Management’s Discussion and Analysis
For the three months and years ended
December 31, 2014 and 2013
MANAGEMENT'S DISCUSSION AND ANALYSIS
Management’s Discussion and Analysis (“the MD&A”) is dated March 5, 2015. The MD&A should be read in conjunction with
TORC Oil & Gas Ltd.’s (“TORC” or the “Company”) audited financial statements as at and for the years ended December 31, 2014 and
December 31, 2013. The reader should be aware that historical results are not necessarily indicative of future performance.
The financial data presented below has been prepared in accordance with International Financial Reporting Standards (“IFRS”), unless
otherwise indicated.
Barrel of Oil Equivalent
Where amounts are expressed on a barrel of oil equivalent (“Boe”) basis, natural gas volumes have been converted to Boe using a ratio
of 6,000 cubic feet of natural gas to one barrel of oil equivalent. This conversion ratio is based upon an energy equivalent conversion
method primarily applicable at the burner tip and does not represent value equivalence at the wellhead. Boe figures may be misleading,
particularly if used in isolation.
Non-IFRS Measurements
The MD&A contains the terms “funds flow from operations, including transaction related costs” , “funds flow from operations, excluding
transaction related costs” , "net debt" and “operating netback” which are not defined by IFRS and therefore may not be comparable to
performance measures presented by others. Funds flow from operations, including transaction related costs represents cash flow from
operating activities prior to changes in non-cash working capital and settlement of decommissioning obligations. Funds flow from
operations, excluding transaction related costs represents cash flow from operating activities prior to changes in non-cash working
capital, settlement of decommissioning obligations and transaction related costs. Working capital (net debt) is calculated as current
assets (excluding financial derivative assets) less: i) current liabilities (excluding financial derivative liabilities), ii) bank debt, and iii) non-
current deferred lease incentives. Operating netback represents revenue and realized gain or loss on financial derivatives, less royalties,
operating expenses and transportation expenses and has been presented on a per Boe basis. Management believes that in addition to
net income, the aforementioned non-IFRS measurements are useful supplemental measures as they assist in the determination of the
Company’s operating performance, leverage and liquidity. Investors should be cautioned, however, that these measures should not be
construed as an alternative to both net income and net cash from operating activities, which are determined in accordance with IFRS, as
indicators of the Company’s performance.
The reconciliation between funds flow from operations, as defined above, and net cash from operating activities, as defined by IFRS, is
as follows:
($ thousands)
Net cash from operating activities (defined by IFRS)
Settlement of decommissioning obligations
Changes in non-cash working capital
Funds flow from operations, including transaction related costs
Three months
ended
Dec 31, 2014
$72,191
225
(30,706)
$41,710
Transaction related costs (recovery)
Funds flow from operations, excluding transaction related costs
38
$41,748
The reconciliation of net debt, as defined above, is as follows:
Three months
ended
Dec 31, 2013
$46,912
-
(5,454)
$41,458
(689)
$40,769
Year ended
Dec 31, 2014
$198,982
347
(10,752)
$188,577
Year ended
Dec 31, 2013
$78,785
262
10,489
$89,536
142
$188,719
6,976
$96,512
Current assets (excluding financial derivative assets)
Less: current liabilities (excluding financial derivative liabilities)
Less: bank debt
Less: non-current deferred lease incentives
Net debt
The reconciliation for operating netback is found within this MD&A.
As at
Dec 31, 2014
$24,754
(89,459)
(179,849)
(104)
($244,658)
As at
Dec 31, 2013
$50,068
(109,971)
(85,000)
(280)
($145,183)
TORC's reporting and measurement currency is the Canadian dollar. Amounts in this MD&A are in Canadian dollars unless otherwise
stated.
TORC Oil & Gas Ltd. Q4 2014 Page 1
MANAGEMENT'S DISCUSSION AND ANALYSIS
Forward-Looking Statements
This MD&A contains forward-looking statements. More specifically, it contains forward-looking statements respecting: (i) the expected
timing of closing the Asset Swap, (ii) TORC's expectation that it will continue to realize natural gas prices greater than AECO
benchmarks, (iii) the anticipated sources of funding for the Company's capital program, (iv) the sufficiency of liquidity and capital
resources to fund the Company's capital program and ongoing operations, and (v) the Company's risk management activities and the
benefits to be obtained therefrom.
The forward-looking statements contained in this MD&A are based on certain key expectations and assumptions made by TORC,
including expectations and assumptions concerning the impact of increasing competition, the general stability of the economic and
political environment in which TORC operates, the ability of the Company to obtain qualified staff, equipment and services in a timely and
cost efficient manner, drilling results, the ability of the operator of the projects which the Company has an interest in to operate the field in
a safe, efficient and effective manner, TORC’s ability to obtain financing on acceptable terms, changes in the Company’s banking facility,
field production rates and decline rates, the ability to reduce operating costs, the ability to replace and expand oil and natural gas
reserves through acquisition, development or exploration, the timing and costs of pipeline, storage and facility construction and
expansion, the ability of the Company to secure adequate product transportation, future petroleum and natural gas prices, currency,
exchange and interest rates, the regulatory framework regarding royalties, taxes and environmental matters in the jurisdictions in which
the Company operates, and TORC’s ability to successfully market its petroleum and natural gas products. Readers are cautioned that
the foregoing list of factors is not exhaustive.
Although TORC believes that the expectations and assumptions on which the forward-looking statements are based are reasonable,
undue reliance should not be placed on the forward-looking statements because TORC can give no assurance that they will prove to be
correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and
uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks, including,
without limitation, factors and risks associated with oil and gas exploration, development, exploitation, production, marketing and
transportation, loss of markets, volatility of commodity prices, currency fluctuations, imprecision of reserve estimates, environmental
risks, competition from other producers, inability to retain drilling rigs and other services, incorrect assessment of the value of
acquisitions, failure to realize the anticipated benefits of acquisitions, the inability to fully realize the benefits of acquisitions, delays
resulting from or inability to obtain required regulatory approvals and inability to access sufficient capital from internal and external
sources. Additional information on these and other factors and risks that could affect the Company’s operations and financial results are
included in reports on file with Canadian securities regulatory authorities and may be accessed through the SEDAR website
(www.sedar.com) or at the Company’s website (www.torcoil.com). Furthermore, the forward looking statements contained in this
document are made as at the date of this document and the Company does not undertake any obligation to update publicly or to revise
any of the included forward looking statements, whether as a result of new information, future events or otherwise, except as may be
required by applicable securities laws.
Asset Acquisitions
Cardium and southeast Saskatchewan asset acquisitions
During the year ended December 31, 2014, the Company acquired various properties and working interests in its core Cardium areas as
well as in southeast Saskatchewan (the "Asset Acquisitions"). The total cash consideration paid after customary purchase price
adjustments was $137.2 million.
The acquisition of these assets increases and consolidates the Company’s exposure to light oil where the Company continues to achieve
drilling and operational success.
Asset acquisition subsequent to December 31, 2014
Subsequent to December 31, 2014, the Company entered into an agreement to acquire light oil assets which are complimentary to
TORC’s existing conventional assets in southeast Saskatchewan (the "Acquisition"). Total consideration for the Acquisition was the
issuance of 16.0 million common shares of TORC, valued at $9.17 per common share on the closing date, for a total value of $146.7
million before customary adjustments.
Asset swap subsequent to December 31, 2014
Subsequent to December 31, 2014, the Company entered into a strategic asset swap of common working interests in the Company’s non-
operated working interest properties in southeast Saskatchewan (the “Asset Swap”). The Asset Swap involves approximately 500 Boe
per day of production with similar amounts of production and reserves being swapped. The Asset Swap is expected to close in the first
quarter of 2015.
TORC Oil & Gas Ltd. Q4 2014 Page 2
MANAGEMENT'S DISCUSSION AND ANALYSIS
Results of Operations
Production
Crude oil (Bbl per day) (1)
NGL (Bbl per day) (1) (2)
Natural gas (Mcf per day) (3)
Total (Boe per day)
Production mix:
Crude oil
NGL
Crude oil and NGL ("Liquids")
Natural gas
(1)
(2)
(3)
"Bbl" refers to barrels.
"NGL" refers to natural gas liquids.
"Mcf" refers to thousand cubic feet.
Three months
ended
Dec 31, 2014
9,690
428
11,033
11,957
Three months
ended
Dec 31, 2013
8,478
363
7,951
10,166
Year ended
Dec 31, 2014
9,051
442
10,626
11,264
Year ended
Dec 31, 2013
4,744
260
6,702
6,121
81%
4%
85%
15%
83%
4%
87%
13%
80%
4%
84%
16%
78%
4%
82%
18%
Production in the three months and year ended December 31, 2014 increased 18% and 84%, respectively, compared to the three months
and year ended December 31, 2013 (the "Corresponding Periods"). In addition to the Company's on-going drilling activities, the increase
includes production from the Asset Acquisitions, and in the year-over-year increase, the acquisition of crude oil and natural gas assets
located in southeast Saskatchewan which initially added approximately 5,700 Boe per day from the closing date on September 9, 2013
(the "SE Saskatchewan Acquisition").
Pricing
Average realized prices:
Crude oil ($ per Bbl)
NGL ($ per Bbl)
Natural gas ($ per Mcf)
Boe ($ per Boe)
Three months
ended
Dec 31, 2014
Three months
ended
Dec 31, 2013
Year ended
Dec 31, 2014
Year ended
Dec 31, 2013
$73.31
40.99
3.83
$64.41
$81.73
54.50
3.61
$72.93
$89.25
53.06
4.62
$78.16
$87.11
53.92
3.31
$73.43
During the three months and year ended December 31, 2014, TORC realized oil prices of $73.31 per Bbl and $89.25 per Bbl,
respectively (Corresponding periods: $81.73 per Bbl and $87.11 per Bbl, respectively).
During the three months and year ended December 31, 2014, TORC's discount to WTI converted to Canadian dollars approximated
$10 per Bbl and $13 per Bbl, respectively (Corresponding Periods: $21 per Bbl and $14 per Bbl, respectively). In the three months and
year ended December 31, 2014, TORC's discount to Edmonton Par averaged approximately $2 per Bbl and $5 per Bbl, respectively
(Corresponding Periods: $5 per Bbl and $6 per Bbl, respectively). The pricing differentials are a function of North American refinery
supply/demand fundamentals as well as crude quality.
In the three months and year ended December 31, 2014, the Company realized gas prices of $3.83 per Mcf and $4.62 per Mcf,
respectively (Corresponding Periods: $3.61 per Mcf and $3.31 per Mcf, respectively). In the three months and year ended
December 31, 2014, the Company's realized gas prices were 18% and 14% above AECO benchmarks, respectively (Corresponding
Periods: 13% and 16% above AECO benchmarks, respectively). TORC expects to continue to realize natural gas prices greater than
AECO benchmarks due to the higher heat content of its natural gas.
(continued)
TORC Oil & Gas Ltd. Q4 2014 Page 3
MANAGEMENT'S DISCUSSION AND ANALYSIS
In the three months and year ended December 31, 2014, the average realized price across all products was $64.41 per Boe and $78.16
per Boe, respectively. For the three months and year ended December 31, 2014, the average realized price was lower by $8.52 per Boe
and higher by $4.73 per Boe, respectively, compared to the Corresponding Periods.
Average Benchmark Prices:
Crude oil – WTI (US$ per Bbl)
Crude oil – Edmonton Par (CDN$ per Bbl)
Natural gas – AECO Daily Spot ($ per Mcf)
Natural gas – AECO Monthly Spot ($ per Mcf)
Exchange rate – (CDN$/US$)
Three months
ended
Dec 31, 2014
Three months
ended
Dec 31, 2013
Year ended
Dec 31, 2014
Year ended
Dec 31, 2013
$73.12
$75.52
$3.24
$3.61
1.14
$97.44
$86.75
$3.18
$2.84
1.05
$92.92
$94.44
$4.04
$3.98
1.10
$97.96
$93.40
$2.86
$2.85
1.03
Revenues
($ thousands)
Crude oil
NGL
Natural gas
Three months
ended
Dec 31, 2014
$65,417
1,565
3,872
$70,854
Three months
ended
Dec 31, 2013
$63,828
1,736
2,642
$68,206
Year ended
Dec 31, 2014
$294,988
8,450
17,891
$321,329
Year ended
Dec 31, 2013
$150,923
5,046
8,105
$164,074
Revenues in the three months and year ended December 31, 2014 increased compared to the Corresponding Periods, despite a 25%
and 5% decrease in US$ WTI oil prices, respectively. This increase in revenues is due to the Company's on-going drilling activities, the
addition of production from the Asset Acquisitions, and in the year-over-year increase, the SE Saskatchewan Acquisition which closed on
September 9, 2013.
Revenues from the sale of crude oil and NGL continue to be greater than 90% of all revenues.
Royalties
($ thousands, unless otherwise noted)
Royalties
$ per Boe
Percentage of revenue
Three months
ended
Dec 31, 2014
$12,338
$11.22
17%
Three months
ended
Dec 31, 2013
$10,730
$11.47
16%
Year ended
Dec 31, 2014
$53,539
$13.02
17%
Year ended
Dec 31, 2013
$24,353
$10.90
15%
Compared to the Corresponding Periods, the Company's corporate royalty rate (as a percentage of revenue) increased slightly in the
three months and year ended December 31, 2014. The year-over-year increase in royalties is primarily due to higher royalty rates
associated with the assets from the SE Saskatchewan Acquisition (at approximately 19% of revenue and includes the Saskatchewan
Resource Tax) which closed in September 2013. The increase in royalties is also due to Crown royalty incentives that have expired for
certain wells, as well as certain wells that were drilled which did not qualify for the Crown royalty incentives.
TORC Oil & Gas Ltd. Q4 2014 Page 4
MANAGEMENT'S DISCUSSION AND ANALYSIS
Operating Expenses
($ thousands, unless otherwise noted)
Operating expenses
$ per Boe
Three months
ended
Dec 31, 2014
$14,408
$13.10
Three months
ended
Dec 31, 2013
$12,386
$13.24
Year ended
Dec 31, 2014
$52,953
$12.88
Year ended
Dec 31, 2013
$26,431
$11.83
For the three months ended December 31, 2014, operating expenses on a per Boe basis remained similar compared to the three months
ended December 31, 2013.
For the year ended December 31, 2014, operating expenses on a per Boe basis increased 9% compared to the year ended
December 31, 2013. This year-over-year increase primarily reflects the higher operating costs associated with the properties acquired in
the SE Saskatchewan Acquisition (approximately $4 per Boe more, compared to the Company's Alberta properties).
Transportation Expenses
($ thousands, unless otherwise noted)
Transportation expenses
$ per Boe
Three months
ended
Dec 31, 2014
$2,222
$2.02
Three months
ended
Dec 31, 2013
$2,154
$2.30
Year ended
Dec 31, 2014
$10,009
$2.43
Year ended
Dec 31, 2013
$8,156
$3.65
For the three months and year ended December 31, 2014, the Company's transportation expenses per Boe decreased 12% and 33%,
respectively, compared to the Corresponding Periods. This largely reflects the benefits associated with further development of
infrastructure, economies of scale associated with greater volumes, and lower transportation costs associated with the properties
acquired in the SE Saskatchewan Acquisition which closed in September 2013.
Operating Netbacks
($ per Boe, unless otherwise noted)
Average daily production (Boepd)
Crude oil ($ per Bbl)
NGL ($ per Bbl)
Natural gas ($ per Mcf)
Average price prior to hedging
Realized gain (loss) on financial derivatives (hedging)
Royalties
Operating
Transportation
Operating netback
Operating netback (prior to hedging)
Three months
ended
Dec 31, 2014
Three months
ended
Dec 31, 2013
Year ended
Dec 31, 2014
Year ended
Dec 31, 2013
11,957
$73.31
$40.99
$3.83
$64.41
$3.94
(11.22)
(13.10)
(2.02)
$42.01
$38.07
10,166
$81.73
$54.50
$3.61
$72.93
$1.08
(11.47)
(13.24)
(2.30)
$47.00
$45.92
11,264
$89.25
$53.06
$4.62
$78.16
($0.04)
(13.02)
(12.88)
(2.43)
$49.79
$49.83
6,121
$87.11
$53.92
$3.31
$73.43
($0.07)
(10.90)
(11.83)
(3.65)
$46.98
$47.05
TORC Oil & Gas Ltd. Q4 2014 Page 5
MANAGEMENT'S DISCUSSION AND ANALYSIS
General and Administrative Expenses
During the three months and year ended December 31, 2014, the Company incurred the following general and administrative expenses
("G&A"):
($ thousands)
Gross general and administrative expenses
Recoveries (1)
Capitalized general and administrative expenses (2)
Total general and administrative
$ per Boe
Three months
ended
Dec 31, 2014
$5,377
(748)
(1,817)
$2,812
$2.56
Three months
ended
Dec 31, 2013
$4,114
(578)
(1,336)
$2,200
$2.35
Year ended
Dec 31, 2014
$18,379
(2,218)
(6,422)
$9,739
$2.37
Year ended
Dec 31, 2013
$13,148
(2,086)
(3,990)
$7,072
$3.17
(1)
(2)
Recoveries refers to those G&A expenditures which under industry practice are reclassified to operating expenses, exploration
and evaluation assets, or property, plant and equipment, dependent on their nature.
Capitalized general and administrative expenses are those G&A expenditures which are directly attributable to the acquisition or
exploration activities of the Company, and are therefore reclassified to exploration and evaluation assets, or property, plant and
equipment, dependent on their nature.
Total general and administrative expenses in the three months and year ended December 31, 2014 increased 28% and 38%,
respectively, compared to the Corresponding Periods. These increases were due to additional employees (resulting in additional
employee compensation costs) and other administrative costs largely associated with the Company's growing operations. However, for
the year ended December 31, 2014, G&A per Boe decreased 25% compared to the year ended December 31, 2013, reflecting improving
G&A efficiencies on a Boe basis due to the Company's growth.
Finance Costs
($ thousands)
Interest expense and financing charges
Accretion on decommissioning obligations
Total
$ per Boe
Three months
ended
Dec 31, 2014
$1,660
751
$2,411
$2.19
Three months
ended
Dec 31, 2013
$975
651
$1,626
$1.74
Year ended
Dec 31, 2014
$6,211
2,819
$9,030
$2.20
Year ended
Dec 31, 2013
$1,387
905
$2,292
$1.02
For the three months and year ended December 31, 2014, interest expense and financing charges increased compared to the
Corresponding Periods primarily due to the Company's higher bank debt, incurred largely in connection with the Asset Acquisitions, the
SE Saskatchewan Acquisition and ongoing business activities.
For the three months and year ended December 31, 2014, accretion on decommissioning obligations increased compared to the
Corresponding Periods due to the additional decommissioning obligations assumed by the Company largely in connection with the Asset
Acquisitions, the SE Saskatchewan Acquisition, as well as ongoing drilling activities.
Under IFRS, non-cash accretion expenses related to decommissioning obligations are presented as part of finance costs.
Average bank debt was as follows:
($ thousands)
Bank debt
Three months
ended
Dec 31, 2014
$168,477
Three months
ended
Dec 31, 2013
$81,637
Year ended
Dec 31, 2014
$133,304
Year ended
Dec 31, 2013
$32,492
TORC Oil & Gas Ltd. Q4 2014 Page 6
MANAGEMENT'S DISCUSSION AND ANALYSIS
Stock-Based Compensation Expenses
Stock-based compensation expenses reflect the value ascribed to the non-cash compensation provided by the Company, and were
calculated utilizing a fair value assessment methodology. These amounts are net of stock-based compensation costs capitalized to
exploration and evaluation assets, and property, plant and equipment when they are related to exploration or acquisition activities (in the
same manner that G&A expenses are capitalized).
($ thousands)
Stock-based compensation expenses
Capitalized stock-based compensation expenses
Total
$ per Boe
Three months
ended
Dec 31, 2014
$3,425
(1,777)
$1,648
$1.50
Three months
ended
Dec 31, 2013
$4,316
(2,121)
$2,195
$2.35
Year ended
Dec 31, 2014
$20,893
(10,446)
$10,447
$2.54
Year ended
Dec 31, 2013
$6,714
(3,319)
$3,395
$1.52
For the three months ended December 31, 2014, stock-based compensation expenses net of capitalized amounts decreased compared
to the same period in 2013, both on a dollar value and on a per Boe basis. This decrease reflects the initially higher stock-based
compensation expenses related to the restricted awards and performance awards granted in October 2013 (the "Share Awards"), which
were granted to the Company's directors, officers and employees, as part of the Company's business model transition to a dividend plus
growth company.
For the year ended December 31, 2014, stock-based compensation expenses net of capitalized amounts increased compared to the
same period in 2013, both on a dollar value and on a per Boe basis. This increase reflects a full twelve months of stock-based
compensation expenses related to the Share Awards in the year ended December 31, 2014, compared to approximately three months of
stock-based compensation expenses related to the Share Awards in the year ended December 31, 2013.
Depletion and Depreciation Expenses
For the three months and year ended December 31, 2014, the Company's depletion and depreciation expenses totaled $29.2 million
($26.56 per Boe) and $114.4 million ($27.82 per Boe), respectively, compared to the Corresponding Periods of $25.4 million ($27.17 per
Boe) and $59.9 million ($26.81 per Boe), respectively.
For the three months and year ended December 31, 2014, the depletion and depreciation expenses on a total dollar basis increased 15%
and 91%, respectively, compared to the Corresponding Periods. This increase is largely due to depletable base additions, primarily from
acquisitions (including the Asset Acquisitions and SE Saskatchewan Acquisition), as well as on-going drilling operations. On a per Boe
basis, for the three months and year ended December 31, 2014, the depletion and depreciation expenses remained relatively consistent
compared to the Corresponding Periods.
Impairment
For the year ended December 31, 2014, the Company recognized impairment of $72.6 million (year ended December 31, 2013: $38.4
million) on exploration and evaluation ("E&E") assets related to certain southern Alberta projects with carrying values exceeding the
recoverable amounts. As at December 31, 2014, the Company determined there to be a trigger regarding these E&E Assets, based on
the Company's near term plans to reduce capital allocated to these exploratory projects given the current depressed crude oil price
environment. As a result the Company impaired these E&E Assets principally comprised of historic land acquisition costs. In the prior
year, for certain southern Alberta projects, the impairment expense related to the excess of carrying values compared to recoverable
values when costs were transferred from E&E Assets to PP&E upon technical feasibility and commercial viability being determined.
Taxes
For the three months and year ended December 31, 2014, the Company recorded a deferred income tax recovery of $8.4 million and a
deferred income tax expense of $6.9 million, respectively (Corresponding Periods: deferred income tax recovery of $4.0 million and a
deferred income tax expense of $1.9 million, respectively). The increase is consistent with the Company's higher pre-tax income (loss) in
the three months and year ended December 31, 2014, compared to the Corresponding Periods.
TORC Oil & Gas Ltd. Q4 2014 Page 7
MANAGEMENT'S DISCUSSION AND ANALYSIS
Net Income
Net income (loss) for the three months and year ended December 31, 2014 were $(30.4) million and $6.3 million, respectively
(Corresponding Periods: $(17.8) million and $(10.1) million, respectively). A larger E&E impairment expense in the three months ended
December 31, 2014, compared to the same period in 2013, resulted in a higher net loss in the fourth quarter of 2014. Despite this larger
E&E impairment expense, the Company recorded net income for the year ended December 31, 2014, compared to a net loss in the
previous year, primarily due to increased production and higher realized commodity prices.
Basic net income (loss) per share for the three months and year ended December 31, 2014 were $(0.32) and $0.07, respectively
(Corresponding Periods: $(0.20) and $(0.18), respectively).
Diluted net income (loss) per share for the three months and year ended December 31, 2014 were $(0.32) and $0.07, respectively
(Corresponding Periods: $(0.20) and $(0.18), respectively).
Funds Flow from Operations, excluding Transaction Related Costs
Funds flow from operations, excluding transaction related costs for the three months and year ended December 31, 2014 was $41.7
million and $188.7 million, respectively (Corresponding Periods: $40.8 million and $96.5 million, respectively).
Basic funds flow from operations, excluding transaction related costs per share for the three months and year ended December 31, 2014
was $0.43 and $2.02, respectively (Corresponding Periods: $0.45 and $1.76, respectively). Diluted funds flow from operations, excluding
transaction related costs per share for the three months and year ended December 31, 2014 was $0.43 and $1.97, respectively
(Corresponding Periods: $0.44 and $1.72, respectively).
For the year ended December 31, 2014, funds flow from operations increased on a total dollar basis (as well as on a basic and diluted
per share basis) compared to the year ended December 31, 2013, primarily due to increased production from drilling and acquisitions, as
well as a higher crude oil weighting in the Company's production mix.
Net Cash from Operating Activities
Net cash from operating activities for the three months and year ended December 31, 2014 was $72.2 million and $199.0 million,
respectively (Corresponding Periods: $46.9 million and $78.8 million, respectively).
Basic net cash from operating activities per share for the three months and year ended December 31, 2014 was $0.75 and $2.13,
respectively (Corresponding Periods: $0.51 and $1.44, respectively).
Diluted net cash from operating activities per share for the three months and year ended December 31, 2014 was $0.74 and $2.08,
respectively (Corresponding Periods: $0.50 and $1.40, respectively).
Compared to the Corresponding Periods, the increased net cash from operating activities on a total dollar basis (as well as on a basic
and diluted per share basis) for the three months and year ended December 31, 2014, is primarily due to increased production from
drilling and acquisitions.
TORC Oil & Gas Ltd. Q4 2014 Page 8
MANAGEMENT'S DISCUSSION AND ANALYSIS
Capital Expenditures
Capital expenditures are summarized as follows:
($ thousands)
Cash:
Land retention costs
Geological and geophysical (disposition)
Drilling and completions
Equipment and facilities
Administrative assets
Exploration and development expenditures
Capitalized general and administrative expenses
Exploration and development expenditures,
including capitalized G&A
Property acquisitions, net of dispositions
Total capital expenditures - cash items
Non-cash:
Property acquisition (disposition)
Gain on disposition of undeveloped land
Decommissioning obligations
Capitalized stock-based compensation
Total capital expenditures
Three months
ended
Dec 31, 2014
Three months
ended
Dec 31, 2013
Year ended
Dec 31, 2014
Year ended
Dec 31, 2013
$103
(168)
29,816
5,406
32
35,189
1,817
37,006
44,907
$81,913
-
-
2,089
1,777
$85,779
$119
591
47,212
12,061
92
60,075
1,336
61,411
(4,859)
$56,552
-
5,000
(868)
2,120
$62,804
$559
(31)
114,896
19,827
138
135,389
6,422
141,811
137,037
$278,848
(64)
-
10,153
10,446
$299,383
$609
900
121,673
30,448
161
153,791
3,990
157,781
489,954
$647,735
1,631
5,000
80,906
3,318
$738,590
In the three months and year ended December 31, 2014, the Company drilled 14 (8.5 net) wells and 47 (30.7 net) wells, respectively. In
the Corresponding Periods, the Company drilled 21 (12.8 net) wells and 42 (26.5 net), respectively.
As described in the Asset Acquisitions section above, during year ended December 31, 2014, the Company acquired various properties
and working interests in its core Cardium and southeast Saskatchewan areas. The total cash consideration paid was approximately
$137.2 million after customary purchase price adjustments.
The Company does not set a budget for acquisitions. When making acquisitions, the Company considers opportunities that align with
strategic parameters and evaluates and finances each prospect on a case-by-case basis.
Share Capital
Weighted average outstanding common shares:
Basic
Diluted
Outstanding Securities:
Common shares
Stock options
Incentive shares
Restricted awards
Performance awards
Warrants
Three months
ended
Dec 31, 2014
Three months
ended
Dec 31, 2013
Year ended
Dec 31, 2014
Year ended
Dec 31, 2013
96,087,489
97,815,323
91,257,722
92,929,448
93,320,376
95,823,544
54,900,265
56,120,796
96,765,123
1,631,686
68,668
1,121,715
1,710,755
2,345,756
91,423,437
1,640,195
129,183
1,249,373
1,818,018
3,480,000
96,765,123
1,631,686
68,668
1,121,715
1,710,755
2,345,756
91,423,437
1,640,195
129,183
1,249,373
1,818,018
3,480,000
In the year ended December 31, 2014, 1,134,244 Warrants were exercised for total cash proceeds of $8.1 million. At
December 31, 2014, there were 2.3 million Warrants outstanding of which 1.2 million of the Warrants were exercisable. The Warrants
expire on December 16, 2015, five years from the date of grant.
(continued)
TORC Oil & Gas Ltd. Q4 2014 Page 9
MANAGEMENT'S DISCUSSION AND ANALYSIS
The Company is authorized to issue an unlimited number of common shares and an unlimited number of preferred shares, issuable in
series.
As at March 5, 2015, the Company had 113,089,640 common shares issued and outstanding, 1,623,798 stock options outstanding,
62,775 incentive shares outstanding, 1,783,903 performance awards outstanding, 1,136,056 restricted awards outstanding, and
2,345,756 warrants outstanding.
Liquidity and Capital Resources
The Company's net debt, as defined above in Non-IFRS Measurements , is as follows:
Current assets (excluding financial derivative assets)
Less: current liabilities (excluding financial derivative liabilities)
Less: bank debt
Less: non-current deferred lease incentives
Net debt
As at
Dec 31, 2014
$24,754
(89,459)
(179,849)
(104)
($244,658)
As at
Dec 31, 2013
$50,068
(109,971)
(85,000)
(280)
($145,183)
Despite the Company's net debt position, it believes that cash flow from operations, combined with undrawn credit facility and its ability to
access additional funding from capital markets, will provide sufficient resources for it to execute its business plans for the foreseeable
future.
The Company may access the following capital resources:
Credit facility
At December 31, 2014, the Company had a reserves-based revolving credit facility of $425 million with a syndicate of banks (the "Credit
Facility"), comprised of a $40 million operating facility from the operating lender (the "Operating Facility") and a $385 million syndicated
facility with a syndicate of banks (the "Syndicated Facility"). Advances under the Credit Facility are available by way of direct advances,
bankers' acceptances and standby letters of credit/guarantees. Direct advances bear interest at the prime rate, U.S. base rate or Libor
rate, as applicable, plus a margin which is dependent on the Company's debt to trailing funds flow ratio. The bankers' acceptances bear
interest at the applicable bankers' acceptance rate plus a stamping fee, based on the Company's debt to trailing funds flow ratio.
Both the Syndicated Facility and the Operating Facility are available on a revolving basis until April 28, 2015. On or before April 28,
2015, at TORC's request and subject to the approval of the lending syndicate, the Credit Facility may be extended for an additional 364
day period. In the event of non-extension, the undrawn portion of the Credit Facility will be cancelled and the amount outstanding will
convert to a 364 day non-revolving term facility with repayment of the Credit Facility due on April 28, 2016. The Credit Facility is secured
by a fixed and floating charge debenture on all of the Company's assets.
The borrowing base is primarily based on reserves and commodity prices estimated by the lenders. The borrowing base of the
Company's Credit Facility is subject to review and redetermination by the lenders on a semi-annual basis and in the event of a change in
the Company's borrowing base properties (including due to a disposition of assets beyond certain defined limits or a change which results
in a material adverse effect, as determined by the lenders). In the normal course, the Company's next credit facility evaluation is due to
be completed by April 28, 2015.
Significant investor
The Company has a significant investor, the CPP Investment Board (“CPPIB”). For so long as CPPIB owns greater than 10% of the
outstanding common shares of the Company, it has the right to participate in future offerings of securities by the Company, whether by
way of public offering or private placement. This includes any offering of common shares and securities convertible or exchangeable into
common shares, up to its pro rata ownership interest immediately prior to such offering in the case of a public offering or a private
placement to five or more investors, in order to maintain its pro rata percentage ownership interest in the Company, and up to all of the
offering in the case of a private placement to less than five investors.
TORC Oil & Gas Ltd. Q4 2014 Page 10
MANAGEMENT'S DISCUSSION AND ANALYSIS
Risk Management - Financial Derivatives
From time to time, the Company may enter into commodity price, interest rate and foreign exchange rate derivative contracts (also known
as hedges) in order to protect acquisition economics and provide some stability of cash flows for capital spending planning purposes.
Commodity prices, interest rates and foreign exchange rates fluctuate due to economic and political events. As well, commodity prices
may fluctuate due to weather conditions and changes in supply and demand. The Company’s risk management activities are conducted
pursuant to the Company’s risk management policies approved by the Board of Directors.
At December 31, 2014, the Company had the following commodity contracts outstanding:
Remaining term
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Mar 31, 2015
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Dec 31, 2015
Type
Costless Collar
Costless Collar
Costless Collar
Differential Swap
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Volume
(Bbl/d)
500
250
250
500
250
250
250
250
250
250
250
250
250
250
Price
(per Bbl in Canadian dollars)
$95.00 - $106.25
$90.00 - $110.55
$90.00 - $112.00
$8.50
$90.00 - $108.00
$90.00 - $109.55
$90.00 - $111.00
$90.00 - $111.25
$90.00 - $112.75
$90.00 - $108.15
$90.00 - $111.75
$90.00 - $111.75
$90.00 - $113.75
$90.00 - $115.85
Reference
C$WTI
C$WTI
C$WTI
C$ Edm
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
At December 31, 2014, the mark-to-market value of these commodity contracts totaled an asset of $24.6 million.
Contractual Obligations
The following table lists the Company's contractual obligations as at December 31, 2014 and the expected timing of these obligations:
($ thousands)
Trade and other payables
Dividends payable
Operating leases (office rent)
Bank debt
Total
Operating commitments
Total
$84,928
4,354
1,990
179,849
$271,121
Less than
1 year
$84,928
4,354
1,257
-
$90,539
1-2 years
-
-
733
179,849
$180,582
3-5 years
-
-
-
-
-
Thereafter
-
-
-
-
-
The Company is, or will be, obligated to pay various costs associated with operations incurred in the normal course of business. These
costs include royalties paid to provincial governments, surface lease rentals and mineral rights to various landowners, abandonment and
reclamation costs, farm-in commitments and office leases. These costs are highly dependent on the future operating environment and
are subject to changes in commodity prices, ownership, production volumes and government policies.
Working capital
The Company manages the pace of its capital spending related to drilling operations by continuously monitoring production, commodity
prices and resulting cash flows. Should circumstances affect cash flow in a detrimental way, the Company is capable of reducing its
capital spending levels.
The industry has a pre-arranged monthly clearing day for payment of revenues from all buyers of crude oil, NGL and natural gas. This
occurs on the 25th day following the month of sale. As a result, the Company’s production revenues are collected in an orderly fashion.
To the extent that the Company has joint venture partners in its activities it collects the partners’ share of capital and operating expenses
on a monthly basis. These are subject to normal collection risk.
(continued)
TORC Oil & Gas Ltd. Q4 2014 Page 11
MANAGEMENT'S DISCUSSION AND ANALYSIS
Accounts payable consist of amounts payable to suppliers relating to capital spending, field operating activities and office expenses.
These invoices are processed within the Company’s normal payment cycle.
Business Conditions and Risks
The Company is engaged in the acquisition, exploration, development and production of crude oil and natural gas assets. TORC’s
business is inherently risky and there is no assurance that hydrocarbon reserves will be discovered and economically produced.
Financial risks associated with the petroleum industry include fluctuations in commodity prices, interest rates, currency exchange rates,
and the ability to access debt and equity financing at reasonable cost. Operational risks include competition, environmental factors,
reservoir performance uncertainties, a complex regulatory environment and safety concerns.
TORC uses its technical, technological and industry knowledge to evaluate potential hydrocarbon plays in order to pay what it believes
are economically sound prices that benefit shareholders. The Company's focus is on areas in which the prospects are understood by
management.
The Company minimizes its business risks by operating a large number of its properties. This enables TORC to control the timing,
direction and costs related to exploration and development opportunities. TORC’s geological focus is on areas in which the prospects are
understood by management. Technological tools are regularly used to reduce risk and increase the probability of success.
The Company complies with all government regulations and has an up-to-date emergency response plan that has been communicated to
field operations by management. The Company also carries insurance coverage to protect itself against potential losses. Maintaining a
highly motivated and talented staff of petroleum and natural gas professionals further minimizes the business risk.
TORC relies on appropriate sources of funding to support the various stages of its business strategy:
●
●
●
Internally-generated cash flow from production is used to fund business activities;
New equity, if available on favourable terms, may be utilized to fund acquisitions and to expand capital programs, when
appropriate; and
Debt may be utilized to fund acquisitions and to expand capital programs.
The Company is exposed to commodity price and market risk for its principal products of crude oil and natural gas. Commodity prices are
influenced by a wide variety of factors, most of which are beyond TORC’s control. To manage this risk, from time to time, the Company
may enter into a number of financial derivative contracts for hedging purposes. These derivative contracts may include contracts related
to crude oil and natural gas prices, as well as foreign exchange and interest rates. The Company may also, from time to time, enter into
fixed physical contracts. The Company monitors the cost and associated benefit of these instruments and contracts as well as any debt
levels and utilization rates on bank lines, and utilizes these derivatives and contracts when warranted.
Inflation risks subject the Company to potential erosion of product netbacks. For example, increasing domestic prices for oil and natural
gas production equipment and services can inflate the costs of operations. In addition, increasing costs of undeveloped land can inflate
costs of both asset and corporate acquisitions.
The supply of service and production equipment at competitive prices is critical to the ability to add reserves at a reasonable cost and
produce them in an economic and timely fashion. In periods of increased activity, these services and supplies can become difficult to
obtain. The Company attempts to mitigate this risk by developing strong long-term relationships with suppliers and contractors and
maintaining an appropriate inventory of production equipment.
Demand for crude oil, NGL and natural gas produced by the Company exists within Canada and the United States; however, crude oil
prices are affected by worldwide supply and demand fundamentals while natural gas prices are currently primarily affected by North
American supply and demand fundamentals. Demand for natural gas liquids is influenced mainly by the demand for petrochemicals in
North American and off-shore markets. TORC mitigates these risks as follows:
●
●
●
●
TORC attempts to explore for and produce crude oil that is of high quality, mitigating its exposure to adverse quality differentials;
Natural gas production will generally be connected to established pipeline infrastructures that operate with minimal interruptions;
Sale arrangements will vary in term and pricing structure creating a diverse portfolio that minimizes risk of exposure to any one
market; and
Financial derivative contracts may be used where appropriate to manage commodity price volatility.
TORC Oil & Gas Ltd. Q4 2014 Page 12
MANAGEMENT'S DISCUSSION AND ANALYSIS
Off Balance Sheet Arrangements
TORC is not involved with any contractual arrangement under which a non-consolidated entity may have an obligation under certain
guarantee contracts, a retained or contingent interest in assets transferred to a non-consolidated entity or similar arrangement that serves
as credit, liquidity or market risk support to that entity for such assets. TORC has no obligation under financial instruments or a variable
interest in an unconsolidated entity that provides financing, liquidity, market risk or credit risk support to the Company.
Critical Accounting Estimates
The preparation of financial statements in conformity with IFRS requires management to make judgments, estimates and assumptions
that affect the application of accounting policies and the reported amounts of assets, liabilities, income and expenses. Estimates and
underlying assumptions are reviewed on an ongoing basis. Actual results may differ from these estimates.
Reserves
The estimation of reserves is critical to various accounting estimates. It requires judgments based on available geophysical, geological,
engineering and economic data. These estimates can change materially as information from ongoing exploratory, development and
production activities becomes available. These estimates can also change as economic conditions impacting crude oil and natural gas
prices, royalties and operating costs change. Reserve estimates can change net income through depletion expense, accretion expense
from decommissioning obligations and the application of impairment tests. Revisions or changes in reserve estimates can have either a
positive or a negative impact on net income.
Decommissioning obligations
The calculation of decommissioning obligations is based on estimated costs to abandon and reclaim its net ownership in all wells and
facilities, the estimated timing of the costs to be incurred and economic inflation and discount rates. These estimates can change due to
technological advances, governmental and regulatory laws and regulations or economic conditions and can impact the amount of the
decommissioning obligations and net income.
Stock-based compensation
The Company’s estimate of stock-based compensation is dependent upon estimates of historic volatility, forfeiture rates and an
assessment of achieving performance conditions. These estimates can impact net income and contributed surplus.
Financial derivatives
By their very nature, the estimated fair value of financial derivative contracts resulting in financial derivative contract assets and
liabilities are subject to measurement uncertainty.
Deferred income taxes
The calculation of deferred income taxes includes estimates of reversal of temporary differences, tax rates substantively enacted and
likelihood of assets being realized. These estimates can impact net income and deferred tax liabilities.
Environmental Regulation and Risk
The oil and gas industry has various environmental risks subject to regulation by various governmental bodies. Environmental legislation
includes, but is not limited to, operational controls, site restoration and abandonment requirements and restrictions on emissions of
various substances related to the production of oil and natural gas. Compliance with this legislation may require additional costs and a
failure to comply may result in fines and penalties.
TORC is committed to minimizing the environmental impact from its operations through an environmental program which includes
stakeholder communication, resource conservation and site restoration.
TORC Oil & Gas Ltd. Q4 2014 Page 13
MANAGEMENT'S DISCUSSION AND ANALYSIS
Disclosure Controls and Internal Controls Over Financial Reporting
Disclosure controls
The Chief Executive Officer and Chief Financial Officer are responsible for the design and operating effectiveness of internal controls
over financial reporting ("ICFR") and disclosure controls and procedures ("DC&P") of the Company.
Internal control over financial reporting
During 2014, the Company completed its transition to the new COSO (2013) Internal Control framework and applied the framework in
evaluating internal control design and operating effectiveness.
In accordance with National Instrument NI 52-109, the Chief Executive Officer and Chief Financial Officer have filed certifications stating
that DC&P and ICFR of the Company have been adequately designed and that there have been no changes in ICFR that have materially
affected, or are reasonably likely to materially affect, ICFR.
Additional Information
Additional information can be obtained by contacting the Company at TORC Oil & Gas Ltd., Suite 1800, Eighth Avenue Place, 525 - 8th
Avenue SW, Calgary, Alberta, Canada T2P 1G1. Additional information is also available on www.sedar.com and on the Company's
website www.torcoil.com.
TORC Oil & Gas Ltd. Q4 2014 Page 14
MANAGEMENT'S DISCUSSION AND ANALYSIS
Summary of Quarterly and Annual Results
(in $000's of dollars, except per share
amounts)
Q4 2014
(1)
Q3 2014
Q2 2014
Q1 2014
Q4 2013
(1)
Q3 2013 Q2 2013 Q1 2013
Petroleum and natural gas sales
70,854
83,798
87,509
79,168
68,206
41,717
28,117
26,034
Net income (loss)
Per share – basic (2)
Per share – diluted (2)
Funds flow from operations, including
transaction related costs (3)
Per share – basic (2)
Per share – diluted (2)
Funds flow from operations, excluding
transaction related costs (3)
Per share – basic (2)
Per share – diluted (2)
Net cash from operating activities (4)
Per share – basic (2)
Per share – diluted (2)
(30,411)
(0.32)
(0.32)
15,146
0.16
0.16
41,710
0.43
0.43
41,748
0.43
0.43
72,191
0.50
0.48
49,005
0.52
0.51
49,029
0.52
0.51
46,236
0.50
0.48
13,494
0.15
0.14
50,655
0.55
0.53
50,735
0.55
0.53
42,436
0.46
0.45
8,029
0.09
0.09
(17,841)
(0.20)
(0.20)
3,287
0.06
0.06
3,340
0.09
0.09
1,130
0.03
0.03
47,207
0.52
0.50
47,207
0.52
0.50
38,119
0.42
0.40
41,458
0.45
0.45
40,769
0.45
0.44
46,912
0.51
0.50
16,223
0.32
0.32
16,580
0.43
0.42
15,274
0.40
0.38
24,163
0.48
0.47
6,055
0.12
0.12
16,397
0.42
0.42
16,153
0.42
0.41
15,274
0.40
0.38
9,665
0.25
0.24
Total assets
1,326,891
1,325,007
1,273,256
1,214,575
1,215,153
1,200,628
611,283
627,989
Total long-term financial liabilities
301,176
265,212
252,502
198,189
183,725
194,647
29,006
25,995
Dividends declared per share
0.1350
0.1350
0.1350
0.1350
0.1283
0.0417
-
-
Net working capital (net debt) (5)
(244,658)
(213,391)
(181,169)
(145,528)
(145,183)
(121,486)
(2,088)
38
(footnotes on next page)
TORC Oil & Gas Ltd. Q4 2014 Page 15
MANAGEMENT'S DISCUSSION AND ANALYSIS
(in $000's of dollars, except per share
amounts)
Year ended
Dec 2014 (1)
Year ended
Dec 2013 (1)
Year ended
Dec 2012 (1)
Petroleum and natural gas sales
321,329
164,074
32,711
Net income (loss)
Per share – basic (2)
Per share – diluted (2)
Funds flow from operations, including
transaction related costs (3)
Per share – basic (2)
Per share – diluted (2)
Funds flow from operations, excluding
transaction related costs (3)
Per share – basic (2)
Per share – diluted (2)
Net cash from operating activities (4)
Per share – basic (2)
Per share – diluted (2)
Total assets
Total long-term financial liabilities
Dividends declared per share
Net working capital (net debt) (5)
6,258
0.07
0.07
188,577
2.02
1.97
188,719
2.02
1.97
198,982
2.13
2.08
(10,084)
(0.18)
(0.18)
89,536
1.63
1.60
96,512
1.76
1.72
78,785
1.44
1.40
(18,767)
(0.81)
(0.81)
13,396
0.58
0.54
17,193
0.74
0.69
8,514
0.37
0.34
1,326,891
1,215,153
627,457
301,176
0.5400
183,725
20,806
0.1700
-
(244,658)
(145,183)
35,077
(1)
(2)
(3)
(4)
(5)
The diluted number of shares is equivalent to the basic number of shares due to stock options, incentive shares, performance and restricted awards, and/or warrants being
antidilutive in periods where the Company has a "net loss" or "net cash used in operating activities". Therefore, the diluted per share amounts in these periods are
equivalent to the basic per share amounts.
In September 2013, the Company consolidated its outstanding common shares, stock options, incentive shares and warrants on a 1 for 5 basis. As a result, the number of
outstanding common shares, stock options, incentive shares and warrants of comparative periods have been reduced by a factor of five, in order for the comparative
common share, stock options, incentive shares, warrants, per share and per diluted share amounts to be equivalent.
"Funds flow from operations, including transaction related costs" and "funds flow from operations, excluding transaction related costs" should not be considered an
alternative to, or more meaningful than, "net cash from (used in) operating activities" as determined in accordance with International Financial Reporting Standards (“IFRS”)
as an indicator of TORC’s performance. "Funds flow from operations, including transaction related costs" represents net cash from (used in) operating activities prior to
changes in non-cash working capital and settlement of decommissioning obligations. "Funds flow from operations, excluding transaction related costs" represents net cash
from (used in) operating activities prior to changes in non-cash working capital, settlement of decommissioning obligations and transaction related costs. TORC also
presents "funds flow from operations, including transaction related costs" and "funds flow from operations, excluding transaction related costs" on a per share basis,
whereby per share amounts are calculated using weighted average shares outstanding consistent with the calculation of earnings per share.
Net cash from operating activities is determined in accordance with IFRS and includes changes in non-cash working capital.
Net working capital (net debt) is calculated as current assets (excluding financial derivative assets) less: i) current liabilities (excluding financial derivative liabilities), ii) bank
debt, and iii) non-current deferred lease incentives.
Since its incorporation on March 23, 2010, the Company has accumulated light oil resource prone acreage and is delineating and developing its
resource base. In November 2012, the Company acquired Vero and completed an equity financing. In September 2013, the Company acquired
significant assets in southeast Saskatchewan, along with another equity financing. In the second, third and fourth quarters of 2014, the
Company acquired various properties and working interests in its core Cardium and southeast Saskatchewan areas. In the fourth quarters of
2012, 2013, and 2014, the Company recorded impairment charges of $13.3 million, $38.4 million, and $72.6 million, respectively, related to its
exploration and evaluation assets, contributing to a net loss for these periods. These events, along with organic drilling growth, have resulted in
an increase in total assets, comprised largely of land and wells, as well as increased petroleum and natural gas sales, influenced by commodity
prices and commodity mix.
TORC Oil & Gas Ltd. Q4 2014 Page 16
Financial Statements
As at and for the years ended
December 31, 2014 and 2013
FINANCIAL STATEMENTS
MANAGEMENT’S STATEMENT OF RESPONSIBILITY
The accompanying financial statements of TORC Oil & Gas Ltd. were prepared by and are the responsibility of management. They have
been prepared in conformity with International Financial Reporting Standards as issued by the International Accounting Standards Board and
include certain assessments that reflect management’s best estimates and judgments. Management has determined such amounts on a
reasonable basis in order to ensure that the financial statements are presented fairly in all material respects. The financial information
contained elsewhere in Management's Discussion and Analysis has been reviewed to ensure consistency with the financial statements.
Management has developed and maintains systems of internal controls designed to provide reasonable assurance that all transactions are
properly recorded in the Company’s financial records, that procedures and policies are adhered to, that the financial statements realistically
report the Company’s operating and financial results, and that assets are safeguarded from unauthorized use. Management believes that this
system of internal controls has operated effectively for the year ended December 31, 2014.
KPMG LLP, an independent firm of chartered accountants, has been engaged to examine the financial statements in accordance with
Canadian generally accepted auditing standards and to provide an independent auditors’ report thereon.
The Board of Directors, through its Audit Committee, has reviewed the financial statements including notes thereto with management and
KPMG LLP. The Audit Committee is composed of three unrelated and independent members of the Board of Directors and meets quarterly
with the financial officers of the Company. KPMG LLP has access to the Audit Committee to review the planning and scope of testing and to
discuss the results of their audit work. On the recommendation of the Audit Committee, the accompanying financial statements have been
approved by the Board of Directors.
(signed)
Brett Herman
President and
Chief Executive Officer
March 5, 2015
Calgary, Canada
(signed)
Jason Zabinsky
Vice President, Finance and
Chief Financial Officer
TORC Oil & Gas Ltd. 2014 Page 1
FINANCIAL STATEMENTS
INDEPENDENT AUDITORS' REPORT
To the Shareholders of TORC Oil & Gas Ltd.
We have audited the accompanying financial statements of TORC Oil & Gas Ltd., which comprise the statements of financial position as at
December 31, 2014 and December 31, 2013, the statements of income (loss) and comprehensive income (loss), changes in equity and cash
flows for the years then ended, and notes, comprising a summary of significant accounting policies and other explanatory information.
Management’s Responsibility for the Financial Statements
Management is responsible for the preparation and fair presentation of these financial statements in accordance with International Financial
Reporting Standards, and for such internal control as management determines is necessary to enable the preparation of financial statements
that are free from material misstatement, whether due to fraud or error.
Auditors’ Responsibility
Our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits in accordance with
Canadian generally accepted auditing standards. Those standards require that we comply with ethical requirements and plan and perform the
audit to obtain reasonable assurance about whether the financial statements are free from material misstatement.
An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the financial statements. The
procedures selected depend on our judgment, including the assessment of the risks of material misstatement of the financial statements,
whether due to fraud or error. In making those risk assessments, we consider internal control relevant to the entity’s preparation and fair
presentation of the financial statements in order to design audit procedures that are appropriate in the circumstances, but not for the purpose
of expressing an opinion on the effectiveness of the entity’s internal control. An audit also includes evaluating the appropriateness of
accounting policies used and the reasonableness of accounting estimates made by management, as well as evaluating the overall
presentation of the financial statements.
We believe that the audit evidence we have obtained in our audits is sufficient and appropriate to provide a basis for our audit opinion.
Opinion
In our opinion, the financial statements present fairly, in all material respects, the financial position of TORC Oil & Gas Ltd. as at December
31, 2014 and December 31, 2013, and its financial performance and its cash flows for the years then ended in accordance with International
Financial Reporting Standards.
(signed)
KPMG LLP
Chartered Accountants
March 5, 2015
Calgary, Canada
TORC Oil & Gas Ltd. 2014 Page 2
TORC Oil & Gas Ltd.
Statements of Financial Position
(in $000's of Canadian dollars)
Assets
Cash and cash equivalents
Trade and other receivables
Deposits and prepaid expenses
Financial derivative asset
Total current assets
Exploration and evaluation assets
Property, plant and equipment
Total non-current assets
Total assets
Liabilities
Trade and other payables
Dividends payable
Deferred lease incentives
Financial derivative liability
Total current liabilities
Bank debt
Deferred premium on flow-through shares
Deferred lease incentives
Decommissioning obligations
Deferred tax liability
Total non-current liabilities
Total liabilities
Equity
Share capital
Contributed surplus
Deficit
Total equity
Total liabilities and equity
Commitments (note 21)
Subsequent events (note 22)
See accompanying notes to the financial statements.
Approved on behalf of the Board
(signed)
Raymond Chan
Director
FINANCIAL STATEMENTS
Note
As at
December 31, 2014
As at
December 31, 2013
20
11
12
16
20
19
21
13
14
15
$
-
22,670
2,084
24,596
49,350
54,596
1,222,945
1,277,541
$
13,626
34,418
2,024
-
50,068
129,093
1,035,992
1,165,085
$
1,326,891
$
1,215,153
$
84,928
4,354
177
-
89,459
179,849
1,925
104
105,670
13,628
301,176
$
105,680
4,114
177
220
110,191
85,000
-
280
93,045
5,400
183,725
$
390,635
$
293,916
$
1,010,428
19,543
(93,715)
936,256
$
958,754
11,881
(49,398)
921,237
$
1,326,891
$
1,215,153
(signed)
Brett Herman
Director
TORC Oil & Gas Ltd. 2014 Page 3
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Statements of Income (Loss) and Comprehensive Income (Loss)
(in $000's of Canadian dollars, except per share amounts)
Three months
ended
Dec 31, 2014
Three months
ended
Dec 31, 2013
Note
Year ended
Dec 31, 2014
Year ended
Dec 31, 2013
Revenues
Petroleum and natural gas sales
Royalties
Realized loss on financial derivatives
Unrealized gain (loss) on financial derivatives
20
Expenses
Operating
Transportation
General and administrative
Transaction related costs
Finance costs
Stock-based compensation
Depletion and depreciation
Gain on disposition of undeveloped land
Impairment of exploration and evaluation assets
Income (loss) before income taxes
Deferred income tax
Income (loss) and comprehensive income (loss)
Income (loss) per share:
Basic
Diluted
See accompanying notes to the financial statements.
6, 7
9
17
12
11
14
18
18
$70,854
(12,338)
58,516
4,334
23,695
86,545
14,408
2,222
2,812
38
2,411
1,648
29,217
-
72,567
125,323
$68,206
(10,730)
57,476
1,008
(1,692)
56,792
12,386
2,154
2,200
(689)
1,626
2,195
25,412
(5,000)
38,355
78,639
$321,329
(53,539)
267,790
(159)
24,816
292,447
52,953
10,009
9,739
142
9,030
10,447
114,360
-
72,567
279,247
$164,074
(24,353)
139,721
(163)
(187)
139,371
26,431
8,156
7,072
6,976
2,292
3,395
59,901
(5,000)
38,355
147,578
(38,778)
(21,847)
13,200
(8,207)
(8,367)
(4,006)
6,942
1,877
($30,411)
($17,841)
$6,258
($10,084)
($0.32)
($0.32)
($0.20)
($0.19)
$0.07
$0.07
($0.18)
($0.18)
TORC Oil & Gas Ltd. 2014 Page 4
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Statements of Changes in Equity
(in $000's of Canadian dollars, unless otherwise noted)
Number of
common shares
(000's)
Number of
warrants
(000's)
Share
capital
Contributed
surplus
Deficit
Total
equity
Balance at December 31, 2012
Issue of common shares (note 15)
Stock-based compensation
Issued on vesting
of incentive shares
Transfer of stock-based
compensation on vesting
of incentive shares
Share issue cost recovery,
net of tax of $5.3 million
Dividends to shareholders (note 16)
Issued pursuant to the share
dividend program (note 16)
Loss for the year
38,585
52,434
-
54
-
-
-
350
-
3,480
$558,630
$6,165
($23,791)
$541,004
-
-
-
-
-
-
-
-
411,607
-
-
-
6,714
-
998
(998)
(15,673)
-
3,192
-
-
-
-
-
-
-
-
-
-
(15,523)
411,607
6,714
-
-
(15,673)
(15,523)
-
3,192
(10,084)
(10,084)
Balance at December 31, 2013
91,423
3,480
$958,754
$11,881
($49,398)
$921,237
Balance at December 31, 2013
Issue of common shares (note 15)
Stock-based compensation
Issued on vesting/exercise of:
Incentive shares
Restricted awards
Performance awards
Stock options
Warrants
Transfer of stock-based
compensation on vesting/exercise of:
Incentive shares
Restricted awards
Performance awards
Stock options
Share issue costs,
net of tax of $0.3 million
Dividends to shareholders (note 16)
Issued pursuant to the share
dividend program (note 16)
Flow-through share liability
Income for the year
91,423
1,442
-
60
424
931
8
1,134
-
-
-
-
-
-
1,343
-
-
3,480
$958,754
$11,881
($49,398)
$921,237
-
-
-
-
-
-
(1,134)
-
-
-
-
-
-
-
-
-
19,710
-
-
-
-
61
8,148
1,000
3,790
8,311
130
(820)
-
14,832
(3,488)
-
-
20,893
-
-
-
-
-
(1,000)
(3,790)
(8,311)
(130)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
19,710
20,893
-
-
-
61
8,148
-
-
-
-
(820)
(50,575)
(50,575)
-
-
6,258
14,832
(3,488)
6,258
Balance at December 31, 2014
96,765
2,346
$1,010,428
$19,543
($93,715)
$936,256
See accompanying notes to the financial statements.
TORC Oil & Gas Ltd. 2014 Page 5
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Statements of Cash Flows
(in $000's of Canadian dollars)
Cash flows from (used in) operating activities:
Income (loss) for the year
Depletion and depreciation
Stock-based compensation
Deferred income tax
Accretion on decommissioning obligations
Unrealized loss (gain) on financial derivatives
Gain on disposition of undeveloped land
Impairment of exploration and evaluation assets
Settlement of decommissioning obligations
Change in non-cash working capital
Net cash from operating activities
Cash flows from (used in) investing activities:
Additions to exploration and evaluation assets
Additions to property, plant and equipment
Property acquisitions
Proceeds from disposition of oil and gas properties
Change in non-cash working capital
Net cash used in investing activities
Cash flows from (used in) financing activities:
Proceeds from bank debt
Proceeds from issue of share capital
Share issue costs
Dividends
Net cash from financing activities
Change in cash and cash equivalents
Cash and cash equivalents, beginning of year
Three months
ended
Dec 31, 2014
Three months
ended
Dec 31, 2013
Year ended
Dec 31, 2014
Year ended
Dec 31, 2013
$
(30,411)
29,217
1,648
(8,367)
751
(23,695)
-
72,567
(225)
30,706
72,191
$
(17,841)
25,412
2,195
(4,006)
651
1,692
(5,000)
38,355
-
5,454
46,912
$
6,258
114,360
10,447
6,942
2,819
(24,816)
-
72,567
(347)
10,752
198,982
$
(10,084)
59,901
3,395
1,877
905
187
(5,000)
38,355
(262)
(10,489)
78,785
(51)
(37,211)
(44,706)
55
(38,039)
(119,952)
38,515
19,710
(965)
(9,499)
47,761
-
-
(10,249)
(53,300)
-
6,914
38,125
(18,510)
(6,572)
-
13
(8,217)
(14,776)
13,626
-
(308)
(141,761)
(137,575)
860
(19,992)
(298,776)
94,849
27,919
(1,097)
(35,503)
86,168
(13,626)
13,626
(43,023)
(119,690)
(488,889)
7,666
31,575
(612,361)
85,000
411,607
(20,903)
(8,217)
467,487
(66,089)
79,715
Cash and cash equivalents, end of year
$
-
$
13,626
$
-
$
13,626
See accompanying notes to the financial statements.
TORC Oil & Gas Ltd. 2014 Page 6
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
1. Reporting entity
TORC Oil & Gas Ltd. (the “Company” or "TORC") was incorporated pursuant to the Business Corporations Act (Alberta) on
March 23, 2010 as 1525893 Alberta Ltd. The Company's name was changed to TORC Oil & Gas Ltd. on December 17, 2010. The
Company's principal business activity is the exploration for and production of petroleum and natural gas in the Western Canadian
Sedimentary Basin.
The Company's principal place of business is located at Suite 1800, Eighth Avenue Place, 525 - 8th Avenue SW, Calgary, Alberta,
Canada T2P 1G1.
2. Basis of preparation
Operating expenses in the statement of income and comprehensive income are presented as a combination of function and nature to
conform with industry practice. Depletion and depreciation is presented on a separate line by its nature, while operating expenses and
general and administrative expenses are presented on a functional basis. Significant expenses such as key management personnel's
short-term employee benefits and stock-based compensation are presented by their nature in the notes to the financial statements.
(a) Statement of compliance
The financial statements have been prepared in accordance with International Financial Reporting Standards ("IFRS") and were
authorized for issue by the Board of Directors on March 5, 2015.
(b) Basis of measurement
The financial statements have been prepared on the historical cost basis, except for derivative financial instruments which are
measured at fair value.
(c) Functional and presentation currency
The financial statements are presented in Canadian dollars, which is the Company’s functional currency.
(d) Use of estimates and judgments
The preparation of financial statements in conformity with IFRS requires management to make judgments, estimates and assumptions
that affect the application of accounting policies and the reported amount of assets, liabilities, income and expenses. Actual results
may differ materially from these estimates.
Estimates and their underlying assumptions are reviewed on an ongoing basis. Revisions to accounting estimates are recognized in
the year in which the estimates are revised and for any future years affected.
Critical judgments in applying accounting policies:
The following are critical judgments that management has made in the process of applying accounting policies and that have the most
significant effect on the amounts recognized in the financial statements.
The Company’s assets are aggregated into cash generating units for the purpose of calculating impairment. Cash generating units
("CGU" or "CGUs") are based on an assessment of the unit’s ability to generate independent cash inflows. The determination of these
CGUs was based on management’s judgment in regards to shared infrastructure, geographical proximity, petroleum type and similar
exposure to market risk and materiality.
(continued)
TORC Oil & Gas Ltd. 2014 Page 7
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
Judgments are required to assess when impairment indicators exist and impairment testing is required. In determining the recoverable
amount of assets, in the absence of quoted market prices, impairment tests are based on estimates of reserves, production rates,
future oil and natural gas prices, future costs, discount rates, market value of land and other relevant assumptions.
The application of the Company’s accounting policy for exploration and evaluation assets requires management to make certain
judgments as to future events and circumstances as to whether economic quantities of reserves will be found so as to assess if
technical feasibility and commercial viability has been achieved.
Judgments are made by management to determine the likelihood of whether deferred income tax assets at the end of the reporting
period will be realized from future taxable earnings.
Key sources of estimation uncertainty:
The following are key estimates and their assumptions made by management affecting the measurement of balances and transactions
in these financial statements.
Estimation of recoverable quantities of proven and probable reserves include estimates and assumptions regarding future commodity
prices, exchange rates, discount rates and production and transportation costs for future cash flows as well as the interpretation of
complex geological and geophysical models and data. Changes in reported reserves can affect the impairment of assets, the
decommissioning obligations, the economic feasibility of exploration and evaluation assets and the amounts reported for depletion,
depreciation and amortization of property, plant and equipment. These reserve estimates are verified by third party professional
engineers, who work with information provided by the Company to establish reserve determinations in accordance with National
Instrument 51-101.
The Company estimates the decommissioning obligations for oil and natural gas wells and their associated production facilities and
pipelines. In most instances, removal of assets and remediation occurs many years into the future. Amounts recorded for the
decommissioning obligations and related accretion expense require assumptions regarding removal date, future environmental
legislation, the extent of reclamation activities required, the engineering methodology for estimating cost, inflation estimates, future
removal technologies in determining the removal cost, and the estimate of the liability specific discount rates to determine the present
value of these cash flows.
In a business combination, management makes estimates of the fair value of assets acquired and liabilities assumed which includes
assessing the value of oil and gas properties based upon the estimation of recoverable quantities of proven and probable reserves
being acquired.
The Company’s estimate of stock-based compensation is dependent upon estimates of historic volatility, forfeiture rates and an
assessment of achieving performance conditions.
The Company’s estimate of the fair value of derivative financial instruments is dependent on estimated forward prices and volatility in
those prices.
The deferred tax liability is based on estimates as to the timing of the reversal of temporary differences, substantively enacted tax rates
and the likelihood of assets being realized.
TORC Oil & Gas Ltd. 2014 Page 8
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
3. Significant accounting policies
The accounting policies set out below have been applied consistently to the years presented in the financial statements by the
Company.
(a) Basis of consolidation
(i) Subsidiaries
Subsidiaries are entities controlled by the Company. Control exists when the Company has the power to govern the financial and
operating policies of an entity so as to obtain benefits from its activities. In assessing control, substantive potential voting rights
are taken into consideration. The financial statements of subsidiaries are included in consolidated financial statements from the
date that control commences until the date that control ceases.
The purchase method of accounting is used to account for acquisitions of subsidiaries and assets that meet the definition of a
business under IFRS. The cost of an acquisition is measured as the fair value of assets given, equity instruments issued and
liabilities incurred or assumed at the date of exchange. Identifiable assets acquired and liabilities assumed in a business
combination are measured initially at their fair values at the acquisition date. The excess of the cost of acquisition over the fair
value of the identifiable assets and liabilities acquired is recorded as goodwill. If the cost of acquisition is less than the fair value
of the net assets of the subsidiary acquired, the difference is recognized immediately in the statement of income and
comprehensive income.
(ii) Jointly owned assets
Many of the Company’s oil and natural gas activities involve jointly owned assets. The financial statements include the
Company’s share of these jointly owned assets and a proportionate share of the relevant revenue and related costs. The
relationships with jointly owned asset partners have been referred to as joint venture in the remainder of the financial statements
as is common in the Canadian oil and gas industry.
(iii) Transactions eliminated on consolidation
Intercompany balances and transactions, and any unrealized income and expenses arising from intercompany transactions, are
eliminated in preparing consolidated financial statements.
(b) Foreign currency
Transactions in foreign currencies are translated to Canadian dollars at exchange rates at the dates of the transactions.
Monetary assets and liabilities denominated in foreign currencies are translated to Canadian dollars at the period end exchange
rate. Non-monetary assets and liabilities denominated in foreign currencies that are measured at fair value are translated to
Canadian dollars at the exchange rate at the date that the fair value was determined. Foreign currency differences arising on
translation are recognized in the statement of income and comprehensive income.
(c) Financial instruments
Non-derivative financial instruments
Non-derivative financial instruments are comprised of cash and cash equivalents including bank overdrafts, trade and other
receivables, trade and other payables, dividends payable and bank debt. Non-derivative financial instruments are recognized
initially at fair value plus any directly attributable transaction costs. Subsequent to initial recognition, non-derivative financial
instruments are measured as described below.
(continued)
TORC Oil & Gas Ltd. 2014 Page 9
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
Cash and cash equivalents:
Cash and short term deposits on the statement of financial position comprise cash at banks and on hand and short term deposits
with an original maturity of three months or less.
For the purpose of the statement of cash flows, cash and cash equivalents consist of cash and cash equivalents defined above,
net of outstanding bank overdrafts.
Other:
Other non-derivative financial instruments, such as bank debt, trade and other receivables, trade and other payables and
dividends payable, are measured at amortized cost using the effective interest method, less any impairment losses.
Derivative financial instruments
The Company may enter into certain financial derivative contracts (often known as "hedges") in order to manage the exposure to
market risks from fluctuations in commodity prices, interest rates and foreign exchange rates. These instruments are not used for
trading or speculative purposes. The Company has not designated its financial derivative contracts as effective accounting
hedges, and thus has not applied hedge accounting, even though the Company considers all commodity contracts to be
economic hedges. As a result, all financial derivative contracts are classified at fair value through profit and loss and are
recorded on the statement of financial position at fair value. Related transaction costs such as trading commissions are
recognized in the statement of income and comprehensive income when incurred.
Forward physical delivery and sales contracts of oil and natural gas products are entered into under normal course of business
and therefore not recorded at fair value on the statement of financial position. These physical delivery contracts are not
considered to be derivative financial instruments or hedges. Settlements on these physical delivery contracts are recognized in
oil and natural gas revenue on the statement of income and comprehensive income.
Share capital
Common shares are classified as equity. Incremental costs directly attributable to the issue of common shares, warrants and
share options are recognized as a deduction from equity, net of any tax effects.
(d) Exploration and evaluation assets ("E&E")
Costs incurred prior to the ownership of licenses and rights to drill on properties are expensed in the statement of income and
comprehensive income as incurred, if the related licenses and rights are not subsequently acquired.
The costs incurred to acquire licenses and rights to drill, including seismic costs, and the subsequent drilling and completing costs
related to these licenses (including employee remuneration, materials and fuel used, rig costs and payments made to contractors)
are capitalized as E&E assets until the drilling of the well is complete and the results have been evaluated.
E&E assets are accumulated in cost centers pending the determination of technical feasibility and commercial viability of the
drilling project. Technical feasibility and commercial viability is considered to be achieved when proven and probable reserves
are determined to exist for a project area. Upon determination of proven and probable reserves, the related E&E assets in the
associated project area are typically reclassified to a different long-term asset category, Property, Plant and Equipment ("PP&E") ,
where the assets may be subject to depletion expense.
E&E assets are measured at cost less accumulated impairment losses and not subject to depletion expense until after these
assets are reclassified to PP&E.
(continued)
TORC Oil & Gas Ltd. 2014 Page 10
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
As facts and circumstances suggest, E&E assets are tested for impairment. The Company compares the carrying amount of its
total E&E assets to the assets' recoverable amount, which, for E&E assets, is generally the fair market value of undeveloped land
at the time of impairment testing. In addition, E&E assets related to specific technically feasible and commercially viable cost
centers are tested for impairment if and when they are reclassified to PP&E. E&E assets are aggregated with the associated
cash generating units for the purposes of impairment testing.
Impairment losses recognized in prior periods are assessed as facts and circumstances suggest to evaluate if those losses have
decreased or no longer exist. If those impairment losses have decreased or no longer exist (recovered), they are reversed
accordingly. Previously recognized impairment losses may be recovered in future reporting periods due to changes in estimates
used to determine the recoverable amount. An impairment loss recovery is recorded only to the extent that the E&E asset’s
carrying amount does not exceed the carrying amount that would have been determined if no impairment loss had been
recognized. Impairment losses and recoveries are recorded in the statement of income and comprehensive income.
(e)
Property, plant and equipment ("PP&E")
There are two categories of PP&E: Developed and Producing ("D&P") assets and Other PP&E assets.
D&P assets include capital costs (i) related to drilling projects where the drilling location is already determined to hold proven
reserves, (ii) that have been reclassified from E&E assets because proven reserves have been determined, and (iii) incurred to
improve an already technically feasible and commercially viable well.
Other PP&E typically includes furniture, fixtures, leasehold improvements and office equipment.
For statement of financial position presentation, both D&P assets and Other PP&E are included in the PP&E category.
(i) Recognition and measurement
PP&E is measured at cost less accumulated depletion and depreciation and accumulated impairment losses. For the purposes of
depletion and depreciation, when significant parts of PP&E have different useful lives, they are accounted for separately so that
depletion and depreciation rates appropriately reflect useful lives.
Gains and losses on disposal of PP&E, property swaps and farm-outs, including oil and natural gas interests, are determined by
comparing the proceeds from disposal of fair value of the asset received or given up, with the carrying amount of the PP&E sold,
and are recognized on a net basis in profit or loss.
For the purposes of impairment testing, assets are grouped into the smallest group of assets that generate independent cash
inflows from continuing use that are largely independent of the cash inflows of other assets or groups of assets. These groups of
assets are called cash generating units ("CGU's").
Impairment testing of PP&E is performed as facts and circumstances suggest by comparing the carrying amount of each CGU to
each CGU's recoverable amount. The recoverable amount of a CGU is the greater of (i) its value in use, and (ii) its fair value less
selling costs. In assessing value in use for D&P assets, the estimated future cash flows from the production of proven and
probable reserves are discounted to their present value using a pre-tax discount rate that reflects current market assessments of
the time value of money and the risks specific to the asset. Value in use is generally computed by reference to the present value
of the future cash flows expected to be derived from proved and probable reserves.
Impairment losses recognized in prior periods are assessed at each reporting date to evaluate if those losses have decreased or
no longer exist. If those impairment losses have decreased or no longer exist (recovered), they are reversed accordingly.
Previously recognized impairment losses may be recovered in future reporting periods due to changes in estimates used to
determine the recoverable amount. An impairment loss recovery is recorded only to the extent that the PP&E carrying amount
does not exceed the carrying amount that would have been determined, net of depletion and depreciation, if no impairment loss
had been recognized. Impairment losses and recoveries are recorded in the statement of income and comprehensive income.
(continued)
TORC Oil & Gas Ltd. 2014 Page 11
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
(ii) Proven and probable reserves
Proven and probable reserves represent the estimated quantities of crude oil, natural gas and natural gas liquids which
geological, geophysical and engineering data demonstrate with a specified degree of certainty to be recoverable in future years
from known reservoirs and which are considered commercially producible. There should be a 50 percent statistical probability
that the actual quantity of recoverable reserves will be more than the amount estimated as proven and probable and a 50 percent
statistical probability that it will be less. At least annually, reserves are evaluated by independent reserve evaluators.
Such reserves may be considered commercially producible if management has the intention of developing and producing them
and such intention is based upon:
●
●
●
a reasonable assessment of the future economics of such production;
a reasonable expectation that there is a market for all or substantially all the expected oil and natural gas production; and
evidence that the necessary production, transmission and transportation facilities are available or can be made available.
Where amounts are expressed on a barrel of oil equivalent (“Boe”) basis, natural gas volumes have been converted to Boe using
a ratio of 6,000 cubic feet of natural gas to one barrel of oil equivalent. This conversion ratio is based upon an energy equivalent
conversion method primarily applicable at the burner tip and does not represent value equivalence at the wellhead. Boe figures
may be misleading, particularly if used in isolation.
(iii) Subsequent costs
Subsequent costs are capital costs incurred to improve an existing D&P asset (such as a well) that is technically feasible and
commercially viable. These costs are capitalized as D&P assets only if they increase the future economic benefits of the asset.
All other expenditures are expensed in the statement of income and comprehensive income as incurred. These improvement
costs include capital costs of further developing proven reserves or enhancing production. The costs of routine maintenance of
D&P assets are recognized in the statement of income and comprehensive income as incurred. The carrying value of any
replaced or sold component is derecognized.
(iv) Depletion and depreciation
The net carrying value of D&P assets is depleted using the unit-of-production method by calculating the ratio of production in the
period to the related proven and probable reserves. The carrying value to be depleted includes estimated future development
costs necessary to produce proven and probable reserves. Future development costs are estimated by considering the level of
development required to produce the proven and probable reserves and are reviewed by independent reserve engineers at least
annually. Undeveloped land related to a proven project area, for which specific proven and probable reserves have not yet been
assigned, are withheld from depletion.
For Other PP&E, depreciation is recognized in the statement of income and comprehensive income on a straight-line basis over
their estimated useful lives. Finance lease assets are depreciated over the shorter of the lease term and their useful lives unless
it is reasonably certain that the Company will obtain ownership by the end of the lease term. Depreciation methods, useful lives
and residual values are reviewed at each reporting date.
(f) Goodwill
The Company records goodwill relating to corporate acquisitions when the purchase price exceeds the fair value of the net
identifiable assets and liabilities acquired by the Company. When goodwill is negative, it is recognized immediately in the
statement of income and comprehensive income. The goodwill balance is assessed for impairment annually or as events occur
that could result in an impairment. Goodwill is measured at cost less accumulated impairment losses.
(continued)
TORC Oil & Gas Ltd. 2014 Page 12
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
For the purposes of impairment testing, goodwill is allocated to CGU’s that are expected to economically benefit from the
business combination from which the goodwill arose. An impairment loss is recognized if the carrying amount of a CGU exceeds
its estimated recoverable amount. Impairment losses are recognized in the statement of income and comprehensive income.
Impairment losses identified in a CGU are first charged against any goodwill related to that CGU, with any remaining impairment
losses charged against E&E or PP&E assets remaining in that CGU. Impairment losses of goodwill cannot be reversed.
(g) Leased assets
Leases where the Company assumes substantially all the risks and rewards of ownership are classified as finance leases. Upon
initial recognition the leased asset is measured at an amount equal to the lower of its fair value and the present value of minimum
lease payments. Subsequent to initial recognition, the asset is accounted for in accordance with the accounting policy applicable
to that asset.
Minimum lease payments made under finance leases are apportioned between the finance expenses and the reduction of the
outstanding liability. The finance expenses are allocated to each year during the lease term so as to produce a constant periodic
rate of interest on the remaining balance of the liability.
Other leases are operating leases, which are not recognized on the Company's statement of financial position.
Payments made under operating leases are recognized in the statement of income and comprehensive income on a straight-line
basis over the term of the lease and not recognized as a liability on the Company's statement of financial position. Lease
incentives received are recognized as an integral part of the total lease expense, over the term of the lease.
(h) Stock-based compensation
The grant date fair value of stock-based compensation on equity instruments, such as stock options, incentive shares and
restricted and performance awards granted to employees, is recognized as stock-based compensation expense, with a
corresponding increase in contributed surplus over the vesting period. A forfeiture rate is estimated at the grant date and is
adjusted to reflect the actual number of stock-based compensation equity instruments that vest including adjustments for
performance conditions. The inputs used in the calculation of the fair value of stock-based compensation are estimated on the
grant date.
(i)
Flow-through shares
The Company may finance a portion of its exploration activities through the issuance of flow-through common shares. Under the
terms of the flow-through share agreements, the resource expenditure deductions for income tax purposes are renounced to
investors in accordance with the appropriate income tax legislation.
The proceeds from the sale of flow-through shares are allocated between the offering of shares and the sale of tax benefits. The
allocation is made based on the difference between the fair market price of the existing shares and the amount the investor pays
for the flow-through shares (given no other differences between the securities). A flow-through share liability is recognized for this
difference. On a pro-rata basis, the previously recorded flow-through share liability is reversed and a corresponding deferred tax
liability (equal to the Company’s effective tax rate multiplied by the flow-through commitment) is recognized as qualifying
expenditures are incurred. Any difference between the reversal of the flow-through share liability and corresponding deferred tax
liability is recognized as deferred tax expense in the statement of income and comprehensive income.
(j) Provisions
A provision is recognized if, as a result of a past event, the Company has a present legal or constructive obligation that can be
estimated reliably, and it is probable that an outflow of economic benefits will be required to settle the obligation. Provisions are
determined by discounting the expected future cash flows at a pre-tax rate that reflects current market assessments of the time
value of money and the risks specific to the liability. Provisions are not recognized for future operating losses.
(continued)
TORC Oil & Gas Ltd. 2014 Page 13
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
Examples of provisions include dismantling, decommissioning and site disturbance remediation activities, and anticipated losses
from lawsuits. Provision is made for the estimated cost of these activities and capitalized in the relevant asset category or
expensed in the statement of income and comprehensive income.
Decommissioning obligations
Decommissioning obligations (also called asset retirement obligations) are measured at the present value of management’s best
estimate of expenditure required to settle the present obligation at the statement of financial position date. Subsequent to initial
measurement, the obligation is adjusted at the end of each reporting period to reflect the passage of time and changes in the
estimated future cash flows underlying the obligation. The increase in the provision due to the passage of time, known as
accretion, is recognized in the statement of income and comprehensive income as finance costs whereas increases/decreases
due to changes in the estimated future cash flows are capitalized. Actual costs incurred upon settlement of the decommissioning
obligations are charged against the provision to the extent the provision was established.
(k) Revenue
Revenue from the sale of oil and natural gas is recorded when the significant risks and rewards of ownership of the product are
transferred to the buyer which is usually when legal title passes to the external party. This is generally at the time product enters
a third party pipeline or facility. Revenue is measured net of discounts, customs duties and royalties. With respect to the latter,
the entity is acting as a collection agent on behalf of others.
Tariffs and tolls charged to other entities for use of pipelines and facilities owned by the Company are recognized as revenue as
they accrue in accordance with the terms of the service or tariff and tolling agreements.
Royalty income is recognized as it accrues in accordance with the terms of the overriding royalty agreements.
(l)
Finance income and costs
Finance costs comprise of interest expense on bank debt, accretion of the discount on decommissioning obligations, and
impairment losses recognized on financial assets.
Interest income is recognized as it accrues in the statement of income and comprehensive income, using the effective interest
method.
(m) Income tax
Income tax expense comprises current and deferred tax. Income tax expense is recognized in the statement of income and
comprehensive income except to the extent that it relates to items recognized directly in equity, such as share issue costs, in
which case it is recognized in equity.
Current tax is the expected tax payable on the taxable income for the year, using tax rates enacted or substantively enacted at the
reporting date, and any adjustment to tax payable in respect of previous years.
Deferred tax is recognized using the balance sheet method, providing for temporary differences between the carrying amounts of
assets and liabilities for financial reporting purposes and the amounts used for taxation purposes. Deferred tax is not recognized
on the initial recognition of assets or liabilities in a transaction that is not a business combination. Deferred tax is measured at the
tax rates that are expected to be applied to temporary differences when they reverse, based on the laws that have been enacted
or substantively enacted at the reporting date. Deferred tax assets and liabilities are offset if there is a legally enforceable right to
offset, and they relate to income taxes levied by the same tax authority on the same taxable entity, or on different tax entities, but
they intend to settle current tax liabilities and assets on a net basis or their tax assets and liabilities will be realized simultaneously.
A deferred tax asset is recognized to the extent that it is probable that future taxable profits will be available against which the
temporary difference can be utilized. Deferred tax assets are reviewed at each reporting date and are reduced to the extent that it
is no longer probable that the related tax benefit will be realized.
(continued)
TORC Oil & Gas Ltd. 2014 Page 14
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
(n) Earnings per share
Basic earnings per share is calculated by dividing the net income or loss attributable to common shareholders of the Company by
the weighted average number of common shares outstanding during the period. Diluted earnings per share is determined by
adjusting the net income or loss attributable to common shareholders and the weighted average number of common shares
outstanding for the effects of dilutive instruments such as options, incentive shares, and restricted and performance awards
granted to employees.
(o) Changes to accounting policies and future accounting pronouncements
On January 1, 2014, the Company adopted the following new standards: IFRIC 21 Levies and amendments to IAS 32 Financial
Instruments Presentation . The adoption of these standards had no impact on the amounts recorded in the financial statements
as at January 1, 2014 or on the comparative periods.
The following accounting standards and amendments, issued by the International Accounting Standards Board (“IASB”), become
effective between January 1, 2016 and January 1, 2018: IFRS 11 (amendments to Accounting for Acquisitions of Interests in
Joint Operations ), IAS 16 and IAS 38 (amendments to Clarification of Acceptable Methods of Depreciation and Amortization ),
IFRS 15 Revenue from Contracts with Customers , and IFRS 9 Financial Instruments . The impact of these accounting standards
and amendments is not expected to have a material impact on the Company's financial statements, although the Company is still
finalizing its assessment.
4. Determination of fair values
A number of the Company’s accounting policies and disclosures require the determination of fair value for both financial and non-
A number of the Company’s accounting policies and disclosures require the determination of fair value for both financial and non-
financial assets and liabilities. Fair values have been determined for measurement and/or disclosure purposes based on the following
financial assets and liabilities. Fair values have been determined for measurement and/or disclosure purposes based on the following
methods. When applicable, further information about the assumptions made in determining fair values is disclosed in the notes
methods. When applicable, further information about the assumptions made in determining fair values is disclosed in the notes
specific to that asset or liability.
specific to that asset or liability.
The Company classifies the fair value of financial instruments according to the following hierarchy based on the amount of
observable inputs used to value the instruments:
●
●
●
Level 1: Values based on unadjusted quoted prices in active markets that are accessible at the measurement date
for identical assets or liabilities.
Level 2: Values based on quoted prices in markets that are not active or model inputs that are observable either
directly or indirectly for substantially the full term of the asset or liability.
Level 3: Values based on prices or valuation techniques that require inputs that are both unobservable and
significant to the overall fair value measurement.
Exploration and evaluation assets, and property, plant and equipment
The fair value of exploration and evaluation assets and property, plant and equipment recognized in a business combination, is based
on market value. The market value of E&E assets and PP&E is the estimated amount for which E&E assets and PP&E could be
exchanged on the acquisition date between a willing buyer and a willing seller in an arm’s length transaction after proper marketing
wherein the parties had each acted knowledgeably, prudently and without compulsion. The market value of oil and natural gas
interests included in E&E assets and PP&E is estimated with reference to the discounted cash flows expected to be derived from oil
and natural gas production based on internally and externally prepared reserve reports. The risk-adjusted discount rate is specific to
the asset with reference to general market conditions.
(continued)
TORC Oil & Gas Ltd. 2014 Page 15
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
Cash and cash equivalents, bank overdrafts, trade and other receivables, trade and other payables, dividends payable and bank debt
The fair value of cash and cash equivalents, bank overdrafts, trade and other receivables, trade and other payables, dividends
payable and bank debt is estimated as the present value of future cash flows, discounted at the market rate of interest at the reporting
date. As at December 31, 2014 and 2013, the fair value of cash and cash equivalents, trade and other receivables, trade and other
payables and dividends payable approximated their carrying value due to their short term to maturity. The fair value of bank debt
approximates its carrying value as it bears a floating rate of interest and the margin charged by the lenders are indicative of current
credit spreads.
Derivatives
The fair value of financial forward contracts and swaps is determined by discounting the difference between the contracted prices and
published forward price curves as at the statement of financial position date, using the remaining contracted oil and natural gas
volumes and a risk-free interest rate. The fair value of costless collars is based on option models that use published information with
respect to volatility, prices and interest rates. The Company classifies its derivatives as Level 2. Level 2 values are based on quoted
prices in markets that are not active or model inputs that are observable either directly or indirectly for substantially the full term of the
asset or liability.
Stock-based compensation
The fair value of employee stock options is measured using a Black-Scholes option pricing model. Measurement inputs include share
price on measurement date, exercise price of the option, expected volatility, weighted average expected life of the instruments (based
on historical experience and general option holder behaviour), expected dividends, forfeiture rate and the risk-free interest rate (based
on government bonds). Incentive shares and restricted and performance awards are fair valued based on the share price on the
measurement date with a forfeiture rate applied.
5.
Financial risk management
(a) Overview
The Company’s activities expose it to a variety of financial risks such as credit risk, liquidity risk and market risk that arise as a result of
its exploration, development, production and financing activities.
This note presents information about the Company’s exposure to each of the above risks, the Company’s objectives, policies and
processes for measuring and managing risk and the Company’s management of capital. Further quantitative disclosures are included
throughout these financial statements.
The Board of Directors oversees management's establishment and execution of the Company’s risk management framework.
Management has implemented and monitors compliance with risk management policies. The Company’s risk management policies
are established to identify and analyze the risks faced by the Company, to set appropriate risk limits and controls and to monitor risks
and market conditions.
(b) Credit risk
Credit risk is the risk of financial loss to the Company if a customer or counterparty to a financial instrument fails to meet its contractual
obligations.
The carrying amount of the Company’s cash and cash equivalents, trade and other receivables, and financial derivative contract
assets represents the maximum credit exposure.
With respect to trade and other receivables, the Company’s exposure to credit risk is influenced mainly by the individual characteristics
of each customer.
(continued)
TORC Oil & Gas Ltd. 2014 Page 16
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
Receivables from petroleum and natural gas marketers are collected on the 25th day of each month following production. The
Company's policy to mitigate credit risk associated with these balances is to establish relationships with credit-worthy marketers, as
well as to carefully assess the extent of credit granted to these parties.
Joint venture receivables are normally collected within one to three months of the joint venture bill being issued to the partner. The
Company attempts to mitigate the risk from joint venture receivables by obtaining partner approval of capital expenditures prior to
expenditure. However, the receivables are from participants in the petroleum and natural gas sector and collection of the outstanding
balances is dependent on industry factors such as commodity price fluctuations, escalating costs and the risk of unsuccessful drilling.
Further risks exist with joint venture partners as disagreements occasionally arise, increasing the risk of non-collection.
The Company does not typically obtain collateral from petroleum and natural gas marketers or joint venture partners. However, the
Company does have the ability to withhold production from joint venture partners in the event of non-payment, as well as requiring
prepayment (cash calls) for significant expenditures.
The Company does not anticipate any default as it transacts with credit-worthy customers and management does not expect any
losses from non-performance by these customers. As such, a provision for doubtful accounts has not been recorded at December 31,
2014 or 2013.
The maximum exposure to credit risk for trade and other receivables at the reporting date by type of customer was:
Petroleum and natural gas marketing companies
Joint venture partners
Other parties (1)
Bank (2)
Total trade and other receivables
December 31, 2014
$13,994
5,328
33
3,315
$22,670
December 31, 2013
$23,874
9,913
432
199
$34,418
(1) Other parties is comprised of goods and services tax ("GST") receivable from the federal government.
(2) Bank is comprised of commodity derivative contract settlements receivable from certain members of the Company's bank syndicate.
The Company’s trade and other receivables are aged as follows:
Current (less than 90 days)
Past due (greater than 90 days)
Total
(c) Liquidity risk
December 31, 2014
$22,670
-
$22,670
December 31, 2013
$34,013
405
$34,418
Liquidity risk relates to the risk that the Company will encounter difficulty in meeting its obligations associated with financial liabilities.
The financial liabilities on the statement of financial position consist of trade and other payables, dividends payable and bank debt.
Trade and other payables and dividends payable are considered due within one year. The terms for bank debt are outlined in note 19.
The Company anticipates it will continue to have adequate liquidity to fund its financial liabilities. The Company has had no defaults or
breaches on its financial liabilities.
(d) Market risk
Market risk is the risk that changes in market prices relating to currency, commodity prices and interest rates will affect the Company’s
net earnings, future cash flows, the value of financial instruments, or the fair value of its assets and liabilities. The objective of market
risk management is to manage and control market risk exposure within acceptable parameters.
(continued)
TORC Oil & Gas Ltd. 2014 Page 17
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
Although the Company generally does not sell or transact in foreign currency, the United States dollar influences the price of petroleum
and natural gas sold in Canada. Furthermore, exchange rate fluctuations can affect the fair value and cash flow from derivative
contracts. For the years ended December 31, 2014 and 2013, the Company did not enter into any foreign currency derivative
contracts.
Commodity prices for crude oil, natural gas liquids and natural gas are also impacted by political events, meteorological conditions and
changes in supply and demand. The Company may enter into commodity derivative contracts that provide downside price protection
in order to provide some stability of cash flows for capital spending and planning purposes. The Company’s risk management
activities are conducted pursuant to its risk management policies approved by the Board of Directors.
Interest rate risk is the risk that future cash flows will fluctuate as a result of changes in interest rates. The Company’s interest rate risk
arises from its floating rate credit facility. For the years ended December 31, 2014 and 2013, the Company did not enter into any
interest rate derivative contracts. Assuming all other variables remain constant, an increase or decrease of one percent in market
interest rates in the year ended December 31, 2014 would have decreased or increased shareholders’ equity and net income by
$1.3 million.
(e) Capital management
The Company's policy is to maintain a strong capital base in order to maintain financial flexibility and to sustain the future development
of the business. The Company manages its capital structure and makes adjustments relative to changes in economic conditions and
the Company's risk profile. In order to maintain the capital structure, the Company may from time to time issue shares and adjust its
capital spending to manage current and projected debt levels. The Company considers its capital structure to include working capital,
bank debt and shareholders’ equity.
The same as in the prior year, in order to optimize capital and operating efficiency, the Company monitors its net debt. Net debt is
calculated as current assets (excluding financial derivative assets) less: i) current liabilities (excluding financial derivative liabilities), ii)
bank debt, and iii) non-current deferred lease incentives. In times of net debt, the Company monitors debt levels based on a ratio of
net debt to annualized funds flow from operations. The Company defines funds flow from operations as cash flow from operating
activities prior to changes in non-cash working capital and settlement of decommissioning obligations.
6. Cardium and southeast Saskatchewan asset acquisitions
During the year ended December 31, 2014, the Company acquired various properties and working interests in its core Cardium and
southeast Saskatchewan areas (together the "Asset Acquisitions").
The Company believes the nature and characteristics of the Asset Acquisitions are complementary to TORC’s light oil focused
strategy.
Transaction costs incurred by the Company totaling $0.1 million related to the Asset Acquisitions were expensed.
The Asset Acquisitions have been accounted for using the acquisition method of accounting, with the operating results included in the
Company's financial and operating results commencing on the respective closing dates of the acquisitions.
Consideration paid (1)
Net assets acquired, at estimated fair value
Property, plant and equipment
Decommissioning obligations
$137,151
$145,080
(7,929)
$137,151
(1)
Consideration paid includes $131.6 million of cash paid and an additional $5.5 million of estimated purchase price adjustments.
(continued)
TORC Oil & Gas Ltd. 2014 Page 18
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
The above amounts are estimates, which were made by management at the time of the preparation of these financial statements
based on information then available. Amendments may be made to these amounts as values subject to estimate are finalized.
The fair value of property, plant and equipment has been determined with reference to an independent reserve report with
consideration also given for land and seismic values that have been included based on estimated market value.
Included in the statement of income and comprehensive income are the following amounts relating to the Asset Acquisitions, from their
respective closing dates to December 31, 2014.
Petroleum and natural gas sales
Net income and comprehensive income
Year ended
Dec 31, 2014
$26,347
$7,904
If the Asset Acquisitions had occurred on January 1, 2014, the Company's pro forma results of petroleum and natural gas sales and
net income and comprehensive income for the year ended December 31, 2014 would have been as follows:
Year ended
December 31, 2014
Petroleum and natural gas sales
Net income and comprehensive income
7. Southeast Saskatchewan asset acquisition
TORC,
as stated in the
statement of
income and
comprehensive
income
$321,329
$6,258
Asset
Acquisitions
(from
Jan 1, 2014 to
closing dates)
$24,557
$7,367
Pro forma
(unaudited)
$345,886
$13,625
On September 9, 2013, the Company closed an acquisition of assets (the "Acquired Assets") located in southeast Saskatchewan (the
"SE Saskatchewan Acquisition").
The Company believes the low decline, high netback, light oil producing characteristics of the Acquired Assets are complementary to
TORC’s strategy.
Transaction costs incurred by the Company totaling $7.0 million related to the SE Saskatchewan Acquisition were expensed.
The SE Saskatchewan Acquisition has been accounted for using the acquisition method of accounting, with the results of the Acquired
Assets' operations included in the Company's financial and operating results beginning September 9, 2013.
Consideration paid
Net assets acquired, at estimated fair value
Property, plant and equipment
Working capital
Derivative contracts
Decommissioning obligations
$492,287
$570,308
1,029
(1,559)
(77,491)
$492,287
(continued)
TORC Oil & Gas Ltd. 2014 Page 19
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
Included in the statement of loss and comprehensive loss for the year ended December 31, 2013 are the following amounts relating to
the Acquired Assets from September 9, 2013 to December 31, 2013:
Petroleum and natural gas sales
Net income and comprehensive income
$52,938
$31,795
If the SE Saskatchewan Acquisition had occurred on January 1, 2013, the Company's pro forma results of petroleum and natural gas
sales and net income and comprehensive income for the year ended December 31, 2013 would have been as follows:
Year ended December 31, 2013
Petroleum and natural gas sales
Net income and comprehensive income
8. Key management personnel compensation
Remuneration and short-term benefits
Stock-based compensation
Capitalized portion of total compensation
Acquired Assets
Jan 1 to
Sep 8, 2013
$121,140
$34,763
As stated
$164,074
($10,084)
Pro forma
(unaudited)
$285,214
$24,679
Year ended
Dec 31, 2014
$4,383
10,804
$15,187
Year ended
Dec 31, 2013
$2,605
3,596
$6,201
(7,466)
$7,721
(3,101)
$3,100
Key management personnel includes the officers and directors of the Company.
Short-term employee benefits and stock-based compensation include both the capitalized and non-capitalized portion of these
expenditures. Stock-based compensation reflects amounts amortized during the respective periods.
9.
Finance costs
Interest expense and financing charges
Accretion on decommissioning obligations
ended
Dec 31, 2014
1,660
751
2,411
$
ended
Dec 31, 2013
975
651
1,626
$
Year ended
Dec 31, 2014
$6,211
2,819
$9,030
Year ended
Dec 31, 2013
$1,387
905
$2,292
TORC Oil & Gas Ltd. 2014 Page 20
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
10. Supplemental cash flow information
Changes in non-cash working capital is comprised of:
ended
Dec 31, 2014
ended
Dec 31, 2013
Year ended
Dec 31, 2014
Year ended
Dec 31, 2013
Source/(use) of cash:
Trade and other receivables
Deposits and prepaid expenses
Trade and other payables
Deferred lease incentives
Non-cash working capital acquired
Related to operating activities
Related to investing activities
Related to financing activities
The following table summarizes interest and taxes paid:
Interest paid
Taxes paid
11. Exploration and evaluation assets
Balance at December 31, 2012
Property acquisitions
Property dispositions
Capital expenditures
Impairment
Transferred to property, plant and equipment
Balance at December 31, 2013
Property acquisitions
Property dispositions
Capital expenditures
Impairment
Transferred to property, plant and equipment
Balance at December 31, 2014
$
$
11,748
(60)
(20,752)
(176)
-
(9,240)
(52,365)
43,125
-
(9,240)
$
$
$
$
$
$
(3,598)
(63)
47,284
(44)
(3,971)
39,608
(3,517)
43,125
-
39,608
$11,748
(60)
(20,752)
(176)
-
($9,240)
$10,752
(19,992)
-
($9,240)
($15,322)
345
40,210
(176)
(3,971)
$21,086
($10,489)
31,575
-
$21,086
Year ended
Dec 31, 2014
$5,715
-
$5,715
Year ended
Dec 31, 2013
$1,135
-
$1,135
$151,111
2,097
(2,666)
40,926
(38,355)
(24,020)
$129,093
707
(100)
308
(72,567)
(2,845)
$54,596
Exploration and evaluation assets ("E&E assets") consist of the Company’s exploration projects, including undeveloped land and
development costs which are pending the determination of proven reserves. Property acquisitions and capital expenditures represent
the Company’s share of costs incurred on E&E assets during the period.
(continued)
TORC Oil & Gas Ltd. 2014 Page 21
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
Impairment
For the year ended December 31, 2014, the Company recognized impairment of $72.6 million (year ended December 31, 2013: $38.4
million) on E&E assets related to certain southern Alberta projects with carrying values exceeding the recoverable amounts. As at
December 31, 2014, the Company determined there to be a trigger regarding these E&E assets, based on the Company's near term
plans to reduce capital allocated to these exploratory projects given the current depressed crude oil price environment. As a result the
Company impaired these E&E assets principally comprised of historic land acquisition costs. In the prior year, for certain southern
Alberta projects, the impairment expense related to the excess of carrying values compared to recoverable values when costs were
transferred from E&E assets to PP&E upon technical feasibility and commercial viability being determined.
12. Property, plant and equipment
Cost:
Balance at December 31, 2012
Property acquisitions
Capital expenditures
Change in decommissioning obligations
Transferred from exploration and evaluation assets
Balance at December 31, 2013
Property acquisitions
Property dispositions
Capital expenditures
Change in decommissioning obligations
Transferred from exploration and evaluation assets
Balance at December 31, 2014
Accumulated depletion and depreciation:
Balance at December 31, 2012
Depletion and depreciation for the year
Balance at December 31, 2013
Depletion and depreciation for the year
Balance at December 31, 2014
Net amount:
As at December 31, 2013
As at December 31, 2014
$393,992
571,910
122,820
3,503
24,020
$1,116,245
144,797
(760)
152,207
2,224
2,845
$1,417,558
$20,352
59,901
$80,253
114,360
$194,613
$1,035,992
$1,222,945
Included in the net amount of property, plant and equipment at December 31, 2014 is office equipment of $0.3 million, net of
accumulated depreciation of $0.4 million (December 31, 2013: $0.3 million, net of accumulated depreciation of $0.2 million).
At December 31, 2014, the Company had $104.2 million of property, plant and equipment which was excluded from depletion at the
time and largely related to undeveloped land (December 31, 2013: $106.5 million). Estimated future development costs of $406.4
million were included in the depletion calculation (December 31, 2013: $307.4 million).
For the year ended December 31, 2014, the Company has capitalized $6.4 million of general and administrative expenses and $10.4
million of stock-based compensation, which are directly attributable to the acquisition or exploration activities of the Company (for the
year ended December 31, 2013: $4.0 million and $3.4 million, respectively).
Based on the facts and circumstances in place at December 31, 2014, there was no impairment of the Company's property, plant and
equipment.
TORC Oil & Gas Ltd. 2014 Page 22
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
13. Decommissioning obligations
Balance, beginning of year
Obligations incurred
Obligations acquired
Obligations settled
Change in estimated future cash outflows
Accretion
Balance, end of year
As at
December 31, 2014
$93,045
2,224
7,929
(347)
-
2,819
$105,670
As at
December 31, 2013
$11,408
2,699
77,491
(262)
804
905
$93,045
The total future decommissioning obligations are based on the Company’s net ownership in wells and facilities, estimated costs to
reclaim and abandon the wells and facilities, and the estimated timing of the costs to be incurred in future periods. The Company has
estimated an undiscounted total future liability of $131.4 million as at December 31, 2014 (at December 31, 2013: $118.4 million) to be
incurred on average in 25 years. For the year ended December 31, 2014, the Company’s risk-free rate of 2.85 percent and an inflation
rate of 1.8 percent per annum were used to calculate the net present value of the decommissioning obligations (year ended December
31, 2013: risk-free rate of 2.85 percent and inflation rate of 1.8 percent per annum). Actual costs may differ from estimated costs due
to changes in laws and regulations, timing of costs, changes in technology and market conditions.
14. Taxes
Tax expense
The combined provision for taxes in the statement of income (loss) and comprehensive income (loss) reflects an effective tax rate
which differs from the expected statutory rate. The reasons for the difference are as follows:
Income (loss) before taxes
Statutory income tax rate
Expected income tax (recovery)
Add (deduct):
Non-deductible stock-based compensation
Flow-through share liability
Permanent depletion
Rate adjustments
Other
Deferred income tax
Year ended
Dec 31, 2014
$13,200
25.6%
3,376
Year ended
Dec 31, 2013
($8,207)
25.3%
(2,078)
2,672
672
264
145
(187)
$6,942
859
2,878
132
86
-
$1,877
As a result of the Company's full year of operations in the province of Saskatchewan (in connection with the SE Saskatchewan
Acquisition), the corporate statutory income tax rate increased slightly in 2014, such that the combined Federal and Provincial statutory
income tax rate increased from 25.3% in 2013 to 25.6% in 2014.
(continued)
TORC Oil & Gas Ltd. 2014 Page 23
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
Deferred tax liability
The components of the deferred tax liability are as follows:
E&E and PP&E
Decommissioning obligations
Loss carryforwards
Financial derivative asset (liability)
Deferred lease incentives
Share issue costs
As at December 31, 2014
$91,311
(27,030)
(51,922)
6,292
(72)
(4,951)
$13,628
As at December 31, 2013
$80,494
(23,554)
(44,316)
(56)
(116)
(7,052)
$5,400
The following table summarizes the continuity of the deferred tax liability:
E&E and PP&E
Decommissioning obligations
Loss carryforwards
Financial derivatives
Deferred lease incentives
Share issue costs
E&E and PP&E
Decommissioning obligations
Loss carryforwards
Financial derivatives
Deferred lease incentives
Share issue costs
As at
Dec 31, 2012
$39,762
(2,852)
(29,486)
381
(158)
(3,938)
$3,709
Recognized in
profit or loss
$15,596
(1,086)
(14,830)
(42)
42
2,197
$1,877
As at
Dec 31, 2013
$80,494
(23,554)
(44,316)
(56)
(116)
(7,052)
$5,400
Recognized in
profit or loss
$7,226
(1,448)
(7,606)
6,348
44
2,378
$6,942
Recognized
in equity
-
-
-
-
-
(5,311)
($5,311)
Recognized
in equity
-
-
-
-
-
(277)
($277)
Asset
acquisition
(note 7)
$20,011
(19,616)
-
(395)
-
-
-
Asset
acquisition
(note 6)
$2,028
(2,028)
-
-
-
-
-
Flow-through
share premium
$5,125
-
-
-
-
-
$5,125
Flow-through
share premium
$1,563
-
-
-
-
-
$1,563
As at
Dec 31, 2013
$80,494
(23,554)
(44,316)
(56)
(116)
(7,052)
$5,400
As at
Dec 31, 2014
$91,311
(27,030)
(51,922)
6,292
(72)
(4,951)
$13,628
As at December 31, 2014, the Company has tax deductions of approximately $1.1 billion (2013: $1.0 billion) available to shelter future
taxable income.
CEE
CDE
COGPE
UCC
Share issue costs
Loss carry forwards (expiring between 2026 to 2033)
As at December 31, 2014
$73,187
170,202
505,353
139,688
19,356
202,990
$1,110,776
As at December 31, 2013
$98,753
151,975
455,824
117,916
27,859
174,804
$1,027,131
TORC Oil & Gas Ltd. 2014 Page 24
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
15. Share capital
In September 2013, the Company consolidated its outstanding common shares, stock options, incentive shares and warrants on a 1
for 5 basis (the "Share Consolidation"). As a result, the number of outstanding common shares, stock options, incentive shares and
warrants of comparative periods have been reduced by a factor of five, in order for the comparative common share, stock options,
incentive shares, warrants, per share and per diluted share amounts to be equivalent.
The Company has a significant investor, the CPP Investment Board (“CPPIB”). For so long as CPPIB owns greater than 10% of the
outstanding common shares of the Company, it has the right to participate in future offerings of securities by the Company, whether by
way of public offering or private placement. This includes any offering of common shares and securities convertible or exchangeable
into common shares, up to its pro rata ownership interest immediately prior to such offering in the case of a public offering or a private
placement to five or more investors, in order to maintain its pro rata percentage ownership interest in the Company, and up to all of the
offering in the case of a private placement to less than five investors.
Share capital - authorized
At December 31, 2014, the Company was authorized to issue an unlimited number of Class A voting common shares, an unlimited
number of Class B non-voting common shares and an unlimited number of preferred shares. The Company has not issued any Class
B non-voting common shares nor any preferred shares.
Share capital - issued
In August 2013, in connection with the SE Saskatchewan Acquisition described in note 6, the Company completed two equity
financings by issuing 52,434,000 subscription receipts at $7.85 per subscription receipt for gross proceeds of $411.6 million, before
share issue costs. In September 2013, these subscription receipts were converted into common shares of TORC on a one-for-one
basis.
On October 29, 2014, the Company completed an equity financing by issuing 1,441,900 common shares on a flow-through basis at a
weighted average of $13.67 per Common Share for gross proceeds of $19.7 million, before share issue costs.
Warrants
On December 17, 2010, the Company closed a private placement to insiders and service providers whereby 5 million units ("Units")
were issued at $4.00 per Unit, for gross proceeds of $20.0 million. Each Unit is comprised of 0.52 common shares, 0.17 common
shares issued on a flow-through basis and 0.7 common share purchase warrants ("Warrants"). Each Warrant entitles the holder to
acquire one common share at a price of $7.18, subject to the following conditions:
●
●
●
●
one-third of the Warrants may be exercised after the Company's stock price (the "Stock Price") exceeds $11.49;
one-third of the Warrants may be exercised after the Company's Stock Price exceeds $14.37;
one-third of the Warrants may be exercised after the Company's Stock Price exceeds $17.24; and
the Stock Price is defined as the weighted average price per share for the 20 consecutive trading days ending immediately before
such date on the Toronto Stock Exchange on which the Company's shares are listed.
In the year ended December 31, 2014, 1,134,244 Warrants were exercised for total cash proceeds of $8.1 million. At
December 31, 2014, there were 2.3 million Warrants outstanding of which 1.2 million of the Warrants were exercisable. The Warrants
expire on December 16, 2015, five years from the date of grant.
TORC Oil & Gas Ltd. 2014 Page 25
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
16. Dividends
(thousands, except
per share amounts)
Dividends declared per share
Cash dividends paid
Dollar value of common shares
issued under the Share Dividend Program
Total dividends
Three months
ended
Dec 31, 2014
$0.135
Three months
ended
Dec 31, 2013
$0.128
Year ended
Dec 31, 2014
$0.54
Year ended
Dec 31, 2013
$0.17
$9,499
$8,217
$35,503
$8,217
3,460
$12,959
3,192
$11,409
14,832
$50,335
3,192
$11,409
The Company's dividend plan enables common shareholders to elect to receive dividends in common shares rather than cash,
calculated at 95% of the weighted average trading price for the five days immediately prior to the payment date (the "Share Dividend
Program").
For the period between January 1, 2015 and March 5, 2015, $9.4 million of dividends have been declared.
17. Stock-based compensation
In September 2013, the Company consolidated its outstanding common shares, stock options, incentive shares and warrants on a 1
for 5 basis (the "Share Consolidation"). As a result, the number of outstanding common shares, stock options, incentive shares and
warrants of comparative periods have been reduced by a factor of five, in order for the comparative common share, stock options,
incentive shares and warrants to be equivalent.
In September 2013, the Company's shareholders approved an award plan (the ‘‘Share Award Plan’’) whereby restricted awards and
performance awards (collectively, ‘‘Share Awards’’) may be granted to the directors, officers and employees of the Company. The
maximum number of common shares issuable under the Share Award Plan, combined with the Company's existing stock option and
incentive share plans, cannot exceed ten percent of the outstanding common shares. In addition, the combined number of restricted
and performance awards cannot exceed 6.5 percent of the outstanding common shares. Share Awards are earned over various
periods, up to three years from the date of grant. Upon being earned, the restricted awards are converted into common shares and
issued from treasury at no cost to the recipient. The performance awards are converted into common shares using a multiplier
between zero and two, dependent on the Company's performance on a set criteria as determined by the Board of Directors. In the
case of both restricted and performance awards, the number of common shares to be issued on the applicable issue date is adjusted
to account for the payment of dividends from the grant date to the applicable issue date.
Stock options
Stock options granted have a term of five years to expiry and have various vesting periods up to three years. The following table
summarizes the Company's stock option activity:
(thousands, except exercise prices)
Balance at December 31, 2012
Granted
Forfeited
Balance at December 31, 2013
Exercised
Balance at December 31, 2014
Exercisable at December 31, 2014
Number of stock
options
1,581
119
(60)
1,640
(8)
1,632
1,457
Weighted
average
exercise price
$16.75
10.65
14.56
$16.38
7.15
$16.43
$16.85
(continued)
TORC Oil & Gas Ltd. 2014 Page 26
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
The following table summarizes stock options outstanding and exercisable at December 31, 2014:
(thousands, unless otherwise noted)
Exercise price:
$7.15 to $9.85
$11.65 to $13.05
$14.94 to $22.99
$7.15 to $22.99
Number
outstanding
Number
exercisable
Weighted
average
remaining term
(years)
31
155
1,446
1,632
5
99
1,353
1,457
3.1
2.8
1.6
1.8
There were no stock options granted in the year ended December 31, 2014. The fair value of each stock option granted in the year
ended December 31, 2013 was estimated on the date of the grant using the Black-Scholes option pricing model with the following
weighted average assumptions:
Three months
ended
Dec 31, 2014
-
-
-
-
-
Three months
ended
Dec 31, 2013
1.7%
4.0
40.0%
0.0%
$5.00
Risk free interest rate
Expected life (years)
Expected volatility (%)
Forfeiture rate (%)
Weighted average fair value of stock options
Incentive shares
The following table summarizes incentive share activity:
(thousands)
Balance at December 31, 2012
Granted
Forfeited
Common shares issued upon vesting
Balance at December 31, 2013
Common shares issued upon vesting
Balance at December 31, 2014
Convertible into common shares at December 31, 2014
Year ended
Dec 31, 2013
1.4%
3.0
40.0%
0.0%
$3.02
Number of
incentive shares
177
17
(11)
(54)
129
(60)
69
-
Incentive shares are earned over various periods, up to three years from the date of grant. Upon being earned, the incentive shares
are converted into common shares and issued from treasury at no cost to the incentive shareholder. The fair value of incentive shares
is deemed to equal the stock price on the date of grant.
(continued)
TORC Oil & Gas Ltd. 2014 Page 27
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
Restricted awards
The following table summarizes restricted award activity:
(thousands)
Balance at December 31, 2012
Granted
Adjustment for payment of dividends
Balance at December 31, 2013
Granted
Adjustment for payment of dividends
Forfeited
Common shares issued upon vesting
Balance at December 31, 2014
Convertible into common shares at December 31, 2014
Number of
restricted
awards
-
1,238
11
1,249
268
60
(31)
(424)
1,122
-
Restricted awards are earned over various periods, up to three years from the date of grant. Upon being earned, the restricted awards
are converted into common shares and issued from treasury at no cost to the restricted award holder. The fair value of restricted
awards is deemed to equal the stock price on the date of grant. The number of common shares to be issued upon being earned is
adjusted to account for the payment of dividends from the grant date to the earning date. For the year ended December 31, 2014, the
weighted average fair value of restricted awards granted was $12.07 per restricted award (year ended December 31, 2013: $9.27 per
restricted award). There is no forfeiture rate included in the calculation of fair values of restricted awards granted.
Performance awards
The following table summarizes performance award activity:
(thousands)
Balance at December 31, 2012
Granted
Adjustment for payment of dividends
Balance at December 31, 2013
Granted
Granted pursuant to performance multiplier (1)
Adjustment for payment of dividends
Forfeited
Common shares issued upon vesting
Balance at December 31, 2014
Convertible into common shares at December 31, 2014
Number of
performance
awards
-
1,802
16
1,818
474
299
103
(52)
(931)
1,711
-
(1)
Performance awards granted pursuant to performance multipliers are not further increased or decreased by future performance
multipliers.
(continued)
TORC Oil & Gas Ltd. 2014 Page 28
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
Performance awards are earned over various periods, up to three years from the date of grant. On the earning date, the performance
awards are converted into common shares and issued from treasury at no cost to the performance award holder, using a multiplier
between zero and two, dependent on the Company's relative performance on a set criteria as determined by the Board of Directors.
The multiplier, which was determined during the earning period, is considered to have been applied at the grant date. The number of
common shares to be issued upon being earned is adjusted to account for the payment of dividends from the grant date to the earning
date. As performance multipliers are known, past grants are adjusted to reflect the multiplier. The fair value of performance awards is
deemed to equal the stock price on the date of grant. For the year ended December 31, 2014, the weighted average fair value of
performance awards granted was $10.94 per performance award (year ended December 31, 2013: $9.27 per performance award).
There is no forfeiture rate included in the calculation of fair values of performance awards granted.
18. Earnings per share
Earnings per share amounts are calculated by dividing the net income for the period attributable to common shareholders of the
Company by the weighted average number of common shares outstanding during the period.
(thousands, except number of common shares and
per share amounts)
Income (loss) for the year
Basic weighted average number of common shares
Diluted weighted average number of common shares
Basic income (loss) per common share
Diluted income (loss) per common share
$
Three months
ended
Dec 31, 2014
(30,411)
96,087,489
97,815,323
-$0.32
-$0.32
$
Three months
ended
Dec 31, 2013
(17,841)
91,257,722
92,929,448
($0.20)
($0.19)
Year ended
Dec 31, 2014
$6,258
93,320,376
95,823,544
$0.07
$0.07
Year ended
Dec 31, 2013
($10,084)
54,900,265
54,900,265
($0.18)
($0.18)
In computing diluted earnings per share for the year ended December 31, 2014, 945,285 warrants, 127,144 stock options, 62,198
incentive shares, 824,772 performance awards and 543,769 restricted awards were added to the basic weighted average common
shares outstanding.
For the year ended December 31, 2013, the diluted number of shares is equivalent to the basic number of shares due to 1,640,195
stock options, 129,183 incentive shares, 3,480,000 warrants, 1,818,018 performance awards and 1,249,373 restricted awards, all of
which are outstanding and antidilutive. Therefore, the diluted per share amounts for net loss are equivalent to the basic per share
amounts.
19. Credit facility
At December 31, 2014, the Company had a reserves-based revolving credit facility of $425 million with a syndicate of banks (the
"Credit Facility"), comprised of a $40 million operating facility from the operating lender (the "Operating Facility") and a $385 million
syndicated facility with a syndicate of banks (the "Syndicated Facility"). Advances under the Credit Facility are available by way of
direct advances, bankers' acceptances and standby letters of credit/guarantees. Direct advances bear interest at the prime rate, U.S.
base rate or Libor rate, as applicable, plus a margin which is dependent on the Company's debt to trailing funds flow ratio. The
bankers' acceptances bear interest at the applicable bankers' acceptance rate plus a stamping fee, based on the Company's debt to
trailing funds flow ratio.
Both the Syndicated Facility and the Operating Facility are available on a revolving basis until April 28, 2015. On or before April 28,
2015, at TORC's request and subject to the approval of the lending syndicate, the Credit Facility may be extended for an additional
364 day period. In the event of non-extension, the undrawn portion of the Credit Facility will be cancelled and the amount outstanding
will convert to a 364 day non-revolving term facility with repayment of the Credit Facility due on April 28, 2016. The Credit Facility is
secured by a fixed and floating charge debenture on all of the Company's assets.
(continued)
TORC Oil & Gas Ltd. 2014 Page 29
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
The borrowing base is primarily based on reserves and commodity prices estimated by the lenders. The borrowing base of the
Company's Credit Facility is subject to review and redetermination by the lenders on a semi-annual basis and in the event of a change
in the Company's borrowing base properties (including due to a disposition of assets beyond certain defined limits or a change which
results in a material adverse effect, as determined by the lenders). In the normal course, the Company's next credit facility evaluation
is due to be completed by April 28, 2015.
20. Financial derivatives
The following table presents a reconciliation of the change in the unrealized amounts for the year ended December 31, 2014:
Financial derivative asset at December 31, 2012
Additions (note 7)
Unrealized loss on financial derivatives
Financial derivative liability at December 31, 2013
Unrealized gain on financial derivatives
Financial derivative asset at December 31, 2014
Commodity contracts outstanding as at December 31, 2014:
Remaining term
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Mar 31, 2015
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Sept 30, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Dec 31, 2015
Jan 1, 2015 - Dec 31, 2015
Reference
C$WTI
C$WTI
C$WTI
C$ Edm
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
C$WTI
Type
Costless Collar
Costless Collar
Costless Collar
Differential Swap
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Costless Collar
Volume
(Bbl/d)
500
250
250
500
250
250
250
250
250
250
250
250
250
250
Price
(per Bbl in Canadian dollars)
$95.00 - $106.25
$90.00 - $110.55
$90.00 - $112.00
$8.50
$90.00 - $108.00
$90.00 - $109.55
$90.00 - $111.00
$90.00 - $111.25
$90.00 - $112.75
$90.00 - $108.15
$90.00 - $111.75
$90.00 - $111.75
$90.00 - $113.75
$90.00 - $115.85
Fair value
$1,526
(1,559)
(187)
($220)
24,816
$24,596
Fair value at
Dec 31, 2014
($000s)
$2,823
2,284
2,287
(27)
1,199
1,190
1,200
1,200
1,192
2,279
2,246
2,236
2,242
2,245
$24,596
As at December 31, 2014, a 10% decrease in the market price detailed in the commodity contracts above would result in a
$6.3 million unrealized gain on financial derivatives and a corresponding increase in income.
TORC Oil & Gas Ltd. 2014 Page 30
FINANCIAL STATEMENTS
TORC Oil & Gas Ltd.
Notes to the Financial Statements
As at and for the years ended December 31, 2014 and December 31, 2013
(in $000's of Canadian dollars, unless otherwise noted)
21. Commitments
Flow-through shares issued in October 2014
On October 29, 2014, the Company closed a private placement offering of 1,441,900 flow-through shares to raise gross proceeds of
$19.7 million (the "Financing"). The Financing was comprised of 772,000 flow-through shares at $14.25 per share issued in respect of
Canadian exploration expenses ("CEE") for gross proceeds of $11.0 million, and 669,900 flow-through shares at $13.00 per share
issued in respect of Canadian development expenses ("CDE") for gross proceeds of $8.7 million. As at December 31, 2014, the
Company fully incurred the required $8.7 million qualifying as CDE. The $11.0 million of CEE must be incurred before December 31,
2015. All qualifying expenditures were renounced to shareholders as at December 31, 2014.
A flow-through share liability of $3.5 million was recorded to reflect the opening fair value of the liability associated with these flow-
through shares at that date. This flow-through share liability was reduced on a pro-rata basis as the Company incurred qualifying
expenditures. As at December 31, 2014, the remaining flow-through share liability was $1.9 million.
Operating lease commitment
(a) Deferred lease incentives
The Company has entered into a lease commitment for office space. The term of the lease is 64 months commencing April 1, 2011,
totaling $5.8 million. Under the terms of the lease, the period from April 1, 2011 until December 31, 2011 did not require any
payments. However, the total expenditure will be amortized over the full term. This resulted in a liability being recorded and
accumulated during the rent free period, which will then reverse and be amortized to income over the remaining term of the office
space lease when payments are made. The short-term and long-term components of the deferred rent expense liability represent
those portions of the accumulated liability that will be amortized within 12 months and beyond that, respectively.
(b) Future lease payments
Future minimum lease payments for the Company's office space as at December 31, 2014 are as follows:
2015
2016
Total
22. Subsequent events
Asset acquisitions
$1,257
733
$1,990
Subsequent to December 31, 2014, the Company entered into an agreement to acquire light oil assets which are complimentary to
TORC’s existing conventional assets in southeast Saskatchewan (the "Acquisition"). Total consideration for the Acquisition was the
issuance of 16.0 million common shares of TORC, valued at $9.17 per common share on the closing date, for a total value of $146.7
million before customary adjustments.
Asset swap
Subsequent to December 31, 2014, the Company entered into a strategic asset swap of common working interests in the Company’s
non-operated working interest properties in southeast Saskatchewan (the “Asset Swap”). The Asset Swap involves approximately 500
Boe per day of production with similar amounts of production and reserves being swapped. The Asset Swap is expected to close in
the first quarter of 2015.
TORC Oil & Gas Ltd. 2014 Page 31