. 359 million compared to 2012 in domestic market, which
represented an increase of approximately 19.8%. Volumes sold in local market were flat during 2013 when compared to
2012 (734,000 tons versus 736,000 tons), having been mainly provided to the electricity generation market. Volumes had
substantially increased during the first quarter of 2013, but were affected by the lower processing capacity temporarily at
the La Plata refinery due to the storm on April 2, 2013. In addition, fuel oil prices increased approximately by 20.1%
during 2013 compared to 2012;
•
Crude oil sales to third parties revenues increased in 2013 by approximately Ps.1,702 million compared to 2012, which
represented an increase of 298%. This increase was due to the temporary lower processing capacity in La Plata refinery, as
mentioned elsewhere in this annual report, crude oil volumes in excess of amounts processed by our Downstream segment
were sold to local third parties which represented an increase of 123,000 cm, and also there were exports sales of
378,000 cm in 2013;
•
Natural gas revenues from sales in Argentina increased in 2013 by approximately Ps.4,492 million compared to 2012,
which represented an increase of 98%. This increase was due to a partial recovery in prices obtained in certain segments in
the domestic natural gas market, such as CNG, power generation plants and some industries. In addition, during 2013, we
recorded revenues related to the Incentive Scheme for Additional Injection of Natural Gas, set by Resolution No. 1/2013
from Planning and Strategic Coordination Commission of the National Plan of Hydrocarbon Investments. The increase was
partially offset by a decrease mainly in sales to the power generation segment and secondarily in the CNG.
•
Grain and related products commercialization revenues increased in 2013 by Ps.1,013 million compared to 2012, which
represented an increase of 78.9%, mainly as a result of higher export volumes, partially offset by lower sales in the local
market; and;
•
In addition, revenues also increased by Ps.1,363 million as a result of the consolidation of GASA, which controls
Metrogas, following our acquisition of control of such company, , and by Ps.266 million as a result of revenues from YPF
Energía Eléctrica S.A. See Note 13 to the Audited Consolidated Financial Statements.
Revenues in 2012 were Ps.67,174 million, which represented a 19.5% increase compared to Ps.56,211 million in 2011. The
evolution and behavior of the oil and gas market, in terms of volume traded among the market players, shows a direct link with the
changes in the macroeconomic variables that affect Argentina, mainly in regard to our core products. Consequently, during 2012, the
evolution of the main productive sectors in Argentina has been affected by, among others factors, the effects of adverse weather
conditions that affected the agricultural sector during 2011 and 2012, which reduced the volume of diesel fuel sold to that sector.
Notwithstanding the foregoing, the main causes of the increase in our revenues during 2012 include:
•
Diesel oil sales revenues in 2012 increased in 2012 by approximately Ps.5,000 million compared to 2011, which
represented a 22.6% increase. The average price received by the Company for the mix of diesel oil during 2012 increased
by approximately 30% compared to 2011. The aforementioned effect was partially offset by an approximately 6% decrease
in sale volumes of our product “Ultradiesel” fuel, although such decrease was partially compensated by an increase in our
service stations sales of our new product Diesel 500.
107
•
•
Gasoline sales revenues increased in 2012 by Ps.3,068 million compared to 2011, which represented a 32.9% increase. This
increase was due to an approximately 6.3% increase in the volume of gasoline sold in 2012 compared to 2011, as well as an
approximately 25% increase in the average price of the mix of gasoline sold by the Company during 2012.
Fuel oil sales revenues increased in 2012 by Ps.1,395 million compared to 2011, which represented a 72.2% increase. This
increase was due to an approximately 108% increase in the volume of fuel oil sold in 2012 compared to 2011 which was in
turn primarily due to increased demand from the electricity generation sector, as well as an approximately 24% increase in the
average price of fuel oil sold by the Company in Argentina in 2012 compared to 2011. Revenues from sales of fuel oil
considering domestic and export sales increased approximately Ps.1,395 million in 2012 compared to 2011.
•
Natural gas sales revenues in Argentina increased in 2012 by Ps.420 million compared to 2011, which represented a 10.1%
increase. This increase was due to the increase of the average price of natural gas sold by the Company by approximately 10%
during 2012. The volume of natural gas sold in Argentina during 2012 remained stable compared to 2011.
As for the international reference price of crude oil, the average price of a barrel of Brent crude oil remained almost unchanged for
2012 over the average for 2011.
According to Notes Nos. 707/12 and 800/12 of the Argentine Secretariat of Energy received during February 2012, the Government
suspended the Petroleum Plus program. As a result, during 2011 our operating result was adversely affected in an amount of
approximately Ps.431 million, by the reversal of the benefits accrued and not yet redeemed by YPF corresponding to such program, at the
time of the suspension. In addition, during 2012, and considering the renegotiation of certain concessions, the Company recognized the
effect of gas imbalances with certain third parties, in accordance with contractual rights, which represented a net positive effect of
approximately 194 million pesos. For further information on our revenues for the years discussed above, see “—Results of operations by
business segment for the years ended December 31, 2013, 2012 and 2011”
Cost of sales
Cost of sales during 2013 was Ps.68,571 million compared to Ps.50,267 million during 2012, which represented a 36.4% increase.
Among the main causes that contributed to this increase, we highlight the following:
•
Higher volumes purchased and prices paid for fuels resulted in a cost increase of Ps.8,349 million. This increase in cost of
sales was due to higher volumes imported of diesel, mainly in its variety of low sulfur (“Eurodiesel”), and of “unleaded” and
“Premium” gasoline, with the aim of domestic demand satisfaction, taking into consideration the effects of the storm that
affected our La Plata refinery that reduced our processing capacity. These imports have been made at higher prices in Ps.
(slightly lower in dollars) during 2013 compared to 2012, resulting in an increase of costs of fuels of approximately Ps.2,946
million, or 78%. In addition, local purchases of diesel and gasoline were made at higher prices of approximately Ps 342
million. Furthermore, the purchases of biofuels (“FAME” and bioethanol) added to diesel and gasoline sold by the Company,
in compliance with current regulations, during 2013, were made at higher prices than in 2012. In the case of bioethanol,
volumes purchased increased by approximately 18.6%, all of which represented an increase of approximately Ps.916 million in
bioethanol costs;
•
Increase in expenses related to operational services and other repair and maintenance services contracts of approximately
Ps.1,974 million, or 27%, due to increased activity mainly in the Upstream segment where the Company has managed to stop
the decline of oil production and further increase natural gas production;
•
During 2013, approximately 150 thousand cm more of crude oil were purchased from third parties compared to 2012, in order
to optimize the supply of liquid fuels in the local market, and to increase the supply of fuel oil to the electricity generating
plants, among others. The average price of crude oil purchases, in pesos, increased by approximately 24.5% during 2013
compared to 2012, principally due to the impact of the depreciation of the Argentine Peso against the U.S. dollar. These factors
caused a net increase in costs of the purchase of crude oil of approximately Ps.1,871 million, or 31%;
•
•
•
Increase in fixed assets depreciation by Ps.2,934 million, or 37%, mainly as a result of higher asset values under depreciation
compared to 2012, due to higher investments in fixed assets during 2012 and 2013, as well as to higher translation differences
of fixed assets remeasured in pesos taking into account the functional currency of the Company;
Higher salaries, social security taxes and other personnel expenses, mainly arising from negotiations and agreements with
unions, with an increase of Ps.1,308 million, or 33%, in costs during 2013 when compared to 2012;
Increase in oil royalties paid by approximately Ps.1.258 million, or 37%, due mainly to the higher wellhead value of
hydrocarbons produced (as a reference, the average purchase price of crude oil during 2013 compared to 2012, showed a slight
increase of 2.5%, reaching U.S.$77 per barrel at the end of 2013: it has greater impact expressed in pesos, due to the 20.4%
average devaluation of the peso between the two periods). Additionally, the amount of royalties for 2013 compared to 2012
increased as a result of the increase in the royalty rates which applied to production from recently renewed concessions, such
as Santa Cruz at the end of 2012.
108
Cost of sales in 2012 was Ps.50,267 million compared to Ps.41,143 million in 2011, representing a 22.2% increase. This
increase was attributable to, among other things:
•
Increase in royalties, driven mainly by the higher crude oil prices at the wellhead. As a reference, the average purchase
price in 2012 was U.S.$72.0 per barrel, while in 2011 it was U.S.$59.7. The increase had greater impact in pesos than in
dollars, due to the average devaluation of 10.3% in 2012. Additionally, the amount of royalties increased in 2012 as a
result of a 2.5% higher production of crude oil, and as a result of the increased rate of royalty applied to production from
recently renewed concessions, such as in Mendoza at the end of 2011 and Santa Cruz at the end of 2012.
•
Increase in the cost of services rendered by third parties, mainly due to negotiations carried out by the Company with
suppliers. In some cases, the increases involved the adjustment of tariffs which had not been changed since 2010, resulting
in a cumulative impact on operating costs during 2012. Additionally, greater development activity occurred during 2012,
related to both unconventional resources and our mature fields, resulting in an increase in operating costs in 2012
•
•
•
•
•
Wage increases primarily as a result of negotiations and agreements with labor unions.
Increases in depreciation of fixed assets by approximately Ps.1,691 million, mainly as a result of higher crude oil
production during 2012, higher capital expenditures and increased effect of currency translation.
During 2012 the Company purchased lower volumes of crude oil from third parties in an amount of approximately 772
mcm compared to the previous year, mainly as a consequence of lower production by the Company in the second quarter
of 2011, as well as the reduced availability in the market of light crude oil from Neuquén in the first quarter of 2012. The
average price for crude purchases from third parties, measured in pesos, increased approximately 34% in 2012 compared to
2011, mainly as a result of price negotiations among domestic producers and refiners in light of the market trend and, to a
lesser extent, to the devaluation of the Argentine peso against the U.S. dollar, considering that such prices are set in U.S.
dollars. Consequently, the net effect of the previously mentioned variations resulted in an increase cost to the Company of
crude oil purchases of approximately 334 million pesos during 2012 compared to 2011;
In addition, during 2012 there were also lower imports of ultra diesel fuel and low-sulfur diesel fuel (Eurodiesel), although
at higher prices compared to the year 2011.
Increases in volumes of purchases of biofuels (FAME and bioethanol) by approximately 23% in 2012 (to blend with our
diesel fuel and gasoline, in compliance with current regulations) at higher prices than those recorded in the same period last
year according to international prices for these products.
Administrative expenses
Our administrative expenses were Ps. 2, 686 millon for 2013, an increase of Ps.454 million, or 20.4%, compared to 2012,
particularly due to increases in wages and social security costs, driven mainly by wage adjustments during 2012 and during 2013, as
well as increases in legal fees related to certain contingencies and because we began consolidating Metrogas S.A. since the takeover
of that company on May 2013, into our consolidated financial statements, as described in Note 13 to our Audited Consolidated
Financial Statements.
Our administrative expenses increased by Ps.410 million (22.5%) in 2012 compared to 2011 mainly due to increases in wages
and related costs, driven mainly by wage adjustments during 2012, as well as increases in fees and compensation for services
rendered by third parties mainly related to technology information service contracts and license expenses.
Selling expenses
Our selling expenses were Ps.7,571 million during 2013 compared to Ps.5,662 million in 2012, which represented an increase of
33.7%, resulting mainly from the increase in fuel freight rates in the domestic market and from higher volumes transported related to
sales increases, and higher export taxes as a result of increased volumes exported during 2013, especially crude oil and LPG volumes
compared to 2012. Higher export taxes related to crude oil exports amounted to Ps.367 million in 2013.
Our selling expenses were Ps.5,662 million in 2012, compared to Ps.5,438 million in 2011, representing an increase of 4.1%.
This increase was attributable mainly to increases in transportation expenses, primarily related to the increase in fuel freight rates in
the domestic market, partially compensated by lower export taxes as a result of lower export volumes of virgin naphtha, light naphtha
and liquefied gas in 2012.
109
Exploration Expenses
Exploration expenses were Ps. 829 million in 2013, with a net increase of Ps.247 million compared to 2012. This was mainly due to the
registration of the permanent abandonment of six exploratory wells in the Neuquina Basin, for shale oil projects. Although these wells did
discover hydrocarbons and provide geological data for the future development of the area, given the production volume and other particular
characteristics thereof, we did not consider them for further commercial development.
Exploration expenses remained almost unchanged in 2012 compared to 2011, mainly due to the similarity of the amount of the exploratory
expenses incurred in the Malvinas area in 2011 and those incurred in 2012 in connection with the abandonment according to unsuccessful result
of the Jaguar well corresponding to our share in the offshore block of Georgetown, Guyana. Additionally, during 2012, exploration activity
related to projects for conventional and unconventional resources in our country continued to be one of our strategic targets.
Other income (expenses), net
During 2013, other income (expense), net, was Ps.704 million compared to expenses of Ps.528 million in 2012. This increase is mainly
attributable to the net effect of the following factors: the U.S.$300 million (Ps. 1,956 millon) recognized in our results of operations relating to
the partial compensation of Coke A damages and operational losses for 2013 related to our insurance coverage for the La Plata refinery incident
in April 2013. partially offset by the non material effect attributable to the total write-off of the book value of the La Plata refinery Coke A Unit
and partial write-off of the book value of the Topping C Unit; our increased provisions related to arbitration proceedings involving the Company
in connection with AES Uruguaiana Emprendimientos S.A. (AESU) and Transportadora de Gas del Mercosur S.A. (TGM), and to the Partial
Award issued by the International Chamber of Commerce Arbitration Tribunal (see Note 3 to the Audited Consolidated Financial Statements).
As we have previously mentioned, the Company was affected by the consequences of an unprecedented storm that involved all the La
Plata, Berisso and Ensenada areas and particularly our La Plata refinery. This storm damaged certain facilities of the Company, and has also had
an impact on operating margins associated with our Downstream segment. Since the storm, the Company has made significant efforts to continue
to satisfy demand, as well as to restore the processing capacity of its Topping C unit on schedule, which has been fully operational since the end
of May 2013.
During 2012 other expenses net were negatively affected, by results related to our subsidiary YPF Holdings, derived from the progress of
settlement negotiations with U.S. government agencies related to certain litigation proceedings, as well as the update of the estimated costs
related to environmental provisions in accordance with new information and / or developments in site characterization, among other factors.
Additionally, in 2011 we had recognized Ps.135 million relating to the insurance compensation related to the accident occurred on the off-shore
platform of the UTE Magallanes in 2010.
Operating income
Operating income in 2013 was Ps.11,160 million compared to Ps.7,903 million in 2012, which represented an increase of Ps.3,257 million
or 41.2%, due to the factors described above.
Operating income in 2012 was Ps.7,903 million, compared to Ps.7,188 million in 2011, representing a 9.9% increase, due to the factors
described above. Our operating margins (operating income divided by revenues) were 11.7% and 12.8% in 2012 and 2011, respectively.
Financial income (expense)
Financial income for 2013 was Ps.2,835 million compared to financial income of Ps.548 million in 2012. This income was mainly due to
higher interest paid due to the higher average amount of borrowings during 2013 and also due to higher interest rates applicable to our debt due to
changes in market conditions in Argentina, which were partially offset by the higher positive exchange rate differences generated by higher peso
depreciation during 2013 compared to 2012, considering the net liability position in pesos of the Company.
Financial income for 2012 was Ps.548 million, compared to negative amount of Ps.287 million for the year 2011. This income was mainly
due to higher financial expenses, due to higher average debt and higher interest rates during the year 2012, which were offset by the effect of the
increase in positive exchange difference generated by the further devaluation of the peso in 2012 compared to previous year, considering the
functional currency of the Company and the peso monetary liability position of the Company.
Income tax and deferred income tax
Income tax and deferred income tax expense during 2013 were Ps.9,269 million, Ps.4,606 million higher than the charge in 2012, which
had reached Ps.4,663 million. The total charge related to current income tax was Ps.2,844 million and Ps.2,720 million respectively in 2013 and
2012, while Ps.6,425 million and Ps.1,943 million respectively, correspond to deferred income tax charges in
110
2013, and 2012, respectively. The latter charges are primarily related to the recording of deferred tax liabilities associated with the
translation differences of fixed assets, taking into account the functional currency of the Company, which represented an increase of
Ps.4,482 million that affected the Company’s results.
Income tax expense for the year 2012 reached Ps.4,663 million compared to Ps.3,141 million in 2011, representing an increase
of 48.4%. Income tax expense in 2012 relates to current income tax in the amount of Ps.2,720 million (Ps.2,495 million for the same
period in 2011), and Ps.1,943 million (Ps.646 million for the same period in 2011) from deferred income tax mainly associated with
translation differences of fixed assets, taking into account the functional currency of the Company and the income tax law.
For additional information on our income tax expense see Note 10 to the Audited Consolidated Financial Statements.
Net income and other comprehensive income
Net income for 2013 was Ps.5,079 million compared to Ps.3,902 million in 2012, representing an increase of 30,2%, due to the
factors described above.
Net income for 2012 was Ps.3,902 million, compared to Ps.4,445 million in 2011, a decrease of 12.2% due to the factors
described above.
Other comprehensive income in 2013 was Ps.12,031 million compared to Ps.4,241 million for 2012, which represented an
increase of 183.7%. This increase is mainly attributable to higher translation differences of fixed assets, due to the impact of the
depreciation of the peso against the U.S. dollar, which is the functional currency of the Company, and the changes in the U.S.
dollar/peso exchange rate.
Based on the above, the total comprehensive income for 2013 was Ps.17,110 million compared to Ps.8,143 million in 2012,
which represented an increase of 110.1%.
Other comprehensive income for the year 2012 was Ps.4,241 million, compared to Ps.1,852 million in 2011, representing an
increase of 129.0%. This increase is mainly attributable to higher translation differences of fixed assets, taking into account the
functional currency of the Company and changes in the exchange rate.
Based on the above, the total comprehensive income for the year 2012 was Ps.8,143 million, compared to Ps.6,297 million for
the year 2011, representing an increase of approximately 29.3%.
Consolidated results of operations by business segment for the years ended December 31, 2013, 2012 and 2011
We have recently 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. Accordingly, the Company has adjusted comparative information for the years 2012 and 2011 to reflect this
reorganization.
The following table sets forth revenues and operating income for each of our lines of business for the years ended December 31,
2013, 2012 and 2011:
Revenues(1)
Exploration and production(2)
Revenues
Revenue from intersegment sales (3)
Total exploration and production
Downstream
Revenues
Revenue from intersegment sales
Total refining and marketing
Corporate and other
Revenues
For the year ended December 31,
2011
2012
2013
(in millions of pesos)
3,851
38,846
42,697
1,135
30,179
31,314
269
23,401
23,670
85,624
1,147
86,771
65,047
1,069
66,116
54.636
848
55,484
638
992
1,306
Revenue from intersegment sales
Total Corporate and others
Less inter-segment sales and fees
Total revenues
Operating income (Loss)
Exploration and production
Downstream
Corporate and other
Consolidation adjustments
Total operating income
2,285
2,923
(42,278)
90,113
1,243
2,235
(32,491)
67,174
651
1,957
(24,900)
56,211
6,324
6,721
(1,522)
(363)
11,160
5,730
4,095
(2,492)
570
7,903
4,067
5,466
(1,714)
(631)
7,188
(1) Revenues are net to us after 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 2.k) 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.16) to the Audited Consolidated Financial Statement.
111
(2)
(3)
Includes exploration costs in Argentina, Guyana 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.
Exploration and Production
During 2013, the Exploration and Production segment had operating income of Ps. 6,324 million, an increase of 10.4%
compared to Ps. 5,730 million for the year 2012.
During 2013 total crude oil production was 2.2% higher than in 2012 (2.81% if only fields operated by YPF are taken into
account), reflecting the efforts of the Company to reverse the production decline since mid 2012. Regarding operations between
business segments, transferred volume between the Exploration & Production segment and Downstream segment was 2.8% lower
during 2013 compared to 2012, mainly due to the temporary reduction in processing capacity suffered at our La Plata refinery due to
the storm on April 2, 2013. As a result of this, crude oil sales increased in the local market during 2013 (about 123,000 m3) and
378,000 m3 were exported, mainly, during the second quarter of the year, while there had been no exports of crude oil in 2012.
The intersegment price in dollars during 2013 increased slightly (2.7%, despite an increase of approximately 23.7% measured in
pesos, considering the depreciation of the peso against the US dollar) compared to 2012.
Natural gas production during 2013 amounted to 33.9 mmm3/d, which represented an increase of approximately 1.4% over the
last year, (4.4% if only fields operated by YPF are taken into account), thus showing a reversal of the decline in production. Our
entire natural gas production, net of internal consumption, is assigned to the Downstream segment for commercialization to third
parties, in which the Exploration & Production segment received the average price obtained by the Company in such sales, net of
commercialization fees. Additionally, the Exploration & Production segment includes the Incentive Scheme for Additional Injection
of Natural Gas, which represented an increase of Ps.4,281 million in revenues during 2013.
As a result of the above factors, crude oil and natural gas net income increased by 36.4% during 2013 compared to 2012.
Operating expenses for the Exploration & Production segment during 2013, compared to 2012, were affected by the following
factors:
•
A Ps.2,713 million increase in fixed assets depreciation, mainly as a result of higher asset values under depreciation
compared to the same period of 2012, due to the increase of investments in fixed assets during 2012 and 2013, as well as to
higher translation differences of fixed assets taking into account the functional currency of the Company;
•
A Ps.1,974 million increase in costs related to operation services and other repair and maintenance services contracts,
primarily due to increased activity, which resulted in the reversal of in the decline in production of crude oil and natural
gas, and also as a result of increased prices paid for such serivces;
•
A Ps.1,258 million increase in royalties paid, due to the higher wellhead price of hydrocarbons produced (as a reference,
the average purchase price of crude oil during 2013, compared to 2012, showed a slight increase of 2.5% to U.S.$77 per
barrel at the end of 2013, although it had greater impact expressed in pesos, due to the 20.4% average devaluation of the
peso against the U.S. dollar). Additionally, the amount of royalties paid for 2013 increased as a result of the increase in
royalty rates applicable to production from recently renewed concessions, such as Santa Cruz at the end of 2012; and
112
•
An increase in provisions recorded by the Company in connection with AES Uruguaiana Emprendimientos S.A. (AESU)
and Transportadora de Gas del Mercosur S.A. (TGM) arbitration claims, and based on the Partial Award issued by the
International Chamber of Commerce Arbitration Tribunal (see Note 3 to the Audited Financial Statements).
Exploration and production revenues increased to Ps.31,314 million in 2012 from Ps.23,670 million in 2011, representing an
increase of 33.6%. Substantially all of our Exploration and Production oil sales went to our Refining and Marketing segment:
intersegment revenues (substantially all of which relate to intersegment sales of crude oil) increased by Ps.6,778 during 2012
compared to the prior year mainly as a result of an approximately 30% increase in the average intersegment price in pesos of a barrel
of oil (an approximately 18% increase in U.S. dollars), which reflects the evolution of prices in domestic market for our different
types of crude oil, as well as due to a 4.5% increase in volumes transferred. The average price of gas sold in the domestic market
presented partial increases in the CNG and Industries segments, totaling additional revenues for Ps.420. Additionally in 2011,
Exploration and Production operating income had been impacted by the reversal of the balance recognized by the Company for
Petroleum Plus program, which was suspended at the beginning of 2012 for a total net amount of Ps 431 million pesos. Also during
2012, and from the renegotiation of concessions, the Company recorded the effect of credits for gas imbalances in its favor and in
relation to other partners, all in accordance with contractual rights, all of which represented a positive net effect between the two
periods of about Ps.194 million pesos. Exploration and Production operating income reached Ps.5,730 million in 2012, a 40.9%
increase from Ps.4,067 million in 2011. Increases in crude oil sales were partially offset by an increase in operating expenses.
Segment operating expenses increased by approximately 30.5% due mainly to (i) a Ps.1,413 million increase in fixed assets
depreciation, mainly as a result of higher assets value under depreciation, (ii) a Ps.1,245 million increase in expenses related to
operation services and other repair and maintenance services contracts due to negotiations carried out by the Company with suppliers,
as well as more activity developed in 2012, (iii) a Ps.929 million increase in royalties paid, due mainly to the higher wellhead value of
hydrocarbons produced (used as the basis for calculation of such royalties), expressed in pesos, mainly as a result of the higher
product prices in 2012 as previously mentioned, and also as a result of the increased rate of royalty which applied to production from
recently renewed concessions, such as in Mendoza at the end of 2011 and Santa Cruz at the end of 2012, and (iv) higher
environmental expenses in Argentina by approximately Ps.374 million.
Exploration expenses remained almost unchanged in 2012 compared to 2011, mainly due to the similarity of the amount of the
exploratory expenses incurred in the Malvinas area in 2011 and those incurred in 2012 in connection with the abandonment according
to unsuccessful result of the Jaguar well corresponding to our share in the offshore block of Georgetown, Guyana. Additionally,
during 2012, exploration activity related to projects for conventional and unconventional resources in our country continued to be one
of our strategic targets.
During 2012, average oil, condensate and liquids production increased by approximately 1.0% compared to 2011,
reaching 275 mbbl/d. However, fiscal year 2011 should not be considered as a reference year in terms of production considering,
among others, the work stoppages that affected our production in such year and for which previous management did not apply
effective measures. Natural gas production in 2012 decreased by 2.1% to 1,179 mmcf/d from 1,208 million cubic feet per day in 2011
(33.4 and 34.2 million cubic meters per day in 2012 and 2011, respectively). This decrease was mainly attributable to the natural
decline in the production curve resulting from the continuing overall maturity of our fields. According to what was previously
mentioned, the total production of oil, condensate, liquids and natural gas, expressed in barrels of oil equivalent, amounted to
177 million in 2012 (approximately 485 thousand barrels per day), compared with 178 million in 2011 (about 488 thousand barrels
per day).
Downstream
During 2013, the Downstream segment, which activities include refining and marketing, logistics, chemicals, natural gas
distribution and electricity power generation, recorded operating income of Ps.6,721 million, compared to Ps.4,095 million in 2012.
The main factors that affected the results of operations of this segment during 2013 are the following:
•
Diesel oil sales revenues during 2013 increased by approximately Ps.7,259 million compared to 2012. Within this context,
the average price for diesel mix during 2013, represented an increase of approximately 25.4% over the average price
obtained for the same period in 2012. In addition, there was a slight increase in sales volumes of approximately 1%
primarily in our Diesel 500 and Eurodiesel products in the retail segment, which was partially offset by a decrease in sales
of Ultradiesel at YPF-branded service stations and transportation segment;
•
Net increase in gasoline sales, during 2013, of approximately Ps.5,320 million compared to 2012 . Within this context,
there was an increase in volumes sold of approximately 10.1% (12.7% if only considered the “unleaded” gasoline).
Additionally, during 2013, the average price for the gasoline mix showed an increase of approximately 29.8% , compared
to the average price registered in 2012;
113
•
•
•
•
•
Sales volumes of fuel oil in the local market during 2013 remained almost unchanged from 2012 (approximately 734,000
tons in 2013 versus 736,000 tons in 2012), which represented primarily sales to the electricity generation market. Product
volumes had increased substantially during the first, quarter of 2013, but then we were affected by lower capacity
utilization temporarily suffered in our Refinery in La Plata from April 2 accident explained below. Additionally, the
average price of fuel oil increased during 2013, approximately 20.1% compared to 2012. These effects had a positive
impact of approximately Ps.359 million in sales revenues from these products compared to 2012;
Petrochemicals sales revenues in the local market, during 2013, experienced higher volumes and higher prices related to
aromatic products, LAB and alcohols, and lower volumes of methanol, but with higher prices, all which represented a net
revenue increase of approximately Ps.470 million compared to 2012. Regarding exports of petrochemicals, there were
higher volumes exported of methanol and solvents , cut under light paraffinic and alcohols, offset by the sales price of
petrochemical exports, resulting in a negative net effect on sales revenue of approximately Ps.33 million;
During 2013, higher volumes imported of “unleaded” and “Premium” gasoline and diesel, mainly in its variety of low
sulfur (“Eurodiesel”), the latter having been made at higher prices in pesos (slightly less in dollars) compared to 2012,
which resulted in a combined increase of approximately Ps.2,946 million. These imports, like the higher local purchases of
diesel and gasoline of approximately Ps.342 million, were undertaken in order to maintain the level of customer
satisfaction;
Higher volumes and costs in purchases of biofuels (“FAME” and bioethanol ) to be included in diesel and gasoline sold by
the Company, in compliance with current regulations (Law No. 26,093), In the case of bioethanol, volumes increased by
approximately 18.6%, all of which represented an increase of approximately Ps.916 million;
During 2013 (especially during the first quarter), approximately 150 thousand cm of crude oil were purchased from third
parties compared to 2012, in order to optimize the supply of liquid fuels in the local market and to increase the supply of
fuel oil to electricity generating plants, among others. The average price of crude oil purchases, in pesos, increased
approximately 24.5% during 2013 compared to 2012, due to an increase in the exchange rate. These effects contributed to
a net increase of the purchase of crude oil from other producers of approximately Ps.1,871 million. Also, the average
purchase price of crude oil exploration and production segment, measured in pesos, increased approximately 23,7% during
2013 compared to 2012;
•
Regarding production costs, during 2013, freight rates for crude oil and raw materials transportation increased as well as
rates for use of port and harbor facilities and contracted services rates for repair and maintenance of our refineries,
primarily due to economic recovery and wage increases. Also, especially in the second and third quarter of 2013, we
recorded charges related to the repair of damages caused by the storm suffered at our refinery La Plata, and to cleaning,
remediation and general repairs of the Complex. As a result of this, the total amount of charges increased by approximately
by 32.8% and considering also the lower level of processing in refineries as mentioned below, the refining cost increased
by approximately 38.2% during 2013 compared to in 2012, being the current Ps.37.5 per barrel;
•
•
Increases in provisions for environmental remediation were recorded for approximately Ps. 287 million in 2013 compared
to 2012; and
Regarding natural gas, the Company has continued to fulfill domestic demand, allocating almost all of its production to the
local market. During 2013, there was a similar level of volumes sold to distributors in the residential segment, decreasing
the volumes allocated to power generation plants, CNG, and to suppliers and customers of the industrial segment. In terms
of prices, there was a partial recovery primarily on CNG and industrial segments in the Argentine market. On the other
hand, average selling prices in dollars to our jointly-controlled company, Mega, whose contract links prices to
internationally traded commodities, decreased approximately by 9.1%, having been increased by approximately 9.4% when
expressed in pesos.
During 2013, the utilization capacity of our refineries was approximately 278 thousand barrels of oil per day, representing a
decrease of approximately 3.6% compared to 2012. This decrease was due almost entirely to the lower refining capacity of La Plata
refinery, affected by a storm. The other two refineries of the Company, Lujan de Cuyo and Plaza Huincul, operated practically at
100% capacity during 2013.
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 disrupted refinery systems and caused 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). The Coke A unit has been shut down permanently
since the storm, and, after a significant restoration effort, the Topping C unit resumed operation with full nominal capacity in late
May 2013.
Regarding this incident, during 2013 we recognized U.S.$300 million in our results of operations relating to the partial
compensation of Coke A damages and operational losses for 2013 related to our insurance coverage for the La Plata refinery incident
in April 2013, partially offset by the non material effect attributable to the total write-off of the book value of the La Plata refinery
Coke A Unit and partial write-off of the book value of the Topping C Unit.
114
For information related to revenues and costs of our subsidiaries Metrogas S.A. and YPF Energía Eléctrica S.A. , which we
began consolidating in the second and third quarters of 2013, respectively , see Note 13 to the Audited Consolidated Financial
Statements.
Downstream segment revenues in 2012 were Ps.66,116 million, a 19.2% increase compared to Ps.55,484 million in revenues
recorded in 2011. This increase was attributable, among other factors, to the following:
•
An approximately 6.0% decrease in the volume sold of diesel fuels, especially in our Ultradiesel in almost all business
segments, partially offset by an increase in the volume sold of our new product, Diesel 500, in the service station segment.
Additionally, the price of all types of diesel fuels sold domestically increased approximately 30%.
•
An approximately 6.3% increase in the volume of gasoline sold, as well as price increases in the mix of gasoline sold
locally of about 25%. The net effect of the aforementioned variations accounted for an increase in revenues of
approximately Ps 3.1 billion in 2012 compared to 2011.
•
•
An approximately 108% increase in domestic fuel oil sales, mainly for power generation. Additionally, the domestic sale
price of fuel oil increased in average by approximately 24% in 2012.
Regarding petrochemicals sales revenues in the local market, during 2012, lower volumes of methanol, aromatics and
alcohols were sold, but with better prices in all these cases, which yielded a net increase in revenues of approximately
Ps. 180 million compared to 2011. As for exports of petrochemicals, decreased export volumes of methanol, solvents and
alcohols and paraffinic cut under light were recorded, which decrease was offset by higher prices for the aggregate amount
of products exported, resulting in a Ps.164 million increase in revenues.
Operating income in 2012 was Ps.4,095 million compared to Ps.5,466 million for the previous year, representing a 25.1%
decrease. Increases in gasoline volumes sold in domestic market and in diesel fuel and gasoline local prices were more than offset by
increased operating expenses, which increase was attributable, among other factors, to the following:
•
•
•
•
A 30% increase in the average price paid for purchases of crude oil from third parties as well as from our Exploration and
Production business segment (which purchases account for approximately 90% of our Refining and Marketing business
segment’s operating costs). This increase reflected the adjustments made in crude oil prices in the domestic market among
local producers, considering the evolution of the market and differences in the quality of crude oil.
A decrease in imports of regular diesel fuel and low-sulfur diesel fuel (Eurodiesel), offset by higher prices compared to
2011.
A 23% increase in the volume of biofuels purchased (FAME and bioethanol) to be incorporated into the fuel and gasoline
sold by the Company, in compliance with current regulations (Law 26,093). Additionally, the price of such biofuels
(particularly bioethanol) increased in 2012.
A 15% increase in refining cost (other than crude oil purchases) during 2012, to Ps.26.3 per barrel in 2012 compared to
Ps.22.9 per barrel in 2011. This increase was mainly attributable to increases in (i) contracted service fees for repair and
maintenance of our refineries, (ii) crude and product transportation fees and use of port facilities, (iii) the cost of electricity,
water and steam and raw materials which are primarily driven by general economic conditions, and (iv) wage increases.
During 2012, the utilization capacity of our refineries was approximately 288 thousand barrels of oil per day, representing an
increase of approximately 1.4% compared to 2011. It is worth noting however, that the utilization capacity of our refineries increased
by approximately 4.8% in the second half of 2012 compared to the second half of the previous year.
Corporate and others
In 2013, operating loss for the Corporate and others segment were Ps.1,522 million, compared to Ps.2,492 million for 2012 .
Segment results were positively affected by lower losses related to the estimated costs of environmental remediations of our
subsidiary YPF Holdings compared to those recorded in 2012, improved results in 2013 by our subsidiary A-Evangelista SA, as well
as by the effect of the redistribution of certain corporate costs to business units and were partially offset by higher costs of salaries,
social security and IT services contracts and institutional advertising.
115
In 2012, operating loss for corporate and others segment reached Ps.2,492 million, a 45.4% increase compared to 2011, particularly
due to higher salaries and related charges, increases in fees and compensation for services, higher technology information services and
licenses expenses and the lower operating income of our controlled company A-Evangelista S.A. primarily due to the recognition of lower
margins in the development of long-term construction operations the cumulative impact of which affected A-Evangelista S.A.’s results for
2012. In addition, the results of this segment were negatively affected by the environmental expenses incurred by our subsidiary YPF
Holdings (incremental negative effect of approximately Ps.249 million in 2012) in accordance with the progress of settlement negotiations
with U.S. government agencies related to litigation, as well as the update of the estimated costs related to environmental provisions in
accordance with new information and / or advancement in sites characterizations.
Liquidity and Capital Resources
Financial condition
Total loans outstanding as of December 31, 2013, 2012 and 2011 was Ps.31,890 million, Ps.17,104 million and Ps.12,198 million,
respectively, consisting of current loans (including the current portion of long-term debt) of Ps.8,814 million and long-term debt of
Ps.23,076 million as of December 31, 2013, of Ps.5,004 million and non-current loans debt of Ps.12,100 million as of December 31, 2012,
and short-term debt of Ps.7,763 million and long-term debt of Ps.4,435 million as of December 31, 2011. As of December 31, 2013, 2012
and 2011, approximately 60%, 52% and 83%of our debt was 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, 2013, we had repurchased approximately U.S.$23.97 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.
2013
For the Year Ended December 31,
2012
(in millions of pesos)
2011
Net cash flows provided by operating activities
Net cash flows used in investing activities
Net cash flows provided by (used in) financing activities
Translation differences generated by cash and equivalents
Net increase/(decrease) in cash and equivalents
Cash and equivalents at the beginning of period
Cash and equivalents provided by the acquisition of GASA
Cash and equivalents at the end of period
20,964
(22,344)
6,979
224
5,823
4,747
143
10,713
17,301
(16,403)
2,654
83
3,635
1,112
12,686
(12,158)
(1,844)
102
(1,214)
2,326
4,747
1,112
Net cash flows provided by operating activities were Ps.20,964 million in 2013, compared to Ps.17,301 million in 2012. This 21%
increase was primarily attributable to improved operating results, after taking account of depreciation of fixed assets and provisions
included in liabilities (mainly recording the provisions related to the effects of awards in arbitration proceedings relating to TGM and
AESU), which did not require dibursement of funds, during 2013 compared to 2012.
Net cash flow provided by operating activities was Ps.17,301 million in 2012, compared to Ps.12,686 million in 2011. This increase
was primarily attributable to higher operating income before depreciation of fixed assets in 2012 compared to 2011, as explained above.
In our opinion, given the operating income of the company and the financing alternatives we expect to have available if needed according
to the information available to us as of the date of this annual report, we consider that our working capital is sufficient for the company’s
present requirements. See “—Risk Factors—Risks Relating to Argentina” and “—Risk Factors—Risks Relating to the Argentine Oil and
Gas Business and Our Business.”
Our principal uses of cash in investing and financing activities during 2013 included Ps.22,288 million for investments in fixed
assets and intangible assets (net of sales of fixed assets and intangible assets), which relate mainly to investments made by our
Exploration & Production unit and investment in our refineries. Our principal uses of cash in investing and financing activities during
2012 included Ps.16,403 million for investments in fixed assets, which relate mainly to investments made by our Exploration and
Production unit and investment in our refineries.
Our principal uses of cash in investing and financing activities in 2011 included Ps.12,158 million for investments in fixed assets,
which relate mainly to investments made by our Exploration and Production unit, as well as net debt repayment totaling Ps.1,844 million
and the payment of dividends amounting to Ps.2,753 million.
116
In addition, net cash flows provided by financing activities in 2013 and 2012 includes our increased financing obtained during
2013, principally incurred with the objective to finance our increased investment activities as mentioned before, totaling
Ps.6,979 million during 2013 in comparison to Ps.2,654 million in 2012. During 2013 we issued notes in the international debt capital
markets for an aggregate principal amount of U.S. dollars 650 million. During 2011, our net cash flow used in financing activities
includes net financing obtained during 2011 in the amount of Ps. 3,721, net of dividends paid in the amount of Ps. 5,565.In the
shareholders’ agreement entered into by Repsol YPF and Petersen Energía in connection with the Petersen Transaction, they had
agreed to effect the adoption of a dividend policy under which we would distribute 90% of our net income as dividends, starting with
our net income for 2007. In 2011, we paid Ps.5,565 million (Ps.14.15 per share) with respect to 2010 earnings. However, 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. Furthermore, at the shareholders’ general ordinary and extraordinary 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 2013. In addition, during 2012 the Company approved its 2013-2017 Strategic Plan, which 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.
The Shareholder’s meeting held on January 8, 2008, approved a Medium Term Notes Program for an amount up to
U.S.$1,000 million. 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.$2,000 million in each time, resulting in a maximum nominal amount in circulation
at any time under the program of U.S.$5,000 million, 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.
Under such Medium-Term Notes Program, YPF S.A. issued several series of notes in the local and international markets, and 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, during 2013 we acquired the
control of GASA which has outstanding notes, including those related to it controlled company Metrogas S.A., for an amount of
Ps.1,225 million as of December 31, 2013. For additional information about the outstanding notes of YPF S.A. and our controlled
companies as of December 31, 2013, see Note 13 to the Audited Consolidated Financial Statements.
In addition, pursuant to Resolution 130/2013 of the Ministry of Economy that created the Argentine Oil Fund (See “Item 4.
Information on the Company—Regulatory Framework and Relationship with the Argentine Government— Exploration and
Production”), the Company has recently received a Ps. 8.5 billion line of credit. The amount we may draw down under this line of
credit can be for investments in fixed assets and working capital in Argentina. Each tranch we draw down under the line of credit will
be due in three annual installments after the fith year since they are disbursed to us, and will accrue interest at BADLAR plus a 400
point margin.
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, 2013, plus accrued but unpaid interest as of that date:
Debt
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)
31,890 8,814 3,379 5,986 3,599 5,892 4,220
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, 2013:
Contractual Obligations
Debt(1)
Operating Lease Obligations
Purchase Obligations(2)
Purchases of services
Purchases of goods
LPG
Total
Less than
1 year
1 –3
years
3 –5
years
More than 5
years
3,349
655
2,155
1,234
920
—
(in millions of U.S.$)(5)
1,820 2,248 1,819
250 297 100
1,273 607 200
621 361 178
652 247
22
— —
—
1,001
8
75
75
—
—
Electricity
Gas
Oil
Steam
Others
Other Liabilities(3)(6)
Total(3)(4)
38
21
4,287
29
545
7,735
13,894
10
7
21
21 — —
122 165 —
12
3
3,666 947 908
7,009 2,663 1,714
6
493
12
49
—
—
—
—
—
2,214
2,509
(1) These projected amounts include interest due during all the periods presented. Interest on variable rate instruments is calculated
using the rate as of December 31, 2013 for all periods. See additionally Operating and Financial Review and Prospects—
Liquidity and Capital Resources—Covenants in our indebtedness.”
117
(2)
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) Reserves for contingent liabilities under commercial contracts, which amounted to U.S.$797 million as of December 31, 2013,
(4)
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 approximately U.S.$15,565 million as of December 31, 2013.
(5) The table is presented in U.S.$, 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, 2013.
We have additional commitments under guarantees. For a discussion of these additional commitments see “—Guarantees
provided” below.
Covenants in our indebtedness
Our financial debt generally contains customary covenants. With respect to a significant portion of our financial debt totalling
Ps.31,890 million, including accrued interest (long- and short-term debt) as of December 31, 2013, we have agreed, among other
things and subject to certain exceptions, not to establish liens or charges on our assets. In addition, approximately 19% of our
financial debt outstanding as of December 31, 2013 was subject to financial covenants related to our leverage ratio and debt service
coverage ratio.
Regarding our outstanding debt amounting to Ps.24,770 million as of December 31, 2013, the creditors 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.
As of the date of this annual report none of our debt is under any event of default that could trigger an acceleration provision. In
connection with the change of control of the Company as a result of the Expropriation Law all waivers have been obtained. As of
December 31, 2013, we were in compliance with all covenants in connection with our indebtedness.
Guarantees provided
As of December 31, 2013, we have issued letters of credit in an aggregate total value of U.S.$27 million (as of the date of this
annual report this amount remains unchanged) to guarantee certain environmental obligations and guarantees in an aggregate amount
of U.S.$57 million in relation with the performance of contracts of certain of our controlled companies.
In addition, see Note 11.c“—Investment Project Agreements” to the Audited Consolidated Financial Statements for a
description of the transaction we entered into with Chevron.
118
Capital investments, expenditures and divestitures
Capital investments and expenditures
Capital investments in 2013 totaled approximately Ps. 30,163 million. The table below sets forth our capital expenditures and
investments by activity for each of the years ended 2013, 2012 and 2011.
Capital Expenditures and Investments(1)
Exploration and Production
Downstream
Corporate and Other
Total
2013
(in
millions
of pesos)
(%)
2012
(in
millions
of pesos)
(%)
2011
(in
millions
of pesos)
24,807
4,903
82
16
12,377 74
4,232 25
9,083
4,032
453
30,163 100%
2
142 1
16,751 100%
231
13,436 100%
(%)
68
30
2
(1)
Includes acquisitions of fixed assets and exploration expenses, net of unproductive drilling expenses and well abandonment
costs.
On August 30, 2012, we approved and announced the Strategic Plan 2013-2017 establishing the basis of our development for the
years to come. Such plan 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) the development of unconventional resources, which we see as a
unique opportunity because a) the expectation related to the existence of large volumes of unconventional resources in Argentina
according to estimates of leading reports on global energy resources, b) we currently possess a relevant participation in terms of
exploration and exploitation rights on the acreage in which such resources could be located in, and c) we believe we can integrate a
portfolio of projects with high production potential; (ii) the re-launch of conventional and unconventional exploration initiatives in
existing wells and expansion to new wells, including offshore; (iii) an increase in capital and operating expenditures in mature areas
with expected higher return and efficiency potential (through investment in improvements, increased use of new perforation
machinery and well intervention); (iv) a return to active production of natural gas to accompany our oil production; and (v) an
increase in production of refined products through an enhancement of the refining capacity (including improving and increasing our
installed capacity and upgrading and converting our refineries). The previously mentioned 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.
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.”
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.”
119
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 April 16, 2012, the Company was notified, through a notarial certification, of Decree No. 530/12 of the National Executive Office,
which provided for the temporary intervention of the Company (the “Intervention”) for a period of thirty (30) days, with the aim of securing
the continuity of its business and the preservation of its assets and capital, securing the provision of fuel and the satisfaction of the country’s
needs, and guaranteeing that the goals of the Expropriation Law are met. See “Item 4. Information on the Company—Regulatory Framework
and Relationship with the Argentine Government—The Expropriation Law.”
In accordance with Article 3 of Decree No. 530/2012, the powers conferred by YPF’s by-laws to the Board and/or the President of the
Company were temporarily granted to Julio M. De Vido, the Intervenor who performed the functions of our Principal Executive Officer and
Principal Financial Officer until the General Shareholders Meeting held in June, 4th, 2012, when a new Board of Directors was appointed.
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.
On May 7, 2012, through Decree No. 676/2012 of the National Executive Office, Mr. Miguel Matías Galuccio was appointed General
Manager of the Company during the Intervention. Furthermore, on June 4, 2012, the Ordinary Shareholders’ meeting appointed new members
of the Board of Directors of the Company, thus concluding the intervention of the Company.
In compliance with the provisions of the Expropriation Law, the CNV convened a general shareholders’ meeting held on June 4, 2012.
The removal of all regular members and alternate members of our Board of Directors and our Supervisory Committee was approved. In
addition, such general shareholders’ meeting fixed the number of regular and alternate members of our Board Directors and Supervisory
Committee and appointed their new regular and alternate members. 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” and “Item 4. Information on the Company—Regulatory Framework and Relationship with the Argentine Government—
The Expropriation Law.”
The Ordinary and Extraordinary Shareholders Meeting held on April 30, 2013 and its continuation of May 30, 2014, appointed the new
members of the Board of Directors of the Company and of the Supervisory Committee.
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
No. 19,550 (the “Argentine Corporations Law”). Our by-laws provide for a Board of Directors of 11 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 and as long as they perform the duties of a
director.
120
Directors shall hold office from one to three years, as determined by the shareholders’ meetings. Since the shareholders’ general
ordinary meeting held on April 30, 2013 and its continuation on May 30, 2013, our Board of Directors is composed of 17 directors and 12
alternates.
In accordance with our by-laws, the Argentine government, 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 by video conference), and the President or his substitute is
entitled to cast the deciding vote in the event of a tie.
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 (4)
Jorge Marcelo Soloaga (4)(3)
Gustavo Alejandro Nagel (4)
Oscar Alfredo Cretini
Roberto Ariel Ivovich
Omar Chafí Félix (1)
Armando Isasmendi (h) (2)
Héctor Walter Valle
Rodrigo Cuesta
José Iván Brizuela
Sebastián Uchitel
Nicolás Marcelo Arceo(4)
Fernando Dasso (4)
Luis García del Río (4)
Carlos María Tombeur
Nicolás Eduardo Piacentino
Axel Kiciloff (3)
Patricia María Charvay (3)
Sergio Affronti (4)
Carlos Héctor Lambré
Francisco Ernesto García Ibañez
José Carlos Blassiotto
Cristian Alexis Girard
Javier Leonel Rodríguez
Jesús Guillermo Grande
Carlos Agustín Colo (4)
Almudena Larrañaga Ysasi-Ysasmendi
Position
Director
Age
Since
Term
Expiration
Chairman, Chief Executive Officer (CEO)
and Director
Director
Director
Director
Director
Director
Director
Director
Director and
Legal Affairs
Corporate Vicepresident
Director
Director
Director and Administration and Finance
Vicepresident
Director and
Human Resources
Vicepresident
Director
Director
Director
Director
Alternate Director
Alternate Director
and Shared Services Vicepresident
Alternate Director
Alternate Director
Alternate Director
Alternate Director
Alternate Director
Alternate Director and Upstream
Executive Vicepresident
Alternate Director and Exploration
45
56
46
56
40
53
38
78
2013
2013
2013
2013
2013
2013
2013
2013
39
40
42
2013
2013
2013
2014
2014
2014
2014
2014
2014
2014
2014
2014
2014
2014
40
2013
2014
48
47
58
47
42
31
44
64
49
34
32
42
2013
2013
2013
2013
2013
2013
2013
2013
2013
2013
2013
2013
2014
2014
2014
2014
2014
2014
2014
2014
2014
2014
2014
2014
45
2013
2014
Executive Manager
Alternate Director
56
41
2013
2013
2014
2014
(1) Designated by the Supervisory Committee and assumed as Director at the Board of Directors’ meeting held in January, 23th, 2014,
replacing Mr. Rodolfo Manuel Lafalla, who had assumed as Director at the Board of Director’s held in September, 23th, 2013,
replacing Mr. Walter Fernando Vázquez.
121
(2) Assumed as Director at the Board of Directors’ meeting held in December, 9th, 2013, replacing Mr. Raúl Eduardo Ortiz who
presented his resignation and it was accepted by the Board of Directors. Representing our Class A shares.
(3) Representing our Class A shares.
(4) As of February, 28 2014, the person owns less than one percent of our Class D shares.
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 May, 31st, 2013. All other officers serve at the discretion of the Board of Directors and may be
terminated at any time without notice.
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 is the Chairman of the Company appointed by the General Shareholders Meeting held in April 30, 2013
and its continuation of May 30, 2013, and CEO appointed by the Board of Directors meeting held on May 31, 2013.
Axel Kicillof
Mr. Kicillof graduated with a degree in economics with a focus on the public sector, from the School of Economic Sciences of
the University of Buenos Aires, from which he subsequently received a Ph.D. in economics. He has extensive experience as an
undergraduate and graduate professor. He was a head researcher at the Institute of Economic Research of the University of Buenos
Aires, a researcher of the Argentine National Scientific and Technical Research Council (“CONICET”), Director of the UBACYT
E017 research project “Argentina After the Convertibility Collapse, Continuities and Breakouts: A New Growth Standard.” He was
the Assistant Director of the IIE’s Center of Studies for Development Planning, University of Buenos Aires, and a researcher of the
Center of Studies for Argentine’s Development. In December 2011, he was officially designated Secretary of Economic Policy and
Development Planning at the Argentine National Ministry of Economy and Finance and since November, 2013 he is the Minister of
Economy and Public Finance. Mr. Kicillof was elected as the representative of the Class A shares held by the Argentine government.
Jorge Marcelo Soloaga
Mr. Soloaga graduated from the Industrial School in Caleta Olivia as a chemical technician. He is currently an employee of
the Company and has been Chairman of the Commission for the Development of Cañadón Seco since 2009. Since 1993, he has acted
as General Secretary of the Oil and Hydrocarbon Union (Sindicato Unido Petroleros e Hidrocarburíferos or SUPeH), 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.
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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 as
the head of Teams and Maintenance, Southwest Affiliate, Service and Operations team leader in Venezuela, a business area manager
(Neuquén – Mendoza – Rosario), a manager at Oil and Gas Argentina and Bolivia, and the general manager for the Andean Region at
Gas y Petróleo del Neuquén S.A. He was the Assistant Secretary 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, as well as the Director
of Exploration and Production at Gas y Petróleo del Neuquén S.A.
Oscar Alfredo Cretini
Mr. Cretini graduated with a degree in geological sciences from the School of Exact and Natural Sciences of the University of
Buenos Aires. He also has a master’s degree in business administration, with a major in business and the environment from the
School of International Business of the University of Belgrano. He has, among others, been the chief geologist for uranium/thorium
exploration in the Saint George Gulf Basin, Province of Chubut, Tronco Amblayo Basins, Salta, Paraná Basin in Paraguay and
Jurassic Basin in Colombia; and a senior consultant to the Alternate President of the Honorary Federal Senate, in fuel energy and
mining. He was also a professional consultant for the program, “Report of the Environmental Impact of the Exploratory Well and
Exploitation of Oilfields of YPF, Golfo San Jorge Basin,” and a local affiliate of the GEA Group, Provinces of Chubut and Santa
Cruz.
Roberto Ariel Ivovich
Mr. Ivovich graduated as a certified public accountant from the National University of Córdoba. He has served as the investment
project auditor of the Federal Investment Council and as an accounting consultant for the Municipality of El Calafate, Santa Cruz, in
the area of collections. Currently he is the appointed representative for the Province of Santa Cruz before the Federal Commission of
Tax Responsibility. Additionally, he is a member of the Federal Tax Commission and he is Chief of Cabinet of the Government of the
Province of Santa Cruz.
Omar Chafi Félix
Mr. Félix has served as Secretary of the Public Work Ministry of the Province of Mendoza. He also has served as City
Councilman of the city of San Rafael, Mendoza from 1995 to 1999, as Mayor of the city of San Rafael, Mendoza from 2003 until
2009 and National Legislator representing the Province of Mendoza from 2009 to 2013. Currently he is President of Telcom
Argentina S.A., a company engaged in mining exploitation and soil transportation. Mr. Félix is also active in the livestock industry.
Armando Isasmendi (h)
Mr. Isasmendi graduated from the Universidad Católica Argentina with a law degree. He is currently the Chairman of
Recursos Energéticos y Mineros de Salta S.A. He has acted as President of the Regulatory Entity of Public Services in the Province of
Salta, and as an advisor in the Ministry of Economic Development in the Province of Salta.
Héctor Walter Valle
Mr. Valle graduated with a degree in political economics from the University of Buenos Aires. He majored in economic and
social planning at the Latin American Institute of Economic and Social Planning and has a specialization in “Problems of Economic
Development and Foreign Trade” from the University of Grenoble. Among other positions, he has been an Assistant Vice-President
of the Economic Science Professional Association of the City of Buenos Aires, the President of the Economic Commission of the
Economic Science Professional Association of the Federal Capital and a board member of the Economic Science Graduate
Association of the Federal Capital. He has been the president of Development Research Foundation since 1991, and from January
2005 to June 2012, he was the President of the Argentine National Fund for the Arts.
Rodrigo Cuesta
Mr. Cuesta earned a law degree from the School of Law and Social Science of the University of Buenos Aires and a master’s
degree in administrative law from Austral University. Among other positions, he was legal advisor at the National Legal Affairs
Office of the Office of the Attorney for the Argentine’s Treasury, General Counsel of the Aerolíneas Argentinas Group and Assistant
Comptroller General of Argentina. Currently, he is our Legal Affairs Corporate Vice-President.
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José Ivan Brizuela
Mr. Brizuela graduated from the University of Buenos Aires with a degree in administration with a focus in finance and a degree
in sociology with a focus in sociology and culture. He has been, among others, a financial system senior consultant at Alpha Estudio
de Economía; the Director of the Agency for Development and Investments at the Argentine National Ministry of the Economy, the
coordinator general of the United Nations Development Program, a representative of the Secretariat of Energy at Nucleoeléctrica
Argentina S.A., and a representative of the Industry’s Secretariat’s Office. In 2004, he founded Sociedad Brisa de Argentina S.A.,
where he is currently Director.
Sebastian Uchitel
Mr. Uchitel earned the title of Analyst in Computers at the School of Exact and Natural Sciences of the University of Buenos
Aires, and a Ph.D. in computers from the School of Engineering, Imperial College in London. Among other positions, he was a
full-time regular adjunct professor in the Computer Department, School of Exact and Natural Sciences of the University of Buenos
Aires, teaching assistant of the Department of Computers, Imperial College in London, associate investigator, Department of
Computers, Imperial College in London, and founding partner and Director of Lemma Informática S.R.L. He was also a part-time
associate professor of the Department of Computers, Imperial College in London and independent investigator at CONICET.
Nicolas Marcelo Arceo
Mr. Arceo earned a degree in economics from the University of Buenos Aires. He holds a PhD in Social Science and a master’s
degree in political economics from the Latin-American Faculty of Social Sciences. Mr. Arceo is our Administration and Finance
Vice-President.
Fernando Dasso
Mr. Dasso earned a degree in labor relations from the University of Buenos Aires. In 1993, he joined our Company and has held
various positions within our Company since then. In 2006, he was appointed Human Resources Director at the Argentina, Bolivia and
Brazil Exploration and Mining Unit. Currently, he is our Human Resources Vice-President.
Luis García del Río
Mr. García del Río earned a law degree from the School of Law and Social Science of the Sevilla University (Spain). Among
other positions, he acted as an attorney for the Spanish government and governmental agencies from 1993 to 2001, legal advisor to
different areas of Repsol between 2001 and 2008. In May 2008 he became a partner of the law firm García del Río & Larrañaga
Abogados where he currently practices law.
Carlos María Tombeur
Mr. Tombeur graduated from the University of Buenos Aires, School of Law and Social Sciences, with a law degree in 1976.
Previously, he was Professor of Economic Law in the School of Economic Sciences and of Commercial Law in the School of Law at
the University of Buenos Aires. Mr. Tombeur was also Professor of Economic Law in the Master’s Degree program in Public Policy
at the University Di Tella. From 1999 to 2005, he served as member of the Board of Directors of YPF S.A. Mr. Tombeur was
appointed controller at Seguro de Depósitos S.A. (SEDESA) (Insurance Deposit Company) by the Central Bank for the period 1997
to 2001. He also served as legal undersecretary of the Ministry of Economy and Public Works and Services for the period 1992 to
1996 and was a member of the Board of Directors of the Central Bank of the Argentine Republic, 1991-1992. Mr. Tombeur was
Partner of the firm Caride Fitte & Tombeur from 1977 until 1991. Mr. Tombeur is currently Partner with the firm Severgnini Robiola
Grinberg & Tombeur. He is also a member of the Bar Association of the City of Buenos Aires and the International Bar Association.
Nicolás Eduardo Piacentino
Mr. Piacentino graduated from the Universidad Católica Argentina, with an engineering degree. He currently provides
services of high-end consultancy on commercial, logistical and production to different companies on mining, grains and energy
matters. He also worked as a trader for several companies, such as Glencore Ltd and Repsol – YPF Trading and Transport S.A.
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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. Among other positions, he acted as manager for
regional administration and planning for YPF Upstream from 1998 to 2001, manager for Repsol Upstream in strategic upstream planning in Latin
America between 2002 and 2004, manager for purchases and hiring for Repsol Upstream between 2004 and 2006, director of Planning and
Control for Europe, Asia and Africa for Repsol Upstream between 2006 and 2008, country manager for Repsol Upstream in Ecuador between
2008 and 2010, and director for corporate development for Repsol Upstream in Spain from 2011 to May 2012. Currently he is our Shared
Services Vice-President.
Carlos Héctor Lambré
Mr. Lambré earned an oil engineering degree from the San Juan de Bosco Patagonia National University. Among other positions, he
served as a manager in the Saint George Gulf Basin Unit for Pan American Energy, general manager for Terminales Marítimas Patagónicas S.A.
(TERMAP S.A.), Director of Amoco Argentina Oil Company, General Director for the Hydrocarbon and Mining Secretary in Chubut. Currently
he serves as the sub-secretary for the Ministry of Hydrocarbons of the Province of Chubut and as executive secretary in the OFEPHI.
Francisco Ernesto García Ibáñez
Mr. García Ibañez earned a law degree from the Litoral University. Among other positions he served as Chief of Cabinet of the Ministry of
Infrastructure, Housing and Transport; Director representing the Province of Mendoza in the Federal Council of Electric Power; Advisory
Cabinet of the Ministry of Infrastructure, Housing and Transport; chairman of the Discipline Board of Ministry of Economy and Finance; counsel
advisor in the Legal Department of the Ministry of Finance and deputy inspector in the Purchasing and Supply Ministry.
José Carlos Blassiotto
Mr. Blassiotto graduated from the University of Belgrano with a law degree. He is currently the Minister of Economy and Public
Construction in the Province of Santa Cruz, as well as the representative of the Province of Santa Cruz in the Argentine Arbitration
Commission, the Commission for Fiscal Responsibility, and the Federal Tax Commission. He is also a professor of Civil and Commercial
Procedural Law in the Criminal Sciences Department in the University Institute of the Argentine Federal Police. He also acted as Legal and
Technical Secretary in the Ministry of Economy and Public Works in Santa Cruz, as Director of Fiscal Prosecutors in the Tribunal in Santa Cruz,
as legal advisor in the Low Chamber in the Province of Santa Cruz, and as Regular Member in the Contracts Committee in the Legal Affairs
Department of the National Lottery.
Cristian Alexis Girard
Mr. Girard graduated from the University of Buenos Aires with a degree in economics. He is currently getting a PhD in Economic
Sciences in the University of Buenos Aires, and is a professor of economics in the Economic Science Department in the University of Buenos
Aires and the Popular University of Madres de Plaza de Mayo. He also serves as director in the National Direction of Companies with
Government Participation, and is currently a Director representing the Argentine government in several companies, such as SIDERAR SAIC,
YPF GAS S.A., Metrogas S.A., Distribuidora de Gas Cuyana S.A. and Gas Natural Fenosa SA.
Javier Leonel Rodríguez
Mr. Rodríguez graduated from the University of Buenos Aires with a degree in Economics. He has also presented his thesis to obtain
a PhD from such University, which is being evaluated. He currently serves as Sub-Secretariat of Economic Planning in the Secretary of
Economic Policy and Development Planning in the National Ministry of Economy and Public Finance.
Jesus Guillermo Grande
Mr. Grande graduated from the National University of Tucumán with an engineering degree. Since 1993, he held various positions at
Schlumberger, serving as Director of Human Resources; President of one of its service lines; and the head of Corporate Strategy Implementation.
He has also served in executive and operational positions in Kuwait, Argentina, Brazil, Angola and the United States. His specialty is
management and operations optimization. Mr Grande is our Upstream Executive Vice-President.
Carlos Agustín Colo
Mr. Colo earned a geology degree from the San Juan de Bosco Patagonia National University. Among other positions, he previously served
as District Chief for the Golfo San Jorge Basin, Director of the Technical Office for Upstream, Director for the Economic Unit composed by Las
Heras and Santa Cruz for YPF and Country Manager for Repsol Colombia. He currently serves as our Exploration Executive Manager.
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Almudena Larrañaga Ysasi –Ysasmendi
Ms. Ysasi-Ysasmendi has been a lawyer member of the bar since 1999. She graduated from Universidad Complutense de
Madrid in 1996, with a law degree. She has served in several companies from Dragados (TECSA) Group, as well as Squire,
Sanders & Dempsey, and Gómez Acebo & Pombo.In 1999 she joined the Legal Affairs Department in REPSOL BUTANO, S.A. In
2006 she was appointed Chief of Legal Affairs (Upstream division) for Europe and Northern Africa in REPSOL Group. In 2007 she
was appointed Chief of Legal Affairs (Upstream and GNL) for Europe and Northern Africa. Since May 1st, 2008, she has been
working as an independent lawyer and is currently partner in García del Río & Larrañaga Abogados.
Patricia María Charvay
Ms. Charvay earned an economics degree and a doctorate degree in Economics from the University of Buenos Aires. Among
other positions, she previously served as a consultant for the Council of Coordination of Social Policies. Currently she represents the
Argentine government serving as a director in several companies, among others Edenor S.A. and Endesa Costanera S.A., and she is a
secretary of Economic Policies and Development Planning for the Argentine National Ministry of Economy and Finance.
Ms. Charvay was elected as alternate Director representative of the Class A shares by the Argentine government.
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.
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.
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Senior Management
Our current senior management as of the date of this annual report consists of:
Name
Miguel Galuccio
Daniel González
Rodrigo Cuesta
Jesús Grande
Carlos Alfonsi
Fernando Giliberti
Nicolás Arceo
Doris Capurro
Fernando Dasso
Sergio Affronti
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
Administration and Finance Vice-President
Communication and Institutional Relations Vice-President
Human Resources Vice-President
Shared Services Vice-President
In addition to the members of our Senior Management for whom outside business interests and experience are described above, we include
the following:
Daniel Gonzalez
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 as 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 Hidroneuquén S.A. and Hidroeléctrica Piedra del Águila S.A. As of the date of this annual
report, Mr. Gonzalez is our Chief Financial Officer (CFO).
Carlos Alfonsi
Mr. Alfonsi graduated with a degree in chemistry from Argentina’s 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 our Company, serving as an operations manager; the 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. Currently, Mr. Alfonsi is our Downstream Executive Vice-President.
Fernando 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, and as South Division Business Support Manager
of the El Guadal-Lomas del Cuyo Pilot Economic Unit, Business Development Manager and Exploration and Production Business Development
Director. In San Antonio (Pride International), he was South Division Business Support Manager and Vice President at the Latin America
Business Unit and Vice President of Business Development at Pioneer Natural Resources of Argentina. In 2006, he founded Oper-Pro Services
S.A. Currently, he is our Strategy and Business Development Vice-President.
Doris Capurro
Mrs. Capurro graduated with a degree in Sociology. During her career Mrs. Capurro specialized in public relations, media, advertising,
political management, marketing and market research. Mrs. Capurro is President of two leading consultant companies in Argentina
(CAPComunications S.A. and Ibarómetro S.A.). Additionally, Mrs. Capurro founded and ran a leading agency for advertising and
communication services (Capurro and Associates) for 20 years until it was acquired in 1999 by the French group Publicis. She received several
national and international awards for advertising, creativity, strategy and management. Mrs. Capurro is the organizer of the International
Conference of Political Management in Buenos Aires, sponsored by the Graduate School of Political Management at George Washington
University and Torcuato Di Tella. She teaches in the Master of Political Communication at the Pontifical University of Salamanca, Spain, and the
University FLACSO in Buenos Aires. She is currently our Communication and Institutional Relations Vice-President.
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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 Stocks Market Law as defined in “Item 9. The Offer and Listing Argentine Securities Market” and Resolution No. 622/2013 of 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”
below.
The Board of Directors of the Company, at its Meeting held on May 31st, 2013 resolved to approve the composition of the Audit Committee.
Consequently, the current members of the Audit Committee as of the date of this filing are: president Héctor Walter Valle, members José Iván
Brizuela and Sebastián Uchitel. Mr. Walter Fernando Vázquez was appointed as an alternate member of our Audit Committee, but he presented his
resignation as Director and alternate member of the Audit Committee which was approved by the Board of Directors on September 23, 2013.
Additionally, Mr. Héctor W. Valle 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 11 meetings
between March 2013 and March 2014.
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 help of the Administration and Finance Vice-President 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, 2013, and comparative information,
included in our report on Form 6-K submitted to the SEC on March 11, 2014.
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.
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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 March 2014, and as a consequence of 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 ending December 31,
2014. The shareholders are expected to consider the designation of Deloitte & Co. S.A. as external auditors of the financial statements for the
year ended December 31, 2014 in a 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” is 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 Annual Shareholders’ meeting held on April 30, 2013 and its continuation of May 30, 2013, Directors Héctor Walter Valle,
Sebastián Uchitel, José Iván Brizuela, Axel Kicillof, Oscar Alfredo Cretini, Roberto Ariel Ivovich, Armando Isasmendi (h), Luis García del
Río, Carlos María Tombeur, Nicolás Eduardo Piacentino and Alternate Directors Patricia María Charvay, Carlos Héctor Lambré, Francisco
Ernesto García Ibañez, José Carlos Blassiotto y Almudena Larrañaga Ysasi Ysasmendi qualified as independent members of our Board of
Directors under the above-described criteria.
Director Omar Chafí Félix, who was designated by the Supervisory Committee and assumed the position of Director at the Board of
Directors meeting held on January 23, 2014, also qualifies as independent member of our Board of Directors under criteria described above.
Disclosure Committee
Composition and responsibilities of our Disclosure Committee
In February 2003, we created a Disclosure Committee to:
•
•
•
monitor the 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;
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•
•
•
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 its 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 people:
Name
Miguel Galuccio
Daniel González
Rodrigo Cuesta
Jesús Grande
Vacant
Carlos Alfonsi
Fernando Giliberti
Nicolás Arceo
Doris Capurro
Fernando Dasso
Javier Fevre
Javier Sanagua
Position
Chairman, Chief Executive Officer and Director
Chief Financial Officer and President of the Disclosure Committee
Legal Corporate Affairs Vice-President and Secretary of the Disclosure Committee
Upstream Executive Vice-President
Quality, Environment, Security and Health Position
Downstream Executive Vice-President
Strategy and Business Development Vice-President
Administration and Finance Vice-President
Communication and Institutional Relations Vice-President
Human Resources Vice-President
Internal Auditor
Reserves Auditor
Compliance with New York Stock Exchange Listing Standards on Corporate Governance
On November 4, 2003, the SEC approved rules proposed by the New York Stock Exchange (the “NYSE”) intended to
strengthen corporate governance standards for listed companies.
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.
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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 nominations 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. 606/12. However, the Company 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 is composed by Directors
Rodrigo Cuesta, Fernando Dasso and Miguel Matias Galuccio.
Separate meetings for non-management directors
In accordance with 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.
Code of Ethics
We have adopted a code of ethics applicable to the Board of Directors and all employees. Since its effective date on August 15,
2003, we have not waived compliance with or amended the code of ethics.
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, 2013 the total cost of the aggregate compensation accrued to the members of the Board of
Directors and YPF’s executive officers for services in all capacities was Ps.128,5 million, including Ps.32.4 million in concept 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.1.7 million in compensation paid to the members of the Supervisory Committee . During 2013,
YPF’s performance-based compensation programs included a bonus plan for approximately 5,600 non-unionized YPF employees and
7,900 unionized YPF employees. This bonus plan 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 2013, 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.
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.
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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.” For the year 2013, the aggregate compensation paid to the members of the Supervisory Committee was Ps.1.7 million.
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
Maria de las Mercedes Archimbal
Enrique A. Fila
Raquel Inés Orozco (alternate member)
Guillermo Cardirola (alternate member)
Cecilia Carabelli (alternate member)
Class of
Shares
Represented
A
D
D
A
D
D
Age
62
31
54
58
38
43
Member
Since
2013
2013
2013
2013
2013
2013
Term
Expires
2014(*)
2014(*)
2014(*)
2014(*)
2014(*)
2014(*)
(*) Members of our Supervisory Committee are appointed in connection with a fiscal year. Our shareholders, in the general ordinary
shareholders’ meeting held on April 30, 2013 and its continuation on May 30, 2013 appointed the members of our Supervisory
Committee for fiscal year 2013.
Gustavo Adolfo Mazzoni
Mr. Mazzoni earned a certified public accountant degree and a postgraduate degree in finance from the University of Buenos Aires.
He also earned a degree in 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 (síndico) of several companies such as Aerolíneas Argentinas S.A., Austral S.A., Optar S.A., Empresa Argentina de Soluciones
Satelitales S.A. (Ar-Sat), Emprendimientos Energéticos Binacionales S.A., Centro de Ensayos de Alta Tecnología S.A., Gas Natural BAN
S.A., among others, and a Director in Radio y Televisión Argentina S.E.
María de las Mercedes Archimbal
Ms. Archimbal earned a law degree from the Argentine Catholic University and a master’s degree in international relations from the
University of San Andrés. Among other positions, she previously served as legal coordinator for the Argentine National Ministry of
Industry. She was a member of the advisory board to the Mercosur Guaranty Fund for medium and small companies. She currently is a
member in the Argentine National Office of the Comptroller General and an alternate statutory auditor in different companies such as
Radio y Televisión Argentina S.E. and Pampa Energía S.A, among others.
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 the statutory auditor (síndico) of Tandanor S.A.I.C. y N., Aeropuertos Argentina
2000 S.A., Distribuidora de Gas Cuyana S.A., and YPF Gas S.A. and an alternate statutory auditor (síndico suplente) 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., and Sociedad del Estado Casa de Moneda.
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Raquel Inés Orozco
Ms. Orozco obtained a law degree from the University of Buenos Aires. Currently, she is the principal corporate statutory
auditor (síndico) at the following companies: Central Térmica Guemes S.A., Telam S.E., Ubatec S.A., Inder S.E., Foncap S.A., LT10
Radio Universidad del Litoral S.A., and Loteria Nacional S.E.
Guillermo Leandro Cadirola
Mr. Cadirola earned his degree as a certified public accountant from the University of Buenos Aires, 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 (síndico) at Administración General de
Puertos S.E., All Central S.A. and All Mesopotámica S.A. He has extensive experience with the management of different
multinational companies in the areas of operations, purchasing and finance.
Cecilia Leonor Carabelli
Ms. Carabelli has a law degree from the School of Law and Social Science of the University of Buenos Aires. Among other
positions, she previously worked for the legal affairs direction of the National Social Security Administration, in the Secretary of
Social Development, as a Director for the Argentine National Senate, and as a Member of the Administration Committee to the
Fiduciary Fund for Mortgage Debtors, representing the Argentine National Ministry of Economy and Finance. Currently, she is a
member of the Argentine National Office of the Comptroller General.
Employee Matters
As of December 31, 2013, we had 17,747 employees, including 9,421 employees of the Downstream business segment, 3,563
employees of the Upstream business segment, and 4,763 employees of the Corporate and Other segment. Approximately 45% of our
employees are represented by the Federation of Oil Workers Union (SUPeH, for its acronym in Spanish) that negotiates with us labor
agreements and salaries which apply to YPF and OPESSA unionized employees. The SUPeH is permanently 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 2011 we began negotiations with the SUPeH, which resulted in the extension of our agreements with such unions until the
end of 2014. The negotiations involved the economic and social conditions for employees that are addressed in the labor agreement.
We consider our current relations with our workforce to be generally good.
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.
In 2012, we negotiated an 18-month salary agreement with unions with whom we directly negotiate, which ended on
December 31, 2013, ensuring both cost control and a low-conflict business environment. During first quarter 2014, we have been
negotiating 2014 salaries increase agreement, which we hope be finished in the next months.
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) at 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 which amounted to Ps.686 million. A substantial majority of lawsuits which were
originated as a consequence of said 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, 2013, YPF was a party in approximately 1,296 labor lawsuits which 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
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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, 2013 there were also approximately 40,500 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.
The following table provides a breakdown of our employees by business units as of December 31, 2013.
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 1,131 employees of Metrogas S.A. and its subsidiaries
Includes 3,175employees 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
3.563
9.421
8.172
43
1.206
4.763
17.747
17.607
113
27
17.747
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 “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.
As of the date of this annual report, the transfer of the shares subject to expropriation between 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 Mach 12, 2014:
Repsol Group (shares subject to expropriation)(1) (3)
Repsol Group(2) (3)
Public(2)(3)
Slim Family(4)
Argentine federal and provincial governments(5)
Employee fund(6)
Number of
shares
200,589,525
46,648,538
113,872,526
32,150,394
11,388
40,422
(%)
51.00%
11.86%
28.95%
8.17%
0.003%
0.01%
(1)
For purposes of ensuring the fulfillment of the objectives of the Expropriation Law, Class D shares representing 51% of our share capital
held by Repsol Group have been declared of public interest and subject to expropriation. See “Item 4. Information on the Company-
Regulatory Framework and Relationship with the Argentine Government-The Expropriation Law.” 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.
(2) According to data provided by The Bank of New York Mellon, as of March 12, 2014.
(3) According to data provided by The Bank of New York Mellon, as of March 12, 2014, there were 183,956,404 ADSs outstanding and 66
holders of record of ADSs. Such ADSs represented approximately 46.8% 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 14, 2014. “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. In addition, the Class D shares subject to expropriation from Repsol Group or its controlling or controlled entities, which
represent 51% of our share capital, 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.”
(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, 2013 are set forth in Note 6 to the Audited Consolidated
Financial Statements. The principal such transactions were our sales of refined and other products to certain joint ventures and affiliates (which
amounted to Ps.2,842 million in 2013), our purchase of petroleum and other products that we do not produce ourselves from certain joint
ventures and affiliates (which amounted to Ps.1,177 million in 2013), 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 before, 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, 2013 and December 31 and January 1, 2012, and transactions with the mentioned parties for the twelve-
month periods ended December 31, 2013 and 2012. 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.
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For an organizational chart showing our organizational structure, including our interests in our principal affiliates, see “Item 4.
Information on the Company—Overview.”
Argentine Law Concerning Related Party Transactions
Section 72 of the Stocks 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 Stocks 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 Stocks Market Law, “related party” means
(i) directors, members of the supervisory committee, 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. 4,674, Ps.2,634 and Ps.2,244 million as of December 31, 2013, 2012 and 2011, 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 the best estimate, based on the information available as of the date of this annual report, of
the probable outcome of the 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, 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
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2004 to the present, 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. 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.
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, and 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 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 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.$1,057 million.
Additionally, YPF was notified of the arbitration process brought by TGM at the ICC, claiming against YPF the payment of
approximately U.S.$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 introduced a counterclaim
against YPF asking the Arbitration Tribunal to condemn YPF and 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 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 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 considered without merit by YPF, which it rejected in its answer to such additional claim.
On April 6, 2011, the Arbitration Tribunal appointed in the “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 Sulgás
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.
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 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 a complaint appeal with the
Argentinean Court 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 on December 10, 2013 established a
proceeding schedule to be held during 2014 pursuant to which AESU, Sulgas and TGM shall submit their arbitration demand on
January 10, 2014 and YPF shall submit the reply on April 21, 2014. Hearings are expected to take place on November 6 and 7, 2014.
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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. On December 16, 2013 the
intervening official issued its opinion in favor of the competence of this court.
On December 27, 2013 YPF filed a nullity request before the National Court of Appeals in the Federal Contentious
Administrative.
Despite having brought the action above, 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
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 such company 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 note addressed to the Company in November 2011. On April 3, 2013, YPF was notified of
the lawsuit filed by TGN claiming for damages. The total amount claimed by TGN amounts to approximately U.S.$207 million as of
the date of this annual report. YPF has answered the lawsuit brought by TGN. Additionally, the plaintiff notified us that it was
terminating the contract, invoking 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 ENARGAS’ jurisdiction) to resolve this matter. Additionally, on January 12, 2012 and
following a mediation process which ended without any agreement, NAFISA filed a complaint against YPF before ENARGAS, under
art. 66 of Law 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’ lack of jurisdiction (as we did in the proceeding against TGN), the accumulation in the trial “TGN / YPF” and rejecting
the claim based on the theory of legal impossibility. On the same date, a similar order of accumulation was also submitted in the trial
“TGN / YPF.” 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 the National Court of Appeals in the Federal Contentious Administrative ruled in favor of
NAFISA. On November 19, 2013 YPF filed an ordinary appeal against such resolution to the Supreme Court of Justice. On
November 27, 2013 YPF filed an extraordinary appeal against such resolution 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 18, 2012, the judge intervening in the trial “TGN / YPF” decided: a) to dismiss the order of accumulation 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) to
accept the new facts alleged by YPF consisting 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 already terminated; c)
extend the demand for which TGN claims invoices relating to services for November and December 2010; and d) open 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 order 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 order 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.
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, investments 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.
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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 National State 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 will be analyzed by the Court experts.
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.
Quilmes claims. We have been notified of 37 judicial 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, and we
have sued the Argentine government to obtain a declaratory judgment declaring this administrative decision null and void. Such declaratory
judgment is still pending. There are 26 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. The plaintiffs are
claiming economic compensation, including damages and associated investigation and cleanup costs, in an undetermined amount and punitive
damages as a consequence of environmental damages, as well as the costs and fees associated with this proceeding, based on alleged
violations of the Spill Compensation and Control Act (“Spill Act”), the Water Pollution Control Act and common law claims relating to a
facility allegedly operated by the defendants and located in Newark, New Jersey that allegedly impacted the Passaic River and Newark Bay.
For a 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 this annual report.
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 date and
upon the opinion of our external counsel, have considered them to be possible contingencies.
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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.
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 execution 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 to dismiss for failure of the plaintiff to state a claim upon which relief may be
granted. 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 declared finalized the 60 days period of suspension
appropriately ordered.
Additionally it should be noted that the Company has learned, however the demand was not notified to YPF, two other legal claims
brought by ASSUPA against: i) concessionaires of the areas of Golfo San Jorge Basin, and ii) concessionaires of areas of Austral basin. The
Company, in case of being notified, expects to answer according to legal terms and the arguments of defense appropriate to the case.
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 previous 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 of taking preventive measures in the area. The National State 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 the mentioned 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 previous to January 1, 1991, according
to the Privatization Law and Decree No. 546/1993.
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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 sanitation
is not practicable, 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.
In addition to the above, YPF has entered into an agreement with the OPDS in connection with the claims related to the channels
adjacent to the La Plata refinery, which is described in “—Accrued, probable contingencies—La Plata refinery environmental
disputes” above.
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 Art. 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 Art. 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 25,156. On January 15, 2007, the CNDC charged us and eight other producers with
violations of Law 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 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 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 fuel 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 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 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 injection, the Argentinian government
presented an extraordinary federal appeal, which has not yet been served to YPF.
We are also subject to other claims before the CNDC which 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.
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Users and Consumers’ Association claim. The Users and Consumers’ Association claimed (originally against Repsol YPF
before extending its claim to YPF) the reimbursement of allegedly excessive prices charged to bottled LPG consumers between 1993
and 2001. 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.489 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 limitation had already elapsed. A ruling is pending on the applicability of the
statute of limitations. Notwithstanding the above, the evidence production period commenced on August 6, 2009.
Quilmes 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.250 million in compensation for personal damages.
Repsol S.A. and others complaints: The Company has been served with the following complaints:
•
A complaint filed by Repsol on July 31, 2012 in the Supreme Court of the State of New York, New York County, United States,
against The Bank of New York Mellon (“BNY”) and the Company. The complaint alleges that Repsol had the right to vote
ADSs owned by a certain third party that were pledged in Repsol’s favor, but that it was unable to exercise those voting rights
due to BNY’s alleged failure to accept and carry out Repsol’s voting instructions in connection with, among other things, the
election of the Company’s Board of Directors at the Company’s shareholders’ meeting on June 4, 2012. The complaint also
asserts claims against the Company for allegedly improperly instructing BNY not to accept Repsol’s voting instructions. On
February 4, 2014, the court granted the Company’s and BNY’s motions to dismiss the complaint, and dismissed all claims
against the Company with prejudice.
•
YPF was notified of four complaints filed by Repsol S.A. in Argentina in connection with the enforcement of Law 26,741,
requesting the invalidation of the Ordinary Shareholders’ Meetings dated on June 4, 2012, July 17, 2012 the Annual General
Meeting No. 38 on September 13, 2012 and April 30, 2013 and its continuation of May 30, 2013, all of which have been
answered by YPF.
•
On February 27, 2014, YPF and Repsol executed an arrangement (the “Arrangement”) whereby, mainly, the parties reciprocally
agreed to withdraw, subject to certain exclusions, all present and future actions and/or claims based on causes occurring prior to
the Arrangement derived from the declaration of public interest and subjection to expropriation of YPF shares owned by Repsol
pursuant to Law No. 26,741, the intervention, temporary takeover of public utility-declared shares and management of YPF.
Likewise, the parties have 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 subject to certain conditions. The withdrawals contemplated by the Arrangement
include those actions filed by Repsol listed above. The Arrangement will enter into force on the day following to the date on
which Repsol notifies YPF that the Agreement signed between Repsol and the Argentine Republic has entered into force. If such
effectiveness does not occur on or prior to May 7, 2014, or at a later date as the parties may agree in writing, the Arrangement
shall not be enforced and shall become void, and the parties shall retain all of the rights preexisting at the date of their signature,
and the Arrangement shall not create any liability for either party. See “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.
•
YPF class action: On April 16, 2013, YPF was served with a putative class action complaint filed by Monroe County
Employees’ Retirement System against the Company, certain of its officers and directors, Repsol S.A., Morgan Stanley & Co.,
Incorporated (“Morgan Stanley”), Credit Suisse Securities (USA) LLC (“Credit Suisse”) and Goldman Sachs & Co. (“Goldman
Sachs,” and together with Morgan Stanley and Credit Suisse, the “Underwriters”), which asserted claims under the Securities
Act of 1933. On May 15, 2013, that action was consolidated with a similar action initiated by Felix Portnoy that asserted claims
under the Securities Exchange Act of 1934. The claims in the consolidated action are based on an alleged failure to inform the
market, during the period between December 22, 2009 and April 16, 2012 and in connection with a March 2011 public offering
of YPF shares, regarding the potential risk of expropriation of the Company, and on the corresponding alleged effect on the
value of the shares. On February 20, 2014, the United States District Court for the Southern District of New York granted
YPF’s, Repsol’s and the Underwriters’ motions to dismiss all of the claims with prejudice.
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 Art. 29 of the Antitrust Protection Law. On January 21, 2004, we
submitted explanations in accordance with Art. 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. On September 2,
2008, the
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CNDC issued Note No. 1131/08 requesting information in relation to the prices in the internal and external markets for the years 2000 to
2008. On October 7, 2008, we provided the information. On December 10, 2008, the CNDC requested us to file the LPG export contracts
signed during the years 2001-2004 as well as to explain the evolution of the prices in the internal and external markets of propane and
butane during the March to December period in the years 2001-2004. On December 16, 2008, 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 resolution 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.
Mendoza royalties dispute. Following certain claims from the province of Mendoza that the international market price be used in the
calculation of royalties relating to internal market transactions based on its interpretation of Section 6 of Law No. 25,561, we commenced
an administrative proceeding. Our request is currently pending. Additionally, YPF filed a declaratory action with the Argentine Supreme
Court, with application for an injunction to declare unconstitutional the interpretation that the province of Mendoza applies to Section 6 of
Law No. 25,561. On April 7, 2009, we were notified that the Argentine Supreme Court has agreed to hear the case brought by YPF, and
issued a preliminary injunction to restrain the province of Mendoza from applying the international market price in calculating the
royalties payable by YPF. During 2013 the Argentine Supreme Court issued a final resolution favorable to us.
YPF Holdings
The following is a brief description of certain environmental and other liabilities related to YPF Holdings, a Delaware corporation.
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, 2013, YPF Holdings’ accruals for environmental and other contingencies totaled approximately Ps1,284
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, many 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 currently available information 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’ obligations.
Newark, New Jersey. A consent decree, previously agreed upon by the U.S. Environmental Protection Agency (the “EPA”), the New
Jersey Department of Environmental Protection (the “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, and as of December 31, 2013, YPF Holdings
has accrued approximately Ps.96 million in connection with such activities.
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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 the remedial investigation and feasibility study (“RI/FS”) being performed and funded by Tierra and a number of
other entities 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 work 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, consisting of approximately 70 companies, calls itself “CPG—Cooperating Parties Group.” 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
mentioned AOC.
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. 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 complete.
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 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. 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 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.
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 decreased or increased 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.
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In June 2007, EPA released a draft Focused Feasibility Study (“FFS”) that outlines several alternatives for remedial action in the lower
eight miles of the Passaic River. These ranged from no action (which would result in comparatively little cost) to extensive dredging and
capping (which according to the draft FFS, EPA estimated could cost from U.S.$0.9 billion to U.S.$2.3 billion), and are all described by EPA
as involving proven technologies that could be carried out in the near term, without extensive research. Tierra, in conjunction with the other
parties of CPG, submitted comments on the draft FFS to EPA, as did a number of other interested parties.
On November 14, 2013, at a Community Advisory Group (“CAG”) meeting, the EPA described the alternatives it is considering in the
revised FFS. The EPA stated that the FFS will set forth four alternatives: (i) no action, (ii) deep dredging with backfill of 9.7 million cubic
yards over 12 years (EPA estimated 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 on the floor of Newark Bay (“CAD”), at an off-site disposal facility or is locally decontaminated and put to
beneficial use); (iii) capping with dredging of 4.3 million cubic yards over 6 years (EPA estimated cost: $1.0 billion to $1.8 billion, depending
on whether there is a CAD or off-site disposal or local decontamination and beneficial use), (iv) focused dredging and capping of 0.9 million
cubic yards over 3 years (EPA estimated cost: U.S.$0.4 billion to U.S.$0.6 billion, depending on whether there is a CAD or off-site disposal or
local decontamination and beneficial use). As of the date of this annual report, the revised FFS is expected to be released to the public as early
as March, 2014. If the EPA keeps to the announced schedule, it is anticipated that the final Record of Decision would be issued in about 12-18
months after the FFS is made public. Based on the information available to the Company as of the issuance date of this report, considering the
potential final proposal, the results of the studies and discoveries to be produced, the many potentially responsible parties involved in the
matter, with its consequent potential allocation of removal costs, and also considering the opinion of external counsels, it is not possible to
reasonably estimate a loss or range of losses on these outstanding matters. Therefore, no amount has been accrued for this litigation by YPF
Holdings Inc.
The 17 miles of the Lower Passaic River from its confluence with Newark Bay to Dundee Dam pursuant to the 2007 AOC will be
subject to a Remedial Investigation / Feasibility Study that is anticipated to be completed in 2015, following which EPA will select a remedy
and notice it for public comment.
Moreover, and 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 and the New Jersey Spill Compensation Fund sued YPF Holdings, Tierra,
Maxus and other affiliates, as well as Occidental (the “New Jersey—litigation with DEP”). These plaintiffs seek 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 have made responsive pleadings and/or filings.
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 allege that defendants
Repsol, YPF, YPF International S.A., YPF Holdings, Inc., CLH Holdings, Inc., 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 assert claims for the fraudulent transfer of
Maxus’ assets, civil conspiracy, breach of fiduciary duty, aiding and abetting, and piercing the corporate veil 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. 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 ten tracks. Phase One will determine liability and Phase Two will determine
damages. In July 2012, the Court amended the trial plan for Track II (plaintiffs’ and Occidentals’ claims against Foreign defendants) and
Track IV (liability for plaintiffs’ and Occidental’s claims stemming from the alleged fraudulent transfers, alter ego, and conspiracy), and
scheduled trial for a date on or after June 1, 2013. Following the issuance of CMO XVII, the State of New Jersey and Occidental filed motions
for partial summary judgment. The State 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 based merely on its current ownership of
the Lister Avenue
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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. 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 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 11, 2012 the Court issued the track VIII order. The track VIII order governs the process by which the Court will conduct
the discovery and trial of the State’s damages against Occidental, Maxus and Tierra (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 are 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, extends 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. In July 2012, the Court amended the trial plan for Tracks II
(plaintiffs’ and Occidentals’ claims against Foreign defendants) and Track IV (liability for plaintiffs’ and Occidental’s claims stemming
from the alleged fraudulent transfers, alter ego, and conspiracy), and scheduled trial for a date on or after June 1, 2013. On October 26, 2012,
the Court again amended the trial plan for Tracks II and IV, adjusting discovery and summary judgment deadlines and setting trial for
February 24, 2014. On February 14, 2013, the plaintiffs 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 (discussed below).
In January 2013, the Court granted YPF, YPF International S.A., YPF Holdings, Inc., CLH Holdings, Inc. and Repsol permission to
file motions to dismiss plaintiffs’ Complaint and Occidental’s Cross-Claims as barred by the applicable statutes of limitations and repose and
because they fail to state a claim upon which relief may be granted. YPF’s motion to dismiss was due on February 18, 2013, but, as
described above, the Court stayed the litigation on February 14, 2013.
As of December 31, 2013, DEP has not filed with the Court dollar amounts on all its claims, but it has previously (a) contended that a
U.S.$50 million cap on damages under one of the New Jersey statutes should not be applicable, (b) alleged that it has incurred over U.S.$118
million in past “cleanup and removal costs,” and is seeking an additional award of between U.S.$10 and U.S.$20 million to fund a study to
assess natural resource damages, and seeks its future investigation and remediation costs, (c) notified Maxus and Tierra’s legal defense team
that DEP is preparing financial models of the cost of other economic impacts, and (d) seeks punitive damages.
The parties to the pending Passaic litigation have also engaged in settlement negotiations. In November 2011, the Special Master (a
retired State judge, appointed to assist the Superior Court with discovery) called for and held a settlement conference in late November 2011
between the plaintiffs, and Repsol, YPF, YPFI, YPFH, CLH, Tierra and Maxus to discuss the parties’ respective positions, but no resolution
was reached.
During the fourth quarter of 2012 and the first quarter of 2013, Maxus and Tierra, together with certain other direct defendants in the
litigation, engaged in on-going mediation and negotiation seeking the possibility of a settlement with the State.
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On March 26, 2013 the State of New Jersey informed the Court of a preliminary settlement agreement between the third parties defendant
and the State of New Jersey. In addition, YPF and certain affiliates (among them, YPF Holdings, Maxus and Tierra) 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’s damages against
Occidental in Track VIII. The Settlement Agreement does not resolve Occidental’s cross-claims.
On December 12, 2013 the Judge approved the Settlement Agreement together with the settlement agreement executed between the State of
New Jersey and the third parties defendants. On January 24, 2014 Occidental filed a notice of appeal from the court’s approval of the Settlement
Agreement, stating that it was not objecting to the material terms of the Settlement Agreement but to the delay in the commencement of Track IV
(Occidental’s claims under the doctrines of alter ego and fraudulent conveyance against Repsol and YPF). On February 3, 2014, the court of
appeals informed the parties that it questioned whether or not Judge Lombardi’s decision on December 12th regarding the timing of Track IV was
final or interlocutory. The State of New Jersey argued to the appellate court that Judge Lombardi’s decision was a final order, while Occidental
argued that the decision was an interlocutory order. The appellate court is expected to decide the question in March or April 2014. On
February 10, 2014 Maxus made the U.S.$65 million payment provided in the Settlement Agreement to an escrow account.
With respect to the third-party claims for contribution that Maxus and Tierra brought against approximately 300 companies and
governmental entities, including certain municipalities and sewage authorities, which could have responsibility in connection with the above
claims, the State of New Jersey has also sought to settle those claims. On March 26, 2013, the plaintiffs advised the Superior Court that a
proposed settlement between the plaintiffs and certain third party defendants had been approved by the requisite threshold number of private and
public third party defendants pursuant to which the third party defendants would pay the State of New Jersey approximately U.S.$34.5 million.
That third party defendant settlement was subsequently submitted for Superior Court approval, which would extinguish Maxus’s and Tierra’s
third-party claims in the litigation. The Superior Court approved that settlement on December 12, 2013.
As of December 31, 2013, YPF Holdings has accrued approximately Ps.805 million comprising the estimated costs for studies, the YPF
Holdings Inc.‘s best estimate of the cash flows it could incur in connection with remediation activities considering the studies performed by
Tierra, the estimated costs related to the Removal AOC of 2008 agreement, and in addition certain other matters related to Passaic River and the
Newark Bay, also including certain related legal matters. However, it is possible that other works, including interim remedial measures or
different of those considered, may be ordered. In addition, the development of new information, the imposition of penalties, or remedial actions
or the result of negotiations related to the referred matters differing from the scenarios that YPF Holdings Inc. has evaluated, could result in
additional costs to the amount currently provisioned.
Passaic River Mile 10.9 Removal Action. In February 2012, the EPA issued to the Cooperating Parties Group (“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, 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. 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. Tierra, on behalf of Occidental,
continues to discuss with EPA how Occidental can comply with the UAO. Pending the outcome of such discussions, the deadline for
Occidental’s submission of financial assurance has been extended indefinitely until further notice from the EPA.
Based on the information available to the Company as of the issuance date of this report, considering the results of the studies and
discovery process as well as the potential responsibility of the other parties involved in this matter and the potential allocation of removal costs,
based on the advice of our external and internal legal counsel, it is not possible to reasonably estimate a loss or range of losses related to these
outstanding matters. Therefore, no amount has been accrued in respect of these claims.
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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. 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 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 Interim Response Action has begun. In
addition, this adjacent property was listed by EPA on the National Priority List in 2007. In July 2010, 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 .The PRG is in active negotiations with the EPA for an RI/FS AOC for the Standard Chlorine Chemical Company site and
expects to execute the AOC in second quarter of 2013. 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, 2013, YPF Holdings has accrued a total of approximately Ps.112 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.116 million as of December 31, 2013 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.
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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 through which it is 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, 2013, YPF Holdings has accrued approximately Ps.23 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.
In June 2005, the EPA designated Maxus as a potentially responsible party (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 2006, Maxus and four other PRPs entered into a Joint
Participation and Defense Agreement, and in January 2007 those PRPs and 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 time period, although there is some dispute about it. The PRP Agreement includes an interim allocation, under which Maxus has a
substantial share. Preliminary work in connection with the RI/FS in respect of this site commenced in the second half of 2006.
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 U.S.$0.8 million.
YPF Holdings has accrued approximately Ps.3 million as of December 31, 2013 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.
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 and 2013, the PRP Group proceeded with the planning and design phase with remediation expected
to take place in 2014. As of December 31, 2013 the Company has reserved approximately Ps.5 million in connection with its obligations for this
matter. 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, 2013, YPF Holdings had accrued approximately Ps.23
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.
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 OCC U.S.$0.6 million covering OCC’s costs for 2010 and 2011, and in September 2012 Maxus paid to OCC an additional
U.S.$31
149
thousand for OCC’s costs for the first semester of 2012. Maxus anticipates that OCC’s costs in the future under the Dallas case will not exceed
those incurred in the first semester of 2012. As of December 31, 2013, only approximately U.S.$6.5 million of disputed claims (relating to
Occidental’s internal costs) remains pending. Maxus has allowances for this claimed amount. 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 was
dismissed in December 2009. 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.
The remaining claims refused consist primarily of claims of personal injury from exposure to vinyl chloride monomer (“VCM”), and
other chemicals, although they are not expected to result in significant liability. However, the declaratory judgment includes liability for claims
arising in the future, if any, which are currently unknown as of the date of this report, and if such claims arise, they could result in additional
liability. As of December 31, 2013, YPF Holdings had accrued approximately Ps.2 million in respect of these matters.
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. As of December, 2013, YPF Holdings has accrued approximately Ps.6 million in respect of this matter.
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. Plaintiff sought U.S.$30 million from Maxus and two parties which was rejected by the defendants. On
June 11, 2013, Maxus signed a Settlement Agreement with the plaintiffs pursuant to which Maxus shall make installment payments totaling $12
million over three years and also perform remediation at the site, which is estimated to cost between $1 and $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. On August 5, 2013, pursuant to the
Settlement Agreement, Maxus made an initial payment of $2 million and on December 31, 2013, Maxus made a second payment of $3 million.
YPF Holdings, including its subsidiaries, is a party to various other lawsuits, the outcomes of which are not expected to have a material adverse
affect on the company’s financial condition. YPF Holdings has established accrued for legal contingencies and environmental issues in those
situations where a loss is probable and can be reasonably estimated.
Dividend Policy
See “Item 10. Additional Information—Dividends.”
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:
2009
2010
2011
2012
2013
2014(1)
(1) Through March 21, 2014
150
High
47.00
50.60
54.58
41.14
34.17
33.08
Low
16.81
33.89
31.25
9.57
12.26
21.85
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.
2012:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2013:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2014:
First Quarter(1)
(1) Through March 21, 2014
High
Low
41.14
24.01
13.69
15.81
26.21
10.25
11.26
9.57
17.45
15.21
20.98
34.17
12.60
12.26
14.84
20.00
33.08
21.85
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.
2013:
September
October
November
December
2014:
January
February
March(1)
(1) Through March 21, 2014
High
Low
20.98
22.68
29.95
34.17
17.23
20.05
20.00
28.06
33.08
28.29
29.88
22.19
21.85
26.17
According to data provided by The Bank of New York Mellon, as of March 12, 2014, there were 183,956,404 ADSs outstanding
and 66 holders of record of ADSs. Such ADSs represented approximately 46.8% of the total number of issued and outstanding Class
D shares as of such date. Excluding ADSs owned by Repsol YPF, outstanding ADSs represented 34.9% of the total number of
outstanding Class D shares as of March 12, 2014. Repsol Group was the holder of 46.6 million of our ADSs at that 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, or “MERVAL”) is the largest stock market in Argentina
and is affiliated with the BASE. MERVAL is a corporation consisting of 134 shareholders who are the sole individuals or entities
authorized to trade, either as principals or agents, in the securities listed on the BASE. Trading on the BASE 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, or “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 mutual funds.
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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)
(1) End-of-period figures for trading on the BASE.
Source: Instituto Argentino de Mercado de Capitales.
2013
3,356
2012
2,300
2011
1,611
2010
1,900
2009
2,185
2008
1,234
124%
107%
87%
132%
191%
119%
367,830
1,526.3
242,324
1,005.5
207,805
848.2
177,613
722.0
133,208
545.93
237,790
962.71
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:
2009
2010
2011
2012
2013
2014(1)
(1) Through March 21, 2014
High
162.00
205.00
222.60
188.50
294.00
330.00
Low
64.00
137.00
150.50
66.50
181.00
250.00
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.
2012:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2013:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2014:
First Quarter(1)
(1) Through March 21, 2014
High
Low
188.50
125.00
90.25
104.00
125.00
66.50
73.00
66.50
133.50
136.00
192.00
294.00
101.30
106.00
115.00
181.00
330.00
250.00
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.
2013:
September
October
November
December
2014:
January
February
March(1)
(1) Through March 21, 2014
High
Low
192.00
213.00
264.50
294.00
148.00
181.00
185.00
237.00
330.00
297.00
311.50
261.00
250.00
276.00
As of December 31, 2013, there were approximately 17,985 holders of Class D shares in Buenos Aires Stock Market.
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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 is 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) have affiliated stock markets and, accordingly, are authorized to quote
publicly offered securities. Securities listed on these exchanges include corporate equity and bonds and government securities.
The BASE, which began operating in 1854, is the principal and longest-established exchange in Argentina. Bonds listed on the
BASE may simultaneously be listed on the Argentine over-the-counter market (Mercado Abierto Electrónico, or “MAE”), pursuant to an
agreement between BASE and MAE that stipulates that equity securities are to be traded exclusively on the BASE, while debt securities
(both public and private) may be traded on both the MAE and the BASE. In addition, through separate agreements with the BASE, all of
the securities listed on the BASE may be listed and subsequently traded on the Córdoba, Rosario, Mendoza, La Plata and Santa Fe
exchanges, by virtue of which many transactions originating on these exchanges relate to BASE-listed companies and are subsequently
settled in Buenos Aires. Although companies may list all of their capital stock on the BASE, controlling shareholders in Argentina
typically retain the majority of a company’s capital stock, resulting in a relatively small percentage of active trading of the companies’
stock by the public on the BASE.
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.
Regulation of the Argentine securities market
The Argentine securities market is regulated and overseen by the CNV, pursuant to Law No. 26,831 (“Stocks 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 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 BASE, 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 BASE and operates SINAC.
Despite a change in the legal framework of Argentine securities trading in the early 2000s, which established new disclosure
requirements and standards of liability for issuers and underwriters; a new tender offers regulation and others minority investors rights;
and new standards in corporate governance among other regulatory changes introduced by Decree 677/01 (the “Transparency Decree”),
there is still a relatively low level of regulation of the market for Argentine securities and investors’ activities in such markets and
enforcement of them has been limited. Because of the limited exposure and regulation in these markets, there may be less publicly
available information about Argentine companies than is regularly published by or about companies in the United States and certain other
countries. However, the CNV has taken significant steps to strengthen disclosure and regulatory standards for the Argentine securities
market, including the issuance of regulations prohibiting insider trading and requiring insiders to report on their ownership of securities,
with associated penalties for noncompliance.
Almost all the provisions of the Transparency Decree have been incorporated in the recently new securities law, Law No. 26,831
enacted in 2012, the “Stocks Market Law,” which applies to individuals and entities that participate in the public offering of securities, as
well as to stock exchanges. Among the key provisions of the Transparency Decree that has been incorporated in the new Stocks 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 to this, the Stocks 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
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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 the international accounting standards (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.
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; (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 3 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.
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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.
Resolution No. 121/2011 issued by the UIF (“Resolution 121”), amended by Resolution No. 1/12, 68/13 and 03/14, 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”) amended by Resolution No 1/12 and 03/14, 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 must report any money laundering
suspicious activity to the UIF within 30 calendar days of its occurrence (or attempt) and any terrorism financing suspicious activity before a 48
hours period has elapsed.
According to this 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 (“FATF”); (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
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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.
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 PPP, 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 PPP. Pursuant to the plaintiff’s request, the federal judge of first instance of Bell Ville, in the province of Cordoba,
granted a preliminary injunction (the “Preliminary Injunction”), ordering that any sale of shares of YPF or any other transaction involving
the sale, assignment or transfer of shares of YPF carried out by Repsol YPF or YPF be suspended, unless the plaintiff and other
beneficiaries of the PPP, organized under the Federation of Former Employees of YPF, are involved or participate in such transactions.
We filed an appeal against such decision, requesting that the Preliminary Injunction be revoked. In addition, we requested the recusal of
the federal judge of first instance of Bell Ville and the issuance of a preliminary injunction offsetting the effects of the Preliminary
Injunction. On March 1, 2011, we were notified that the intervening judge had allowed our appeal, suspending the effects of the
Preliminary Injunction. In addition, a preliminary injunction was granted to explicitly allow the free disposition of our shares, provided
that Repsol YPF, directly or indirectly continues to own at least 10% of our shares. On December 5, 2011, the Court of Appeals
confirmed this preliminary injunction and modified the Preliminary Injunction of the federal judge of first instance of Bell Ville. Both the
federal judge of first instance of Bell Ville, on July 21, 2011, and the Court of Appeals, on December 15, 2011, decided in favor of the
jurisdiction the federal court in Buenos Aires to resolve this matter. Under the jurisprudence of the Federal Supreme Court of Argentina
(upholding numerous decisions of the relevant Courts of Appeals), YPF should 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.
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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 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.”
As of the date of this annual report, the transfer of the shares subject to expropriation between 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 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” and “Item 7. Major Shareholders and Related Party Transactions.”
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 Shareholder’s 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 No. 19,550 (the “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.
In order to attend the meeting, shareholders must obtain a deposit certificate from a broker or from the depository trust company.
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. YPF will issue to each shareholder a deposit certificate required for admission into the meeting.
Shares certified and registered in the attendance book shall not be disposed of before the meeting is held unless the corresponding
deposit is cancelled.
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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 to the
approval of their management duties or their removal for cause.
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 election, performance and remuneration of
directors and members of the Supervisory Committee. In addition,, pursuant to the Stocks 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 Buenos Aires Stock Exchange, 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.
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 in 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, granted in a special meeting of the holders of such shares.
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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
Superintendent of Corporations (Inspección General de Justicia, or “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 11 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 shall hold office from one to three years, as determined by the shareholders’ meetings. Since the shareholders’ general
ordinary and extraordinary meeting held on April 30, 2013 and its continuation on May 30, 2013, our Board of Directors is composed of 17
directors and 12 alternates.
In accordance with our by-laws, the Argentine government, 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.
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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.
In the shareholders’ agreement entered into by Repsol YPF and Petersen Energía in connection with the Petersen Transaction,
they had agreed to effect the adoption of a dividend policy under which we would distribute 90% of our net income as dividends,
starting with our net income for 2007. In 2011 we paid Ps.5,565 million (Ps.14.15 per share) with respect to 2010 earnings. However,
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. Recently the Company approved its 2013-2017 Strategic Plan which
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. Furthermore, at the shareholders’ general ordinary and extraordinary
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 2013.
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,
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
Pesos Per Share/ADS
1Q 2Q 3Q 4Q
Total
— 9.00 — 4.50 13.50
— 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
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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 may declare interim dividends, in which case each
member of the Board and of the Supervisory Committee is jointly and severally liable 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 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, an amount equivalent to 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 Directors and Officers”);
third, an amount is segregated to pay dividends on preferred stock, if any; and
fourth, the remainder of net income may be distributed as dividends to common shareholders or allocated for voluntary or
contingent reserves as determined by the shareholders’ meeting.
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 approve 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 stock dividends,
shares are required to be delivered within three months of our 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 Commercial Code, the statute of limitations to the right of
any shareholder to receive dividends declared by the shareholders’ meeting is three years from the date on which it has been made
available to the shareholder.
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 The Bank of New York S.A., 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 Stocks
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.
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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.
•
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.” 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 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)
(iii)
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;
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
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(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.
Exchange Regulations
See “Item 3. Key Information —Exchange Regulations” for information on the monetary and currency exchange control
restrictions in effect in Argentina.
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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), 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, 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.
Transfer taxes
The sale, exchange or other disposition of our Class D shares or ADSs is not subject to transfer taxes.
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 21.95%, 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.
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.
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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 treaty between Argentina and Spain had remained in force until December 31, 2012. The new one has
been signed but not ratified by their governments. 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.
Recent 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
abovementioned 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 (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 aliquot 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% aliquot on 90% of the sums paid.
Applying the 15% aliquot, 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% aliquot, except for the dividends received by companies and other local entities, which are still not
computed for tax purposes (regardless of its application, in this case, the so-called “Equalization Tax”).
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.”
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.
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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.
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 dividends paid by qualified foreign corporations to certain non-corporate
U.S. Holders in taxable years before January 1, 2013 were taxable at a maximum rate of 15%. Beginning after December 31, 2012,
the
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maximum capital gains rate to such non-corporate U.S. Holders increased from 15% to 20% for securities being held longer than one year
and 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. Such gain
or loss will generally be U.S.-source gain or loss for foreign tax credit purposes. The deductibility of capital losses is subject to limitations.
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 2013 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, certain adverse consequences could apply to you.
If YPF were treated as a PFIC for any taxable year during which you held a Class D share or ADS, any gain you recognized on a sale
or other disposition of the Class D share or ADS would be allocated ratably over your holding period for the Class D share or ADS. The
amounts allocated to the taxable year of the disposition and to any year before YPF became a PFIC would be taxed as ordinary income. The
amount allocated to each other taxable year would be subject to tax at the highest rate in effect for individuals or corporations, as
appropriate, and an interest charge would be imposed on the resulting tax liability. Further, the portion of any distribution in respect of Class
D shares or ADSs that is in excess of 125% of the average of the annual distributions that you received on Class D shares or ADSs during
the preceding three years or your holding period, whichever is shorter, would be subject to taxation in the same manner as gains. 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 prior taxable years, the capital gain rate
discussed above with respect to dividends paid by qualified foreign corporations to certain non-corporate holders would not apply.
If we were a PFIC for any taxable year during which a U.S. Holder held Class D shares or ADSs, such U.S. Holder may be required to
file a report containing such information as the U.S. Treasury may require.
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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 who are individuals 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,
2013, 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.”
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.”
The Argentine peso has recently been subject to devaluation (approximately 23% during January 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.
169
Interest rate exposure
The table below provides information about our assets and liabilities as of December 31, 2013 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.”
Less than
1 year
1 – 2
years
Expected Maturity Date
2 – 3
years
(in millions of pesos)
3 – 4
years
4 – 5
years
More than
5 years
Total
Fair
Value
Assets
Fixed rate
Other
Receivables
Interest rate
Variable rate
Other
4,419
0.70%-22.5%
0
0.00%
—
—
— — 4,419 4,420
Receivables
Interest rate
16
17
CER(1)+8%/0.07 %-22.26% CER(1)+8% CER(1)+8% CER(1)+8% CER(1)+8%
2,118
17
17
2,185 2,185
170
Liabilities
Fixed rate
YPF’s Negotiable
Obligations
Interest rate
Related Parties
Interest rate
Other debt
Interest rate
Variable rate
YPF’s Negotiable
Obligations
Interest rate
Related parties
Interest rate
Other debt
Interest rate
Less than
1 year
1 – 2
years
2 – 3
years
3 – 4
years
4 – 5
years
More than 5
years
Total
Fair
Value
(in millions of pesos)
Expected Maturity Date
3,123
754
3,672
664
4,267
704 13,184 13,401
2.5%-19% 0.10%-8.88% 3,5%-6,25% 1.29%-3.5% 3,5%-8,88% 3.5%-10%
—
—
—
—
—
— —
—
2,975
2-31%
168
2-15.25%
230
2-15.25%
58
2-15.25%
48
2-15.25%
3,479 3,502
865
1,329
1,284
2,699
1,586
3,515 11,278 11,279
BADLAR
(2) +3%-
+4% /
LIBOR
+7.5%
BADLAR
(2) +3,24 +
4% / LIBOR
+7.5%
—
—
BADLAR
(2)+4.25% /
LIBOR
+7.5%
—
BADLAR
+4.25%-
+4.75% /
LIBOR
+7.5%
—
BADLAR
+4.75% /
LIBOR +
7.5%
BADLAR
+2.25%
—
— —
—
1,472
1,147
819
198
—
— 3,635 3,635
Libor +
4-6%/
BADLAR
+4%
Libor +
4-6%/
BADLAR
+4%
Libor +
4-6%/
BADLAR
+4%
Libor + 4- 4.5%
(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.
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. For
information on our hydrocarbons delivery commitments as of December 31, 2013, 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 issuing ADSs
pursuant to our deposit agreement (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.
171
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)
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
Expenses of the depositary
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
Cancellation of ADSs for the purpose of withdrawal
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
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 2013, 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 31,2013, YPF, under the supervision and with the participation of YPF’s management, including our current
Principal Executive Officer and Principal Financial Officer (see “Item 6. Directors, Senior Management and Employees—
Management of the Company”), performed an evaluation of the effectiveness of the design and operation of our disclosure controls
and procedures (as defined in Rule 13a-15(f) 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.
172
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.
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 (see “Item 6. Directors, Senior Management and Employees-Management of the Company”), we
conducted an evaluation of the effectiveness of our internal control over financial reporting based on the criteria established in
Internal Control-Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission
(“COSO”). Based on this assessment, our management concluded that, as of December 31, 2013, our internal control over financial
reporting was effective based on those criteria.
Our internal control over financial reporting as of December 31, 2013 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 have designated Héctor W. Valle as YPF’s Audit Committee Financial Expert. Mr. Valle was designated
by the Board of Directors at the meeting held on May 31, 2013. YPF believes that Mr. Valle possesses the attributes of an Audit
Committee Financial Expert set forth in the instructions to Item 16A of Form 20-F. Mr. Valle is an independent director.
ITEM 16B. Code of Ethics
YPF has adopted a Code of Ethics applicable to all employees of YPF and the Board of Directors. Since its effective date on
August 15, 2003, we have not waived compliance with, nor made any amendment to, the Code of Ethics. A copy of our Code of
Ethics is filed as an Exhibit to this annual report. YPF undertakes to provide to any person without charge, upon request, a copy of
such Code of Ethics. A copy of the Code of Ethics 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) 5441-5531
Fax (011-54-11) 5441-2113
173
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
2013
Fees
Expenses
Fees
2012
Expenses
2011
Fees
Fees
(in thousands of pesos)
18,943
455
85
288
19,771
295 13,988
—
686
— — — —
—
295 15,063
188 12,883 110
594 —
66
—
130 —
254 13,607 110
389 —
(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 reflected in agreements dated on or after June 9, 2011. Prior to such date, the contracting of
YPF’s external auditor, or any affiliate of the external auditor, for all audit and non-audit services, was approved by the Audit and
Control Committee of Repsol YPF, in accordance with the same pre-approval policy.
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 and Control Committee of Repsol YPF (with respect
to services contracted prior to June 9, 2011) or by the Audit Committee of YPF (with respect to services contracted on or after June 9,
2011).
ITEM 16D. Exemptions from the Listing Standards for Audit Committees
None
174
ITEM 16E. Purchases of Equity Securities by the Issuer and Affiliated Purchasers
Period
January 2013
February 2013
March 2013
April 2013
May 2013
June 2013 (from
06/06/2013 to
13/06/2013)
June 2013 (from
13/06/2013 to
28/06/2013)
July 2013 (from
1/07/2013 to
09/07/2013)
August 2013
(from
14/08/2013 to
30/08/2013)
September 2013
(from
02/09/2013 to
16/09/2013)
October 2013
November 2013
(from
11/11/2013 to
19/11/2013)
December 2013
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
445,528
81.66
445,528
83,617,213
287,306
83.00
287,306
59,772,008
120,568
104.67
120,568
47,151,572
194,111
—
104.88
—
184,849
—
144.86
—
194,111
—
184,849
—
26,792,811
26,792,811
—
—
(a) The Board of Directors, at its meeting held on June 6, 2013, 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 additionally Note 1.b.10.iii to the Audited Consolidated Financial Statements.
ITEM 16F. Change in Registrant’s Certifying Accountant
During the years ended December 31, 2013, 2012 and 2011 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.”
ITEM 17. Financial Statements
The registrant has responded to Item 18 in lieu of responding to this Item.
PART III
ITEM 18. Financial Statements
The following financial statements are filed as part of this annual report:
Reports of Independent Registered Public Accounting Firm
Consolidated Balance Sheets of YPF S.A. as of December 31, 2013, 2012 and 2011
Consolidated Statements of Comprehensive Income of YPF S.A. for the years ended December 31, 2013, 2012 and 2011
Consolidated Statements of Changes in Shareholders’ equity of YPF S.A. for the years ended December 31, 2013, 2012 and
F-2
F-3
2011
F-4
Consolidated Statements of Cash Flows of YPF S.A. for the years ended December 31, 2013, 2012 and 2011
F-6
Notes to the Audited Consolidated Financial Statements of YPF S.A. for the years ended December 31, 2013, 2012 and 2011 F-7
175
ITEM 19. Exhibits
1.1 By-laws (Estatutos) of YPF S.A. as amended (Spanish Version) *
1.2 By-laws (Estatutos) of YPF S.A. as amended (English Version) **
11.1 Code of Ethics***
12.1
Section 302 Certification by Chief Executive Officer
12.2
Section 302 Certification by Chief Financial Officer
13.1
Section 906 Certification
23.1 Consent of DeGolyer and MacNaughton
23.2 Consent of IHS Global Canada Inc.
99.1 Reserves Audit Report of DeGolyer and MacNaughton.
99.2 Reserves Audit Report of IHS Global Canada Inc.
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 2004 annual report on Form 20-F filed on June 30, 2005.
176
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
/s/ Daniel Gonzalez
By:
Name: Daniel Gonzalez
Title: Chief Financial Officer
Dated: March 27, 2014
177
Consolidated Financial Statements
as of December 31, 2013 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 balance sheets of YPF SOCIEDAD ANONIMA (an Argentine Corporation) and its
controlled companies (the “Company”) as of December 31, 2013, 2012 and 2011, 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,
2013. 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 financial
statements are free of material misstatements. An audit includes examining, on a test basis, evidence supporting the amounts and
disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made
by Management, as well as evaluating the overall 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, 2013, 2012 and 2011, and the results of their
operations and their cash flows for each of the three years in the period ended December 31, 2013, 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, 2013, based on the criteria established in
Internal Control - Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission
and our report dated March 27, 2014, expressed an unqualified opinion on the Company’s internal control over financial reporting.
Buenos Aires City, Argentina
March 27, 2014
Deloitte & Co. S.A.
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, 2013, based on the criteria established in Internal Control - Integrated
Framework (1992) 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, 2013, based on the criteria established in Internal Control - Integrated Framework (1992) 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, 2013 and our report dated March 27, 2014 expressed an unqualified opinion on those consolidated financial
statements.
Buenos Aires City, Argentina
March 27, 2014
Deloitte & Co. S.A.
Guillermo D. Cohen
Partner
CONSOLIDATED FINANCIAL STATEMENTS AS OF DECEMBER 31, 2013 AND COMPARATIVE INFORMATION
Index
– Cover
– Consolidated balance sheet
– Consolidated statements of comprehensive income
– Consolidated statements of changes in shareholders’ equity
– Consolidated statements of cash flow
– Notes to the consolidated financial statements
1) Consolidated Financial Statements
a) Presentation Basis
b) Significant Accounting Policies
b.1) Functional and Reporting Currency and tax effect on Other Comprehensive Income
b.2) Financial assets
b.3) Inventories
b.4) Intangible assets
b.5) Investments in companies
b.6) Fixed assets
b.7) Provisions
b.8) Impairment of fixed assets and intangible assets
b.9) Methodology used in the estimation of recoverable amounts
b.10) Pension plans and other similar obligations
b.11) Revenue recognition criteria
b.12) Recognition of revenues and costs associated with construction contracts
b.13) Leases
b.14) Earnings per share
b.15) Financial liabilities
b.16) Taxes, withholdings and royalties
b.17) Shareholders’ equity accounts
b.18) Business combinations
b.19) New standards issued
c) Accounting Estimates and Judgments
d) Financial Risk Management
Page
F-1
F-2
F-3
F-4
F-6
F-7
F-7
F-7
F-8
F-8
F-9
F-10
F-10
F-11
F-11
F-13
F-14
F-15
F-15
F-17
F-18
F-18
F-18
F-18
F-19
F-20
F-22
F-22
F-24
F-25
2) Analysis of the main accounts of the consolidated financial statements
a) Cash and equivalents
b) Trade receivables
c) Other receivables and advances
d) Inventories
e) Investments in companies
f) Evolution of intangible assets
g) Composition and evolution of fixed assets
h) Accounts payable
i) Loans
j) Provisions
k) Revenues, cost of sales and expenses
3) Provisions for pending lawsuits, claims and environmental liabilities
4) Capital Stock
5) Investments in Companies and Joint Ventures and Other Agreements
6) Balances and Transactions with Related Parties
7) Benefit Plans and Other Obligations
8) Operating Leases
9) Earnings per Share
10) Income Tax
11) Contingent Liabilities, Contingent Assets, Contractual Commitments, main regulations and others
a) Contingent liabilities
b) Contingent assets
c) Contractual commitments, main regulations and others
12) Consolidated Business Segment Information
13) Business combinations
14) Subsequent Events
15) Supplemental information on oil and gas activities (unaudited)
– Exhibits to Consolidated Financial Statements
F-29
F-29
F-30
F-30
F-31
F-31
F-31
F-32
F-34
F-34
F-37
F-38
F-39
F-53
F-54
F-56
F-58
F-59
F-60
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F-65
F-65
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YPF SOCIEDAD ANONIMA
Macacha Güemes 515 – Ciudad Autónoma de Buenos Aires, Argentina
FISCAL YEAR NUMBER 37
BEGINNING ON JANUARY 1, 2013
CONSOLIDATED FINANCIAL STATEMENTS AS OF DECEMBER 31, 2013 AND COMPARATIVE 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.
Date of registration with the Public Commerce Register: June 2, 1977.
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, 2013
(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-1
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
CONSOLIDATED BALANCE SHEET
AS OF DECEMBER 31, 2013 AND COMPARATIVE INFORMATION
(amounts expressed in millions of Argentine pesos – Note 1.b.1)
Note
2013
2012
2011
Noncurrent Assets
Intangible assets
Fixed assets
Investments in companies
Deferred income tax assets, net
Other receivables and advances
Trade receivables
Total non-current assets
Current Assets
Inventories
Other receivables and advances
Trade receivables
Cash and equivalents
Total current assets
Total assets
Shareholders’ 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 (per corresponding statements)
Noncurrent Liabilities
Provisions
Deferred income tax liabilities, net
Other taxes payable
Salaries and social security
Loans
Accounts payable
Total noncurrent liabilities
Current Liabilities
Provisions
Income tax liability
Other taxes payable
Salaries and social security
Loans
Accounts payable
Total current liabilities
Total liabilities
Total liabilities and shareholders’ equity
2.f 2,446 1,492 1,300
2.g 93,496 56,971 43,522
2.e 2,124 1,914 2,013
30
48
10
882
2.c 2,927 1,161
22
15
2.b
101,081 61,601 47,769
34
54
2.d 9,881 6,922 6,006
2.c 6,506 2,635 2,788
2.b 7,414 4,044 3,315
2.a 10,713 4,747 1,112
34,514 18,348 13,221
135,595 79,949 60,990
10,600 10,674 10,674
37,416 20,586 12,746
48,016 31,260 23,420
224 — —
48,240 31,260 23,420
2.j 19,172 10,663 9,206
10 11,459 4,685 2,724
136
38
2.i 23,076 12,100 4,435
60
2.h
54,547 27,759 16,599
362
8
101
48
470
162
2.j 1,396
122
1,045
1,119
820
965
541 —
511
920
537
789
2.i 8,814 5,004 7,763
2.h 20,312 12,856 11,195
32,808 20,930 20,971
87,355 48,689 37,570
135,595 79,949 60,990
Notes 1 to 14 and the accompanying exhibits I, II and III are an integral part of these statements.
F-2
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
FOR THE YEAR ENDED DECEMBER 31, 2013 AND COMPARATIVE INFORMATION
(amounts expressed in millions of Argentine pesos, except for per share amounts in Argentine pesos – Note 1.b.1)
Revenues
Cost of sales
Gross profit
Selling expenses
Administrative expenses
Exploration expenses
Other income (expense), net
Operating income
Income on investments in companies
Financial income (expense), net:
Gains (losses) on assets
Interests
Exchange differences
(Losses) gains on liabilities
Interests
Exchange differences
Net income before income tax
Current Income tax
Deferred 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 gains (losses) – Pension Plans(2)
Translation differences from investments in companies(3)
Translation differences from YPF S.A. (4)
Total other comprehensive income for the year(1)
Total comprehensive income for the year
2012
2013
Note
2.k 90,113 67,174
2.k (68,571) (50,267)
21,542 16,907
2.k (7,571) (5,662)
2.k (2,686) (2,232)
(582)
(829)
2.k
(528)
704
2.k
11,160 7,903
114
353
2011
56,211
(41,143)
15,068
(5,438)
(1,822)
(574)
(46)
7,188
685
924
(2,175)
198
(337)
180
(173)
(3,833) (1,557)
7,919 2,244
14,348 8,565
10 (2,844) (2,720)
10 (6,425) (1,943)
5,079 3,902
(1,045)
751
7,586
(2,495)
(646)
4,445
5,125 3,902
(46) —
4,445
—
9 13.05
9.92
11.30
6
(416)
18
(198)
12,441 4,421
12,031 4,241
17,110 8,143
(12)
(110)
1,974
1,852
6,297
Immediately reclassified to retained earnings.
(1) Entirely assigned to the parent company’s shareholders.
(2)
(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.
Notes 1 to 14 and the accompanying exhibits I, II and III are an integral part of these statements.
F-3
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY
FOR THE YEAR ENDED DECEMBER 31, 2013 AND COMPARATIVE INFORMATION
(amounts expressed in millions of Argentine pesos, except for the amounts per share expressed in pesos – Note 1.b.1)
Shareholders’ contributions
Reserves
Suscribed
capital
3,933
Adjustment to
contributions
7,281
Issuance
premium Total Legal
640 11,854 2,243
Future
dividends
596
Investments
—
Other
comprehensive
income
Retained
earnings
—
7,995
Equity attributable to
Non-
Parent
controlling
company’s
shareholders
interest
22,688
—
Total
shareholders’
equity
22,688
Balances at the beginning of year
As decided by the General Ordinary
Shareholder’s Meeting of April 26, 2011:
– Absorption of the effect of the
modification of previous year’s
information (Note 4).
– Reversal of Legal Reserve (Note 4).
– Reversal of Reserve for future dividends
– Appropriation to Reserve for future
dividends
As decided by the Board of Directors’
Meeting of April 26, 2011:
– Cash dividends (7 per share)
As decided by the Board of Directors’
Meeting of November 2, 2011:
– Cash dividends (7.15 per share)
Other comprehensive income for the year
Actuarial losses reclassification – Pension
Plans
Net income
Balances as of December 31, 2011
As decided by General Ordinary
Shareholders’ Meeting of July 17, 2012:
– Reversal of Reserve for future dividends
– Appropriation to Reserve for investments
– Appropriation to Reserve for future
dividends
As decided by the Board of Directors’
Meeting of November 6, 2012:
– Cash dividends (0.77 per share)
Other comprehensive income for the year
Actuarial gains reclassification – Pension
Plans
Net income
Balances as of December 31, 2012
—
—
—
—
(1,180)
—
—
— (1,180) —
— —
(236)
— — —
—
—
(596)
—
— — —
6,622
—
—
—
—
—
—
—
1,180
236
596
—
(6,622)
—
—
—
—
—
—
—
—
—
—
—
—
—
—
— — —
(2,753)
—
—
—
(2,753)
—
(2,753)
—
—
—
—
3,933
—
—
—
—
—
—
—
3,933
—
—
— — —
— — —
(2,812)
—
—
—
6,101
— — —
— — —
640 10,674 2,007
—
—
1,057
—
—
—
—
—
—
1,852
12
—
1,864
—
—
(2,812)
1,852
(12)
4,445
7,818
—
4,445
23,420
—
—
— — —
— — —
(1,057)
—
—
5,751
—
—
1,057
(5,751)
—
— — —
303
—
—
(303)
—
—
— — —
— — —
(303)
—
—
—
6,101
— — —
— — —
640 10,674 2,007
—
—
—
—
—
—
—
5,751
—
4,241
(18)
—
6,087
—
—
18
3,902
6,741
—
—
—
(303)
4,241
—
3,902
31,260
—
—
—
—
—
—
—
—
—
—
—
—
—
(2,812)
1,852
—
4,445
23,420
—
—
—
(303)
4,241
—
3,902
31,260
F-4
shares
Accrual of share-
based benefit
plans
Settlement of share-
based benefit
plans(3)
Acquisition of
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY
FOR THE YEAR ENDED DECEMBER 31, 2013 AND COMPARATIVE INFORMATION
(amounts expressed in millions of Argentine pesos, except for the amounts per share expressed in pesos – Note 1.b.1)
Suscri-
bed
capital
Adjust-
ment to
contribu-
tions
Treasury
shares
Shareholders’ contributions
Acqui-
sition
cost of
treasury
shares
Adjust-
ment to
treasury
shares
Share -
based
benefit
plans
Share
trading
Premium
Issuance
Premium Total
Legal
Future
dividends
Reserves
Equity
attributable to
Purchase
of
treasury
shares
Initial
IFRS
adjust-
ment
Invest-
ments
Other
compre-
hensive
income
Parent
company’s
share-
holders
Non-
contro-
lling
interest
Total
share-
holders’
equity
Retained
earnings
Balances as of
December 31,
2012
3,933 6,101 — — —
—
—
640 10,674 2,007
— 5,751 — —
6,087
6,741
31,260 — 31,260
Purchase of treasury
(12)
(19)
12
19 —
(120)
—
—
(120) —
— — — — —
—
(120) —
(120)
— — — —
81(2) —
—
—
81 —
— — — — —
—
81 —
81
—
—
(35) —
(35)
—
178
178
3
5
(3)
(5)
(41)
10
(4)
—
(35) —
— — — — —
GASA (Note 13) — — — — —
—
—
— — —
— — — — —
YPF Tecnologia
S.A. non-
controlling capital
contributions
As decided by the
— — — — —
— — — — — — — — — —
—
—
92
92
General Ordinary
shareholders’
meeting of
April 30, 2013
– Appropriation to
reserve for
investments
– Appropriation to
reserve for future
dividends
– Appropriation to
reserve for share-
based employee
benefit plans
– Appropriation to
— — — — —
—
—
— — —
— 2,643 — — —
(2,643)
— — —
— — — — —
—
—
— — —
330 — — — —
(330)
— — —
— — — — —
—
—
— — —
— —
120 — —
(120)
— — —
special reserve for
IFRS initial
adjustment
As decided by the
— — — — —
—
—
— — —
— — — 3,648 —
(3,648)
— — —
Board of
Directors’
meeting of
August 9, 2013
– Cash dividends
(0.83 per share)
Other
comprehensive
income for the
year
— — — — —
—
—
— — —
(326) — — — —
—
(326) —
(326)
— — — — —
—
—
— — —
— — — — 12,031
—
12,031 — 12,031
Actuarial gains
reclassification –
Pension Plan
Net income
Balances as of
December 31,
2013
— — — — —
— — — — —
(6)
—
— — — — — — — — — —
— — — —
— — —
—
6
5,125
— — —
(46) 5,079
5,125
3,924 6,087
9
14
40
(110)
(4)
640 10,600 2,007
4 8,394
120 3,648 18,112(1)
5,131
48,016
224 48,240
(1)
(2)
(3)
Includes 18,836 corresponding to the effect of the translation of the financial statements of YPF S.A. and (724) corresponding to the effect of the translation of
the financial statements of investments in companies with functional currency different to dollar, as detailed in Note 1.b.1. During the year ended December 31,
2013, (115) have been reclassified in relation with the effect of the translation of the financial statements of Pluspetrol Energy S.A. as result of the spin-off of
such Company (see Note 13).
Includes 38 corresponding to long-term benefit plans as of December 31, 2012, which were converted to share-based benefit plans (see Note 1.b.10) and 43
corresponding to the accrual of share-based benefit plans for the year ended December 31, 2013.
Net of employees income tax withholding related to the share-based benefit plans.
Notes 1 to 14 and the accompanying exhibits I, II and III are an integral part of these statements.
F-5
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOW
FOR THE YEAR ENDED DECEMBER 31, 2013 AND COMPARATIVE INFORMATION
(amounts expressed in millions of Argentine pesos – Note 1.b.1)
Cash flows from operating activities
Net income
Adjustments to reconcile net income to cash flows provided by operating activities:
Income 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
Net increase (decrease) of fixed assets provisions
Income tax
Net increase in provisions
Changes in assets and liabilities:
Trade receivables
Other receivables and advances
Inventories
Accounts payable
Other taxes payables
Salaries and social security
Decrease in provisions from payment
Interest, exchange differences and other (1)
Dividends from investments in companies
Income tax payments
Net cash flows provided by operating activities
Cash flows used in investing activities(2)
Payments for investments:
Acquisition of fixed assets and intangible assets
Acquisition of investment in companies
Capital contributions to investments in companies
Proceeds from sale of fixed and intangible assets (Note 11.c)
Net cash flows used in investing activities
Cash flows used in financing activities
Payments of loans
Payments of interest
Proceeds from loans
Dividends paid
Net cash flows provided by (used in) financing activities
Translation differences generated by cash and equivalents
Net increase (decrease) in cash and equivalents
Cash and equivalents at the beginning of year
Cash and equivalents provided by business combinations (Note 13)
Cash and equivalents at the end of year
Net increase (decrease) in cash and equivalents
COMPONENTS OF CASH AND EQUIVALENTS AT THE END OF YEAR
– Cash
– Other financial assets
TOTAL CASH AND EQUIVALENTS AT THE END OF YEAR
2013
2012
2011
5,079 3,902
4,445
197
(114)
(353)
11,236 8,129
(685)
6,438
61
1,022
21
9,269 4,663 3,141
1,261
3,256 2,208
2,336 1,170
(1)
16
152
(517)
22
14
(2,627)
745
(3,288)
(2,959)
(916) (2,258)
3,243 1,857 2,330
(111)
272
253
147
(713) (1,406) (1,126)
895
(825)
579
388
(3,290) (2,047)
(4,233)
20,964 17,301 12,686
(1,243)
280
374
262
(27,639) (16,403) (12,156)
—
(36) —
(2)
(20) —
5,351 — —
(22,344) (16,403) (12,158)
(920)
(326)
6,979 2,654
(6,804) (28,253)
(2,720)
16,829 32,130
(16,997)
(457)
21,175
(303) (5,565)
(1,844)
102
5,823 3,635
(1,214)
4,747 1,112 2,326
—
10,713 4,747 1,112
(1,214)
5,823 3,635
143 —
224
83
950
777
4,533
6,180 3,797
335
10,713 4,747 1,112
(1) Does not include translation differences generated by cash and equivalents, which is exposed separately in the statement.
(2) The main investing activities that have not affected cash and equivalents correspond to unpaid acquisitions of fixed assets and
concession extension bonus at the end of the year for 2,833, increase in hydrocarbons wells abandonment obligations costs for 4,357,
capital contributions in kind to investments in companies for 133 and the incorporation of assets and liabilities related to business
combinations mentioned in Note 13.
Notes 1 to 14 and the accompanying exhibits I, II and III are an integral part of these statements.
F-6
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
FOR THE YEAR ENDED DECEMBER 31, 2013 AND COMPARATIVE INFORMATION
(amounts expressed in millions of Argentine pesos, except where otherwise indicated – Note 1.b.1)
1. CONSOLIDATED FINANCIAL STATEMENTS
1.a) Presentation Basis
•
Application of International Financial Reporting Standards
The consolidated financial statements of YPF S.A. (hereinafter “YPF”) and its controlled companies (hereinafter and all
together, the “Group” or the “Company”) for the year ended December 31, 2013 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”).
The amounts and other information corresponding to the years ended on December 31, 2012 and 2011 are an integral part of the
consolidated financial statements mentioned above and are intended to be read only in relation to these statements.
•
Criteria adopted by YPF in the transition to IFRS
At the date of the transition to IFRS (January 1, 2011, hereinafter the “transition date”), the Company has followed the following
criteria in the context of the alternatives and exemptions provided by IFRS 1 “First-Time Adoption of International Financial
Reporting Standards”:
I.
Fixed assets and intangible assets have been measured at the transition date at the functional currency defined by the
Company according to the following basis:
a)
b)
Assets as of the transition date which were acquired or incorporated before March 1, 2003, date on which General
Resolution No. 441 of the CNV established the discontinuation of the remeasurement of financial statements in
constant pesos: the value of these assets measured according to the accounting standards outstanding in Argentina
before the adoption of IFRS (“Previous Argentine GAAP”) have been adopted as deemed cost as of March 1, 2003
and remeasured into U.S. dollars using the exchange rate in effect on that date;
Assets as of the transition date which were acquired or incorporated subsequently to March 1, 2003: have been
valued at acquisition cost and remeasured into U.S. dollars using the exchange rate in effect as of the date of
incorporation or acquisition of each asset.
II. The cumulative translation differences generated by investments in foreign companies as of the transition date were
reclassified to retained earnings. Under previous Argentine GAAP, these differences were recorded under shareholders’
equity as deferred earnings.
The effect arising from the initial application of IFRS, considering the mentioned criteria has been recorded in the “Initial
IFRS adjustment reserve account within Shareholders’ equity”. See additionally Note 1.b.17).
•
Use of estimations
The preparation of the consolidated financial statements in accordance with IFRS, which is YPF´s Board of Directors’
responsibility, require certain accounting estimates to be made and the Board of Directors and Management to make judgments
when applying accounting standards. Areas of greater complexity or that require further judgment, or those where assumptions
and estimates are significant, are detailed in Note 1.c “Accounting Estimates and Judgments”.
•
Consolidation policies
a) General criteria
F-7
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 balance sheet and in the consolidated statement of
comprehensive income, in accordance with their respective nature.
Paragraph a) of Exhibit I details the controlled companies which were consolidated using the full consolidation method and
Exhibit II details the main joint operations which were proportionally consolidated.
In the consolidation process, balances, transactions and profits between consolidated companies 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.
YPF, 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. (“YPF Tecnología”). 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 13, during second quarter 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 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 13.
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 YPF 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
F-8
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 income
(expense), net” in the consolidated statement of comprehensive income for the year in which they arise.
Assets, liabilities and income and expenses related to controlled companies and investments in companies are measured using
their respective functional currency. The effects of translating into U.S. dollars the financial information of companies with a
functional currency different from the U.S. dollar are recognized in “Other comprehensive income” for the year.
Reporting Currency
According to General Resolution No. 562 of the CNV, the Company must file its financial statements in pesos. Accordingly, the
financial statements prepared by YPF in its functional currency have to be translated into reporting currency, following the
criteria described below:
•
•
Assets and liabilities of each balance sheet presented are translated at the closing exchange rate outstanding at the date of
each balance sheet presented;
Items of the statement of comprehensive income are translated at the exchange rate prevailing at the date of each
transaction (or, for practical reasons and when exchange rates do not fluctuate significantly, the average exchange rate of
each month); and
•
The exchange differences resulting from this process are reported in “Other comprehensive income”.
Tax effect on other comprehensive income:
Results accounted for in “Other comprehensive income” related to exchange differences arising from investments in companies
with functional currencies other than U.S. dollars and also as a result of the translation of the financial statements of YPF to its
reporting currency (pesos), have no effect on the current or deferred income tax because as of the time that such transactions
were generated, they had no impact on net income nor taxable income.
1.b.2) Financial assets
The Company classifies its financial assets when they are initially recognized and reviews their classification at the end of each
year, according to IFRS 9, “Financial Instruments”.
A financial asset is initially recognized at its fair value. Transaction costs that are directly attributable to the acquisition or
issuance of a financial asset are capitalized upon initial recognition of the asset, except for those assets designated as financial
assets at fair value through profit or loss.
Following their initial recognition, the financial assets are measured at its amortized cost if both of the following conditions are
met: (i) the asset is held with the objective of collecting the related contractual cash flows (i.e., it is held for non-speculative
purposes); and (ii) the contractual terms of the financial asset give rise, on specified dates, to cash flows that are solely payments
of principal and interest on its outstanding amount. If either of the two criteria is not met, the financial instrument is classified at
fair value through profit or loss.
A financial asset or a group of financial assets measured at its amortized cost is impaired if there is objective evidence that the
Company will not be able to recover all amounts according to its (or their) original terms. The amount of the loss is measured as
the difference between the asset’s carrying amount and the present value of the estimated cash flows discounted at the effective
interest rate computed at its initial recognition, and the resulting amount of the loss is recognized in the consolidated statement
of comprehensive income. Additionally, if in a subsequent period the amount of the impairment loss decreases, the previously
recognized impairment loss is reversed to the extent of the decrease. The reversal may not result in a carrying amount that
exceeds the amortized cost that would have been determined if no impairment loss had been recognized at the date the
impairment was reversed.
F-9
The Company writes off a financial asset when the contractual rights on the cash flows of such financial asset expire, or the
financial asset is transferred.
In cases where current accounting standards require the valuation of receivables at discounted values, the discounted value does
not differ significantly from their face value.
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 every product.
The Company 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 Company 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 2.f). At the end of each year, such assets are measured at cost,
considering the criteria adopted by the Company in the transition to IFRS (see Note 1.a), less any accumulated amortization and
any accumulated impairment losses.
The main intangible assets of the Company are as follows:
I.
Service concessions arrangements: includes transportation and storage concessions (Note 2.f). These assets are valued at
their acquisition cost considering the criteria adopted by the Company in the transition to IFRS (Note 1.a), net of
accumulated amortization. They are depreciated using the straight-line method during the course of the concession period.
II. Exploration rights: the Company recognizes exploration rights as intangible assets, which are valued at their cost
considering the criteria adopted by the Company in the transition to IFRS (see Note 1.a), 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 expenditures, 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 Company in the transition to IFRS (see Note 1.a), 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. Management
reviews annually the mentioned estimated useful life.
F-10
The Company has no intangible assets with indefinite useful lives as of December 31, 2013, 2012 and 2011.
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.
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.
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 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, provided that the
Company has the intention to provide the corresponding financial support.
In paragraph b) of Exhibit I 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. The Company 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 Company in the transition to IFRS (see Note 1.a).
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 (“overhauls”), 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 eliminated from the
balance sheet.
F-11
Repair and 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.
The carrying value of the fixed assets based on each cash generating unit, as defined in Note 1.b.8, does not exceed their
estimated recoverable value.
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.
The Company reviews annually the estimated useful life of each class of assets.
iii. Oil and gas exploration and production activities:
The Company 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 2.f).
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 company 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 2.g).
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)
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.
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b)
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.
v. Environmental tangible assets:
The Company 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 Company makes a distinction between:
a)
b)
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; and
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
extend they are significant, as required by IAS No 37, “Provisions, contingent liabilities and contingent assets” (see
Note 11).
F-13
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 Company, 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 Company compares their carrying value
with their recoverable value at the end of each year, or more frequently, if there are indicators that the carrying amount of an
asset may not be recoverable. In order to assess impairment, assets are grouped into cash-generating units (“CGUs”), whereas
the asset does not generate cash flows that are independent of those generated by other assets or CGUs, considering regulatory,
economic, operational and commercial conditions. Considering the above mentioned, and specifically in terms of assets
corresponding to the Upstream, they have been grouped into four CGUs (one of them grouping the assets of fields with oil
reserves, and three units that group assets of fields with reserves of natural gas considering the country´s basins -Neuquina,
Noroeste and Austral basins-), which are the best reflect of how the Company currently manage them in order to generate
independent cash flows. The remaining assets are grouped at the Downstream CGU which mainly includes the assets assigned to
the refining of crude oil (or that complement such activity) and marketing of such products, in MetroGAS CGU which includes
assets related to the distribution of natural gas and in YPF Energía Eléctrica CGU, which includes assets related to generation
and commercialization of electric energy.
The recoverable amount is the higher of fair value less costs to sell and 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 an asset (or a CGU) is estimated to be less than its carrying amount, the carrying amount of the
asset (or the CGU) is reduced to its recoverable amount, and an impairment loss is recognized as an expense under “Impairment
losses recognized and losses on disposal of fixed assets/intangible assets” 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 value of the corresponding asset is calculated
to determine whether a reversal of the impairment loss 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.
There were no impairment charges or reversals for the years ended on December 31, 2013, 2012 and 2011.
F-14
1.b.9) Methodology used in the estimation of recoverable amounts
•
Company’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.
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 CGUs 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.
Cash flows of the Downstream and YPF Energía Eléctrica CGUs are estimated on the basis of the projected sales trends,
unit contribution margins, fixed costs and investment or divestment 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 reference prices considered are based on a combination of market prices available in those markets where the
Company operates, also taking into consideration specific circumstances that could affect different products the Company
commercializes and management’s estimations and judgments.
Estimated net future cash flows are discounted to its present value using a rate that reflects the average capital cost for each
CGU.
For the valuation of the assets of the MetroGAS CGU, cash flows are developed based on estimates of the future behavior
of certain variables that are sensitive in determining the recoverable value, among which stands out: (i) the nature, timing
and extension of tariff increases and cost adjustments recognition, (ii) gas demand projections, (iii) evolution of costs to be
incurred, and (iv) macroeconomic variables such as growth rate, inflation rate, foreign currency exchange rate, among
others.
MetroGAS prepared its projections on the understanding that it will get tariff increases according to the current economic
and financial situation of MetroGAS. Within these premises, and in terms of tariff increase estimations, the scenarios range
from a tariff adjustment in order to meet adjustments obtained by other companies in that business up to a recovery of tariff
levels prevailing in 2001 and in relation to regional tariffs in South America, especially in Brazil and Chile. A probability
approach has been used to weight the different scenarios assigning an outcome probability to each cash flow scenario
projected, based on current objective information. However, MetroGAS is unable to ensure that the realization of the
assumptions used to develop these projections will be in line with its estimates, so they might differ significantly from the
estimates and assumptions used as of the date of preparation of these consolidated financial statements.
1.b.10) Pension plans and other similar obligations
i. Retirement plan:
Effective March 1, 1995, YPF and certain subsidiaries 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 2% and 9% of his
monthly compensation and YPF will pay an amount equal to that contributed by each member.
F-15
The plan members will receive from YPF and certain subsidiaries 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.
Such companies have the right to discontinue this plan at any time, without incurring termination costs.
The total charges recognized under the Retirement Plan amounted to approximately 42, 41 and 46 for the years ended
December 31, 2013, 2012 and 2011, respectively.
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.
The amount charged to expense related to the Performance Bonus Programs was 466, 372 and 306 for the years ended
December 31, 2013, 2012 and 2011, respectively.
iii. Share-based benefit plan:
During the year, YPF has decided to implement share-based benefits plans. These plans cover certain executive and
management positions and key personnel with critical technical knowledge. The above mentioned plans are aimed at aligning
the performance of executives and key technical staff with the objectives of the strategic plan of the Company.
These plans are to give 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. The implementation of these plans has included the conversion of
certain long term compensation plans existing to date. 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.
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.
Additionally, YPF expects to acquire treasury shares in market transactions to fulfill these obligations. As of December 31,
2013, 1,232,362 shares have been repurchased in both local and United States market. The acquisition cost of these shares has
been recorded in “Acquisition cost of treasury shares” account with in shareholders’ equity (see section 1.b.17) of this Note).
The amounts recognized in net income in relation with the share-based plans previously mentioned, which are disclosed
according to their nature, amounted to 43 for the year ended on December 31, 2013.
Information related to outstanding plans in each year is as follows:
Balance at beginning of year
– Granted
– Settled
– Expired
Balance at the end of year(1)
Expense recognized during the year
Fair value of shares on grant date (in dollars)
(1) The average remaining life of the plan is between 10 and 34 months.
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Quantity of
shares-plan
—
1,769,015
(479,174)
—
1,289,841
Total
43
14.75
iv. Pension Plans and other Post-retirement and Post-employment benefits
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 pension plans and other post-retirement and post-employment benefits, are included in
Note 7.
Additionally, the Company’s 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 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 Company has transferred to the buyer the significant risks and rewards of ownership of the goods;
the Company 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 Company; and
the costs incurred or to be incurred in respect of the transaction can be measured reliably.
Grants for capital goods
Argentine tax authorities provide a tax incentive for investment in capital goods, computers and telecommunications for
domestic manufacturers through a fiscal bonus, provided that manufacturers have industrial establishments located in Argentina,
a requirement that is satisfied by the controlled company A-Evangelista S.A. The Company recognizes such incentive when the
formal requirements established by Decrees No. 379/01, 1551/01, its amendments and regulations are satisfied, to the extend
there is reasonable certainty that the grants will be received.
The bonus 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.
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1.b.12) Recognition of revenues and costs associated with construction contracts
Revenues and costs related to construction activities performed by A-Evangelista S.A., controlled company, 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, 2013, 2012 and 2011:
Contracts in progress
Revenues of
the year
Costs incurred
plus accumulated
recognized profits
312
684
993
2,359
889
1,112
Advances
received
368
122
106
Retentions
—
—
13
2013
2012
2011
1.b.13) 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 Company has no financial leases as they are defined by IFRS.
1.b.14) Earnings per share
Basic earnings per share are 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 1.b.10).
Additionally, diluted earnings per share are calculated by dividing the net income for the year attributable to YPF’s shareholders
by the weighted average of ordinary shares of YPF outstanding during the period adjusted by the weighted average of ordinary
shares of YPF that would be issued on the conversion of all the dilutive potential ordinary shares into YPF ordinary shares. As
of the date of the issuance of these financial statements there are no instruments outstanding that imply the existence of potential
ordinary shares, thus the basic earnings per share matches the diluted earnings per share.
1.b.15) Financial liabilities
Financial liabilities (loans and account payables) are initially recognized at their fair value less the transaction costs incurred.
Since the Company 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.
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“Accounts payable” and “Other liabilities” are recognized at their face value since their discounted value does not differ
significantly from their face value.
The Company derecognizes financial liabilities when the related obligations are settled or expire.
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, as described in Note 2.i,
the Company 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 income. The Company 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 Company 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 (see additionally Note 2.i). 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.
1.b.16) Taxes, withholdings and royalties
Income tax and tax on minimum presumed income
The Company 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 Company 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.
For the years ended December 31, 2013, 2012 and 2011, the amounts determined as current income tax were higher than tax on
minimum presumed income and they were included in the “Income tax” account of the statement of comprehensive income.
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, YPF is entitled to seek reimbursement of such paid tax from the applicable shareholders, using the method
YPF considers appropriate.
F-19
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 from the Ministry of Economy and Public
Finance, published on January 3, 2013, modified the reference and floor prices. The outstanding regime provides that when the
international price exceeds the reference price of US$ 80 per barrel, the producer will collect a floor price of US$ 70 per barrel,
depending on the quality of the crude oil sold, with the remainder being withheld by the Argentine Government. When the
international price is under the reference price but over US$ 45 per barrel, a 45% withholding rate should be applied. If such
price is under US$ 45 per barrel, the Government will have to determine the export rate within a term of 90 business days.
The withholding rate determined as indicated above also currently applies to diesel, gasoline and other crude derivative
products. In addition, the procedure for the calculation mentioned above applies to other crude derivatives and lubricants, based
upon different withholding rates, reference prices and prices allowed to producers. 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.17) 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, even though such accounts would have had a different
outstanding balance whether IFRS had been applied instead.
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, considering the absorption order stated in the paragraph “Retained
earnings”.
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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 1.b.10.iii).
Issuance premiums
Corresponds to the difference between the amount of subscription of the capital increase and the corresponding face value of the
shares issued.
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.
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, 2013, 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 1.b.10.iii) and Note 4.
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.
F-21
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.
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.
Non-controlling interest
Corresponds to the interest in the net assets acquired and net income of MetroGAS (30%) and YPF Tecnología (49%),
representing the rights on shares that are not owned by YPF.
1.b.18) Business combinations
Business combinations are accounted for by applying the acquisition method when YPF takes effective control over the acquired
company.
YPF 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. YPF 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.
If the business combination is achieved in stages, YPF 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 YPF. 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.19) New standards issued
The standards, interpretations and related amendments published by the IASB and endorsed by the FACPCE and the CNV that
are being applied by the Company, are the following:
IFRS 13 “Fair Value Measurement”
In May 2011, the IASB issued IFRS 13 “Fair value measurement” which is effective for fiscal years beginning on or after
January 1, 2013, with early application permitted.
The IFRS 13 sets out a single framework for measuring fair value when required by other IFRSs. The IFRS applies to financial
or non-financial items measured at fair value.
F-22
The fair value is measured as “the price that would be received to sell an asset or paid to transfer a liability in an orderly
transaction between market participants at the measurement date”.
IAS 19 “Employee Benefits”
In June 2011, the IASB issued an amendment to IAS 19 “Employee benefits”, which is effective for fiscal years beginning on or
after January 1, 2013, with early application permitted.
The amendment to the IAS 19 eliminates the option to defer the recognition of actuarial gains and losses in the measurement of
defined benefit plans, which implies the recognition of all these differences in other comprehensive income.
IAS 1 “Presentation of Financial Statements”
In June 2011, the IASB issued an amendment to IAS 1 “Presentation of Financial Statements”, which is effective for fiscal years
beginning on or after July 1, 2012, with early application permitted.
The amendments to IAS 1 improve the presentation of items included in the Statement of comprehensive income, classifying by
nature and grouping items that may be reclassified to profit and loss section of the income statement in the subsequent periods,
when conditions are met, and the items that will not be reclassified.
Adoption of the amendment to IAS 1 did not have an impact on the operating income or the financial position of the Company,
implying only new revelations on the statement of comprehensive income.
The adoption of the standards and interpretations or amendments mentioned in the previous paragraphs did not have a
significant impact on the financial statements.
In addition to IFRS 9 “Financial Instruments”, IFRS 10 “Consolidated Financial Statements”, IFRS 11 “Joint Arrangements”,
and IFRS 12 “Disclosure of Interests in Other Entities”, as well as the amendments to IAS 27, “Separate financial statements”
and IAS 28, “Investments in Associated and Joint ventures” which have been early applied as of the date of transition, the
Company has not applied early any other standard or interpretation permitted by the IASB.
The standards and interpretations or amendments of them, published by the IASB and adopted or in process to be adopted by the
Federation of Professional Councils in Economic Sciences and the CNV, that are not in force because their effective date is
subsequent to December 31, 2013 and that are not applied in advance to the effective date by the Company are the following:
IFRIC 21 “Levies”
In May 2013, IASB issued the IFRIC Interpretation 21, “Levies”, which is effective for fiscal years beginning on or after
January 1, 2014, with early application permitted.
IFRIC 21 addresses the accounting for a liability to pay a levy imposed by governments on entities in accordance with
legislation.
IAS 36 “Impairment of assets”
In May 2013, the IASB issued an amendment to IAS 36, “Impairment of assets”, which is effective for fiscal years beginning on
or after January 1, 2014, with early application permitted.
The amendment to IAS 36 changes disclosures requirements regarding the determination of impairment of assets.
IAS 39 “Financial instruments: Recognition and measurement”
In June 2013, IASB issued a limited modification to IAS 39 with the purpose of allowing the continuation of hedge accounting
in circumstances when a hedging instrument is required to be novated.
F-23
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.
Annual improvements cycle to IFRS
On December 2013, IASB issued two documents with amendments to IFRS which are mostly effective for fiscal years
beginning on or after July 1, 2014, with early application permitted.
The Company is analyzing the impact of the adoption of these amendments; however, it estimates that the adoption of such
amendments will not have an impact on the operating income or the financial position of the Company, and, in some cases, will
imply only new disclosures.
1.c) Accounting Estimates and Judgments
The preparation of financial statements in accordance with IFRS requires Management to make assumptions and estimates that affect
the amounts of the assets and liabilities recognized, the presentation of contingent assets and liabilities at the end of each year and the
income and expenses recognized during the year. Future results may differ depending on the estimates made by Management.
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) impairment
test of assets (see Note 1.b.9), (4) provisions for environmental liabilities and hydrocarbon wells abandonment obligations (see Note
1.b.6, paragraph iv), and (5) the calculation of income tax and deferred income tax.
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).
The company 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, 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. YPF 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.
F-24
The Company 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 issue existing prior to December 31,
1990. The Company 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 for 13,509 as of December 31, 2013, the Company has accrued
1,690 corresponding to 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 Company 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 Company’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
3.
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
Company’s tax balances.
1.d) Financial Risk Management
The Company’s activities involve various types of financial risks: market, liquidity and credit. The Company maintains an
organizational structure and systems that allow the identification, measurement and control of the risks to which it is exposed.
In addition, the table below details the classes of financial instruments of the Company classified in accordance to IFRS 9:
Financial Assets
At amortized cost
Cash and equivalents (1)
Other receivables and advances (1)
Trade receivables (1)
At fair value through profit or loss
Cash and equivalents (2)
Financial Liabilities
At amortized cost
Accounts payable (1)
Loans (3)
Provisions(1)
2013
2012
2011
8,691
4,018
7,468
3,870
1,392
4,059
886
1,529
3,337
2,022
877
226
20,655
31,890
485
13,014
17,104
416
11,256
12,198
500
(1) Fair value does not differ significantly from their book value.
(2) Corresponds to investments in mutual funds with price quotation. The fair value was determined based on unadjusted quoted
prices (Level 1) in the markets where those financial instruments trade. The net gains (losses) for the years ended December 31,
2013, 2012 and 2011 for these instruments are disclosed as “Interest on assets” in the Statements of Comprehensive Income.
(3) Their fair value, considering unadjusted quoted prices (Level 1) for Negotiable Obligations and interest rates offered to the
Company (Level 3) for the other financial loans, at the end of year, as appropriate, amounted to 33,784, 17,238 and 12,264 as of
December 31, 2013, 2012 and 2011, respectively.
F-25
Market Risk
The market risk to which the Company is exposed is the possibility that the valuation of the Company’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.
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 Company does not use derivatives as a hedge
against exchange rate fluctuations. Otherwise, according to the Company’s functional currency, and considering the conversion
process to presentation currency, the fluctuations in the exchange rate related to the value of financial assets and liabilities in pesos
does not have any effect in Shareholders’ equity.
The following table provides a breakdown of the effect a variation of 10% in the prevailing exchange rates on the Company’s net
income, taking into consideration the exposure of financial assets and liabilities denominated in pesos as of December 31, 2013:
Impact on net income before income
tax
corresponding to financial assets and
liabilities
Appreciation (+) / depreciation
(-) of exchange rate of peso
against dollar
+10%
-10%
December 31,
2013
759
(759)
During January 2014, the exchange rate of the U.S. dollar relative to the Argentine Peso in the free exchange market increased
approximately 23% from $ 6.52 as of December 31, 2013 to a value approximating $ 8 from January 24, onward, remaining in that
order until the date of issuance of these financial statements. The Company estimates the effect of that devaluation applied to the net
position of financial assets and liabilities at December 31, 2013, and further considering the effect on the position of other non-
financial assets and liabilities at the same date and the corresponding effect on the estimation of the provision for income tax and
deferred income tax, would not have a significant effect on the results of the Company in 2014.
Interest Rate Risk
The Company is exposed to the risk associated with fluctuations in the interest rates which depend on the currency and maturity date
of its loans or of the currency it has invested in financial assets.
The Company’s short-term financial liabilities as of December 31, 2013 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 liabilities include negotiable obligations and financial loans with local and international financial institutions.
Approximately 60% (19,266) of the total of the financial loans of the Company is denominated in U.S. dollars and the rest in
Argentine pesos, as of December 31, 2013. 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.
F-26
The Company 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, 2013 that accrues interest
considering the applicable rate:
Fixed interest rate
Variable interest rate
Total
December 31, 2013
Financial
Assets (1)
4,078
2,102
6,180
Financial
Liabilities (2)
17,158
14,732
31,890
(1)
(2)
Includes only short-term investments. 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.
The portion of liabilities which accrues variable interest rate is mainly exposed to the fluctuations in LIBOR and BADLAR.
Approximately 10,939 accrue variable interest of BADLAR plus a spread between 2.25% and 4.75%, and 3,642 accrues variable
interest of LIBOR plus a spread between 4.00% and 7.50%. Additionally 151 that accrue annual interest rate of 19% plus the
proportion of the increase in crude oil and natural gas production of the Company with an annual cap of 24%.
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)
For the year ended
December 31, 2013
+100
-100
(84)
84
Other Price Risks
The Company 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 Company is reached by certain regulations that affect the determination of export prices received by the Company,
such as those mentioned in Note 1.b.16 and 11.c, which consequently limits the effects of short-term price volatility in the
international market.
As of December 31, 2013, 2012 and 2011, the Company has not used derivative financial instruments to hedge risks related to
fluctuations in commodity prices.
Liquidity Risk
Liquidity risk is associated with the possibility of a mismatch between the need of funds (related, for example, to operating and
financing expenses, investments, debt payments and dividends) and the sources of funds (such as net income, disinvestments and
credit-line agreements by financial institutions).
As mentioned in previous paragraphs, YPF pretends 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, 2013
the availability of liquidity reached 13,211, considering cash for 4,533, other liquid financial assets for 6,180 and bank financing and
available credit lines for 2,500. Subsequent to December 31, 2013, the Company has obtained a credit line from the National Treasury
of 8,500. 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 and in April 2013 (see Note 2.i).
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After the process which concluded with the change of shareholders mentioned in Note 4, the Company 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.
The table below sets forth the maturity dates of the Company’s financial liabilities as of December 31, 2013:
December 31, 2013
Maturity date
0 - 1
year
1 - 2
years
2 - 3
years
3 - 4
years
4 - 5
years
More than
5 years
Total
Financial Liabilities
Accounts payable(1)
Loans
Provisions
40 — —
20,185
8,814 3,379 5,986 3,599 5,892
412
409
52
24 — — —
18 20,655
4,220 31,890
485
(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. With respect to a significant portion of the
financial loans, as of December 31, 2013, the Company has agreed, among other things and subject to certain exceptions, not to
establish liens or charges on assets. Additionally, approximately 19% of the outstanding financial debt as of December 31, 2013 is
subject to financial covenants related to the leverage ratio and debt service coverage ratio of the Company.
A portion of the Company’s financial debt provides that certain changes in the Company’s control and/or nationalization may
constitute an event of default. Moreover, the Company’s financial debt also contains cross-default provisions and/or cross
acceleration provisions that could cause all of the financial debt to be accelerated if the debt having changes in control and/or
nationalization events provisions is defaulted. As of the issuance date of these financial statements, the Company has obtained formal
waivers from all the financial creditors in relation to its outstanding debt subject to the mentioned terms at the moment in which the
change in control occurred mentioned in Note 4. Additionally and related to the outstanding debt of YPF subsidiaries, GASA and
MetroGAS, see Note 2.i) of these consolidated financial statements.
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 Company.
Credit risk in the Company is measured and controlled on an individual customer basis. The Company has its own systems to conduct
a permanent evaluation of credit performance of all of its debtors and customers, and the determination of risk limits with respect to
customers, in line with best practices using for such end internal customer records and external data sources.
Financial instruments that potentially expose the Company to a concentration of credit risk consist primarily of cash and equivalents,
trade receivables and other receivables and advances. The Company 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, the Company provides
credit based on ongoing credit evaluations to its customers and certain related parties. Additionally, the Company accounts for credit
losses in the other comprehensive income statement, based on specific information regarding its clients. As of the date of these
consolidated financial statements, the Company’s customer portfolio is diversified.
The allowances 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.
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The maximum exposure to credit risk of the Company as of December 31, 2013 based on the type of its financial instruments and
without excluding the amounts covered by guarantees and other arrangements mentioned below, as of December 31, 2013, is set forth
below:
Cash and equivalents
Other financial assets
Following is the breakdown of the financial assets past due as of December 31, 2013.
Maximum exposure
as of December 31,
2013
10,713
11,486
Less than three months past due
Between three and six months past due
More than six months past due
Current trade
receivable
357
272
702
1,331
Other current
receivables and
advances
208
52
99
359
At such date, the provision for doubtful trade receivables amounted to 658 and the provisions for other doubtful receivables amounted
to 19. These allowances are the Company’s best estimate of the losses incurred in relation with accounts receivables.
Guarantee Policy
As collateral of the credit limits granted to customers, YPF 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, YPF also has obtained other guarantees as credit insurances, surety bonds, guarantee customer –
supplier, car pledges, etc.
The Company has effective guarantees granted by third parties for a total amount of 2,131 and 1,965 as of December 31, 2013 and
2012, respectively.
During the year ended December 31, 2013, YPF executed guarantees received for an amount of 4. As of December 31, 2012 and
2011, YPF executed guarantees received for an amount of 2 and 6, respectively.
2. ANALYSIS OF THE MAIN ACCOUNTS OF THE CONSOLIDATED FINANCIAL STATEMENTS
Details regarding the significant accounts included in the consolidated financial statements are as follows:
Consolidated Balance Sheet as of December 31, 2013 and Comparative Information
2.a) Cash and equivalents:
Cash
Short-term investments
Financial assets at fair value through profit or loss
F-29
2013
4,533
4,158
2,022
10,713
2012
950
2,920
877
4,747
2011
777
109
226
1,112
2.b) Trade receivables:
Accounts receivable and related parties(1)
Provision for doubtful trade receivables
(1) See Note 6 for additional information.
Changes in the provision for doubtful trade receivables
2013
2012
2011
Noncurrent
Current
8,066
60
(6)
(652)
54 7,414
Noncurrent Current Noncurrent Current
22 3,769
(454)
22 3,315
4,538
(494)
4,044
20
(5)
15
—
Amount at beginning of year
Increases charged to expenses
Decreases charged to income
Amounts incurred
Translation differences
Reclassifications and others
Amount at end of year
2.c) Other receivables and advances:
2013
2012
Noncurrent
provision
for
doubtful
trade
receivables
5
—
—
—
1
—
6
Current
provision
for
doubtful
trade
receivables
494
191
(73)
—
40
—
652
Noncurrent
provision
for
doubtful
trade
receivables
—
—
—
—
—
5
5
Current
provision
for
doubtful
trade
receivables
454
56
(25)
(2)
16
(5)
494
2011
Current
provision
for
doubtful
trade
receivables
465
63
(73)
(6)
5
—
454
2013
2012
2011
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
Insurance receivables (Note 11.b)
Miscellaneous
Provision for other doubtful accounts
Provision for valuation of other receivables to their estimated
realizable value
Noncurrent
—
22
67
517
397
11
3
—
1,852(3)
—
62
2,931
—
Current
377
1,233
34
81
253
490
166
1,062
595(3)
1,956
357
6,604
(98)
Noncurrent
—
9
98
347
40
22
—
—
278
Current Noncurrent Current
227
1,022
21
217
176
274
104
563
56
— —
221
2,881
(93)
223
750
17
77
193
239
106
542
129
—
455
2,731
(96)
97
891
—
—
10
83
385
7
8
—
—
600
—
69
1,162
—
(4)
2,927
—
6,506
(1)
1,161
—
2,635
(9) —
2,788
882
(1) See Note 6 for additional information.
(2)
Includes among others, advances to customs agents for the payment of taxes and import rights related to the imports of fuels and
other products.
Includes the receivables related to the investment agreement with Chevron Corporation (see Note 11.c).
(3)
F-30
Changes in the provisions of other receivables and advances
2013
Provision for
valuation of
other
noncurrent
receivables to
their estimated
realizable value
Provision for
other current
doubtful
accounts
Provision for
valuation of
other
noncurrent
receivables to
their estimated
realizable value
2012
2011
Provision for
valuation of
other
noncurrent
receivables to
their estimated
realizable value
Provision for
other current
doubtful
accounts
Provision for
other current
doubtful
accounts
1
3
—
—
4
96
2
—
—
98
9
—
(4)
(4)
1
93
3
—
—
96
16
—
—
(7)
9
93
—
—
—
93
Amount at beginning of
year
Increases charged to
expenses
Decreases charged to
income
Amounts incurred
Amount at end of year
2.d) Inventories:
Refined products
Crude oil and natural gas
Products in process
Construction works in progress
Raw materials and packaging materials
2013
5,713
3,451
115
107
495
9,881(1)
2012
4,316
1,813
106
230
457
6,922(1)
2011
3,608
1,733
68
256
341
6,006(1)
(1) As of December 31, 2013, 2012 and 2011, the net value of the inventories does not differ, significantly, from their cost.
2.e) Investments in companies:
Investments in companies (Exhibit I)
Provision for reduction in value of investments in companies
2013
2,136
(12)
2,124
2012
1,926
(12)
1,914
2011
2,070
(57)
2,013
2.f) Evolution of intangible assets:
Main account
Service concessions
Exploration rights
Other intangibles
Total 2013
Total 2012
Total 2011
2013
Cost
Amounts at
beginning
of year
Increases
Translation
effect
2,769
408
1,266
4,443
3,724
3,128
201
264
159
624
145
414
931
161
455
1,547
571
225
Net decreases,
reclassifications
and transfers
16
(32)
(1)
(17)
3
(43)
Amounts at
the end
of year
3,917
801
1,879
6,597
4,443
3,724
2013
Amortization
2012
2011
Accumulated
at beginning
of year
Net decreases,
reclassifications
and transfers
Depreciation
rate
Increases
Translation
effect
Accumulated
at the end
of year
Net book
value
12-31
Net book
value
12-31
Net book
value
12-31
1,839
6
—
(20)
4-5%
—
94
17
618
5
2,551
8
1,366
793
930
402
804
345
Main account
Service
concessions
Exploration rights
Other intangibles
Total 2013
Total 2012
Total 2011
1,106
2,951
2,424
2,201
(4)
(24)
(4)
—
7-33%
86
197
152
61
404
1,027
379
162
1,592
4,151
2,951
2,424
287
2,446
160
151
1,492
1,300
The Company does not have intangible assets with indefinite useful lives as of December 31, 2013, 2012 and 2011.
F-31
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; 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.
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 pipelines and petroleum products and by the National Gas
Regulatory Authority (Ente Nacional Regulador del Gas or “ENARGAS”) for gas pipelines. Upon expiration of a transportation
concession, the pipelines and related facilities automatically revert to the Argentine State without payment to the holder.
The Privatization Law granted YPF a 35-year transportation concession with respect to the pipelines operated by Yacimientos
Petrolíferos Fiscales S.A. at the time. The main pipelines related to such transport concessions are:
•
•
•
•
•
La Plata / Dock Sud
Puerto Rosales / La Plata
Monte Cristo / San Lorenzo
Puesto Hernández / Luján de Cuyo
Luján de Cuyo / Villa Mercedes
Management considers that the assets referred to above meet the criteria set forth by IFRIC 12, and should be therefore recognized as
intangible assets.
2.g) Composition and evolution of fixed assets:
Net book value of fixed assets
Provision for obsolescence of materials and equipment
Main account
Land and buildings
Mineral property, wells and related equipment
Refinery equipment and petrochemical plants
Transportation equipment
Materials and equipment in warehouse
Drilling and work in progress
Exploratory drilling in progress(4)
Furniture, fixtures and installations
Selling equipment
Infrastructure for natural gas distribution
Electric power generation facilities
Other property
Total 2013
Total 2012
Total 2011
Amounts at
beginning of
year
4,954
121,313
18,272
1,022
3,375
13,658
955
1,641
2,851
—
—
2,802
170,843
135,618
113,531
Increases
105
5,380
5
39
4,288
23,812
911
17
3
2,730
1,542
388
39,220(5)(7)(8)
16,209(5)
13,817(5)
F-32
2013
93,662
(166)
93,496
2012
57,103
(132)
56,971
2011
43,645
(123)
43,522
2013
Cost
Translation
effect
1,554
41,979
6,384
333
1,183
4,992
296
530
982
—
—
888
59,121
20,282
9,287
Net decreases,
reclassifications
and transfers
352
11,205
4,606
72
(3,270)
(22,622)
(1,235)
79
248
(8)
—
(8)
(10,581)(6)
(1,266)(1)
(1,017)(1)
Amounts at
the end
of year
6,965
179,877
29,267
1,466
5,576
19,840
927
2,267
4,084
2,722
1,542
4,070
258,603
170,843
135,618
Accumulated
at beginning
of year
2,048
Net decreases,
reclassifications
and transfers
(4)
Translation
effect
Accumulated
at the end
of year
616
2,804
Net book
value
4,161
Increases
144
2012
2011
Net book
value
2,906
Net book
value
2,546
2013
Depreciation
Depreciation
rate
2%
(2)
93,306
(1,459)
9,752
32,073
133,672 46,205(3) 28,007(3)
23,778(3)
12,427
701
—
—
—
1,392
2,143
—
—
1,723
113,740
91,973
78,755
(44)
(10)
—
—
—
—
—
—
4-5%
4-20%
1,005
101
4,223
230
17,611 11,656
444
1,022
5,845
321
3,752
195
—
—
—
10%
10%
—
—
—
144
162
—
—
—
454
729
—
5,576
3,375
2,076
— 19,840
13,658
9,152
—
927
1,990
3,034
277
1,050
955
249
708
—
419
199
461
—
2-5%
1,107
—
1,107
1,615
—
(13)
(1,530)(6)
(84)(1)
(12)(1)
5-7%
10%
1,060
355
13,830(7)(8)
8,129
6,438
—
576
38,901
13,722
6,792
1,060
2,641
482
1,429
—
1,079
—
1,067
164,941 93,662
113,740
91,973
57,103
43,645
Main account
Land and buildings
Mineral property, wells
and related equipment
Refinery equipment and
petrochemical plants
Transportation equipment
Materials and equipment
in warehouse
Drilling and work in
progress
Exploratory drilling in
progress(4)
Furniture, fixtures and
installations
Selling equipment
Infrastructure for natural
gas distribution
Electric power generation
facilities
Other property
Total 2013
Total 2012
Total 2011
(1)
Includes 4 and 26 of net book value charged to fixed assets provisions for the years ended December 31, 2012 and 2011,
respectively.
(5)
Includes 3,748, 2,800 and 1,601 of mineral property as of December 31, 2013, 2012 and 2011, respectively.
(2) Depreciation has been calculated according to the unit of production method (Note 1.b.6).
(3)
(4) As of December 31, 2013, there are 55 exploratory wells in progress. During year ended on such date, 50 wells were drilled, 22
wells were charged to exploratory expenses and 24 were transfer to proved properties which are included in the account Mineral
property, wells and related equipment.
Includes 4,357, (276) and 695 corresponding to hydrocarbon wells abandonment costs for the years ended December 31, 2013,
2012 and 2011.
Includes 91 from the write-down of the assets of Coke A unit as a consequence of the incident in La Plata refinery on April
2013, as a result of the storm that took place in that city (see also Note 11.b) and 6,708 from the decrease of assets related to the
investment project agreement (see also Note 11.c).
Includes 3,137 and 1,352 of increases and accumulated amortization, respectively, corresponding to GASA on the acquisition
date (see Note 13).
Includes 1,878 and 1,242 of increases and accumulated amortization, respectively, corresponding to YPF Energía Eléctrica on
the spin-off date (see Note 13).
(7)
(6)
(8)
As described in Note 1.b.6, YPF capitalizes the financial cost as a part of the cost of the assets. For the years ended on December 31,
2013, 2012 and 2011 the annual average rate of capitalization were 12.03%, 8.55% and 5.91% and the capitalized amount were 605,
340 and 125, 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 on December 31,
2013, 2012 and 2011:
Amount at beginning of year
Increases charged to expenses
Decreases charged to income
Amounts incurred
Translation differences
Amount at end of year
2013
132
16
—
—
18
166
2012
123
22
(23)
(4)
14
132
2011
115
21
—
(26)
13
123
Set forth below is the evolution of the exploratory wells in evaluation stage for the years ended on December 31, 2013, 2012 and
2011:
Amount at beginning of year
Additions pending the determination of proved reserves
Decreases charged to exploration expenses
Reclassifications to mineral property, wells and related equipment
with proved reserves
Translation difference
Amount at end of year
2013
815
424
(255)
2012
160
683
(35)
2011
136
155
—
(481)
207
710
(63)
70
815
(143)
12
160
F-33
The following table shows exploratory wells capitalized for a period longer than a year and the number of projects related to such
costs as of December 31, 2013:
Between 1 and 5 years
More than 5 years
Total
2.h) Accounts payable:
Trade and related parties(1)
Investments in companies with negative shareholders’ equity
Extension of Concessions—Provinces of Chubut, Mendoza,
Santa Cruz and Neuquén
Accounts payable from joint operations and other agreements
Miscellaneous
(1) See additionally Note 6.
2.i) Loans:
Negotiable Obligations(2)
Other financial debts
Principal
maturity
Interest rate (1)
Noncurrent
0.10-24.00% 2013-2028 20,474
2.00-32.00% 2013-2018
Amount
143
—
143
Number of
projects
3
—
3
Number of
wells
4
—
4
2013
2012
2011
Noncurrent
Noncurrent
Current Noncurrent
Current
Current
153 17,360
127
—
35 10,705
—
9,494
33
4 — —
1,036
275
1,193
—
42
596
470 20,312
451
936 —
104
714
798 —
—
27
23
536
413
60 11,195
162 12,856
2013
2012
2011
Current
4,296
4,518(3)(4)
8,814
Noncurrent Current Noncurrent
Current
9,216 725
2,884 4,279
12,100 5,004
678
313
3,757 7,450
4,435 7,763
2,602(3)(4)
23,076
(1) Annual interest rate as of December 31, 2013.
(2) Disclosed net of 137, 450 and 75, corresponding to YPF’s outstanding Negotiable Obligations repurchased through open market
(3)
(4)
transactions as of December 31, 2013, 2012 and 2011, respectively.
Includes approximately 5,715 corresponding to loans agreed in U.S. dollars, which accrue interest at rates between 2.00% and
8.25%.
Includes 926 corresponding to loans granted by Banco Nación Argentina, denominated in argentine pesos of which 424 accrue
fixed interest rate of 15% until December 2015 and then accrue variable interest of BADLAR plus a spread of 4 points and 502
accrue variable interest of BADLAR plus a spread of 4 points with a cap of the overall portfolio of Banco Nación lending
interest rate. See also Note 6.
F-34
Details regarding the Negotiable Obligations of the Company are as follows:
(in millions)
Issuance
Month
– YPF:
–
March
June
September
September
Year
Principal
value
1998 US$ 100
70
2010 US$
300
2011 $
100
2012 $
200
$
2012
Class
Interest rate(4)
Principal
maturity Noncurrent Current Noncurrent Current Noncurrent Current
2013
Book value
2012
2011
(1) (7) (3) —
(2) (7)
(2) (7)
(2) (7)
(2) (7)
Class III
Class V
Class VI
Class VII
Fixed
—
—
—
10.00%
—
—
—
2028
—
—
—
10
534
— —
— —
— —
1
40
—
347
— —
101
—
7
377
5
301
—
301
— —
2014
—
202
200
2
— —
2015
2014
800
—
413
853
1,200
636
11
7
— —
— —
6.25%
2016
3,587
45
2,702
34
— —
September
2012
$
1,200
(2) (5) (7)
Class VIII
October
October and
December
November and
December
2012 US$ 130
US$ 552
2012
(2) (6) (7) Class IX Fixed
Fixed
Class X
(2) (5) (6) (7)
2012
$
2,110
(2) (5) (7)
Class XI
December
December and
March
2012 $
$
2012/3
150
2,828
(2) (7)
(2) (5) (7)
Class XII
Class XIII
March
March
May
April
April
April
June
July
July
October
2013 $
300
2013 US$ 230
300
2013 $
2,250
$
2013
(2) (7)
Class XIV Fixed
(2) (6) (7) Class XV Fixed
(2) (7)
Class XVI
Fixed
Class XVII
(2) (5)
2013 US$
2013 US$
2013
$
61
89
1,265
2013 $
2013 US$
100
92
US$ 150
2013
(2) (6) (7)
(2) (6)
(2) (5)
(2)
(2) (6)
(2)
Class XVIII Fixed
Class XIX Fixed
Class XX
Class XXI
Fixed
Class XXII Fixed
Class
XXIV
October
2013
$
300
(2)
Class XXV
Variable
BADLAR
plus 3% 21.73%
Variable
BADLAR
plus 4% 22.73%
5.00%
Variable
BADLAR
plus
4.25% 22.48%
—
—
Variable
BADLAR
plus
4.75% 23.60%
19.00%
2.50%
19.00%
Variable
BADLAR
plus
2.25% 21.46%
0.1%
1.29%
Variable
BADLAR
plus
2.25% 21.03%
19.00%
3.50%
Variable
LIBOR
plus
7.50% 7.74%
Variable
BADLAR
plus
3.24% 22.45%
Fixed
2017
—
2,110
64
— —
2,110
—
56
151
— —
— —
2018
2014
2014
2014
22
2,828
—
304
— 1,497
303
—
2,328
15
— —
— —
— —
— —
— —
— —
— —
2020
2015
2017
2,250
83
397 —
1
579
— —
— —
— —
— —
— —
— —
2020
2014
2020
1,265
—
510
10
101
89
— —
— —
— —
— —
— —
— —
2018
860
125
— —
— —
2015
300
13
— —
— —
December
2013
US$ 500
December
2013
$
150
– MetroGAS:
January
January
– GASA:
March
March
2013 US$ 163
16
2013 US$
2013 US$
2013 US$
51
1
(2)
(2)
Class
XXVI
Class
XXVII
8.875%
2018
3,251
10
— —
— —
Variable
(8)
24%
2014
—
151
— —
— —
Serie A-L Fixed
Serie A-U Fixed
8.875%
8.875%
Serie A-L Fixed
Serie A-U Fixed
8.875%
8.875%
2018
2018
2015
2015
840 —
91 —
— —
— —
— —
— —
262 —
10 —
20,474 4,296
— —
— —
725
9,216
— —
— —
313
678
(1) Corresponds to the 1997 M.T.N. Program for U$S 1,000 million.
(2) Corresponds to the 2008 M.T.N. Program for U$S 5,000 million.
(3) The Company has granted to certain holders of this negotiable obligation an option to sell (“put”) such securities at face value,
for an amount of up to 444 approximately, which can be executed between 2020 and 2028.
Interest rate as of December 31, 2013.
(4)
(5) The ANSES and/or the Argentine Hydrocarbons Fund have participated in the primary subscription of these negotiable
obligations, which may at the discretion of the respective holders, be subsequently traded in the securities market where these
negotiable obligations are authorized to be traded.
(6) The payment currency of these Negotiable Obligations is the Argentine Peso at the Exchange rate applicable under the terms of
the series issued.
(7) As of the date of issuance of these financial statements, the Company has fully complied with the use of proceeds disclosed in
the pricing supplements.
(8) Accrue an annual variable interest rate equivalent to the sum of a floor interest rate of 19% plus a spread related to YPF’s total
hydrocarbons production (natural gas, oil-condensate and gasoline) according to the information of the National Secretariat of
Energy with a maximum interest rate of 24%.
For additional information about covenants assumed by the Company and maturity of loans see Note 1.d) Financial risk management.
•
YPF’s Negotiable Obligations
The Shareholder’s meeting held on January 8, 2008, approved a Notes Program for an amount up to US$ 1,000 million. Subsequently
the amount of the program was extended by the corresponding approval of the Shareholders’ meeting, totalizing a maximum nominal
amount outstanding of US$ 5,000 million or its equivalent in other currencies. The funds from this program may be used for any of
the alternatives provided in Law No. 23,576 of negotiable obligations and its supplementary rules.
F-35
•
•
Negotiable Obligations of MetroGAS S.A. and Gas Argentino S.A. – Debt Restructuring:
MetroGAS:
In compliance with the preventive agreement between MetroGAS and its creditors, in relation with MetroGAS voluntary
reorganization petition, on January 11, 2013 new negotiable obligations were issued by MetroGAS (the “new negotiable obligations
of MetroGAS”) which were granted in exchange to the financial and non-financial creditors verified and declared acceptable.
On February 1 and February 13, 2013 MetroGAS presented to the Court the documentation that demonstrates the fulfillment of the
debt exchange and the issuance of the new negotiable obligations of MetroGAS in order to obtain the removal of the general
prohibition and obtain the legal declaration of the accomplishment of the preventive agreement under the terms and conditions of art.
59 of the Bankruptcy law.
The issuance of the new negotiable obligations of MetroGAS was approved by the CNV on December 26, 2012, within the
framework of the Global Negotiable Obligation Issuance Program of MetroGAS for a nominal value of up to US$ 600 million.
MetroGAS issued the new negotiable obligations to be exchanged for existing negotiable obligations:
•
•
Series A-L for an amount of US$ 163,003,452.
Series B-L for an amount of US$ 122,000,000.
and in exchange of non-financial debt of MetroGAS negotiable obligations:
•
•
Series A-U for an amount of US$ 16,518,450.
Series B-U for an amount of US$ 13,031,550.
From the date of issuance, all MetroGAS obligations under the terms of the Previous Negotiable Obligations and the previous non-
financial debt were terminated and all rights, interests and benefits stipulated therein were annulled and canceled. Consequently, the
previous Negotiable Obligation and the previous non-financial debt were extinguished and no longer constitute MetroGAS
enforceable obligations. In this order, the debt exchange was accounted for as a debt extinguishment following the guidelines of IFRS
9. The result, before tax effect, of the restructuring of the outstanding debt obligations of MetroGAS was recognized by that company
during the three months ended on March 31, 2013. Since this result was recognized by MetroGAS prior to the YPF’s acquisition, the
effect arising thereof has been considered in the initial accounting of the acquisition of MetroGAS (see Note 13).
The principal value of the Class A New Negotiable Obligations of MetroGAS shall be fully redeemed at its maturity on December 31,
2018 in a single payment. The Class A New Negotiable Obligations of MetroGAS will accrue an annual nominal interest rate of
8.875%. The Class B New Negotiable obligations of MetroGAS maturing on 2018 will only accrue interest if there is a triggering
event (which includes the anticipated maturity in case of an event of default under the terms of the new issued negotiable obligations)
occurs before the Deadline, and in the case no triggering event occurs, the Class B New Negotiable obligations of MetroGAS will be
automatically canceled and will no longer constitute an enforceable obligation for MetroGAS. Interest on the Series AL and AU will
be paid every six months on June 30 and December 31 of each year, although MetroGAS has exercised the option to capitalize 100%
of the interest accrued between the date of issuance and June 30, 2013 and 50% of the interest accrued between July 1, 2013 and
December 31, 2013 and has the option to capitalize 50% of the interest to be accrued between January 1, 2014 and June 30, 2014.
Additionally, in accordance with the terms and conditions of issuance of the New Negotiable obligations of MetroGAS, it and its
subsidiaries, must comply with certain restrictions relating to indebtedness, restricted payments (including dividends), liens, among
others.
F-36
•
GASA:
In compliance with the preventive agreement between GASA and its creditors, in relation with the voluntary reorganization petition
of GASA, on March 15, 2013 GASA proceeded to exchange the existing negotiable obligations held by its financial creditors and the
credits of nonfinancial creditors verified and declared acceptable by the New Negotiable obligations.
GASA issued new negotiable obligations (the “new negotiable obligations of GASA”) to be delivered in exchange for previous
existing negotiable obligations:
•
•
Series A-L for an amount of US$ 50,760,000.
Series B-L for an amount of US$ 67,510,800.
and in exchange for the financial debt of the Company’s Previous Negotiable Obligations:
•
•
Series A-U for an amount of US$ 1,306,528.
Series B-U for an amount of US$ 1,737,690.
The issuance of the new negotiable obligations of GASA AL and BL series were approved by the CNV on February 5, 2013.
From the date of issuance, all GASA obligations under the terms of the previous negotiable obligations and the previous financial
debt were terminated and all rights, interests and benefits stipulated therein were annulled and canceled. Consequently, the Previous
Negotiable obligations and the previous financial debt were extinguished and no longer constitute an enforceable obligation for
GASA. The debt exchange was accounted for as an extinguishment of debt following the guidelines of IFRS 9. The result before tax
effect of the debt restructuring of GASA was recognized in the statement of income during the three months ended on March 31,
2013. Since this result was recognized by GASA prior to YPF’s acquisition, the effect arising thereof has been considered in the
initial accounting of the acquisition of GASA (see Note 13).
The principal value of the Class A new negotiable obligations of GASA will be fully redeemed at its maturity on December 31, 2015
in a single payment. If GASA pays the total accrued non-capitalized interest to that date and the capital corresponding that would
have been capitalized in accordance with the terms of issuance up to that date, then the maturity of the new negotiable obligations of
GASA will be on December 31, 2016. The Class A new negotiable obligations of GASA will accrue an annual nominal interest of
8.875%. The Class B new negotiable obligations of GASA, maturing on 2015, will only accrue interest if there is a triggering event
(which includes the anticipated maturity in case of an event of default under the terms of the negotiable obligations issued) occurs
before the Deadline, and if the triggering event has not occur, the Class B new negotiable obligations of GASA will be automatically
canceled and will no longer constitute enforceable obligations for GASA. Interest will be paid every six months on June 15 and
December 15 of each year, GASA will have the option to capitalize 100% of the interest accrued between the date of issuance and
December 15, 2015. GASA has exercised this option for the accrued interest from the date of issuance to December 15, 2013.
Additionally, in accordance with the terms and conditions of issuance of the new negotiable obligations, GASA and its subsidiaries,
must comply with certain restrictions relating to indebtedness, restricted payments (including dividends), liens, among others.
2.j) Provisions:
Amount as of December 31, 2012
Increases charged to expense
Decreases charged to income
Decrease from payments
Translation differences
Reclassifications and others
Amount as of December 31, 2013
Provision
for pensions
Noncurrent Current
136
3
—
—
46
(17)
168
16
—
—
(16)
5
17
22
Provision for pending
lawsuits and
contingencies
Provision for
environmental
liabilities
Provision for
hydrocarbon wells
abandonment
obligations
Noncurrent
Current
Noncurrent
122
29
(41)
(160)
9
200
159
677
208
—
—
138
(259)
764(2)
2,892
1,877
(90)
—
579
(238)
5,020
F-37
Current
489
551
—
(432)
59
259
926(3)
Noncurrent
6,958
719
—
—
1,355
4,188(1)
13,220
Current
193
—
—
(105)
29
172(1)
289
Provision
for pensions
Provision for pending
lawsuits and
contingencies
Provision for
environmental
liabilities
Provision for
hydrocarbon wells
abandonment
obligations
Amount as of December 31, 2011
Increases charged to expense
Decreases charged to income
Decrease from payments
Translation differences
Reclassifications and others
Amount as of December 31, 2012
Noncurrent Current Noncurrent
2,167
1,058
(31)
—
210
(512)
2,892
143
5
—
—
(1)
(11)
136
14
—
—
(11)
2
11
16
Current
118
15
(4)
(519)
—
512
122
Noncurrent
567
707
(24)
—
53
(626)
677(2)
Current
581
—
—
(735)
17
626
489(3)
Noncurrent
6,329
477
—
—
489
(337)(1)
6,958
Current
252
5
—
(141)
16
61(1)
193
Provision
for pensions
Provision for pending
lawsuits and
contingencies
Provision for
environmental
liabilities
Provision for
hydrocarbon wells
abandonment
obligations
Amount as of January 1, 2011
Increases charged to expense
Decreases charged to income
Decrease from payments
Translation differences
Reclassifications and others
Amount as of December 31, 2011
Noncurrent
Current
Noncurrent
Current
Noncurrent
130
18
—
—
13
(18)
143
17
—
—
(23)
2
18
14
2,186
459
—
—
109
(587)
2,167
95
26
—
(590)
—
587
118
544
247
—
—
27
(251)
567(2)
Current
502
122
—
(311)
17
251
581(3)
Noncurrent
5,228
165
—
—
241
695(1)
6,329
Current
243
224
—
(224)
9
—
252
(1)
(2)
(3)
Includes 4,357, (276) and 695 corresponding to the annual revision of hydrocarbons well abandonment costs, which has
counterpart in fixed assets for the years ended on December 31, 2013, 2012 and 2011, respectively.
Includes provisions for environmental liabilities of YPF Holdings Inc. for 550, 431 and 346, as of December 31, 2013, 2012 and
2011, respectively.
Includes provisions for environmental liabilities of YPF Holdings Inc. for 268, 145 and 278, as of December 31, 2013, 2012 and
2011, respectively.
2.k) Revenues, cost of sales and expenses:
For the years ended December 31, 2013, 2012 and 2011
Revenues
Sales(1)
Revenues from construction contracts
Turnover tax
2013
92,978
312
(3,177)
90,113
2012
68,817
684
(2,327)
67,174
2011
57,054
993
(1,836)
56,211
(1)
Includes 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).
Cost of sales
Inventories at beginning of year
Purchases for the year
Production costs
Translation effect
Inventories at end of year
Cost of sales
2013
6,922
26,323
42,980
2,227
(9,881)
68,571
2012
6,006
17,974
32,374
835
(6,922)
50,267
2011
3,748
17,679
25,354
368
(6,006)
41,143
F-38
Expenses
Salaries and social security taxes
Fees and compensation for services
Other personnel expenses
Taxes, charges and contributions
Royalties and easements
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
Contractual commitments
Unproductive exploratory drillings
Transportation, products and charges
Provision (recovery) for doubtful trade
receivables and other doubtful accounts
Publicity and advertising expenses
Fuel, gas, energy and miscellaneous
Total 2013
Total 2012
Total 2011
Production
costs
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
32,374
25,354
2013
Administrative
expenses
Selling
expenses
963(2)
800(2)
177
62
2
19
12
—
179
73
19
106
104
2
—
3
—
156
9
2,686
2,232
1,822
634
154
62
2,704
13
53
194
—
291
13
127
397
169
5
—
2,220
123
109
303
7,571
5,662
5,438
2012
2011
Exploration
expenses
Total
4,488
1,075
997
Total
98 5,906
14 1,361
23 1,370
4 3,893(1) 2,680(1)
11 5,871
592
3 1,956
77
77
— 11,236
197
4,469
255
1,481
32
8,129
152
—
16
5 2,143
— 3,043
13 7,959
174
—
514
514
— 4,805
1,561
2,937
5,922
212
316
3,878
—
—
123
265
51 2,581
829 54,066
582
574
31
182
2,053
40,850
Total
3,493
837
852
2,902(1)
3,546
182
1,054
52
6,438
61
1,120
3,282
4,154
88
350
2,769
(12)
273
1,747
33,188
(1)
(2)
Include approximately 1,757, 1,307 and 1,826 corresponding to hydrocarbon export withholdings for years ended December 31,
2013, 2012 and 2011, respectively.
Includes 74 corresponding Board of Directors’ members and Statutory Auditor’s fee for all concept. On May 30, 2013 the General
Ordinary and Extraordinary Shareholder’s meeting of YPF decided to approve as honorary in advance for such fee the sum of
approximately 74 for the year 2013.
The expense recognized in the statement of comprehensive income related to research and development activities during the years ended
December 31, 2013, 2012 and 2011 amounted to 83, 58 and 53, respectively.
Other income (expense), net
Environmental remediation and others from YPF Holdings Inc.
Lawsuits and contingencies
Insurance (Note 11.b)
Miscellaneous
2013
(201)
(1,069)
1,956
18
704
2012
(572)
(143)
—
187
(528)
2011
(280)
(72)
135
171
(46)
3. PROVISIONS FOR PENDING LAWSUITS, CLAIMS AND ENVIRONMENTAL LIABILITIES
The Company is 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 against it, result in the imposition of
material costs, fines, judgments or other losses. While the Company 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 Company, could
significantly exceed the recorded provisions.
F-39
As of December 31, 2013, the Company has accrued pending lawsuits, claims and contingencies which are probable and can be
reasonably estimated, amounting to 5,179. The most significant pending lawsuits and contingencies accrued are described in the
following paragraphs.
Additionally, the Company 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.
The most significant pending lawsuits and contingencies provisioned are described in the following paragraphs.
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
F-40
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.
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. 1,410/2010, 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”).
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 and on March 20, 2009, notified YPF the
termination of the contract. 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$ 1,057 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
F-41
in the three proceedings are to be solved in “YPF vs. AESU” arbitration. On April 19 and 24, 2012, AESU and Sulgás 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.
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 Court. 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.
Despite having brought the action above, 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 partial
award, YPF 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 as of the date of these consolidated financial
statements. 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.
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,
F-42
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. 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.
As of December 31, 2013, the Company has provisioned 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.
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. In addition to the aforementioned, the Company has
other 26 judicial 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.
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Other claims and environmental liabilities:
In relation to environmental obligations, and in addition to the hydrocarbon wells abandonment legal obligations for 13,509 as of
December 31, 2013, the Company has provisioned 1,690 corresponding to environmental remediation, which evaluations and/or
remediation works are probable and can also 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 Company 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.
In addition to what has been mentioned in the preceding paragraphs, 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. (“Tierra”), 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 Tierra.
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 the selling date, 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.
The most significant contingencies recorded by the controlled company YPF Holdings Inc. are described in the following paragraphs.
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.
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 Tierra. This project
is in the operation and maintenance phase. YPF Holdings Inc. has provisioned approximately 96 in connection with such activities.
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 Tierra 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 the remedial
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investigation and feasibility study (“RIFS”) being performed and funded by Tierra and a number of other entities of the lower portion
of the Passaic River pursuant to a 2007 administrative settlement agreement (the “2007 AOC”). The parties to the 2007 AOC are
discussing the possibility of further work with the EPA. The entities that have agreed to fund the RIFS have negotiated an interim
allocation of RIFS 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”). As of December 31, 2013, approximately 70 entities, including Tierra, have
agreed to participate in the RIFS in connection with the 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 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 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 semester of 2011, Maxus and Tierra 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. Tierra estimates that the total cost to implement the CSO AOC is
approximately US$ 5 million and will take approximately 2 years to complete.
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 has 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
Tierra 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 Tierra (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 Tierra under the 2004 AOC. Tierra proposed to the other parties that,
for the third stage of the RIFS undertaken in Newark Bay, the costs be allocated on a per capita basis. The parties have not agreed to
Tierra’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 Tierra, 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.
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 Tierra and Occidental, requesting that the group enters into an agreement to conduct
a cooperative
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assessment of natural resources damages in the Passaic River and Newark Bay. In November 2008, Tierra 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, Tierra declined to extend this
agreement.
In June 2008, the EPA, Occidental, and Tierra entered into an AOC (“Removal AOC from 2008”), pursuant to which Tierra (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 (153,000 cubic meters) 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 Tierra 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.
In addition, in June 2007, EPA released a draft Focused Feasibility Study (the “FFS”) that 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, which according to the draft FFS, EPA estimated could cost from US$ 900 million to
US$ 2,300 million and are all described by EPA as involving proven technologies that could be carried out in the near term, without
extensive research. Tierra, in conjunction with the other parties working under the CPG, submitted comments on the legal and
technical defects of the draft FFS to EPA. On September 18, 2012, at a Community Advisory Group (“CAG”) meeting, the EPA
described the alternatives considered in the Focused Feasibility Study (FFS). The EPA stated that the FFS will set forth four
alternatives: (i) no action (cost: US$8.6 million); (ii) deep dredging of 9.6 million cubic yards over 11 years (cost: US$ 1.3 billion to
US$ 3.4 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 over 6 years (cost:
US$ 1 billion to US$ 1.9 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 over 3 years (the alternative proposed by the CPG). The EPA indicated that it had discarded alternative
(iv) and that is currently in favor of alternative (iii). As of the date of these financial statements, the FFS is expected to be released to
the public in the first quarter of 2014. If EPA keeps to the announced schedule, it is anticipated that the final Record of Decision
would be issued between twelve to eighteen months after the FFS had been made public. Based on the information available to the
Company as of the issuance date of these financial statements, considering the potential final proposal, the results of the studies and
discoveries to be produced, the several potential responsible parties involved in the matter, with its consequent potential allocation of
removal costs, and also considering the opinion of external counsels, it is not possible to reasonably estimate a loss or range of losses
on these outstanding matters. Therefore, no amount has been accrued for this matter by YPF Holdings Inc.
According to the AOC 2007, the 17 miles of the Lower Passaic River from its confluence with Newark Bay to Dundee Dam pursuant
to the 2007 AOC will be subject to a Remedial Investigation / Feasibility Study that is anticipated to be completed in 2015, following
which EPA will select a remedy and notice it for public comment.
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, Tierra, Maxus and several companies, besides
Occidental. The DEP seeks remediation of natural resources damaged and punitive damages and other matters. The defendants have
made responsive pleadings and filings. In March 2008, the Court denied motions to dismiss by Occidental, Tierra and Maxus. The
DEP filed its Second Amended Complaint in April 2008. YPF filed a motion to dismiss for lack of personal
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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 Tierra 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 contains the Trial Plan for the case. This Trial Plan divides the case into two phases, each with its own mini-trials. Phase One
will determine liability and Phase Two will determine damages. 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 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 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
Tierra 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, YPF and Maxus, on the other hand to discuss the parties’ respective positions, but
no agreement was reached.
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 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 11, 2012 the Court issued the track VIII order. The track VIII order governs the process by which the Court will
conduct the discovery and trial of the State’s damages against Occidental, Maxus and Tierra (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. Recently, the State and the third party defendants have reported that they
are continuing to make progress towards a settlement, which were not disclosed to third parties.
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 are 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.
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As of December 31, 2013, DEP has not filed with the Court dollar amounts on all its claims, but it has (a) contended that a US$
50 million cap on damages under one of the New Jersey statutes should not be applicable, (b) alleged that it has incurred
approximately US$ 118 million in past “cleanup and removal costs”, (c) is seeking an additional award between US$ 10 and US$
20 million to fund a study to assess natural resource damages, (d) notified Maxus and Tierra’s legal defense team that DEP is
preparing financial models of costs and of other economic impacts and, (e) is seeking reimbursement for external legal fees paid.
During the fourth quarter of 2012 and the first quarter of 2013, YPF, YPF Holdings, Maxus and Tierra 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 Tierra approved in Boards of Directors the authorization to
sign the settlement agreement (the “Agreement”) above mentioned. The proposal of the Agreement, which does not imply
endorsement of facts or rights and that it is presented only with conciliatory purposes, is 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, YPF would make cash payment of US$ 65 million at the time of approval of the
Agreement.
During 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 U$S 65 million in an escrow account. Occidental appealed Judge Lombardi’s decision as the
settlement agreement was approved. The decision has not been resolved yet.
As of December 31, 2013, YPF Holdings has accrued 805 comprising the estimated costs for studies, YPF Holdings Inc.’s best
estimate of the cash flows it could incur in connection with remediation activities considering the studies performed by Tierra, the
estimated costs related to the Removal AOC of 2008 agreement, and in addition certain other matters related to Passaic River and the
Newark Bay, also including certain related legal matters. However, it is possible that other works, including interim remedial
measures or different from those considered, may be ordered. In addition, the development of new information, the imposition of
penalties or remedial actions or the result of negotiations related to the referred matters differing from the scenarios that YPF
Holdings Inc. has evaluated, could result in additional costs to the amount currently accrued.
Passaic River Mile 10.9 Removal Action. In February 2012, the EPA issued to the Cooperating Parties Group (“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 2, 3, 7, 8 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 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. Occidental declined to execute this AOC formalized its resignation
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 US$ 20 million, for the
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completion of such works. 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 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. The deadline for Occidental’s submission of financial assurance has
been extended to March 14, 2014. Based on the information available to the Company as of the issuance date of this report,
considering the results of the studies and discovery process as well as the potential responsibility of the other parties involved in this
matter and the potential allocation of removal costs, based on the advice of our external and internal legal counsel, it is not possible to
reasonably estimate a loss or range of losses related to these outstanding matters. Therefore, no amount has been accrued in respect of
these claims.
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, Tierra 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.
Tierra, 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. Tierra submitted its remedial investigation reports to the DEP in 2001, and the
DEP continues to review the report.
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 Tierra, 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 28 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.
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 Tierra, 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.
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In March 2008, the DEP approved an interim response action plan for work to be performed at the Kearny Plant by Tierra and the
adjacent property by Tierra in conjunction with other parties. As of the date of issuance of these consolidated financial statements,
work on the interim response action has begun. This adjacent property was listed by EPA on the National Priority List in 2007. In
July 2010, 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 parties have agreed to coordinate remedial efforts, forming the “Peninsula
Restoration Group” or “PRG.” In the fourth quarter 2011, the PRG reached an agreement in principle with a new party, whereby
would join the PRG. The PRG is in active negotiations with the EPA for an RIFS AOC for the Standard Chlorine Chemical
Company, which was jointly signed with another three potentially responsible parties during May 2013. On-site work began during
the fourth quarter of 2013, once EPA approved the work plan.
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. 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, 2013, there are approximately 112 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 Tierra’s reports and other
developments.
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 RIFS at the former Painesville’s Plant area. OEPA has
divided the Painesville Work Site into 20 operable units, including operable units related to groundwater. Tierra has agreed to
participate in the RIFS as required by the OEPA. Tierra submitted the remedial investigation report to the OEPA, which was finalized
in 2003. Tierra 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
discussed below (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. As of December 31, 2013, YPF
Holdings Inc. has accrued a total of 116 for its estimated share of the cost to perform the RIFS, 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 RIFS progresses, YPF Holdings Inc. will continuously assess the condition of the
Painesville’s plants works site and make any required changes, including additions, to its provision as may be necessary.
Other Sites. Pursuant to settlement agreements with the Port of Houston Authority and other parties, Tierra 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
F-50
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, 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 through which it is agreed to reimburse
certain costs incurred by the afore mentioned 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, 2013, YPF Holdings Inc. has accrued 23 for its estimated share of remediation activities
associated with Greens Bayou facility.
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 2007, Maxus signed with four other parties potentially involved, an AOC to conduct RIFS about contamination in the soil,
groundwater, as well as in the Kinnickinnic River sediments. Exposure of Maxus at the site appears linked to the period 1966-1973,
although there is some controversy about it.
Preliminary Works in connection with the RIFS of this site commenced in the second half of 2006.
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.
YPF Holdings Inc. has accrued 3 as of December 31, 2013 for its estimated share of the costs of the RIFS. 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.
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 RIFS. The RIFS 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 the fourth quarter of 2013 the PRP Group completed the design and planning
phase, and the remedial actions will take place in 2014. As of December 31, 2013 YPF Holdings has accrued 5 in connection with its
obligations for this matter.
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, 2013, YPF Holdings Inc. has accrued approximately 23 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.
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, 2013, YPF Holdings Inc. has accrued 23 in connection with its
estimate of these obligations.
F-51
Legal Proceedings. 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.
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 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. Tierra 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. This decision will require Maxus to accept responsibility of various matters which it has refused indemnification since 1998
which could result in the incurrence of costs in addition to YPF Holdings Inc.’s current provisions for this matter. Maxus has paid
approximately US$ 17 million to Occidental. In March 2012, Maxus paid to OCC US$ 0.6 million covering OCC’s costs for 2010
and 2011, and in September 2012 Maxus paid to OCC an additional US$ 31 thousand for OCC’s costs for the first semester of 2012.
Maxus anticipates that OCC’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”. 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. Additionally, the remaining claims received and refused
consist primarily of claims of potential personal injury from exposure to vinyl chloride monomer (“VCM”), and other chemicals,
although they are not expected to result in significant liability. However, the declaratory judgment includes liability for claims arising
in the future, if any, related to this matters, which are currently unknown as of the date of issuance of these consolidated financial
statements, and if such claims arise, they could result in additional liabilities for Maxus. As of December 31, 2013, YPF Holdings Inc.
has accrued approximately 2 in respect to these matters.
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. The obligation to pay some future costs is still pending. As of December 31, 2013,
YPF Holdings Inc. has accrued 6 in respect of this matter.
F-52
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. Plaintiff sought US$ 30 million from Maxus and two parties which
was rejected by the defendants. YPF Holdings presently believes that relatively little remediation activity is merited and intends to
vigorously defend the case. Maxus has made appropriate responsive pleadings in the matter, also has requested a change of venue for
the treatment of the matter. On June 2013, Maxus signed an agreement with its plaintiffs, in which Maxus has to make installment
payments over three years, and by which also forced itself to remediate the site. As of December 31, 2013, YPF Holdings Inc. has
accrued approximately 65 in respect to these matters.
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.
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 provisioned based on the best information
available as of the date of the issuance of these financial statements.
4. CAPITAL STOCK
The Company’s subscribed capital as of December 31, 2013, 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, 2013, 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.
Law No. 26,741 enacted on May 4, 2012, changed the 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 the 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.
In relation with the adoption of IFRS, General Resolution No. 576/2010 set that the issuers that, in accordance with previous
Argentine GAAP, had used the option of disclosing in note to the financial statements the deferred income tax liability arisen from the
difference between the book value of fix assets remeasured into constant argentine pesos and their corresponding historical cost used
for fiscal purposes, must recognize such liability with a debit to unappropriated retained earnings. The resolution also established that
this recognition could be recorded in any intermediate period or year until the date of transition to IFRS, inclusive. In addition, the
resolution above mentioned established that, as an exception, the Shareholders’ meeting that would consider the financial statements
of the year in which the deferred tax liability is recognized, could record such debit in unappropriated retained earnings into capital
accounts not represented by shares (subscribed capital) or into retained earnings accounts, not providing a predetermined order for
such accounting.
F-53
YPF recognized in the year ended December 31, 2010 the deferred tax liability arisen from the difference between the book value of
fix assets in constant argentine peso and its corresponding historical value used for fiscal purposes, including the retroactive effects
from such change in accounting criteria.
The General Ordinary Shareholders’ meeting of April 26, 2011, decided the absorption against “Adjustment to contributions”, of the
effect of the mentioned deferred income tax liability registration, as described above, for an amount of 1,180. Also, as consequence of
this absorption, the General Shareholders´ meeting decided the reversal of Legal Reserve for an amount of 236, to adjust its balance
to legal requirements.
On April 30, 2013, a General Ordinary Shareholders’ meeting was held, which has approved the financial statements of YPF for the
year ended December 31, 2012 and additionally decided the following in relation with the distribution of earnings of fiscal year ended
as of December 31, 2012: (i) appropriate to a special reserve 3,648 corresponding to the initial application of IFRS pursuant to
General Resolution No. 609 of the CNV; (ii) 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 financial statements for the year ended December 31,
2012 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; (iii) to appropriate the amount of 2,643 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 (iv) the appropriation to a reserve for future dividends in an amount of 330, empowering the Board of
Directors to determine the opportunity of payment which should not exceed the ending of the present fiscal year. On August 9, 2013,
the Board of Directors decided to pay a dividend of $ 0.83 per share which was available for shareholders on August 28, 2013.
As of December 31, 2013, YPF has purchased 1,232,362 shares issued for an amount of 120 and has settled 479,174 shares to the
beneficiaries of the share-based benefit plan, as mentioned in the above paragraph, retaining 167,986 shares in respect of income tax
related to the settlement of such shares. The cost of such purchases 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. The difference between the acquisition cost of repurchased shares and the accrued value of the settled
shares under the share-based benefit plans have been recorded in the “Share trading premium” account. See Note 1.b.10.iii) and
1.b.17).
5. INVESTMENTS IN COMPANIES AND JOINT VENTURES AND OTHER AGREEMENTS
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, 2013, 2012 and 2011:
Amount of investments in affiliated companies valued using the equity method
Amount of investments valued at cost
Sub-Total participations in affiliated companies and others
Amount of investments in joint ventures valued using the equity method
Sub-Total participations in joint ventures
Provision for reduction in value of holdings in companies
2013
213
14
227
1,909
1,909
(12)
2,124
2012
603
12
615
1,311
1,311
(12)
1,914
2011
637
13
650
1,420
1,420
(57)
2,013
As mentioned in Note 1.b.5 and in Exhibit I, the investments in companies with negative shareholders’ equity are disclosed in
“Account payable” account to the extent the Company has the intention, as of the end of the year, to provide the corresponding
financial support.
F-54
The main changes that affected the amount of the investments previously mentioned, during the years ended on December 31, 2013,
2012 and 2011, are the following:
Amount at the beginning of year
Acquisitions and contributions
Income from investments valued using the equity method
Dividends declared
Translation difference
Other
Amount at the end of year
2013
1,914
153
353
(280)
470
(486)(1)
2,124
2012
2,013
—
114
(388)
167
8
1,914
2011
1,839
2
685
(602)
89
—
2,013
(1) Primarily includes movements generated in relation with the spin-off of Pluspetrol Energy S.A.
Exhibit I.b) provides information of investments in companies.
The following table shows the main magnitudes of income/(expenses) from the investments in companies, calculated according to the
equity method, for the years ended on December 31, 2013, 2012 and 2011 (see Exhibit I). YPF has made adjustments, where
applicable, to the amounts reported by such companies in order to conform the accounting principles used by such companies to those
used by YPF:
Affiliated companies
2012
2013
Joint ventures
2011 2013 2012 2011
Net income
Other comprehensive income
Comprehensive income for the year
63
120
183
14 90 290 100 595
85
5 4 350 162
262 680
19
640
94
Additionally, as mentioned in Note 1.a), the Company participates as of December 31, 2013, in Joint Operations which give to the
Company a percentage contractually established 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 information
available to the Company’s Management. Exhibit II includes a detail of the most significant Joint Operations in which the Company
participates, indicating the nature of its operations.
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.
The assets and liabilities as of December 31, 2013, 2012 and 2011, and expenses for the three years then ended 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
2013
9,472
661
10,133
2,342
1,247
3,589
2012
7,136
551
7,687
1,661
1,048
2,709
2011
5,611
688
6,299
1,249
1,026
2,275
2013
4,647
43
2012
3,858
281
2011
3,239
268
F-55
6. BALANCES AND TRANSACTIONS WITH RELATED PARTIES
The Company enters into operations and transactions with related parties according to general market conditions, which are part of
the normal operation of the Company with respect to their purpose and conditions.
As mentioned in Note 4, on May 3, 2012, Law No. 26,741, was passed by the Argentine Congress, which declared of public utility
and subject to expropriation the 51% of the equity of YPF represented by an equal percentage of Class D shares owned, directly or
indirectly, by Repsol and its controlled or controlling entities, and at the same moment, establishing the temporally occupation of such
shares in the terms of articles 57 and 59 of Law No. 21,499. The information detailed in the tables below shows the balances with
joint ventures and affiliated companies as of December 31, 2013, 2012 and 2011 and transactions with the mentioned parties for the
years ended December 31, 2013, 2012 and 2011. Additionally, the balances and transactions held with the entities within the Repsol
group and PESA’s affiliates are included until the date the conditions required to be considered as related parties were met.
Trade
receivables
2013
Other
receivables
Non
Accounts
payable
Trade
receivables
2012
Other
receivables
Non
Accounts
payable
Trade
receivables
Other
receivables
Accounts
payable Loans
2011
Non
Non
Current
Current
Current
Current Current Current
Current
Current Current Current
Current
Current Current
Joint ventures:
Profertil S.A.
Compañía Mega
23
2 —
S.A. (“Mega”)
489
7 —
79
591
15 —
24 —
34
28
4
66
29
422
6
5
—
—
37
19
27
2 —
122
—
459 — —
18
—
61
512
—
23
34 —
6
62
75
561
23 —
25 —
18
—
158 —
109
5
484
2
89
4
350
8
59 —
291
10
—
— — —
— — —
—
—
76 — —
104 — —
2
—
— — —
45 — —
3 —
— —
— — —
8
—
—
—
6
— — —
4
—
— — —
19
—
—
—
11
— — —
10
—
— — —
1
—
—
—
2
— — —
1
—
— — —
13
— — —
6
— — —
2 —
— — —
12 —
—
484
17
109
20
—
63
—
—
269
—
—
4
—
—
350
15
—
50
— — —
— — —
291
104 —
18
—
48
—
—
—
Trade
receivables
2013
Other
receivables
Current
Current
Non
Current
Accounts
payable
Trade
receivables
2012
Other
receivables
Current Current
Current
Non
Current
2011
Accounts
payable
Trade
receivables
Other
receivables
Accounts
payable
Current
Current
Current
Current Current
Non
Loans
Non
Current
Main
shareholders
and other
related
parties under
their control:
Repsol
Repsol YPF Gas
S.A.
Repsol Sinopec
Brasil S.A.
Repsol
Venezuela
S.A.
Repsol Ecuador
S.A.
— — —
—
—
—
—
— — —
—
—
—
—
— — —
—
—
—
—
—
—
—
—
43 —
123
—
32
13 —
37
—
—
6 —
—
—
— — —
—
— — —
—
—
6 —
— —
— — —
—
—
—
—
—
—
7 —
2
—
Refinería del
Norte S.A.
(“Refinor”)
Affiliated
companies:
Central Dock Sud
S.A.
Pluspetrol
Energy S.A.(1)
Metrogas S.A.(1)
Oleoductos del
Valle S.A.
Terminales
Marítimas
Patagónicas
S.A.
Oleoducto
Trasandino
(Argentina) S.A.
Gasoducto del
Pacífico
(Argentina) S.A.
Oiltanking
Ebytem S.A.
Bizoy S.A.
Repsol
Comercial
S.A.C.
Repsol
Exploración
S.A.
Repsol Bolivia
S.A.
Repsol Tesorería
y Gestión
Financiera
S.A.
Repsol Butano
S.A.
Others
— — —
—
—
—
—
—
—
8 —
—
—
— — —
—
—
—
—
— — —
—
—
—
—
—
—
—
14 —
2
—
—
19 —
—
—
— — —
—
—
—
—
—
— — —
—
538
— — —
— — —
— — —
484
700
41
—
—
—
129
—
—
—
1 — —
1
782
—
350
—
38
—
—
—
112
—
26
58
723
20 —
24 —
160 —
291
185
—
—
60 —
538
224
538
430
F-56
2013
2012
2011
Purchases
and
Services
Interest
and fees
gained Revenues
Purchases
and
Services
Interest and
fees gained
(lossed), net Revenues
Revenues
Purchases
and Services
(recoveries
of expenses),
net
Loans
received
(paid), net
Interest and
fees gained
(lossed), net
132
1,786
561
2,479
179
142
17
—
277 —
325 —
—
76
—
678
119
1,696
495
2,310
70
54
—
61
17
—
—
—
168
102
126
—
1
139
—
—
—
12
—
—
—
—
24
363
60 —
102 —
—
—
17
498
—
—
—
396
—
—
—
8
—
—
—
—
—
—
—
—
—
—
—
—
—
—
78
—
—
—
—
— —
— —
—
—
—
—
—
1
—
—
—
—
—
—
—
—
—
—
—
—
—
—
2,842
—
1
1
1,177
—
—
—
17
—
7
94
2,800
273
166
125
564
33
27
—
51
78
8
36
101
—
334
2
—
1
—
—
—
—
—
366
—
—
—
19
388
1,286
—
—
—
—
81
1,720
447
2,248
3
—
—
—
—
—
—
—
—
3
—
—
—
—
—
—
—
—
(5)
(1)
(3)
—
(1)
(10)
(7)
163
1
80
—
—
—
—
—
—
244
7
—
320
—
—
—
—
—
—
—
—
—
268
595
3,087
460
95
160
715
38
28
—
39
—
—
—
—
—
—
—
—
50
—
4
—
10
72
—
241
—
—
—
—
(4)
—
5
12
—
(7)
(3)
(7)
(24)
—
—
—
—
179
151
1,107
—
—
(403)
—
—
—
—
538
—
(29)
(78)
(23)
5
5
—
—
—
—
12
—
—
—
—
—
—
—
—
12
(19)
—
—
(3)
—
—
—
—
(8)
—
(1)
(7)
(1)
(39)
(27)
Joint ventures:
Profertil S.A.
Mega
Refinor
Affiliated companies:
Central Dock Sud S.A.
Pluspetrol Energy S.A.(1)
Metrogas S.A.(1)
Oleoductos del Valle S.A.
Terminales Marítimas
Patagónicas S.A.
Oleoducto Trasandino
(Argentina) S.A.
Gasoducto del Pacífico
(Argentina) S.A.
Oiltanking Ebytem S.A.
Bizoy S.A.
Main shareholders and
other related parties
under their control:
Repsol
Repsol YPF Transporte y
Trading S.A.
Repsol YPF Gas S.A.
Repsol Netherlands Finance
B.V.
Repsol Venezuela S.A.
Repsol Ecuador S.A.
Repsol Exploración S.A.
Repsol Bolivia S.A.
Repsol Tesorería y Gestión
Financiera S.A.
Repsol Butano S.A.
Nuevo Banco de Entre Ríos
S.A.
Nuevo Banco de Santa Fe
S.A.
Others
(1)
Includes balances and operations until take over or spin-off date (see Note 13).
Additionally, in the normal course of business, and taking into consideration that YPF is the main oil and gas company in Argentina,
its 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
the provision of fuel oil to CAMMESA, which is destined to thermal power plants, and the purchases of energy to the mentioned
company by YPF, and electric energy sales to CAMMESA and fuel oil purchase by YPF Energía Eléctrica (the operations of sale and
purchase for the year ended on December 31, 2013 amounted to 2,930 and 792, respectively, and for the year ended December 31,
2012, amounted to 1,993 and 454, respectively, while the net balance as of December 31, 2013 and 2012 was a receivable of 455 and
96, respectively); the regasification service provided to ENARSA in the regasification projects of GNL in Escobar and Bahía Blanca
and the purchase of natural gas to ENARSA, imported by the mentioned company from Bolivia (the operations for the year ended
December 31, 2013, amounted to 1,015 and 1,107, respectively, and for the year ended December 31, 2012 amounted to 1,371 and
895, respectively, while the net balance as of December 31, 2013 and 2012 was a receivable of 430 and 356, respectively); the
provision of jet fuel to Aerolíneas Argentinas S.A. and Austral Líneas Aéreas Cielos del Sur S.A. (the operations for the year ended
December 31, 2013 and 2012, amounted to 1,495 and 777, while the balance as of December 31, 2013 and 2012 was a receivable of
104 and 61, respectively). The benefits of the incentive scheme for the Additional Injection of natural gas, among others, (see “Gas
agreement” in Note 11.c) with the Department of Federal Planning Investment and Services (the operations for the year ended
December 31, 2013 and 2012, amounted to 4,289 and 82, respectively, while the net balance as of that date was a receivable of 1,787
and 82, respectively) and the compensation for providing gas oil to public transport of passengers at a differential price with the
Argentine Secretariat of Domestic Commerce (the operations for the year ended December 31, 2013, amounted to 2,208, while the
net balance as of that date was a receivable of 116). Such transactions are generally based on medium-term agreements and are
provided according to general market or regulatory conditions, as applicable. Additionally, the Company 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 2.i) of these consolidated 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 occurred in Refinería La Plata in April, 2013 (for further detail see Note 11.b).
F-57
Furthermore, in relation to the investment agreement signed between YPF and Chevron subsidiaries; YPF has a non-controlling interest in
Compañía de Hidrocarburo No Convencional S.R.L (“CHNC”) with which YPF carries out transactions in connection with the above
mentioned investment agreement (for further detail see Note 11.c).
The table below discloses the compensation for the Company’s key management personnel, including members of the Board of Directors and
principal managers (managers with executive functions appointed by the Board of Directors), for the years ended December 31, 2013, 2012 and
2011:
Employee benefits (short-term)
Share-based benefits
Post-retirement benefits
Termination benefits
Other long-term benefits
2013(1)
96
29
3
—
—
128
2012(1)
86
—
2
8
3
99
2011(1)
136
—
3
—
4
143
(1)
Includes the compensation for YPF’s key management personnel which developed their functions during the mentioned years.
7. BENEFIT PLANS AND OTHER OBLIGATIONS
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, 2013.
Defined-benefit obligations
Net 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) losses
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
Benefits paid and settlements
Fair value of assets at the end of the year
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-58
2012
2013
2011
190 152 157
— — —
— — —
157
152
190
2013
152
57
—
3
(6)
(16)
190
2012
157
21
—
5
(18)
(13)
152
2011
147
15
—
6
12
(23)
157
2013
—
16
(16)
—
2012
—
13
(13)
—
2011
—
23
(23)
—
2013
2011
(Loss) Income
2012
— — —
(6)
— — —
(6)
(3)
(3)
(5)
(5)
Amounts recognized in Other Comprehensive Income
Actuarial gains (losses) net
Total recognized in Other Comprehensive Income
Actuarial assumptions
Discount rate
Expected return on assets
Expected increase on salaries
(Loss) Income
2013
6
6
2012
18
18
2011
(12)
(12)
2013
2012
2011
3.25 – 3.9% 2.5 – 3.0% 3.4 – 3.7%
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:
Expected employer’s contributions during 2014
Estimated future benefit payments are as follows:
2014
2015
2016
2017
2018 – 2075
18
18
17
16
15
57
The weighted average duration used in the estimation of future payments was between 6.5 and 7.5.
The Company 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 year ended
December 31, 2013.
For additional information about other existing benefit plans, see Note 1.b.10).
8. OPERATING LEASES
As of December 31, 2013, the principal contracts related to operating leases include:
•
•
•
Leasing of production equipment used in fields and equipment for natural gas compression, whose contracts have an
average duration of 3 years with an option to renew for an additional year and for which contingent payments are
calculated based on a rate per unit of use (pesos per hour/day of use).
Leasing of vessels and barges for the transportation of hydrocarbons, whose contracts have an average duration of 5 years
and for which contingent payments are calculated based on a rate per unit of use (pesos per hour/day of use).
Leasing of land for the installation and operation of service stations, whose contracts have an average duration of
approximately 10 years and for which contingent payments are calculated based on a rate per unit of estimated sales of
fuel.
Expenses recognized for the years ended December 31, 2013, 2012 and 2011, related to operating leases amounted to approximately
3,520, 2,540 and 1,733, respectively, corresponding 1,493, 939 and 714 to minimum payments, and 2,027, 1,601 and 1,019 to
contingent payments, which have been recorded in the “Rental of real estate and equipment” and “Operation Services and other
Service Contracts” accounts.
F-59
As of December 31, 2013, the estimated future payments related to these contracts are:
Estimated future payments
9. EARNINGS PER SHARE
Within 1
year
4,161
From 1 to 5
years
2,881
Over 6
years
158
As of the date of issuance of these financial statements, YPF has not issued equity instruments that give rise to potential ordinary
shares considering the Company’s intention of setting the share based benefit plans through treasury shares purchase. As a result, the
calculation of diluted earnings per share coincides with the basic 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:
Net income
Average number of shares outstanding
Basic and diluted earnings per share (pesos per share)
2013
5,125
2012
3,902
2011
4,445
392,789,433 393,312,793 393,312,793
13.05
9.92
11.30
Basic and diluted earnings per share are calculated as shown in Note 1.b.14.
10. INCOME TAX
The calculation of the income tax expense accrued for the years ended December 31, 2013, 2012 and 2011 is as follows:
Current income tax
Deferred income tax
2013
(2,844)
(6,425)
(9,269)
2012
(2,720)
(1,943)
(4,663)
2011
(2,495)
(646)
(3,141)
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, 2013, 2012 and
2011, 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
Translation differences
Effect of the valuation of inventories measured in functional currency
Income from investments in companies
Non-taxable income—Law No. 19,640 (Tierra del Fuego)
Tax loss carry forwards
Miscellaneous
Income tax expense
2013
14,348
35%
(5,022)
2012
8,565
35%
(2,998)
2011
7,586
35%
(2,655)
(7,186)
4,008
(807)
124
7
(103)
(290)
(9,269)
(2,327)
1,213
(303)
40
25
(172)
(141)
(4,663)
(881)
389
(128)
240
58
(201)
37
(3,141)
The Company did not recognize deferred income tax assets amounting to 978, 2,523 and 2,030 as of December 31, 2013, 2012 and
2011, respectively, from which 559, 441 and 448 corresponds to taxable temporary differences not recoverable and 419, 2,082 and
1,581 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 31, 2013, 395 will expire between the years 2018 and 2031
and 24 have an indefinite carry forward.
F-60
The composition of the Company’s deferred income tax assets and liabilities as of December 31, 2013, 2012 and 2011, is as follows:
Deferred tax assets
Nondeductible provisions and other liabilities
Tax loss and other tax credits
Miscellaneous
Total deferred tax assets
Deferred tax liabilities
Fixed assets
Miscellaneous
Total deferred tax liabilities
Net deferred tax liability
2013
2012
2011
1,723
45
115
1,883
1,055
45
54
1,154
885
45
26
956
(11,659)
(1,649)
(13,308)
(11,425)(1)
(5,125)
(666)
(5,791)
(4,637)
(3,465)
(185)
(3,650)
(2,694)
(1)
Includes (363) arising from the business combination as detailed in Note 13.
As of December 2013, 2012 and 2011, 34, 48 and 30, respectively, had been classified as deferred income tax assets and 11,459,
4,685 and 2,724, respectively, as deferred income tax liabilities arising from the deferred income tax net balance of each individual
company that take part in these consolidated financial statements.
As of December 31, 2013, 2012 and 2011, the causes that generated charges in “Other comprehensive income” did not generate
temporary differences subject to income tax.
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
F-61
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.
Additionally it should be noted that the Company has become aware, however it had not been notified, of two other legal
claims brought by ASSUPA against: i) concessionaires of the areas of Golfo San Jorge Basin, and ii) concessionaires of
areas of Austral basin. The Company, in case of being notified, expects to answer according to legal terms and the
arguments of defence that may correspond to the case.
•
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 3 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.
With respect to claims not consolidated, for the time being, it is not possible to reasonably estimate the monetary outcome,
as long as, if applicable, estimate the corresponding legal fees and expenses that might result. Additionally, YPF believes
that most damages alleged by the plaintiff, if proved, might be attributable to events that occurred prior to YPF’s
privatization and would therefore be the responsibility of the Argentine Government in accordance with the Privatization
Law concerning YPF.
F-62
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, which is described in Note 3—“La Plata and Quilmes
environmental claims”.
•
Other environmental claims in Quilmes: YPF has been notified of a complaint filed by neighbours of Quilmes city,
province of Buenos Aires, claiming approximately 250 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.
•
National Antitrust Protection Board: 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.
•
Users and Consumers’ Association claim: The “Users and Consumers Association” (Unión de Usuarios y Consumidores)
claimed originally against Repsol YPF (then extending its claim to YPF) the reimbursement of the overprice allegedly
charged to bottled LPG consumers between 1993 and 2001. The claim is for an unspecified sum, amounting to 91 in the
period 1993 to 1997 (this sum, brought up-to-date would be approximately 489), together with an undetermined amount for
the period 1997 to 2001. The Company claimed the application of the statute of limitations (as well as other defences)
since, at the date of the extension of the claim, the two-year limit had already elapsed. Notwithstanding, on August 6, 2009,
the evidence production period commenced and the evidence is now being produced.
F-63
•
Repsol S.A. and others complaints:
The Company was notified of a complaint filed by Repsol on July 31, 2012 in the Supreme Court of the State of New
York, New York County, USA, against The Bank of New York Mellon (“BNY”) and the Company. In accordance with the
contents of such complaint, Repsol claims damages for the alleged failure by BNY to accept and carry out voting
instructions provided by Repsol in connection with, among other things, the election of the Company’s Board of Directors
at the Company’s shareholders’ meeting on June 4, 2012, thereby allegedly violating BNY’s contractual obligations.
Repsol alleges that, in addition to the American Depositary Shares (“ADS”) it owns, it had the right to vote ADS owned by
a certain third party that were pledged in Repsol’s favor, and it was unable to exercise such voting rights due to alleged
failures by BNY described above and an allegedly inappropriate intervention by the Company whereby the Company
instructed BNY not to accept Repsol’s voting instructions. On April 29, 2013, YPF filed a motion to dismiss the complaint
and on August 20, 2013 there was a hearing on the matter. It is noted that an initial exchange of witness interrogatories and
documentation (discovery) between Repsol and YPF had begun. On February 6, 2014, YPF became aware that the New
York Supreme Court, in the United States, decided to dismiss all claims, including the claim for damages, submitted by
Repsol against YPF and BONY. Among other matters, it found that Repsol did not demonstrate that YPF: (i) was negligent
or acted in bad faith; (ii) was involved in BONY´s alleged failure to timely transfer voting instructions; and (iii) willfully
interfered in the relationship between Repsol and BONY. Once this decision is final, Repsol will not be able to submit a
further complaint against YPF for the mentioned claims.
Additionally, YPF was notified of three complaints filed by Repsol S.A. in connection with the enforcement of Law
26,741, requesting the invalidation of the Ordinary shareholders’ meetings dated on June 4, 2012, July 17, 2012 and the
Annual General Meeting No. 38 on September 13, 2012, all of which have been answered by YPF. On October 8, 2013,
the tribunal decided to open the case for the submission of evidence, and scheduled a hearing for February 27, 2014. On
November 20, 2013, the Company was notified of a new complaint submitted by Repsol, requesting the nullity of the
Ordinary and Extraordinary Shareholders Meeting dated April 30, 2013 -and its continuation on May 30, 2013- including
the decisions taken therein.
•
YPF class action:
On April 16, 2013, YPF has been served of a class action related to certain YPF share sale transactions undertaken by
Repsol in March 2011, initiated by Monroe County Employees Retirement System, later consolidated with a similar claim
initiated by Felix Portnoy. The claim is based on an alleged failure to inform the market, during the period between
December 22, 2009 and April 16, 2012 (period of the class) and consequently the purchaser parties in such transactions, as
of the date set forth above, regarding the potential risk of expropriation of the Company, and on the alleged effect on the
value of the shares. On July 26, 2013, plaintiffs have notified the parties their intention to amend the complaint for second
time, after its first amendment when Felix Portnoy was included in the Plaintiff class. Both YPF and the Underwriters’
representatives (excluded from the first amendment) have expressed their opposition to such proposed second amendment.
On October 8, 2013, despite the opposition of YPF, the federal district court of New York, granted the Plaintiffs’ request to
file a second amended complaint including new claims under Section 11 of the Securities Act. On October 29, 2013,
Plaintiffs filed a second consolidated amended complaint. On November 26, 2013, YPF submitted a motion to dismiss the
new complaint. On February 20, 2014, the Tribunal dismissed all claims made individually and on behalf of others in
similar scenarios against YPF and other respondents, concluding that claimants did not: (i) identify any omission or
misrepresentation of information by YPF, (ii) allege any facts demonstrating that YPF had the intent to deceive the
investors, (iii) demonstrate that the purported failure to disclose the risk of expropriation caused the alleged damages. The
Tribunal also held that the statute of limitations for the claims raised under the Securities Act of 1933 has lapsed. Once this
decision is final, claimants will not be able to submit a further complaint against YPF for the mentioned claims.
F-64
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
On April 2, 2013, the facilities of the Company 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/d 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. As a consequence, the Company continues with the settlement process of the
incident, with the insurance company.
Based on the documentation provided to the insurance adjuster appointed by reinsurers, and after their analysis, in
November 2013 the Company requested an advanced payment on account of the total compensation that will result from
this process, of approximately US$ 300 million. This advance was accepted and recognized by the reinsurers and,
consequently, was recorded by the Company in the statement of comprehensive income for the year. Of this amount, US$
215 million corresponds to the damage to property and the rest to a partial acknowledgment of lost profits pursuant to the
rights arising from the insurance policy. Consequently, as of December 31, 2013, the Company has recorded a gain of
1,956 disclosed in “Other income (expense), net” account.
The Company is still in the process of claim lost profits, whose coverage extends until January 16, 2015.
c) Contractual commitments, main regulations and others:
•
•
Contractual commitments: The Company 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 Company 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 Company 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 Company is fulfilling the agreed commitments mentioned above. To the
extent that the Company does not comply with such agreements, we could be subject to significant claims, subject to the
defences that the Company might have.
Natural gas regulatory requirements: In addition to the regulations that affect the natural gas market mentioned in “Natural
gas market” (Note 3), 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
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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.
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 8, 2011, ENARGAS published Resolution No. 1,982, which supplements Decree No. 2,067 of
November 27, 2008, which had created a fiduciary fund to finance natural gas and other imports necessary to complement
the natural gas injection required to satisfy the internal demand. This Resolution adjusts the tariff charges established by
Executive Decree No. 2,067/08 and extends the type of users reached by the tariff adjustment, including users in the
residential segment and gas processing and electric generation companies, among others, which has impacted on the
operations of the Company and, very significantly in some companies under joint control, all of which have appealed
against such resolution. In particular, the impact that the application of the tariff charge mentioned has on the operations of
Mega is so significant that, if the situation is not solved in favour of Mega, it could have serious difficulties in the future to
continue its activity.
These consolidated financial statements do not include any adjustments related to the recoverability of the assets of Mega
which could be accrued on the assumption that it would cease its activity. This measure applies to consumptions that were
made since December 1, 2011.
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On November 24, 2011, ENARGAS issued Resolution No. 1,991, which extends the type of users that will be required to
pay tariff charges. YPF has challenged the validity of such resolutions. On April 13, 2012, a preliminary induction was
granted in relation with the processing plant El Portón, suspending the effects of such resolutions with respect to the
mentioned plant.
•
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.
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
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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 judgement 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.
•
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. 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.
•
Other regulatory requirements: During 2005, the Secretariat of Energy by means of Resolution No. 785/2005 modified by
Resolution No. 266/2008 of the Ministry of Federal Planning, Public Investment and Services, created the National
Program of Hydrocarbons
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and its derivatives Warehousing Aerial Tank Loss Control, measure aimed at reducing and correcting environmental
pollution caused by hydrocarbons and its derivatives warehousing-aerial tanks. The Company has begun to develop and
implement a technical and environmental audit plan as required by the resolution.
•
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.
•
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 below).
•
Investment Promotion Regime for the Exploitation of Hydrocarbons—Decree No. 929/2013: the 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.
Companies submitting “Investment Projects for the Exploitation of Hydrocarbons” (the “Project”) with the Commission,
for its approval and inclusion in the Promotion Regime, must hold exploration permits and/or exploitation concessions
granted by the Federal Government and/or the Provinces. If the company does not hold exploration permits and/or
exploitation concessions, it must operate associated with a company that does hold such permit or concession rights, be
duly registered at the “National Register of Hydrocarbons Investments” created by Federal Decree 1,277/2012, have
submitted the “Annual Investment Plan” established by Federal Decree 1,277/2012 and the Project must involve the
performance of a direct investment in foreign currency for an amount not lower than US$ 1 billion, calculated at the time
of submission of the Project and to be invested during the first five years of the Project. The beneficiaries of the Promotion
Regime shall enjoy in terms of Law N° 17,319 the following benefits: (i) from the 5th year of the start-up of their respective
‘Investment Projects for the Exploitation of Hydrocarbons’, the right to freely market abroad the 20% of the oil and gas
produced in their Projects, at 0% export tax rate, (ii) the right to maintain abroad all the foreign currency proceeds of the
aforementioned oil and gas exports, provided that, as a result of the relevant investment project, at least US$ 1 billion are
transferred to the Argentine financial market; (iii) in periods in which domestic production of hydrocarbons is insufficient
to cover domestic needs, the beneficiaries shall, from the 5th year of the start-up of their respective projects, be entitled to
obtain, in relation to the 20% of oil and gas production that cannot be exported, a price not lower than the reference export
price.
Additionally, the Decree creates the figure of the “Concession for the Unconventional Exploitation of Hydrocarbons”,
which involves the extraction of liquid and/or gaseous hydrocarbon by unconventional stimulation techniques applied in
fields located in geological formations of shale or slate rocks (shale gas or shale oil), tight
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sands (tight sands, tight gas, tight oil), coal seams (coal bed methane) and/or characterized, in general, by the presence of
low-permeability rocks. The Decree recognizes that, in accordance with the provisions of Law No. 17,319, the companies
that holds exploration and/or exploitation concessions, which were included in the Promotional Regime, will have the right
to request a “Concession for the Unconventional Exploitation of Hydrocarbons”. Also the holders of a “Concession for the
Unconventional Exploitation of Hydrocarbons”, may request the consolidation of an adjacent area held by the same title
holders as a single “Concession for the Unconventional Exploitation” insofar they can establish the geological continuity
of the adjacent areas.
•
Natural Gas Agreement: 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 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$/MBTU for all gas injected above certain threshold (Additional Injection).
The Projects shall comply with minimum requirements established in Resolution 1/2013, and will be subject to approval
consideration by the Commission. The Projects have a maximum term of five (5) years, renewable at the request of the
beneficiary, and subject to the decision of the Commission. If the beneficiary company, for certain month, does not reach
the compromised production increase of its project, approved by the Commission, it will have to compensate its failure to
achieve the minimum total injection committed in such Project.
•
CNV new regulatory framework: Through Resolution No. 622/2013, dated September 5, 2013, the CNV approved the
Resolutions (N.T. 2013) applicable to the companies subject to its oversight, pursuant to the Capital Market Law
No. 26,831, and regulatory Decree No. 1,023, dated August 1, 2013. Such Resolution abrogates CNVs’ prior regulations
(N.T. 2001 and amendments) and the general Resolutions No. 615/2013 and No. 621/2013, as from the effectiveness of
Resolutions (N.T. 2013).
•
Agreements of extension of concessions
•
Province of Neuquén: On December 28, 2000, through Decree No. 1,252/2000, the Argentine Federal Executive
Branch (the “Federal Executive”) extended for an additional term of 10 years (until November 2027) the concession
for the exploitation of Loma La Lata – Sierra Barrosa area granted to YPF. The extension was granted under the
terms and conditions of the Extension Agreement executed between the Argentine Government, the Province of
Neuquén and YPF on December 5, 2000. Under this agreement, YPF paid US$ 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;
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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 of 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 N° 2867.
•
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, 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” in order to fund the purchase of
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.
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•
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 JV 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-72
•
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 and Los Chorrillos until 2027 and 2026, respectively. As of the date of
issuance of these consolidated financial statements, the abovementioned agreement is pending approval by the
Legislative from Tierra del Fuego province.
•
Agreements of project investments
•
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 area. This first pilot project includes the drilling of
more than 100 wells.
Altogether with what has already been invested by the Company in the area, this new investments will result in a
total investment of US$ 1,500 million in the pilot project, where 15 drilling rigs are currently operating and more
than 10,000 barrels of oil equivalent per day are being extracted.
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, 2013.
In addition to the abovementioned assignment (the net credit for the assignment in favor of YPF as of December 31,
2013, amounts to 1,616), during December 2013, YPF and CHNC have made transactions, among which it is
possible to highlight the net purchases of gas and crude oil by YPF for 50. These transactions were completed under
the general and regulatory market conditions. 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.
F-73
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.
In addition to what has already been invested by YPF in the area and once the agreed amount has been completed
and the pilot project has been closed, both companies estimate that, subject to compliance with certain conditions,
they will continue with the total development of the LC Area, sharing investments at 50% each.
•
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, of which Dow will provide up to 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.
If Dow exercises the conversion option, YPF would contribute 50% of its participation in the “El Orejano” area,
which comprises a total area of 45 km2 (11,090 acres) in the Province of Neuquén and a 50% interest in a joint
venture to be formed for the exploitation of this area. If Dow does not exercise the option, the parties have agreed on
the repayment conditions of the financing agreement, over a term of five years.
As of December 31, 2013 the Company has received the first payment of the aforementioned transaction, amounting
US$ 30 million, which has been recorded within “Noncurrent Loans” in the Company’s Balance Sheet.
•
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 (which shall be completed in a 12-month term), 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.
Moreover, the Company shall make an additional equal investment for the drilling of 17 more wells, from which it
will be entitled to 100% of the production.
Once the first investment stage has concluded, Petrolera Pampa may choose to continue during the second
investment stage (to be completed in a 12-month term), which envisages an investment of US$ 70 million for the
drilling of 15 wells.
Once the two stages have been completed, the Parties may make the necessary investments for the future
development of the Area, in accordance with their respective interest (50% each).
•
Principal rules applicable to MetroGAS activities: 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. Under the License, MetroGAS is entitled to render the public service of gas distribution for a term of 35 years
(for which MetroGAS may require—upon expiration—its extension for an additional 10-year term, subject to ENARGAS
evaluation and approval).
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.
F-74
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. The Public Emergency Law enacted in 2002 decreed the suspension of the periodical revision of
the tariff regime established in the License.
MetroGAS management is currently under a renegotiation process with the National Government to adapt certain terms of
the License in order to counteract the economic and financial situation that affects at company. As of the date of issuance
of these financial statements it is neither possible to predict the outcome of the aforementioned process of renegotiation nor
the effect it will have on MetroGAS’s economic and financial situation.
•
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 Interconexión”, “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:
•
•
•
SE Resolution No. 146/2002: 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. 406/2004: 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.
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
F-75
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. 220/2006, 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.
•
The Company is committed with third parties under commercial contracts to purchase services and goods (such as LPG,
electricity, gas, oil and steam), which as of December 31, 2013 amounted to 14,008. Additionally, there are commitments
to carry out exploration activities and to make certain investments and expenditures until the expiration of some of the
Company’s concessions that amounted to 101,189 as of December 31, 2013, which includes the commitments for
concessions extensions mentioned in the paragraphs above.
12. CONSOLIDATED BUSINESS SEGMENT INFORMATION
The different segments in which the Company is organized have in consideration the different activities from which the Company
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 Company’s business strategy.
The company has recently organized its reporting structure grouping the “Chemical” and “Refining and Marketing” segments in a
new and unique segment named “Downstream”. The structure above mentioned is mainly due to the common and/or shared strategy,
to both businesses converge, considering the synergies generated between them, from fuel maximization approach offered to the
market, in terms of volume and quality. Accordingly, the Company has adequate comparative information for the years 2012 and
2011 according to the aforementioned change.
In this line, the new reporting segment structure, taking into account the criteria established by IFRS 8, is as follows: the exploration
and production, 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 (“Exploration and Production”); the refining, transport, purchase of
crude oil and natural gas to third parties and intersegment sales, and marketing of crude oil, natural gas, refined products,
petrochemicals, electric power generation and natural gas distribution (“Downstream”); and other activities, not falling into these
categories, are classified under “Corporate and Other”, principally including corporate administrative expenses and assets,
construction activities and the environmental remediation according to the controlled company YPF Holdings (see Note 3).
F-76
Sales between business segments were made at internal transfer prices established by the Company, which generally seek to approximate to market
prices.
Operating income (loss) and assets for each segment have been determined after intersegment adjustments.
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(2)
Acquisitions of fixed assets(2)
Assets
For the year ended December 31, 2012
Revenues from sales
Revenues from intersegment sales
Revenues
Operating income (loss)
Income (loss) on investments in companies
Depreciation of fixed assets
Acquisitions of fixed assets
Assets
For the year ended December 31, 2011
Revenues from sales
Revenues from intersegment sales
Revenues
Operating income (loss)
Income on investments in companies
Depreciation of fixed assets
Acquisitions of fixed assets
Assets
Exploration
and Production
Downstream
Corporate
and Other
Consolidation
Adjustments
3,851
38,846
42,697
6,324
(93)
9,591
28,849
70,775
1,135
30,179
31,314
5,730
—
6,878
11,835
41,980
269
23,401
23,670
4,067
—
5,465
9,554
31,729
85,624
1,147
86,771
6,721
446
1,452
4,903
51,336
65,047
1,069
66,116
4,095
114
1,065
4,232
30,901
54,636
848
55,484
5,466
685
820
4,032
27,233
638
2,285
2,923
(1,522)
—
193
453
15,161
992
1,243
2,235
(2,492)
—
186
142
8,031
1,306
651
1,957
(1,714)
—
153
231
3,534
—
(42,278)(1)
(42,278)
(363)
—
—
—
(1,677)
—
(32,491)(1)
(32,491)
570
—
—
—
(963)
—
(24,900)(1)
(24,900)
(631)
—
—
—
(1,506)
Total
90,113
—
90,113
11,160
353
11,236
34,205
135,595
67,174
—
67,174
7,903
114
8,129
16,209
79,949
56,211
—
56,211
7,188
685
6,438
13,817
60,990
(1) Correspond to the elimination of income between segments of the group YPF.
(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 13).
The distribution of revenues by geographic area, according to the markets for which they are intended, for the years ended on December 31, 2013,
2012 and 2011, and fixed assets by geographic area as of December 31, 2013, 2012 and 2011 are as follows:
Argentina
Mercosur and associated parties
Rest of América
Europe
Total
Revenues
Fixed assets
2012
2013
2012
2013
2011
2011
78,070 59,428 48,244 93,255 56,779 43,311
21
6,461 3,894 3,985
4,022 2,812 2,028
190
1,560 1,040 1,954 — — —
90,113 67,174 56,211 93,496 56,971 43,522
20
221
24
168
As of December 31, 2013 no external client represents 10% or more of the Company’s revenue from its ordinary activities.
13. BUSINESS COMBINATIONS
– GASA
As mentioned in Note 1.a), 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.
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.
F-77
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 Company 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), the Company controls 100% of GASA.
As described in Resolution 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.
Name and description
of the acquired entity:
The acquisition date,
the percentage acquired
and primary reasons for
the acquisition:
The acquisition-date fair
value of the total
consideration transferred
and the acquisition-date
fair value of each main
asset:
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),
which have been incorporated into the Company’s balance sheet as of the acquisition date:
Cash and 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.
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 under
“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
GASA since the
acquisition date included
in the financial statements
of the Company for the
year:
Revenues
Cost of sales
Gross profit
Other operating expenses
Operating income
Financial income (expense), net
Income tax
Net loss for the year
F-78
1,363
(1,044)
319
(266)
53
(326)
139
(134)
Income and expenses from
ordinary activities of GASA
since the beginning of the
current year and until
December 31, 2013:
Revenues
Cost of sales
Gross profit
Other operating expenses
Operating income
Financial income (expense), net
Income tax
Net income for the year
1,848
(1,425)
423
(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 (see Note 2.i) for a total
amount of 1,141.
Revenues and net incomes of the Company considering the present business combination since the beginning of the current year
would have been 90,581 and 5,710, respectively.
– YPF Energía Eléctrica S.A.
On June 4, 2013, the Company, Pluspetrol Resources Corporation BV (“PPRC”) and Pluspetrol Energy SA (“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 SA was created
(spun off company), on which the Company directly or indirectly holds 100% interest and the Company withdrew its
participation in PPE.
As a result of the spin off, YPF Energía Eléctrica SA 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 SA. On July 31, 2013, the Company 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
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:
Fair value of the
consideration
transferred and fair value
of the main assets of the
acquisition:
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 the Company 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 under the “Income on investments in companies” account in
the comprehensive income statement of the Company for the year ended December 31, 2013.
F-79
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:
Revenues
Cost of sales
Gross profit
Other operating expenses
Operating income
Financial income (expense), net
Income tax
Net income for the year
266
(162)
104
8
112
(16)
(28)
68
Given the nature of the spin-off process through which the above mentioned business was acquired, is not possible to calculate the
effect that would have had over revenues and net income if the business combination was considered since the beginning of the year.
14. SUBSEQUENT EVENTS
•
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. YPF will own 100% interest in the Area, and will become the operator. Puesto Hernández currently produces
over 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 investment plans to optimize the
Area’s production potential until 2027. The Company estimates that the amount paid for the business combination will be
mainly classified as fixed assets.
•
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 Company expects that such
consideration will be accounted for mainly as fixed assets.
•
On February 12, 2014, YPF S.A. and its subsidiary YPF Europe B.V. (constituted in January, 2014) accepted an offer
made by Apache Overseas lnc. and Apache International Finance II S.a.r.I. (“Apache”) for the acquisition of 100% of
Apache’s interest in foreign companies that control certain Argentine companies which are the owners of assets located in
the Argentine Republic, and the acquisition of certain intercompany loans owed by the aforementioned Argentine
companies.
Pursuant to this transaction, YPF takes control of all the assets of the Apache Group in Argentina and, together with YPF
Europe B.V., of certain intercompany loans. The price for the transaction, as agreed upon by the parties, is US$
800 million plus working capital and minus adjustments that may be produced at the contract closing date due to activities
outside the ordinary course of business. The payment will be made with an initial deposit of US$ 50 million, which was
made on February 12, 2014, and the settlement of the remaining balance within the next 30 days, and from that moment the
Company takes control of the mentioned companies. The primary assets included in this transaction, located in the
provinces of Neuquén, Tierra del Fuego and Río Negro, produce a total of 46,800 oil equivalents barrels per day, and have
an important infrastructure of pipelines and facilities, employing around 350 employees. In addition, certain assets have
potential for exploration and development in the Vaca Muerta formation.
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As result of the previously described transaction, YPF acquires the following corporate shares: (i) 100% of the capital
stock of Apache Canada Argentina Investment S.a.r.I. and 100% of the capital stock of Apache Canada Argentina
Holdings S.a.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.
On March 12, 2014, YPF completed the acquisition of the mentioned companies and the assignment of certain
intercompany loans owed by the Argentine companies -which are the owners of the assets located in the Republic of
Argentina- in favor of YPF and YPF Europe B. V., through the payment of the outstanding amount to complete the agreed
price of US$ 786 million. Following the completion of the acquisition, and within a 60-days period, the sellers will prepare
and deliver to YPF and YPF Europe B.V. the final completion statements in order to be accepted or not by the latters
within a 90-days period, requiring any price adjustment, if any.
As of the issuance date of these financial statements, given the recentness of the acquisition, the accounting of the business
combination is incomplete, consequently the Company is unable neither to disclose information about the fair value of the
net assets acquired and other disclosures required by IFRS 3, nor to state if any goodwill or result will arise from the
mentioned acquisition.
Additionally, on February 12, 2014, YPF 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.a.r.I.), 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 approval
from the corresponding regulatory agencies of this transaction is pending.
•
•
As of the date of the issuance of these consolidated financial statements, the Company was in the process of the issuance of
the Negotiable Obligations Class XXIX for an amount of 500, which will accrue variable interest and maturing between
2018 and 2020; the Negotiable Obligations Class XXX for an amount of 500, which will accrue variable interest and
maturing on 2015, and of voluntary exchange of Negotiable Obligations which accrue 10% interest and maturing on 2028
for Additional Negotiable Obligations Class XXVI for a face value up to U$S 100 million.
Law No. 26,741 of Hydrocarbon Sovereignty, declared of public utility and subject to expropriation the 51% of the shares
of YPF, owned directly or indirectly by Repsol S.A., its main shareholders and its subsidiaries. Further, the mentioned law
established the temporary occupation of the shares reached by it, following the procedures set forth in Law No. 21,499. On
February 25, 2014, the Government of the Argentine Republic and Repsol S.A. (“Repsol”) achieved an agreement (here in
after, the “Agreement”) in relation to the expropriation compensation of 200,589,525 YPFs Class “D” shares in conformity
with Law No. 26,741, under the framework of Law No. 21,499 of Expropriation. In conformity with such law the Ministry
of the Economy and Finance of the Nation signed the document whereby Repsol agrees to accept a payment of US$
5,000 million in sovereign bonds as compensation for the expropriation. The Agreement involves the withdrawal of
judicial and arbitral claims filed by Repsol – including the ones against YPF – and a waiver for further claims. The
enforcement of the Agreement is subject to the ratification of the General Shareholders’ Meeting of Repsol and of the
Argentine Congress. On February 27, 2014, the Argentine Republic and Repsol signed the Agreement.
Additionally, on February 27, 2014, YPF and Repsol executed an arrangement (the “Arrangement”) whereby, mainly, the
parties reciprocally withdraw, subject to certain exclusions, all present and future actions and/or claims based on causes
occurring prior to the Arrangement derived from the declaration of public interest and subjection to expropriation of the
YPF’s shares, owned by Repsol, pursuant to Law No. 26,741, the intervention, temporary takeover of public utility
declared shares and management of YPF.
F-81
Likewise, the parties have 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 subject to certain conditions.
The Arrangement will be enforced on the day following to the date on which Repsol notifies YPF that the Agreement
signed between Repsol and the Government of the Argentine Republic has been enforced. If such enforcement does not
occur on or prior May 7, 2014, or at a later date as the parties may agree in writing, the Arrangement shall not be enforced
and shall remain void, and the parties shall retain all of the rights preexisting at the date of their signature, and the
Arrangement shall not create any liability for either party.
•
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 6 tanks, 4 of which are for
processing and 2 are for dispatch of treated crude oil, concentrates the production of 10 fields in the Malargue area, which
constitutes a daily production of approximately 9,200 barrels of oil and represents 3.8% of the oil production of YPF. As of
the date of these financial statements, the fire has been completely extinguished and maintenance works have commenced
to reinitiate operations of the surrounding facilities, which had been preventatively shut down due to the risk of being
affected, and to work on reestablishing production. The technical personnel of the Company are currently defining the plan
for the total resumption of activities in the coming days. In addition the Company is in the process of gathering the
necessary information to make a claim under our existing insurance coverage.
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 Company as of December 31, 2013, which were not already considered in
such consolidated financial statements according to IFRS.
The consolidated financial statements as of December 31, 2013, presented for regulatory purposes before the CNV, have been
approved by the Board of Directors’ meeting and authorized to be issued on March 7, 2014, and will be considered by the next annual
Shareholders’ meeting. These consolidated financial statements, which comprise those presented before the CNV on March 7, 2014,
plus an update of Note 14 – “Subsequent events” and the inclusion of Note 15 – “Supplemental information on oil and gas activities”,
have been approved by Management on March 27, 2014.
15. 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, 2013, 2012 and 2011 was calculated in accordance with the SEC rules and
FASB’s ASC 932 as amended. Accordingly, crude oil prices used to determine reserves were calculated considered the
underweighted average price of the first-day-of-the-month price for each month within the twelve-month period ended December 31,
2013, 2012 and 2011, respectively, for crude oils of different quality produced by the Company. The Company considered the
realized prices for crude oil in the domestic market taking into
F-82
account the effect of exports taxes as were enforced by the enacted laws as of each of the corresponding years (until 2016 in
accordance with Law No. 26,732). For the years beyond the mentioned periods, the Company considered the underweighted average
price of the first-day-of-the-month price for each month within the twelve-month period ended December 31, 2013, 2012 and 2011,
respectively, which refers to the WTI prices adjusted by each different quality produced by the Company. 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.
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 crude oil and natural gas liquids.
Technology used in establishing proved reserves additions in 2013
YPF’s estimated proved reserves as of December 31, 2013, 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, surface geological 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.
Changes in YPF’s Estimated Net Proved Reserves
The table below sets forth information regarding changes in YPF’s net proved reserves during 2013, 2012 and 2011, by hydrocarbon
product.
Crude oil, condensate and natural gas
liquids
Worldwide Argentina
Other
foreign Worldwide Argentina
Other
foreign
(Millions of barrels)
Worldwide Argentina
Other
foreign
2013
2012
2011
Consolidated entities
At January 1,
Developed
Undeveloped
Revisions of previous estimates (1)
Extensions and discoveries
Improved recovery
Purchase of minerals in place (2)
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 (1)
Extensions and discoveries
Improved recovery
Purchase of minerals in place
590
453
137
105
29
11
2
(7)
(102)
628
477
151
1
(*)
(*)
(*)
589
453
136
105
29 —
11 —
2 —
(7) —
(*)
(102)
1
627
476
1
151 —
1
1
1 —
1 —
— — —
— — —
— — —
— — —
— — —
584
437
147
82
18
6
—
—
(100)
590
453
137
1
1
—
—
—
—
—
1
583
436
1
147 —
81
1
18 —
6 —
— —
— —
(99)
589
453
136
(1)
1
(*)
(*)
1 —
1 —
— —
— —
— —
— —
— —
1
530
531
403
1
404
127 —
127
90
1
91
43 —
43
19
19 —
— — —
— — —
(1)
(100)
(99)
1
584
583
436
437
1
147 —
147
1
1
1 —
1 —
— — —
— — —
— — —
— — —
— — —
Sale of minerals in place (2)
Production for the year
At December 31,
Developed
Undeveloped
(1) —
(1)
(*)
(*) —
— — —
— — —
— — —
—
—
1
1
—
— —
— —
1 —
1 —
— —
— — —
— — —
1 —
1 —
— — —
1
1
F-83
Crude oil, condensate and natural gas
liquids
Worldwide
Argentina
Other
foreign
Worldwide
Argentina
(Millions of barrels)
Other
foreign Worldwide Argentina
Other
foreign
2013
2012
2011
Consolidated and Equity-
accounted entities
At January 1,
Developed
Undeveloped
Total
At December 31,
Developed (5)
Undeveloped (6)
Total (7)
454
137
591
477
151
628
454
136
590
(*)
(*)
1
1
476
151 —
1
627
438
147
585
454
137
591
1
437
147 —
1
584
454 —
136 —
1
590
405
127
532
438
147
585
1
404
127 —
1
531
1
437
147 —
1
584
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) Approximately 1 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.
(3) Oil production for the years 2013, 2012 and 2011 includes an estimated approximately 15, 13 and 12 mmbbl, respectively, of
crude oil, condensate and natural gas liquids 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, condensate and natural gas liquids
in respect of royalty payment which are a financial obligation, or are substantially equivalent to a production or similar tax, is
not material.
(4) Proved oil reserves of consolidated entities as of December 31, 2013, 2012 and 2011 include an estimated approximately 93, 85
and 76, and, respectively, of crude oil, condensate and natural gas liquids in respect of royalty payments which, as described
above, are a financial obligation, or are substantially equivalent to a production or similar tax. 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, is not material.
Includes natural gas liquids of 55, 56 and 58 as of December 31, 2013, 2012 and 2011, respectively.
Includes natural gas liquids of 21, 13 and 14 as of December 31, 2013, 2012 and 2011, respectively.
Includes natural gas liquids of 76, 70 and 74 as of December 31, 2013, 2012 and 2011, respectively.
(5)
(6)
(7)
Natural gas
Worldwide Argentina
Other
foreign Worldwide Argentina
Other
foreign
(Billions of standard cubic feet)
Worldwide
Argentina
Other
foreign
2013
2012
2011
Consolidated entities
At January 1,
Developed
Undeveloped
Revisions of previous estimates (1)
Extensions and discoveries
Improved recovery
Purchase of minerals in place (2)
Sale of minerals in place
Production for the year (3)
At December 31,
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 (2)
2,186 2,183
1,810 1,807
376
565
179
2
73
(10)
(436)
(437)
2,558 2,555
1,938 1,935
3
3
376 —
1
564
179 —
2 —
73 —
(10) —
(1)
3
3
620 —
620
36 —
36
36 —
36
— — —
— — —
— — —
— — —
— — —
(31) —
(31)
2,362
1,760
602
220
31
4
—
—
(432)
2,186
1,810
376
38
38
—
8
—
—
—
—
2,360
1,758
602
219
2
2
(*)
1
31 —
4 —
— —
— —
(1)
(431)
3
2,183
3
1,807
376 —
38 —
38 —
— —
8 —
— —
— —
— —
— —
2,533 2,531
1,948 1,946
2
2
585 —
585
1
165
166
104
104 —
— — —
— — —
— — —
(1)
(440)
(441)
2
2,362 2,360
2
1,760 1,758
(*)
602
602
1
48 —
48
48
48 —
— — —
1 —
— — —
— — —
— — —
— — —
Production for the year (3)
At December 31,
Developed
Undeveloped
(5)
(5) —
— — —
— — —
— — —
(10)
36
36
—
(10) —
36 —
36 —
— —
(12) —
(12)
38 —
38
38
38 —
— — —
F-84
Natural gas
Consolidated and Equity-accounted
2013
2012
2011
Worldwide Argentina
Other
foreign Worldwide Argentina
Other
foreign Worldwide Argentina
Other
foreign
(Billions of standard cubic feet)
entities
At January 1,
Developed
Undeveloped
Total
At December 31,
Developed
Undeveloped
Total (4)
1,846 1,844
2
376
376 —
2,222 2,220
2
1,797
602
2,399
1,795
2
602 —
2
2,397
1,996 1,994
585
2
585 —
2
2,581 2,579
1,938 1,935
620
3
620 —
3
2,558 2,555
1,846
376
2,222
1,844
2
376 —
2
2,220
1,797 1,795
602
2
602 —
2
2,399 2,397
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) Approximately 31 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.
(3) Natural gas production for the years 2013, 2012 and 2011 includes an estimated approximately 47, 48 and 48 bcf, respectively, of natural
(4)
gas 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.
Proved natural gas reserves of consolidated entities as of December 31, 2013, 2012 and 2011 include an estimated approximately 285, 252
and 254, respectively, of natural gas in respect of royalty payments which, as described above, are a financial obligation, or are
substantially equivalent to a production or similar tax. 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, is not material.
2013
2012
2011
Oil equivalent (1)
Consolidated entities
At January 1,
Developed
Undeveloped
Revisions of previous estimates (2)
Extensions and discoveries
Improved recovery
Purchase of minerals in place (3)
Sale of minerals in place
Production for the year (4)
At December 31, (5)
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 (3)
Production for the year (4)
At December 31, (5)
Developed
Undeveloped
Worldwide Argentina
Other
foreign
Worldwide
(Millions of barrels of oil-equivalent)
Argentina
Other
foreign Worldwide Argentina
Other
foreign
979
776
203
206
61
11
15
(9)
(180)
1,083
822
261
1
978
775
1
203 —
205
1
61 —
11
—
15 —
(9) —
(*)
(179)
1
1,082
821
1
261 —
8
8
—
—
—
—
—
(7)
(1)
—
—
—
8 —
8 —
— —
— —
—
—
— —
—
—
(7) —
(1) —
— —
— —
—
—
F-85
1,005
751
254
121
24
7
—
—
(178)
979
776
203
8
8
—
2
—
—
—
—
(2)
8
8
—
7
1
1,004
750
1
254 —
1
120
24 —
—
— —
— —
(1)
(177)
1
978
775
1
203 —
—
—
8 —
8 —
— —
2 —
—
— —
—
— —
(2) —
8 —
8 —
—
—
982
751
231
121
62
18
—
—
(178)
1,005
751
254
1
981
750
1
231 —
1
120
62 —
—
18
— —
— —
(1)
(177)
1
1,004
750
1
254 —
10
10
—
1
—
—
—
—
(3)
8
8
—
10 —
10 —
— —
1 —
—
—
— —
—
—
— —
(3) —
8 —
8 —
—
—
Oil equivalent (1)
Consolidated and Equity-
accounted entities
At January 1,
Developed
Undeveloped
Total
At December 31,
Developed
Undeveloped
Total (5)
2013
2012
2011
Worldwide Argentina
Other
foreign Worldwide
Argentina
Other
foreign Worldwide Argentina
Other
foreign
(Millions of barrels of oil-equivalent)
783
203
987
1
782
203 —
1
986
759
254
1
758
254 —
1
1,013 1,012
822
261
1
821
261 —
1,083 1,082
1
783
203
987
1
782
203 —
1
986
761
231
992
759
254
1
760
231 —
1
991
1
758
254 —
1
1,013 1,012
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 oil and natural gas reserves are considered
prospectively in the calculation of depreciation.
(3) Approximately 6.5 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.
(4) Barrel of oil-equivalent production of consolidated entities for the years 2013, 2012 and 2011 includes an estimated approximately
23, 22 and 21, respectively, of oil and natural gas in respect of royalty payments which, as described above, are a financial
obligation, or are substantially equivalent to a production or similar tax. Oil and natural gas 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, is not
material.
(5) Proved oil-equivalent reserves of consolidated entities as of December 31, 2013, 2012 and 2011 include an estimated approximately
144, 130 and 121, respectively, of oil and natural gas in respect of royalty payments which, as described above, are a financial
obligation, or are substantially equivalent to a production or similar tax. Oil and 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.
The paragraphs below explain in further detail the most significant changes in our reserves during 2013.
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 million barrels (“mmbbl”) of crude oil, condensate, and
natural gas liquids, and 564 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 Chubut Province.
Because of this, approximately 43 mmbbl of oil proved reserves and 15 bcf of proved 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 oil and 150 bcf of 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 gas proved developed reserves were added in Loma La Lata Central, in the
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 oil
and 8.2 bcf of 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.
F-86
•
•
•
•
In the Rincón del Mangrullo field approximately 6 mmbbl of liquids proved reserves, and 74 bcf of mainly proved
undeveloped gas reserves were added because of additional drilling activity planned for 2014.
The Chihuido de la Sierra Negra field added approximately 7 mmbbl of oil and 3 bcf of 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 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 in 6 mmbbl of liquids and 4 bcf of gas mainly in the Barranca Baya, Loma La Lata Norte, Loma Campana, Cerro
Fortunoso, and Vizcacheras fields.
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
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 reserves and resources 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 mainly oil proved reserves.
Also in the Golfo San Jorge Basin, 37 new extension wells drilled in the Barranca Baya Field added 2.6 mmboe of mainly
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 behaviour 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%.
F-87
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.
Capitalized costs
The following tables set forth capitalized costs, along with the related accumulated depreciation and allowances as of December 31,
2013, 2012 and 2011:
Consolidated capitalized costs
Proved oil and gas properties
Mineral property, wells and
related equipment
Support equipment and
facilities
Drilling and work in progress
Unproved oil and gas
properties
Total capitalized costs
Accumulated depreciation and
Argentina
2013
Other
foreign Worldwide
Argentina
2012
Other
foreign Worldwide Argentina
2011
Other
foreign
Worldwide
177,058
1,869 178,927 119,579
1,291
120,870 97,820 1,082
98,902
7,601
8,998
—
—
7,601
8,998
5,437
5,739
—
—
5,437 3,569 —
5,739 3,176 —
3,569
3,176
4,577
198,234
83
3,833
4,660
1,952 200,186 134,588
78
1,369
3,911 2,729
2,807
135,957 107,294 1,160 108,454
78
valuation allowances
Net capitalized costs
(133,558)
64,676
(1,676) (135,234)
276 64,952
(93,316)
41,272
(1,142)
227
(94,458) (75,312) (909)
41,499 31,982 251
(76,221)
32,233
Argentina
2013
Other
foreign Worldwide Argentina
2012
Other
foreign
Worldwide Argentina
2011
Other
foreign
Worldwide
—
—
—
278
—
278
274 —
—
—
—
—
—
—
—
—
— —
—
—
—
—
—
—
—
—
—
—
—
278
—
—
—
—
— — —
— — —
— — —
274 —
278
(212) —
—
66
(212)
66
(193) —
81 —
(193)
81
274
—
—
—
274
Company’s share in equity method
investees’ capitalized costs
Proved oil and gas properties
Mineral property, wells and
related equipment
Support equipment and
facilities
Drilling and work in progress
Unproved oil and gas
properties
Total capitalized costs
Accumulated depreciation and
valuation allowances
Net capitalized costs
Costs incurred
The following tables set forth the costs incurred for oil and gas producing activities during the years ended December 31, 2013, 2012
and 2011:
Consolidated costs incurred
Acquisition of unproved properties
Acquisition of proved properties
Exploration costs
Development costs
Total costs incurred
Argentina
Argentina
— —
78 —
1,683
57
15 26,175
72 27,936 10,717
— — —
78 — —
1,644 237
9,073 106
343
1,626
26,160
27,864
2012
Other
foreign Worldwide Argentina
2011
Other
foreign Worldwide
179
—
1,667
7,949
9,795
—
179 —
— — —
1,881 1,508 159
9,179 7,942
7
11,060 9,629 166
2013
Other
foreign Worldwide
Company’s share in equity method investees’
capitalized costs
Exploration costs
Development costs
Argentina
— —
— —
2013
Other
foreign Worldwide
2012
Other
foreign Worldwide Argentina
Argentina
— — —
3 —
—
— — —
18 —
3
2011
Other
foreign Worldwide
—
18
Total costs incurred
— —
—
3 —
3
18 —
18
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-88
Differences between these tables and the amounts shown in Note 12, “Consolidated Business 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
Company’s share in equity method
investees’ capitalized costs
Net sales to unaffiliated parties
Net intersegment sales
Total net revenues
Production costs
Depreciation and expense for
2013
Other
foreign Worldwide Argentina
4,437
3,027
276
— 38,908
276 41,935
(55) (24,993)
(829)
(59)
243
27,053 —
243
31,490
(54)
(18,904)
(284)
(298)
Argentina
2,751
38,908
41,659
(24,938)
(770)
2012
Other
foreign Worldwide Argentina
2011
Other
foreign
4,680 2,888 239
27,053 20,686 —
31,733 23,574 239
(48)
(18,958) (14,186)
(464) (110)
(582)
Worldwide
3,127
20,686
23,813
(14,234)
(574)
(9,464)
(715)
(135)
—
(9,599)
(715)
(6,789)
(105)
(475) —
(6,894) (5,619) (115)
(387) —
(475)
(5,734)
(387)
5,772
(1,997)
27
(22)
5,799
(2,019)
(200)
5,024
(1,752) —
(34)
4,824 2,918
(1,752) (1,018) —
2,884
(1,018)
3,775
5
3,780
3,272
(200)
3,072 1,900
(34)
1,866
2013
Other
foreign Worldwide
—
—
—
—
—
—
—
—
Argentina
—
—
—
—
2012
Other
foreign Worldwide Argentina
2011
Other
foreign
Worldwide
Argentina
96 —
31 —
127 —
(56) —
96
31
127
(56)
104 —
25 —
129 —
(57) —
valuation allowances
—
—
—
(27) —
(27)
(2) —
Pre-tax income from
producing activities
Income tax expense
Results of oil and gas
producing activities
—
—
—
—
—
—
44 —
(15) —
44
(15)
70 —
(25) —
—
—
—
29 —
29
45 —
104
25
129
(57)
(2)
70
(25)
45
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 at the
beginning of each month, for crude oils of different quality produced by the Company. The Company considered the realized prices
for crude oil in the domestic market taking into account the effect of exports taxes as were enforced by the enacted laws as of each of
the corresponding years (until 2016 in accordance with Law No. 26,732). For the years beyond the mentioned periods, the Company
considered the underweighted average price of the first-day-of-the-month price for each month within the twelve-month period ended
December 31, 2013, 2012 and 2011, respectively, which refers to the WTI prices adjusted by each different quality produced by the
Company. Additionally, since there are no benchmark market natural gas prices available in Argentina, the Company used average
realized gas prices during the years ended December 31, 2013, 2012 and 2011 to determine its gas reserves.
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.
F-89
The future cash inflows and outflows in foreign currency have been remeasured at the selling exchange rate of Argentine pesos 6.52,
4.90 and 4.30 to US$ 1, as of December 31, 2013, 2012 and 2011, respectively.
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.
Consolidated standardized measure
of discounted future net cash flows
Future cash inflows (1)
Future production costs
Future development costs
Future income tax expenses
10% annual discount for
estimated timing of cash
flows
Standardized measure of
discounted future net
cash flows
Argentina
357,749
(185,727)
(49,164)
(25,403)
2013
Other
foreign Worldwide
641 358,390
(151) (185,879)
(180) (49,344)
(150) (25,553)
2012
Other
foreign Worldwide Argentina
2011
Other
foreign Worldwide
305
(102)
(1)
(65)
225,199 173,871 364 174,235
(74,735)
(118,705) (74,604) (131)
(26,119)
(48)
(27,014) (26,071)
(18,558)
(82)
(14,107) (18,476)
Argentina
224,894
(118,603)
(27,013)
(14,042)
(35,935)
(54) (35,989)
(24,793)
(18)
(24,811) (19,090)
(15)
(19,105)
61,520
106 61,626
40,443
119
40,562 35,630
88
35,718
2013
2012
2011
Company’s share in equity method investee’s
standardized measure of discounted future
net cash flows
Future cash inflows (1)
Future production costs
Future income tax expenses
10% annual discount for estimated
Argentina
— —
— —
— —
Other
foreign Worldwide
Argentina
Other
foreign Worldwide
Argentina
Other
foreign Worldwide
—
—
—
528 —
(172) —
(101) —
528
(172)
(101)
594 —
(169) —
(144) —
594
(169)
(144)
timing of cash flows
— —
—
(61) —
(61)
(66) —
(66)
Standardized measure of discounted
future net cash flows
— —
—
194 —
194
215 —
215
(1) For the years ended December 31, 2013, 2012 and 2011, future cash inflows are stated net of the effect of withholdings on
exports until 2016 in accordance with Law No. 26,732.
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, 2013, 2012 and 2011:
2013
2012
2011
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
Changes in estimated future
development and abandonment costs
Development costs incurred during the
year that reduced future development
Consolidated
40,562
(20,402)
3,174
21,996
6,963
(11,012)
Company’s
share in
equity
method
investees
194
—
—
—
—
—
Company’s
share in
equity
method
investees Consolidated
44,029
215
Consolidated
35,718
(14,932)
(120)
(13,397)
(6,206)
(32)
(24,583)
7,378
3,967
(94)
14
10,771
—
8,491
9
(8,714)
Company’s
share in
equity
method
investees
194
(99)
2
84
—
(5)
costs
Accretion of discount
Net change in income taxes
Others
End of year
7,544
4,592
(5,284)
13,493
61,626
—
—
—
(194)(1)
—
4,821
3,419
1,583
4,908
40,562
3
17
58
30
194
3,487
4,112
7,897
3,625
35,718
4
15
5
15
215
(1) Approximately 194 were transferred to Consolidated Entities as a result of YPF Energía 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.
F-90
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
CONSOLIDATED BALANCE SHEETS AS OF DECEMBER 31, 2013 AND COMPARATIVE INFORMATION
CONSOLIDATED COMPANIES, JOINT VENTURES AND AFFILIATED
(amounts expressed in millions of Argentine pesos, except where otherwise indicated – Note 1.b.1)
a) Consolidated companies(12)
Description of the Securities
Last Financial Statements Available
2013
Information of the issuer
Exhibit I
Face
Value
Amount
Main Business
Registered Address
Date
Capital
Stock
Income
(Loss)
Equity
Holding
in
Capital
Stock
Name and Issuer
Controlled companies:
YPF International S.A. (8)
YPF Holdings Inc. (8)
Class
Common
Common
Operadora de Estaciones de
Common
Servicios S.A.
A-Evangelista S.A.
Common
YPF Servicios Petroleros S.A.
Common
YPF Inversora Enérgetica S.A. (9)
Common
YPF Energía Eléctrica S.A. (13)
Common
$
$
$
$
Bs. 100 2,512,290
Investment
Investment and finance
US$
0.01
810,614
1 163,701,747
1 8,683,698
1
47,500
1 59,955,411
Commercial management of
YPF’s gas stations
Engineering and construction
services
Wells perforation and/or
reparation services
Investment
YPF Chile S.A. (14)
Common
YPF Tecnología S.A.
Common
$
1 30,006,540
— 44,830,700
$
1 194,100,000
b) Companies valued using the equity method
Exploration, development,
industrialization and marketing
of hydrocarbons, and generation,
transportation and marketing of
electric power
Lubricants and aviation fuels
trading and hydrocarbons
research and exploration
Investigation, development,
production and
commercialization of
technologies, knowledge, goods
and services.
Calle La Plata 19, Santa Cruz de
la Sierra, República de Bolivia
1330 Lake Robbins Drive, Suite
300, The Woodlands, Texas,
U.S.A.
Macacha Güemes 515, Buenos
Aires, Argentina
Macacha Güemes 515, Buenos
Aires, Argentina
Macacha Güemes 515, Buenos
Aires, Argentina
Macacha Güemes 515, Buenos
Aires, Argentina
Macacha Güemes 515,
Buenos Aires, Argentina
12-31-13
236
3
531
99.99%
12-31-13
12-31-13
12-31-13
12-31-11
12-31-13
5,269
(250)
(1,238)
100.00%
163
206
404
99.99%
9
— (10)
43
30
104
100.00%
39
100.00%
60
(120)
118
99.99%
Villarica 322, Módulo B1,
Quilicura, Santiago
Macacha Güemes 515, Buenos
Aires, Argentina
12-31-13
30
121
364
100.00%
12-31-13
262
(3)
303
100.00%
12-31-13
194
11
205 51.00%
Description of the Securities
Las Financial Statements Available
2012
2011
2013
Information of the issuer
Name and
Issuer
Joint Ventures:
Class
Face
Value
Amount
Book
Value(3)
Cost(2)
Main Business
Registered
Address
Date
Capital
Stock
Income
(Loss)
Equity
Holding
in
Capital
Stock
Book
Value(3)
Book
Value(3)
Compañía
Mega S.A.(6)(8)
Profertil S.A.(8)
Refinería del Norte
S.A.
Affiliated
Companies:
Oleoductos del
Valle S.A.
Terminales
Marítimas
Patagónicas S.A.
Oiltanking Ebytem
S.A.(8)
Inversora Dock
Sud S.A.
Pluspetrol Energy
S.A.(11)
Oleoducto
Trasandino
(Argentina) S.A.
Common $
1 244,246,140
408
—
Common $
1 391,291,320 1,088
—
Separation,
fractionation and
transportation of
natural gas liquids
Production and
marketing of
fertilizers
Common $
1
45,803,655
413
1,909
— Refining
—
San Martín 344,
P. 10º, Buenos
Aires, Argentina
Alicia Moreau de
Justo 740, P. 3°,
Buenos Aires,
Argentina
Maipú 1, P. 2º,
Buenos Aires,
Argentina
09-30-13
203
(109)
445
38.00%
199
405
12-31-13
783
660
1,358
50.00%
818
761
09-30-13
92
56
669
50.00%
294
1,311
254
1,420
Common $
10
4,072,749
70(1) —
Common $
10
476,034
55
—
Common $
10
351,167
58
—
Gasoducto del
Pacífico
(Argentina) S.A. Preferred $
Central Dock Sud
S.A.
1
15,579,578
16
—
Common $ 0.01 2,822,342,992 — (7)
46
Common $
1 103,501,823 — (7)
193
Oil transportation
by pipeline
Oil storage and
shipment
Hydrocarbon
transportation and
storage
Gas transportation
by pipeline
Electric power
generation and bulk
marketing
Investment and
finance
12-31-13
12-31-13
Florida 1, P. 10°,
Buenos Aires,
Argentina
Av. Leandro N.
Alem 1180,
P.11°, Buenos
Aires, Argentina
Terminal
Marítima Puerto
Rosales –
Provincia de
Buenos Aires,
Argentina
San Martín 323,
P. 13º, Buenos
Aires, Argentina 12-31-13
Pasaje Ingeniero
Butty 220, P. 16°,
Buenos Aires,
Argentina
Pasaje Ingeniero
Butty 220, P. 16°,
Buenos Aires,
Argentina
12-31-13
03-31-13
03-31-13
110
4
205
37.00%
67(1)
75(1)
14
(2)
173
33.15%
58
47
12
30
83
30.00%
44
43
156
102
192 10.00%
6
356
(59)
32
9.99%(5)
— (7)
4
4
241
(35)
148
42.86%
— — —
—
—
71
344
101
309
— —
— —
—
—
Preferred $
1
27,018,720
15
—
Oil transportation
by pipeline
—
Macacha Güemes
515, P. 3°,
Buenos Aires,
Argentina
09-30-13
34
7
44 36.00%
12
13
Other companies:
Others(4)
— —
—
13
227
2,136
49
288
288
—
—
— — —
—
—
13
615
1,926
54(15)
650
2,070
(1)
(2)
(3)
(4)
(5)
(6)
(7)
Holding in shareholders’ equity, net of intercompany profits.
Cost net of cash dividends and stock redemption.
Holding in shareholders’ equity plus adjustments to conform to YPF accounting methods.
Includes Gasoducto del Pacífico (Cayman) Ltd., A&C Pipeline Holding Company, Poligás Luján S.A.C.I.,Oleoducto Transandino (Chile) S.A., Bizoy S.A.,
Civeny S.A. and Bioceres S.A.
Additionally, the Company has a 29.93% indirect holding in capital stock through Inversora Dock Sud S.A.
As stipulated by shareholders’ agreement, joint control is held in this company by shareholders.
Holding in negative shareholders’ equity as of December 31, 2013, 2012 and 2011 was disclosed in “Accounts payable” after adjustments in shareholders’ equity
to conform to YPF accounting methods.
(8)
(9)
The U.S. dollar has been defined as the functional currency of this company.
During the current year, YPF Inversora Energética S.A., took control of GASA. As of 31 December 2013, the Company owns directly and indirectly 100% of the
capital stock of GASA, which owns 70% of the capital stock of MetroGAS (see Note 13).
(10) No value is disclosed as the carrying value is less than 1.
(11) The Company has been spun-off (see Note 13).
(12) Additionally, YPF Services USA Corp. Eleran Inversiones 2011 S.A.U, Energía Andina S.A., Compañía Minera Argentina S.A., YPF Perú SAC., YPF Brasil
Comercio Derivado de Petróleo Ltd., Wokler Investment S.A. and YPF Colombia S.A. have been consolidated.
(13) Company created as a consequence of the spun-off of Pluspetrol Energy S.A. (see note 13).
(14) The peso chileno has been defined as functional currency for this company.
(15)
Includes 41 corresponding to GASA, which was disclosed as a company under significant influence before the business combination detailed in Note 13.
F-91
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
INTEREST IN JOINT OPERATIONS AND OTHER AGREEMENTS
As of December 31, 2013, the main exploration and production joint operations and other agreements in which the Company
participates are the following:
Exhibit II
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 and Mendoza
El Tordillo
Chubut
La Tapera y Puesto Quiroga
Chubut
Llancanelo
Mendoza
Magallanes
Santa Cruz, Tierra del Fuego and
National Continental Shelf
Palmar Largo Formosa and Salta
Puesto Hernández
Neuquén and Mendoza
Ramos
Salta
San Roque
Neuquén
Tierra del Fuego
Tierra del Fuego
Yacimiento La Ventana – Río
Tunuyán
Mendoza
Zampal Oeste
Mendoza
Neptune
USA
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.
51.00%
YPF S.A.
50.00%
30.00%
Enap Sipetrol Argentina S.A.
Pluspetrol S.A.
61.55%
Petrobras Energía S.A.
42.00%
Pluspetrol Energy S.A.
34.11%
Total Austral S.A.
30.00%
Petrolera L.F. Company S.R.L.
60.00%
YPF S.A.
70.00%
YPF S.A.
15.00%
BHPB Pet (Deepwater) Inc.
F-92
YPF SOCIEDAD ANONIMA AND CONTROLLED COMPANIES
BALANCE SHEET AS OF DECEMBER 31, 2013 AND COMPARATIVE INFORMATION
MONETARY ASSETS AND LIABILITIES DENOMINATED IN CURRENCIES OTHER THAN ARGENTINE PESOS
INFORMATION REQUIRED BY ARTICLE 63 OF LAW No. 19,550
Exhibit III
(amount expressed in million)
Account
Noncurrent Assets
Other receivables and advances
Total noncurrent assets
Current Assets
Trade receivables
Other receivables and advances
Cash and equivalents
Total current assets
Total assets
Noncurrent Liabilities
Provisions
Other taxes payables
Salaries and social security
Loans
Accounts payable
Total noncurrent liabilities
Current Liabilities
Provisions
Loans
Salaries and social security
Accounts payable
Total current liabilities
Total liabilities
(1) Buying exchange rate.
(2) Selling exchange rate.
Foreign currency and amount
12-31-2011
12-31-2012
12-31-2013
Exchange rate in
pesos
as of 12-31-13
Value in pesos as
of 12-31-13
US$
88 US$
UYU — UYU
BRL — BRL — BRL
80 US$
319
26 UYU —
4
€€
€€
2
176 US$
263
US$ 519 US$
UYU 132 UYU
2 UYU —
CLP — CLP 5,839 CLP 8,688
21
BRL — BRL — BRL
502
113 US$
US$ 200 US$
3
34
UYU 225 UYU
6 BOP —
16 BOP
BOP
CLP — CLP — CLP 1,087
98 US$
US$ 166 US$
649
33 BOP —
BOP
23 BOP
189
997 CLP
CLP — CLP
6
50 UYU
UYU — UYU
4
BRL — BRL — BRL
105 UYU
3
€€
US$ 1,169 US$ 1,233 US$ 2,095
16
US$ — US$ — US$
US$
1
3 US$
3 US$
US$ 1,038 US$ 1,087 US$ 1,980
60
5 US$
US$
8
UYU — UYU — UYU
14 US$
123
58 US$
US$ 102 US$
985
US$ 1,312 US$
736 US$
13
BRL — BRL — BRL
2
1 US$
US$ — US$
10
UYU — UYU
9 UYU
2
BRL — BRL — BRL
US$ 1,372 US$ 1,479 US$ 1,776
186
27
UYU 111 UYU
BOP — BOP
23
CLP — CLP 4,994 CLP 6,629
6
BRL — BRL — BRL
48
74 UYU
53 BOP
49
€€
€€
€€
F-93
6.48(1)
— (1)
2.77(1)
6.48(1)
— (1)
0.01(1)
2.77(1)
6.48(1)
8.96(1)
0.31(1)
— (1)
0.01(1)
6.48(1)
— (1)
0.01(1)
0.31(1)
2.77(1)
6.52(2)
6.52(2)
6.52(2)
6.52(2)
6.52(2)
0.35(2)
6.52(2)
6.52(2)
2.79(2)
6.52(2)
0.35(2)
2.79(2)
6.52(2)
9.00(2)
0.35(2)
0.96(2)
0.01(2)
2.79(2)
2,067
—
11
2,078
1,704
—
87
58
3,253
27
11
—
11
4,205
—
2
2
11
9,371
11,449
13,660
104
7
12,910
391
3
27,075
802
6,422
36
13
4
6
11,580
1,674
9
22
66
17
20,651
47,726
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 27, 2014.
/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 27, 2014.
/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, 2013 (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 27, 2014.
/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 14, 2014
Mr. Daniel Gonzalez
YPFS.A.
Macacha Guemes 515
C1106BKK Buenos Aires
Argentina
Ladies and Gentlemen:
We hereby consent to the reference to DeGolyer and MacNaughton as set forth under the section “Internal Controls on Reserves
and Reserves Audits,” and to the inclusion of our third-party letter report dated August 30, 2013, and as an exhibit in YPF S.A.’s
report on Form 20-F for the year ended December 31, 2013, to be filed with the United States Securities and Exchange Commission
(SEC).
Our third-party letter report contains our independent estimates of the proved crude oil, condensate, natural gas liquids, gasoline,
marketable gas, and oil equivalent reserves as of October 1, 2013, of certain selected properties in the Gulf of Mexico, the Texas
Panhandle region, and western Oklahoma in which YPF S.A. holds interests.
Very truly yours,
DeGOLYER and MacNAUGHTON
Texas Registered Engineering Firm F-716
Exhibit 23.2
March 19, 2014
YPF S.A.
Macacha Guemes 515
Ciudad Autonoma de Buenos Aires
Buenos Aires, Argentina
Ladies and Gentlemen:
We hereby consent to the reference to IHS Global Canada Inc. as set forth under the section “Internal Controls on Reserves and
Reserves Audits”, and to the inclusion of our third party report dated January 31, 2014 and as an exhibit in YPF S.A.’s report on Form
20-F for the year ended December 31, 2013, to be filed with the United States Securities and Exchange Commission (SEC).
Our third-party letter report contains our independent estimates of the proved crude oil, condensate, natural gas liquids, marketable
gas and oil equivalent reserves as of September 30, 2013, of certain selected properties in Argentina in which YPF S.A. holds
interests.
Yours truly,
IHS GLOBAL CANADA INC.
Dale Struksnes, B. Comm., CMA, C.E.T.
Manager, Reserve Evaluations
IHS FEKETE RESERVOIR SOLUTIONS
Exhibit 99.1
DEGOLYER AND MACNAUGHTON
5001 SPRING VALLEY ROAD
SUITE 800 EAST
DALLAS, TEXAS 75244
APPRAISAL REPORT
as of OCTOBER 1,
2013 on
CERTAIN PROPERTIES
owned by
MAXUS ENERGY CORPORATION
EXECUTIVE SUMMARY
DEGOLYER AND MACNAUGHTON
TABLE of CONTENTS
FOREWORD
Scope of Investigation
Authority
Source of Information
DEFINITION of RESERVES
ESTIMATION of RESERVES
VALUATION of RESERVES
SUMMARY and CONCLUSIONS
Page
1
1
2
3
4
8
l0
14
DEGOLYER AND MACNAUGHTON
5001 SPRING VALLEY ROAD
SUITE 800 EAST
DALLAS, TEXAS 75244
APPRAISAL REPORT
as of OCTOBER 1,
2013 on
CERTAIN PROPERTIES
owned by
MAXUS ENERGY CORPORATION
EXECUTIVE SUMMARY
FOREWORD
Scope of Investigation
This report is an appraisal, as of October 1, 2013, of the extent and value of the proved and probable crude oil,
condensate, natural gas liquids (NGL), and natural gas reserves of certain properties that Maxus Energy Corporation (Maxus) has
represented that it owns. The properties appraised consist of working and overriding royalty interests located in Oklahoma and Texas
(Crescendo) and offshore Gulf of Mexico (Neptune).
Estimates of proved reserves presented in this report have been prepared in compliance with the regulations
promulgated by the United States Securities and Exchange Commission (SEC). Estimates of probable reserves presented in this report
have been prepared in accordance with the Petroleum Resources Management System (PRMS) approved in March 2007 by the
Society of Petroleum Engineers, the World Petroleum Council, the American Association of Petroleum Geologists, and the Society of
Petroleum Evaluation Engineers. These reserves definitions are discussed in detail in the Definition of Reserves section of this report.
Reserves estimated in this report are expressed as gross and net reserves. Gross reserves are defined as the total
estimated petroleum remaining to be produced after September 30, 2013. Net reserves are defined as that portion of the gross reserves
attributable to the interests owned by Maxus after deducting royalties and interests owned by others.
DEGOLYER AND MACNAUGHTON
This report also presents values for proved and probable reserves using initial prices and costs provided
by Maxus. Future prices were estimated using guidelines established by the SEC and the Financial Accounting Standards Board
(FASB). A detailed explanation of the future price and cost assumptions is included in the Valuation of Reserves section of this
report.
Values shown herein are expressed in terms of future gross revenue, future net revenue, and present
worth. Future gross revenue is that revenue which will accrue to the appraised interests from the production and sale of the estimated
net reserves. Future net revenue is calculated by deducting estimated production taxes, ad valorem taxes, operating expenses, and
capital costs from the future gross revenue. Operating expenses include field operating expenses, transportation expenses,
compression charges, and an allocation of overhead that directly relates to production activities. Future income tax expenses were not
taken into account in the preparation of these estimates. Present worth is defined as future net revenue discounted at a specified
arbitrary discount rate compounded monthly over the expected period of realization. In this report, present worth values using a
discount rate of 10 percent are reported in detail and values using discount rates of 5, 10, 15, 20, 25, and 30 percent are reported as
totals.
Estimates of oil, condensate, NGL, and gas reserves and future net revenue should be regarded only as
estimates that may change as further production history and additional information become available. Not only are such reserves and
revenue 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.
Authority
This report was prepared at the request of Mr. Fernando Segovia, Purchasing Manager, Maxus Energy
Corporation.
2
DEGOLYER AND MACNAUGHTON
Source of Information
Data used in the preparation of this report were obtained from Maxus, from reports filed with the
appropriate regulatory agencies, and from other public sources. In the preparation of this report we have relied, without independent
verification, upon information furnished by Maxus with respect to property interests being appraised, 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. It was not considered
necessary to make a field examination of the physical condition and operation of the properties.
3
DEGOLYER AND MACNAUGHTON
DEFINITION of RESERVES
Petroleum reserves included in this report are classified by degree of proof as proved or probable. Only
proved and probable reserves have been evaluated for this report. Proved reserves classifications used in this report are in accordance
with the reserves definitions of Rules 4-lO(a) (1}-(32) of Regulation S-X of the SEC. Proved 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.
(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.
4
DEGOLYER AND MACNAUGHTON
(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.
evaluated herein.
The following definitions for developed and undeveloped reserves apply only to proved reserves
5
DEGOLYER AND MACNAUGHTON
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
The probable reserves presented in this report have been prepared in accordance with the PRMS approved
in March 2007 by the Society of Petroleum Engineers, the World Petroleum Council, the American Association of Petroleum
Geologists, and the Society of Petroleum Evaluation Engineers. Probable and possible reserves are based on geoscience and/or
engineering data similar to that used in estimates of proved reserves, but technical or other uncertainties preclude such reserves being
classified as proved.
Probable Reserves—Probable reserves are those additional reserves which analysis of geoscience and engineering data indicate
are less likely to be recovered than proved reserves but more certain to be recovered than possible reserves. It is equally likely
that actual remaining quantities recovered will be greater than or less than the sum of the estimated proved plus probable
reserves (2P). In this context, when probabilistic methods are used, there should be at least a 50-percent probability that the
actual quantities recovered will equal or exceed the 2P estimate.
Possible Reserves—Possible reserves are those additional reserves which analysis of geoscience and engineering data suggest
are less likely to be recoverable than probable reserves. The total quantities ultimately recovered from the project have a low
probability to exceed the sum of proved plus probable plus possible reserves (3P), which is equivalent to the high estimate
scenario. In this context, when probabilistic methods are used, there should be at least a 10-percent probability that the actual
quantities recovered will equal or exceed the 3P estimate.
The extent to which probable and possible reserves ultimately may be recategorized as proved reserves is
dependent upon future drilling, testing, and well performance. The degree of risk to be applied in evaluating probable and possible
reserves is influenced by economic and technological factors as well as the time element. Probable reserves in this report have not
been adjusted in consideration of these additional risks to make them comparable to proved reserves. No possible reserves have been
evaluated for this report.
7
DEGOLYER AND MACNAUGHTON
ESTIMATION of RESERVES
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, which for
proved reserves are 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)” and for probable reserves are as
presented in accordance with definitions established by the PRMS. 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.
When applicable, the volumetric method was used to estimate the original oil in place (OOIP). Structure
maps were prepared to delineate each reservoir, and isopach maps were constructed to estimate reservoir volume. Electrical logs,
radioactivity logs, core analyses, and other available data were used to prepare these maps as well as to estimate representative values
for porosity and water saturation. When adequate data were available and when circumstances justified, material-balance and other
engineering methods were used to estimate OOIP.
Estimates of ultimate recovery were obtained after applying recovery factors to OOIP. These recovery
factors were based on consideration of the type of energy inherent in the reservoirs, analyses of the petroleum, the structural positions
of the properties, and the production histories. When applicable, material-balance and other engineering methods were used to
estimate recovery factors. An analysis of reservoir performance, including production rate, reservoir pressure, 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 based on current economic conditions.
8
DEGOLYER AND MACNAUGHTON
analogy with similar wells or reservoirs for which more complete data were available.
In certain cases, when the previously named methods could not be used, reserves were estimated by
Gas quantities estimated herein are expressed as wet gas and sales gas. Wet gas is defined as the total gas
to be produced before reductions for volume loss due to fuel and flare consumption and reduction for plant processing. Sales gas is
defined as that portion of the wet gas to be produced from the reservoirs, measured at the point of delivery, after reduction for fuel
usage, flare, and shrinkage resulting from field separation and plant processing. Gross gas quantities are reported as wet gas. Net gas
quantities are reported as sales gas. All gas quantities are expressed at a temperature base of 60 degrees Fahrenheit COF) and at the
legal pressure base of the state or area in which the reserves are located. Condensate reserves estimated herein are those to be
recovered by normal lease separation.
In the preparation of this report, as of October 1, 2013, gross production estimated to October 1, 2013,
was deducted from gross ultimate recovery to arrive at the estimates of gross reserves. Production data from certain properties were
available through April 2013. Data available from wells drilled to August 16, 2013, were used in this report.
follows, expressed in thousands of barrels (Mbbl) and millions of cubic feet (MMcf):
The proved and probable reserves, as of October 1, 2013, of the properties appraised are estimated as
Gross Reserves
Net Reserves
Oil and
Condensate
(Mbbl)
NGL
(Mbbl)
Wet Gas
(MMcf)
Oil and
Condensate
(Mbbl)
NGL
(Mbbl)
Sales
Gas
(MMcf)
Proved
Developed Producing
Developed Nonproducing
Undeveloped
Total Proved
Probable*
8,056
0
0
8,056
5,699
187 463,860
0
0
0
0
187 463,860
4,460
192
* Probable reserves have not been risk adjusted to make them comparable to proved reserves.
9
0
0
753 25 2,897
0
0
25 2,897
392
25
753
748
0
0
DEGOLYER AND MACNAUGHTON
VALUATION of RESERVES
prices were estimated using guidelines established by the SEC and the FASB.
Revenue values in this report have been prepared using initial prices and costs specified by Maxus. Future
In this report, values for proved and probable reserves are based on projections of estimated future
production and revenue prepared for these properties with no risk adjustment applied to the probable reserves. Probable reserves
involve substantially higher risk than proved reserves. Revenue values for probable reserves have not been adjusted to account for
such risks; this adjustment would be necessary in order to make probable reserves values comparable with values for proved reserves.
The following assumptions were used for estimating future prices and costs:
Oil and Condensate Prices
Maxus has represented that the oil and condensate 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 requested that this report be delivered at the
end of August 2013, approximately 30 days before the “as of’ date of this report. In doing so, the September 1, 2013,
posted product price, the final product price used to determine the average product price for the 12-month period preceding
the “as of’ date of the evaluation, was not available. At Maxus’ request the final product price used to calculate the average
product price for the 12-month period preceding the “as of’ date of this report was the product price posted on August 16,
2013. Maxus supplied differentials by field to a West Texas Intermediate reference price of $95.10 per barrel and the prices
were held constant thereafter. The volume-weighted average price attributable to estimated proved reserves was $92.96 per
barrel of oil and condensate.
10
DEGOLYER AND MACNAUGHTON
NGLPrices
Maxus supplied differentials by field to a reference price of $60.48 per barrel and the prices were held constant thereafter.
The volume-weighted average price attributable to estimated proved reserves was $52.92 per barrel.
Natural Gas Prices
Maxus has represented that the natural 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. Maxus requested that this report be delivered at the end of
August 2013, approximately 30 days before the “as of’ date of this report. In doing so, the September 1, 2013, posted gas
price, the final gas price used to determine the average gas price for the 12-month period preceding the “as of’ date of the
evaluation, was not available. At Maxus’ request the final gas price used to calculate the average gas price for the 12-
month period preceding the “as of’ date of this report was the gas price posted on August 16, 2013. The gas prices were
calculated for each property using differentials to the Henry Hub reference price of $3.58 per million British thermal units
(MMbtu) furnished by Maxus and held constant thereafter. The volume-weighted average price attributable to estimated
proved reserves was $3.601 per thousand cubic feet.
Operating Expenses and Capital Costs
Estimates of operating expenses and capital costs based on current costs were used for the lives of the properties with no
increases in the future based on inflation. In certain cases, future costs, either higher or lower than current costs, may have
been used because of anticipated changes in operating conditions. Future capital costs were estimated using expected
2013 values and were not adjusted for inflation.
11
DEGOLYER AND MACNAUGHTON
reserves, as of October 1, 2013, of the properties appraised is summarized as follows, expressed in thousands of dollars (M$):
The estimated future revenue to be derived from the production and sale of the net proved and probable
Future Gross Revenue, M$
Production and Ad Valorem Taxes, M$
Operating Expenses, M$
Capital Costs, M$
Abandonment Costs, M$
Future Net Revenue**, M$
Present Worth at 10 Percent**, M$
Developed
Producing:
81,757
908
17,716
0
28,800
34,333
30,218
Developed
Nonproducing:
0
0
0
0
0
0
0
Undeveloped
0
0
0
0
0
0
0
Total
Proved
81,757
908
17,716
0
28,800
34,333
30,218
Probable*
72,291
0
12,675
13,500
0
46,116
29,764
*
**
Values for probable reserves have not been risk adjusted to make them comparable to values for proved reserves.
Future income tax expenses were not taken into account in the preparation of these estimates.
development plan provided by Maxus.
The development of production and the resulting timing of capital expenditures were based on a
In our opinion, the information relating to estimated proved reserves, estimated future net revenue from
proved reserves, and present worth of estimated future net revenue from proved reserves of oil, condensate, natural gas liquids, 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, 932-235-
50-9, 932-235-50-30, and 932-235-50-31(a), (b), and (e) 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 (i) future income tax expenses have not been
taken into account in estimating the future net revenue and present worth values set forth herein, (ii) estimates of the proved
developed and proved undeveloped reserves are not presented at the beginning of the year, and (iii) the as-of date of this report does
not coincide with Maxus’ fiscal year.
preparation of this report but before the “as-of’ date of October 1, 2013, that might have affected the reserves, prices, and costs used
in the estimates presented herein were not taken into account.
This report was completed on August 30, 2013; therefore, events that may have occurred after the
12
DEGOLYER AND MACNAUGHTON
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.
To the extent that the above-enumerated rules, regulations, and statements require determinations of an
13
DEGOLYER AND MACNAUGHTON
SUMMARY and CONCLUSIONS
offshore Gulf of Mexico. The estimated net proved and probable reserves of the properties appraised, as of October 1, 2013, are
summarized as follows, expressed in thousands of barrels (Mbbl) and millions of cubic feet (MMcD):
Maxus has represented that it owns interests in certain properties located in Oklahoma, Texas, and
Proved
Developed Producing
Developed Nonproducing
Undeveloped
Total Proved
Probable*
Net Reserves
Oil and
Condensate
(Mbbl)
753
0
0
753
748
NGL
(Mbbl)
25
0
0
25
25
Sales
Gas
(MMcf)
2,897
0
0
2,897
392
* Probable reserves have not been risk adjusted to make them comparable to proved reserves.
Estimated revenue and costs attributable to Maxus’ interests in the reserves, as of October 1, 2013, of the
properties appraised under the aforementioned assumptions concerning future prices and costs are summarized as follows, expressed
in thousands of dollars (M$):
Future Gross Revenue, M$
Production and Ad Valorem Taxes, M$
Operating Expenses, M$
Capital Costs, M$
Abandonment Costs, M$
Future Net Revenue**, M$
Present Worth at 10 Percent**, M$
Developed
Producing
81,757
908
17,716
0
28,800
34,333
30,218
Developed
Nonproducing Undeveloped
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Total
Proved
81,757
908
17,716
0
28,800
34,333
30,218
Probable*
72,291
0
12,675
13,500
0
46,116
29,764
*
**
Values for probable reserves have not been risk adjusted to make them comparable to values for proved reserves.
Future income tax expenses were not taken into account in the preparation of these estimates.
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 October 1, 2013, estimated oil and gas volumes. The reserves estimated in this report can be produced
under current regulatory guidelines.
14
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. DeGolyer and MacNaughton does not have any financial
interest, including stock ownership, in Maxus. Our fees were not contingent on the results of our evaluation. This 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.
Submitted,
/s/ DeGolyer and MacNaughton
DeGOLYER and MacNAUGHTON
Texas Registered Engineering Firm F-716
SIGNED: August 30, 2013
/s/ Paul J. Szatkowski. P.E.
Paul J. Szatkowski. P.E.
Senior Vice President
DeGolyer and MacNaughton
15
SEC RESERVES AUDIT OF CERTAIN P&NG INTERESTS
Exhibit 99.2
OF YPF S.A.
IN ARGENTINA
AS OF SEPTEMBER 30, 2013
Prepared For:
YPF S.A.
Prepared By:
IHS GLOBAL CANADA INC.
January 31, 2014
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 September 30, 2013
Dear Mr. Javier Sanagua:
This reserve statement has been prepared by IHS Global Canada Inc. (IHS) and issued on January 31, 2014 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
Zona Central – Bella Vista Este
Lajas Ute
Working Interest (%)
50
50
IHS has conducted an independent audit examination as of September 30, 2013, of the hydrocarbon liquid and natural gas proved
reserves for 23 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.
The Chubut properties (Manantiales Behr, Restinga ali, Zona Central-Bella Vista Este and Sarmiento No Operada) were evaluated
based on the information available as at December 31, 2013. Reserves were revised for these Chubut properties to reflect the new
extensions to the concession dates.
On the basis of technical and other information made available to us concerning these properties, we hereby provide the reserve
summary given in the table below.
IHS FEKETE RESERVOIR SOLUTIONS
Summary of Remaining Hydrocarbon Volumes
Proved
Developed Producing
Developed Non-Producing
Undeveloped
Total Proved
Liquids
(E3m3)
Gas
(E6m3)
28213.0
81.0
12314.2
40608.3
5900.5
2.7
3985.0
9888.3
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 tables below contain the reserves for each property.
[3]
TOTAL LIQUID HYDROCARBONS
Entity
Cuyo
Barrancas
Estructura Cruz de Piedra
Lunlunta Carrizal
Ugarteche
Total Cuyo
San Jorge
Barranca Baya
Lomas Del Cuy
Los Monos
Los Perales
Manantiales Behr
Restinga Ali
Rio Mayo*
Sarmiento No Operada
Seco Leon
Zona Central - Bella Vista Este
Total San Jorge
Neuquina
Aguada Toledo - Sierra Barrosa
Barranca De Los Loros*
Cerro Fortunoso
Cerro Liupuca*
Cerro Negro*
El Manzano*
Lajas Ute
Las Manadas
Volcan Auca Mahuida
Total Neuquina
GRAND TOTAL
* YPF has not assigned any reserves to these fields
[4]
LIQUID HYDROCARBONS (E3m3)
PDP
(CDEP)
PDNP
(CDNP)
PUD
(CND)
TP
2190.5
830.1
274.3
476.6
3771.5
11.0
0.0
0.0
0.0
11.0
103.8
165.4
97.6
26.1
392.9
2305.3
995.5
371.9
502.7
4175.4
2642.2
1890.6
94.0
6246.5
4269.1
84.7
0.0
3.1
3632.7
1994.6
20857.5
1054.7
0.0
1682.9
0.0
0.0
0.0
0.0
60.0
786.5
3584.0
28213.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
70.0
70.0
81.0
2031.2
1168.7
0.0
2703.9
42.6
0.0
0.0
0.0
3376.1
287.3
9609.7
1145.5
0.0
551.9
0.0
0.0
0.0
0.0
194.6
419.6
2311.6
12314.2
4673.4
3059.3
94.0
8950.4
4311.7
84.7
0.0
3.1
7008.8
2281.9
30467.2
2200.2
0.0
2234.7
0.0
0.0
0.0
0.0
254.6
1276.1
5965.6
40608.3
NATURAL GAS VOLUMES
Entity
Cuyo
Barrancas
Estructura Cruz de Piedra
Lunlunta Carrizal
Ugarteche
Total Cuyo
San Jorge
Barranca Baya
Lomas Del Cuy
Los Monos
Los Perales
Manantiales Behr
Restinga Ali
Rio Mayo*
Sarmiento No Operada
Seco Leon
Zona Central - Bella Vista Este
Total San Jorge
Neuquina
Aguada Toledo - Sierra Barrosa
Barranca De Los Loros*
Cerro Fortunoso
Cerro Liupuca*
Cerro Negro*
El Manzano*
Lajas Ute
Las Manadas
Volcan Auca Mahuida
Total Neuquina
GRAND TOTAL
* YPF has not assigned any reserves to these fields
[5]
GAS (E6m3)
PDP
(CDEP)
PDNP
(CDNP)
PUD
(CND)
TP
28.7
14.1
4.1
7.0
53.9
92.3
167.7
16.9
1587.0
359.8
2.3
0.0
0.0
432.6
24.1
2682.7
2600.2
0.0
0.0
0.0
0.0
0.0
448.4
5.2
110.1
3163.9
5900.5
0.2
0.0
0.0
0.0
0.2
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
2.5
2.5
2.7
1.2
2.8
1.5
0.4
5.9
30.1
16.9
5.6
7.4
60.0
61.4
96.1
0.0
160.5
5.0
0.0
0.0
0.0
109.5
3.1
435.6
3492.7
0.0
0.0
0.0
0.0
0.0
0.0
16.9
34.0
3543.6
3985.0
153.7
263.8
16.9
1747.5
364.8
2.3
0.0
0.0
542.1
27.2
3118.3
6092.9
0.0
0.0
0.0
0.0
0.0
448.4
22.1
146.6
6710.0
9888.3
OIL VOLUMES
Entity
Cuyo
Barrancas
Estructura Cruz de Piedra
Lunlunta Carrizal
Ugarteche
Total Cuyo
San Jorge
Barranca Baya
Lomas Del Cuy
Los Monos
Los Perales
Manantiales Behr
Restinga Ali
Rio Mayo*
Sarmiento No Operada
Seco Leon
Zona Central - Bella Vista Este
Total San Jorge
Neuquina
Aguada Toledo - Sierra Barrosa
Barranca De Los Loros*
Cerro Fortunoso
Cerro Liupuca*
Cerro Negro*
El Manzano*
Lajas Ute
Las Manadas
Volcan Auca Mahuida
Total Neuquina
GRAND TOTAL
* YPF has not assigned any reserves to these fields
[6]
OIL (E3m3)
PDP
(CDEP)
PDNP
(CDNP)
PUD
(CND)
TP
2152.7
830.1
274.3
476.6
3733.7
11.0
0.0
0.0
0.0
11.0
103.8
165.4
97.6
26.1
392.9
2267.5
995.5
371.9
502.7
4137.6
2642.2
1890.6
94.0
6246.5
4269.1
84.7
0.0
3.1
3632.7
1994.6
20857.5
1054.7
0.0
1682.9
0.0
0.0
0.0
0.0
60.0
786.5
3584.0
28175.2
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
70.0
70.0
81.0
2031.2
1168.7
0.0
2703.9
42.6
0.0
0.0
0.0
3376.1
287.3
9609.7
1145.5
0.0
551.9
0.0
0.0
0.0
0.0
194.6
419.6
2311.6
12314.2
4673.4
3059.3
94.0
8950.4
4311.7
84.7
0.0
3.1
7008.8
2281.9
30467.2
2200.2
0.0
2234.7
0.0
0.0
0.0
0.0
254.6
1276.1
5965.6
40570.4
NGL VOLUMES
Entity
Cuyo
Barrancas
Estructura Cruz de Piedra
Lunlunta Carrizal
Ugarteche
Total Cuyo
San Jorge
Barranca Baya
Lomas Del Cuy
Los Monos
Los Perales
Manantiales Behr
Restinga Ali
Rio Mayo*
Sarmiento No Operada
Seco Leon
Zona Central - Bella Vista Este
Total San Jorge
Neuquina
Aguada Toledo - Sierra Barrosa
Barranca De Los Loros*
Cerro Fortunoso
Cerro Liupuca*
Cerro Negro*
El Manzano*
Lajas Ute
Las Manadas
Volcan Auca Mahuida
Total Neuquina
GRAND TOTAL
* YPF has not assigned any reserves to these fields
[7]
NGL (E3m3)
PDP
(CDEP)
PDNP
(CDNP)
PUD
(CND)
37.8
0.0
0.0
0.0
37.8
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
37.8
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
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
TP
37.8
0.0
0.0
0.0
37.8
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
37.8
It is our understanding that the Proved reserves estimated in this report as of September 30, 2013 constitute approximately 25.5% of
YPF’s Proved reserves. It is also our understanding that the Proved Undeveloped reserves estimated in this report constitute
approximately 38.6% of all YPF’s Proved Undeveloped reserves as of September 30, 2013. In addition, the Manantiales Behr,
Restinga Ali, Rio mayo, Sarmiento No Operada and Zona Central-Bella Vista Este fields which were audited as of December 31,
2013 represented approximately 3.5% of the YPF Proved reserves and 1.5% of the YPF Proved Undeveloped reserves as of
December 31, 2013. 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 January 31, 2014.
The Chubut properties (Manantiales Behr, Restinga ali, Zona Central-Bella Vista Este and Sarmiento No Operada) were evaluated
based on the information available as at December 31, 2013. Reserves were revised for these Chubut properties to reflect the new
extensions to the concession dates.
IHS’ audit of the YPF reserves 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 used to assess the
reserves estimates and the classification/categorization of the proposed development plans.
This audit examination was based on reserve estimates and other information provided by YPF to IHS through December 2013 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 economic tests for the September 30, 2013 reserve volumes were based on realized crude oil, condensate, NGL and average gas
sales prices as shown in the following table, as advised by YPF. A prior twelve-month first-day-of-the-month average price for West
Texas Intermediate (WTI) crude of US$96.90/BBL serves as the foundation for the oil, condensate and gasoline price. YPF is subject
to extensive regulations relating to the oil and gas industry in Argentina which include specific natural gas market regulations as well
as hydrocarbon export taxes that apply until 2017 according to Law 26,217, all of which affect the realized prices of oil and other
products in the domestic market. As a result, crude oil prices used to determine reserves are set at the beginning of every month until
2013, for crude oils of
[8]
different quality produced by YPF, considering the realized prices for crude oils of such quality in the domestic market, taking into
account the effects of Law 26,217. Additionally, a significant portion of the Argentine gas market is regulated. Natural gas prices for
the residential and power generation segments, as well as natural gas for vehicles, are regulated by the government. Natural gas prices
for industrial consumers are negotiated by market participants on a private basis. As a result, there are no benchmark market natural
gas prices available in Argentina. IHS reviewed and accepted the prices used by YPF in estimating the reserves in Argentina.
In addition, YPF increments the crude oil, condensate and gasoline price in 2017 due to the scheduled expiration of the export
retention tax mentioned above. There is no certainty at this point that this will occur, as the export tax has been scheduled to expire
several times in the recent past but extended as the deadline approached. Maintaining the current price would potentially have an
impact on the reserves estimates.
Cuyo
Barrancas
Estructura Cruz de Piedra
Lunlunta Carrizal
Ugarteche
San Jorge
Barranca Baya
Lomas Del Cuy
Los Monos
Los Perales
Manantiales Behr
Restinga Ali
Rio Mayo*
Sarmiento No Operada
Seco Leon
Zona Central - Bella Vista Este
Neuquina
Aguada Toledo - Sierra Barrosa
Barranca De Los Loros*
Cerro Fortunoso
Cerro Liupuca*
Cerro Negro*
Prices Based on WTI US$/BBL & US$/MMBTU
Crude Oil
Condensate
2014 - 2016
(US$/BBL)
Crude Oil
Condensate
2017+
(US$/BBL)
NGL
2014
(US$/BBL)
Natural Gas
2014+
(US$/MMBTU)
89.14
89.14
89.14
89.14
91.30
89.04
91.30
91.30
—
—
89.04
88.04
89.04
88.04
93.72
94.14
85.84
92.59
92.59
21.06
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
7.09
7.09
7.09
—
5.97
5.60
5.97
5.97
4.10
—
—
—
5.97
—
4.85
—
—
—
—
67.22
67.22
67.22
67.22
71.00
67.12
71.00
71.00
66.12
66.12
67.12
66.12
67.12
66.12
75.56
75.98
63.92
74.43
74.43
[9]
Neuquina - cont’d -
El Manzano*
Lajas Ute
Las Manadas
Volcan Auca Mahuida
* YPF has not assigned any reserves to these fields
Prices Based on WTI US$/BBL & US$/MMBTU
Crude Oil
Condensate
2014 - 2016
(US$/BBL)
Crude Oil
Condensate
2017+
(US$/BBL)
NGL
2014
(US$/BBL)
Natural Gas
2014+
(US$/MMBTU)
63.92
75.56
75.98
75.98
85.84
93.72
94.14
94.14
—
—
—
—
—
4.85
—
—
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 produce economically the projected volumes.
IHS has reviewed the estimates of total remaining recoverable hydrocarbon liquid and gas volumes at September 30, 2013 and has
also reviewed the Chubut properties (Manantiales Behr, Restinga Ali, Zona Central-Bella Vista Este and Sarmiento No Operada)
based on information available as at December 31, 2013 regarding new extensions to the concession dates and associated reserve
revisions.
It is IHS’ opinion that the estimates of total remaining recoverable hydrocarbon liquid and gas volumes at September 30, 2013, and
additionally, the Chubut properties (Manantiales Behr, Restinga Ali, Zona Central-Bella Vista Este and Sarmiento No Operada)
evaluated with updated concession date information as at December 31, 2013 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.
[10]
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.
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 Inc.
Dale Struksnes, B. Comm., CMA, C.E.T.
Manager, Reserve Evaluations
[11]
TABLE OF CONTENTS
LETTER OF TRANSMITTAL
TABLE OF CONTENTS
CERTIFICATES OF QUALIFICATION
LIMITATIONS OF REPORT
RESERVE DEFINITIONS
STANDARD OIL INDUSTRY TERMS AND ABBREVIATIONS
[12]
Page
2
12
13
25
26
29
I, Maria Tjoa, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
4.
I graduated from the University of Dalhousie, Halifax, Nova Scotia with a Bachelor in Engineering in Electrical with Computer
Engineering, in 2003 and have in excess of 7 years experience in the Petroleum Industry.
I am an Engineer-In-Training in the Province of Alberta.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
5. 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.
/s/ Maria Tjoa
Maria Tjoa, E.I.T.
[13]
I, Carmen M. Bujor, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
4.
I graduated from the University of Bucharest, Romania with a B.Sc. in Chemical Engineering in 1986, and have in excess of 17
years experience in the Petroleum Industry.
I am a registered Professional Engineer in the Province of Alberta.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
5. 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.
/s/ Carmen M. Bujor
Carmen M. Bujor, P.Eng.
[14]
I, Robert V. Coles, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
I graduated from the Technical University of Nova Scotia with a Bachelor of Engineering (Mining Engineering) in 1981 and
have in excess of 32 years experience in reservoir engineering, business development and property evaluation the Petroleum
Industry.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
4. 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.
/s/ Robert V. Coles
Robert V. Coles
[15]
I, Cesar Velasquez, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
I graduated from the Central University of Venezuela, Caracas, Venezuela, with a B.Sc. in Petroleum Engineering in 1997, hold
a Specialization, Integrated Reservoir Management from the Central University of Venezuela conferred in 2003, and have in
excess of 17 years of experience in the Petroleum Industry.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
4. 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.
/s/ Cesar Velasquez
Cesar Velasquez
[16]
I, Ehsan Motamed, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
I graduated from the Petroleum University of Technology, Iran, with a B.Sc. in Chemical Engineering in 1999, hold a M.Sc.
degree in Petroleum Engineering from the Petroleum University of Technology, Iran conferred in 2010, and have in excess of 12
years experience in the Petroleum Industry.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
4. 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.
/s/ Ehsan Motamed
Ehsan Motamed
[17]
I, Ivan Olea, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
I graduated from the National Autonomous University of Mexico, Mexico City, Mexico, with a B.Sc. in Petroleum Engineering
in 2003, hold a M.Sc. degree in Mechanical Engineering from the University of Calgary conferred in 2006, and have in excess
of 7 years experience in the Petroleum Industry.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
4. 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.
/s/ Ivan Olea
Ivan Olea
[18]
I, Dale Struksnes, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
4.
I graduated from the Southern Alberta Institute of Technology with an Honours Diploma in Petroleum Technology in 1988 and
have in excess of 25 years experience in the Petroleum Industry.
I am a certified Engineering Technologist in the Province of Alberta.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
5. 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.
/s/ Dale Struksnes
D. Struksnes, B. Comm., CMA, C.E.T.
[19]
I, Jason K. Wilhelm, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
4.
I graduated from the University of Saskatchewan with a B.Sc. in Chemical Engineering in 1996 and have in excess of 17 years
experience in the Petroleum Industry.
I am a registered Professional Engineer in the Province of Alberta.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
5. 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.
/s/ Jason K. Wilhelm
Jason K. Wilhelm, P. Eng.
[20]
I, Norbert K. Alwast, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
4.
I graduated from the University of Calgary with a B.Sc. in Geology in 1986. I have in excess of 27 years experience in the
Petroleum Industry.
I am a registered Professional Geologist in the Province of Alberta.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
5. 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.
/s/ Norbert K. Alwast
Norbert K. Alwast, P. Geol.
[21]
I, Michael G. Muirhead, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
4.
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 22 years experience in the Petroleum Industry.
I am a registered Professional Geologist in the Province of Alberta.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
5. 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.
/s/ Michael G. Muirhead
Michael G. Muirhead, P. Geol.
[22]
I, John B. Hughes, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
4.
I graduated from the University of Calgary with a B.Sc. in Geology in 1972 and have in excess of 41 years experience in the
Petroleum Industry.
I am a registered Professional Geologist in the Province of Alberta.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
5. 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.
/s/ John B. Hughes
John B. Hughes, P. Geol.
[23]
I, Gary D. Metcalfe, certify that:
CERTIFICATE OF QUALIFICATION
1.
2.
3.
4.
I graduated from the University of Calgary with a B.Sc. in Mechanical Engineering in 1976 and have in excess of 37 years
experience in the Petroleum Industry.
I am a registered Professional Engineer in the Province of Alberta.
I am employed by the engineering firm, IHS Global Canada Inc., named as having prepared a report entitled, “SEC Reserves
Audit of Certain P&NG Interests of YPF S.A. in Argentina as of September 30, 2013.”
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.
5. 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.
/s/ G. D. Metcalfe
G. D. Metcalfe, P. Eng.
[24]
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 Inc.
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.
This report has 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 and
no part thereof should be reproduced, distributed or made available to any other person, company, regulatory body or organization
without the complete context of the report and the knowledge and consent of IHS Global Canada Inc.
The analyses, interpretations and opinions expressed in this report reflect the best judgement of IHS Global Canada Inc. Due to the
inherent risks associated with the petroleum business, IHS Global Canada Inc. assumes no responsibility and makes no warranty
whatsoever in connection with the information, analyses, interpretations and opinions presented herein.
[25]
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.
[26]
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.
(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.
[27]
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.
[28]
STANDARD OIL INDUSTRY TERMS AND ABBREVIATIONS
oAPI
B
BBL
/BBL
BSCF or BCF
BSCFD 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
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
[29]
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 nitially 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
[30]
STANDARD OIL INDUSTRY TERMS AND ABBREVIATIONS
Page 3 of 3
Reserve Classifications
PDP Proved Developed Producing
PDNP Proved Developed Non-Producing
PO Possible
PR
Probable
PUD Proved Undeveloped
TP
TPP Total Proved Plus Probable
TPPP Total Proved Plus Probable Plus Possible
1P
2P
3P
Proved Reserves
Proved Plus Probable Reserves
Proved Plus Probable Plus Possible Reserves
Proved
[31]