EXHIBIT 2
---------
2004 ANNUAL REPORT CONSOLIDATED FINANCIAL STATEMENTS
Consolidated Balance Sheets
AS AT DECEMBER 31 2004 2003
(millions of Canadian dollars)
- ------------------------------------------------------------------------------------------------------------------------------
ASSETS
CURRENT ASSETS
Cash $ 28 $ 104
Accounts receivable and other 1,176 751
Current portion of other long-term assets (note 4) 34 -
------------ --------
1,238 855
PROPERTY, PLANT AND EQUIPMENT (note 5) 17,064 13,714
OTHER LONG-TERM ASSETS (note 4) 108 74
------------ --------
$ 18,410 $ 14,643
============ ========
LIABILITIES
CURRENT LIABILITIES
Accounts payable $ 379 $ 464
Accrued liabilities 1,057 582
Current portion of long-term debt (note 6) 194 184
Current portion of other long-term liabilities (note 7) 260 130
------------ --------
1,890 1,360
LONG-TERM DEBT (note 6) 3,538 2,748
OTHER LONG-TERM LIABILITIES (note 7) 1,208 938
FUTURE INCOME TAX (note 8) 4,450 3,591
------------ --------
11,086 8,637
SHAREHOLDERS' EQUITY
SHARE CAPITAL (note 9) 2,408 2,353
RETAINED EARNINGS 4,922 3,650
FOREIGN CURRENCY TRANSLATION ADJUSTMENT (note 10) (6) 3
------------ --------
7,324 6,006
------------ --------
$ 18,410 $ 14,643
============ ========
COMMITMENTS (note 13)
Approved by the Board:
(/S/ CATHERINE M. BEST)
CATHERINE M. BEST
Chair of the Audit Committee and Director
(/S/ N. MURRAY EDWARDS)
N. MURRAY EDWARDS
Vice-Chairman of the Board and Director
69
CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
Consolidated Statements of Earnings
FOR THE YEARS ENDED DECEMBER 31 2004 2003 2002
(millions of Canadian dollars, except per common share amounts)
- --------------------------------------------------------------------------------------------------------------------------------
REVENUE $ 7,547 $ 6,155 $ 4,459
Less: royalties (1,011) (872) (600)
REVENUE, NET OF ROYALTIES 6,536 5,283 3,859
EXPENSES
Production 1,400 1,209 931
Transportation 250 262 262
Depletion, depreciation and amortization 1,769 1,509 1,298
Asset retirement obligation accretion (note 7) 51 62 68
Administration 115 87 61
Stock-based compensation (note 7) 259 200 -
Interest 189 201 203
Risk management activities 434 148 83
Foreign exchange gain (91) (335) (32)
----------- --------- ----------
4,376 3,343 2,874
----------- --------- ----------
EARNINGS BEFORE TAXES 2,160 1,940 985
Taxes other than income tax (note 8) 165 107 63
Current income tax (note 8) 116 92 8
Future income tax (note 8) 474 338 375
----------- --------- ----------
NET EARNINGS $ 1,405 $ 1,403 $ 539
=========== ========= ==========
NET EARNINGS PER COMMON SHARE (note 11)
Basic $ 5.24 $ 5.23 $ 2.11
Diluted $ 5.20 $ 5.06 $ 2.04
=========== ========= ==========
Consolidated Statements of Retained Earnings
FOR THE YEARS ENDED DECEMBER 31 2004 2003 2002
(millions of Canadian dollars)
- --------------------------------------------------------------------------------------------------------------------------------
BALANCE - BEGINNING OF YEAR AS PREVIOUSLY REPORTED $ 3,644 $ 2,414 $ 1,908
Change in accounting policy (note 2) 6 10 41
----------- --------- ----------
BALANCE - BEGINNING OF YEAR AS RESTATED 3,650 2,424 1,949
Net earnings 1,405 1,403 539
Dividend on common shares (note 9) (107) (81) (64)
Purchase of common shares (note 9) (26) (96) -
----------- --------- ----------
BALANCE - END OF YEAR $ 4,922 $ 3,650 $ 2,424
=========== ========= ==========
70
2004 ANNUAL REPORT CONSOLIDATED FINANCIAL STATEMENTS
Consolidated Statements of Cash Flows
FOR THE YEARS ENDED DECEMBER 31 2004 2003 2002
(millions of Canadian dollars)
- --------------------------------------------------------------------------------------------------------------------------------
OPERATING ACTIVITIES
Net earnings $ 1,405 $ 1,403 $ 539
Non-cash items
Depletion, depreciation and amortization 1,769 1,509 1,298
Asset retirement obligation accretion 51 62 68
Stock-based compensation 249 200 -
Unrealized risk management activities (40) - -
Unrealized foreign exchange gain (94) (343) (36)
Deferred petroleum revenue tax (recovery) (45) (9) 10
Future income tax 474 338 375
Deferred charges (33) 10 (84)
Abandonment expenditures (32) (40) (43)
Net change in non-cash working capital (note 14) (14) (48) (157)
----------- ---------- --------
3,690 3,082 1,970
----------- ---------- --------
FINANCING ACTIVITIES
Issue (repayment) of bank credit facilities 357 (647) (1,234)
Repayment of medium-term notes (125) - -
Repayment of senior unsecured notes (54) (85) (16)
Issue of US dollar debt securities 830 - 1,749
Repayment of obligations under capital leases (7) (8) (4)
Dividend on common shares (101) (77) (60)
Issue of common shares on exercise of stock options 24 89 84
Purchase of common shares (33) (144) -
Net change in non-cash working capital (note 14) 6 (11) 27
----------- ---------- --------
897 (883) 546
----------- ---------- --------
INVESTING ACTIVITIES
Expenditures on property, plant and equipment (4,582) (2,486) (2,552)
Net proceeds on sale of property, plant and equipment 7 20 76
----------- ---------- --------
Net expenditures on property, plant and equipment (4,575) (2,466) (2,476)
Net change in non-cash working capital (note 14) (88) 341 (25)
----------- ---------- --------
(4,663) (2,125) (2,501)
----------- ---------- --------
(DECREASE) INCREASE IN CASH (76) 74 15
CASH - BEGINNING OF YEAR 104 30 15
----------- ---------- --------
CASH - END OF YEAR $ 28 $ 104 $ 30
=========== ========== ========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION (note 14)
71
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
Notes to the Consolidated Financial Statements
(tabular amounts in millions of Canadian dollars, unless otherwise stated)
1. ACCOUNTING POLICIES
Canadian Natural Resources Limited (the "Company") is a senior independent oil
and natural gas exploration, development and production company based in
Calgary, Alberta, Canada. The Company's operations are focused in North America,
largely in western Canada, the North Sea and Offshore West Africa.
Within western Canada, the Company is developing its Horizon Oil Sands Project
(the "Horizon Project") and maintains its midstream activities. The Horizon
Project involves a plan to recover bitumen through mining operations, while the
midstream activities include the Company's pipeline operations and an
electricity co-generation system.
The consolidated financial statements of the Company have been prepared in
accordance with accounting principles generally accepted in Canada.
A summary of differences between accounting principles in Canada and those
generally accepted in the United States ("US") is contained in note 17.
Significant accounting policies are summarized as follows:
PRINCIPLES OF CONSOLIDATION
The consolidated financial statements include the accounts of the Company and
all of its subsidiaries and partnerships. A significant portion of the Company's
activities are conducted jointly with others and the consolidated financial
statements reflect only the Company's proportionate interest in such activities.
MEASUREMENT UNCERTAINTY
Management has made estimates and assumptions regarding certain assets,
liabilities, revenues and expenses in the preparation of the consolidated
financial statements. Such estimates primarily relate to unsettled transactions
and events as of the date of the consolidated financial statements. Accordingly,
actual results may differ from estimated amounts.
Depletion, depreciation and amortization, and amounts used for ceiling test
calculations are based on estimates of oil and natural gas reserves and
commodity prices, production expenses and capital costs required to develop and
produce those reserves. The majority of the Company's reserve estimates are
evaluated annually by independent engineering firms. By their nature, estimates
of reserves and the related future cash flows are subject to measurement
uncertainty, and the impact of differences between actual and estimated amounts
on the consolidated financial statements of future periods could be material.
The calculation of asset retirement obligations includes estimates of the future
costs to settle the asset retirement obligation, the timing of the cash flows to
settle the obligation, and the future inflation rates. The impact of differences
between actual and estimated costs, timing and inflation on the consolidated
financial statements of future periods could be material.
The measurement of petroleum revenue tax expense and the related provision in
the consolidated financial statements are subject to uncertainty associated with
future recoverability of oil and natural gas reserves, commodity prices and the
timing of future events, which could result in material changes to deferred
amounts.
CASH
Cash comprises cash on hand and demand deposits. Other investments (term
deposits and certificates of deposit) with a term to maturity of three months or
less from the transaction date are reported as cash equivalents.
PROPERTY, PLANT AND EQUIPMENT
The Company follows the full cost method of accounting for oil and natural gas
properties and equipment as prescribed by the Canadian Institute of Chartered
Accountants ("CICA"). Accordingly, all costs relating to the exploration for and
development of oil and natural gas reserves are capitalized and accumulated in
country-by-country cost centres. Administrative overhead incurred during the
development phase of large capital projects is capitalized until commercial
production commences. Proceeds on disposal of properties are ordinarily deducted
from such costs without recognition of profit or loss except where such disposal
constitutes a significant portion of the Company's reserves in that country.
For mining activities the property acquisition, exploration and development
costs are capitalized.
DEPLETION, DEPRECIATION AND AMORTIZATION
The costs related to each cost centre from which there is production are
depleted on the unit-of-production method based on the estimated proved reserves
of that country. Volumes of net production and net reserves before royalties are
converted to equivalent units on the basis of estimated relative energy content.
In determining its depletion base, the Company includes estimated future costs
to be incurred in developing proved reserves and excludes the cost of unproved
properties and major development projects. The unproved properties are assessed
periodically to ascertain whether impairment has occurred. When proved reserves
are assigned or the value of the unproved property is considered to be impaired,
the cost of the unproved property or the amount of the impairment is added to
costs subject to depletion. Certain costs for major development projects from
which there has been no commercial production are not subject to depletion until
commercial production commences.
Processing and production facilities are depreciated on a straight-line basis
over their estimated lives.
72
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
The Company reviews the carrying amount of its oil and natural gas properties
("the properties") relative to their recoverable amount ("the ceiling test") for
each cost centre at each annual balance sheet date, or earlier if circumstances
or events indicate impairment may have occurred. The recoverable amount is
calculated as the undiscounted cash flow from the properties using proved
reserves and expected future prices and costs. If the carrying amount of the
properties exceeds their recoverable amount, then an impairment loss equal to
the amount by which the carrying amount of the properties exceeds their fair
value is recognized in depletion. Fair value is calculated as the cash flow from
those properties using proved and probable reserves and expected future prices
and costs, discounted at a risk-free interest rate.
Midstream assets are depreciated on a straight-line basis over their estimated
lives. The Company reviews the recoverability of the carrying amount of the
midstream assets at each annual balance sheet date. If the carrying amount of
the midstream assets exceeds their recoverable amount, then an impairment loss
equal to the amount by which the carrying amount of the midstream assets exceeds
their fair value is recognized in depreciation.
Head office capital assets are amortized on a declining balance basis over their
estimated useful lives.
DEFERRED CHARGES
Deferred charges include deferred financing costs associated with the issuance
of long-term debt and settlement costs of long-term natural gas contracts.
Deferred charges are amortized over the original term of the related instrument.
ASSET RETIREMENT OBLIGATION
The fair values of asset retirement obligations related to long-term assets are
recognized as a liability in the period in which they are incurred. Retirement
costs equal to the fair value of the asset retirement obligations are
capitalized as part of the cost of the associated capital assets and are
amortized to expense through depletion over the life of the asset. The fair
value of the asset retirement obligation is estimated by discounting the
expected future cash flows to settle the asset retirement obligation at the
Company's credit-adjusted risk-free interest rate. In subsequent periods, the
asset retirement obligation is adjusted for the passage of time and for any
changes in the amount or timing of the underlying future cash flows.
FOREIGN CURRENCY TRANSLATION
Foreign operations that are self-sustaining are translated using the current
rate method. Under this method, assets and liabilities are translated to
Canadian dollars from their functional currency using the exchange rate in
effect at the consolidated balance sheet date. Revenues and expenses are
translated to Canadian dollars at the monthly average exchange rates. Gains or
losses on translation are included in the foreign currency translation
adjustment in shareholders' equity in the consolidated balance sheets.
Foreign operations that are integrated are translated using the temporal method.
For foreign currency balances and integrated subsidiaries, monetary assets and
liabilities are translated to Canadian dollars at the exchange rate in effect at
the consolidated balance sheet date and non-monetary assets and liabilities are
translated at the exchange rate in effect when the assets were acquired or
obligations incurred. Revenues and expenses are translated to Canadian dollars
at the monthly average exchange rates. Provisions for depletion, depreciation
and amortization are translated at the same rate as the related items.
Gains or losses on the translation of long-term debt denominated in US dollars
are either recognized in net earnings immediately, or in the foreign currency
translation adjustment (note 10) for translation gains or losses on that portion
of the US dollar denominated debt designated as a hedge of self-sustaining
foreign operations
PETROLEUM REVENUE TAX
The Company accounts for future United Kingdom petroleum revenue tax ("PRT") by
the life-of-the-field method. The total future liability or recovery of PRT is
estimated using current sales prices and costs. The estimated future PRT is
apportioned to accounting periods on the basis of total estimated future
revenues. Changes in the estimated total future PRT are accounted for
prospectively.
PRODUCTION SHARING CONTRACT
Production generated from offshore Cote d'Ivoire is shared by the terms of the
Production Sharing Contract ("PSC") with the State Oil Company of Cote d'Ivoire
("Petroci"). Revenues are divided into cost recovery revenues and profit
revenues. Cost recovery revenues allow the Company to recover the capital and
operating costs carried by the Company on behalf of Petroci. These revenues are
reported as sales revenues. Profit revenues are allocated to joint venture
partners in accordance with their respective equity interests, after a portion
has been allocated to the Cote d'Ivoire Government. The Government's share of
revenues attributable to the Company's equity interest is reported as either a
royalty expense or a current tax expense in accordance with the PSC.
INCOME TAX
The Company follows the liability method of accounting for income taxes. Under
this method, future income tax assets and liabilities are recognized based on
the estimated tax effects of temporary differences in the carrying value of
assets and liabilities in the consolidated financial statements and their
respective tax bases, using income tax rates substantively enacted on the
consolidated balance sheet date. The effect of a change in income tax rates on
the future income tax assets and liabilities is recognized in net earnings in
the period of the change.
73
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
REVENUE RECOGNITION
Revenues are recognized when products have been delivered or services have been
performed.
STOCK-BASED COMPENSATION PLANS
The Company accounts for its stock-based compensation plans using the fair value
method. A liability for expected cash settlements under the Company's Stock
Option Plan (the "Option Plan") is accrued over the vesting period of the stock
options based on the difference between the exercise price of the stock options
and the market price of the Company's common shares. The liability is revalued
quarterly to reflect changes in the market price of the Company's common shares
and the net change is recognized in net earnings. When stock options are
surrendered for cash, the cash settlement paid reduces the outstanding
liability. When stock options are exercised for common shares under the Option
Plan, consideration paid by employees, officers or directors and the previously
recognized liability associated with the stock options are recorded as share
capital.
The Company also has an employee stock savings plan. Contributions to the
employee stock savings plan are recorded as compensation expense at the time of
the contribution.
The Company also has a stock bonus plan. Contributions to the stock bonus plan
are recorded as compensation expense over the vesting period.
RISK MANAGEMENT ACTIVITIES
Financial instruments that do not qualify as hedges under Accounting Guideline
13 or are not designated as hedges are recorded at fair value on the Company's
consolidated balance sheet, with subsequent changes in fair value recognized in
net earnings.
The Company utilizes various financial instruments to manage its commodity
prices, foreign currency and interest rate exposures. These financial
instruments are not used for trading purposes.
The Company enters into commodity price contracts to manage anticipated sales of
crude oil and natural gas production in order to protect cash flow for capital
expenditure programs. The Company also enters into foreign currency denominated
financial instruments to manage future US dollar denominated crude oil and
natural gas sales. Gains or losses on these contracts are included in risk
management activities.
The Company enters into interest rate swap agreements to manage its fixed to
floating interest rate mix on long-term debt. The interest rate swap contracts
require the periodic exchange of payments without the exchange of the notional
principle amount on which the payments are based. Gains or losses on interest
rate swap contracts designated as hedges are included in interest expense. Gains
or losses on interest rate contracts not designated as hedges are included in
risk management activities.
The Company enters into cross currency swap agreements to manage its currency
exposure on long-term debt. The cross currency swap contracts require the
periodic exchange of payments with the exchange at maturity of notional
principal amounts on which the payments are based. Gains or losses on cross
currency swap contracts designated as hedges are included in interest expense.
Gains or losses on the termination of financial instruments that have been
accounted for as hedges are deferred under non-current assets or liabilities on
the consolidated balance sheets and amortized into net earnings in the period in
which the underlying hedged transaction is recognized. In the event a designated
hedged item is sold, extinguished or matures prior to the termination of the
related derivative instrument, any unrealized gain or loss is recognized in net
earnings.
PER COMMON SHARE AMOUNTS
The Company uses the treasury stock method to determine the dilutive effect of
stock options and other dilutive instruments. This method assumes that proceeds
received from the exercise of in-the-money stock options not included as a
liability are used to purchase common shares at the average market price during
the year. The dilutive effect of convertible securities is calculated by
applying the "as-if-converted" method, which assumes that the securities are
converted at the beginning of the period and that income items are adjusted to
net earnings.
COMPARATIVE FIGURES
Certain figures provided for prior years have been reclassified to conform to
the presentation adopted in 2004.
Common share data has been restated to reflect the two-for-one share split in
May 2004.
74
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
2. CHANGES IN ACCOUNTING POLICIES
ASSET RETIREMENT OBLIGATION
Effective January 1, 2004, the Company retroactively adopted the CICA's Section
3110, "Asset Retirement Obligations". The Section requires the recognition of a
liability for the fair value of the asset retirement obligation related to
long-term assets. Retirement costs equal to the fair value of the asset
retirement obligation are capitalized as part of the cost of the associated
capital asset and amortized to expense through depletion over the life of the
asset. In subsequent periods, the asset retirement obligation is adjusted for
the passage of time and any changes in the amount or timing of the underlying
future cash flows. Previously, future site restoration costs were accrued over
the life of the Company's proved reserves. This new standard was adopted
retroactively and prior period comparative balances have been restated. Adoption
of the standard had the following effects on the Company's consolidated balance
sheet as at December 31, 2003:
December 31, 2003
- --------------------------------------------------------------------------------------------------------------------------------
Increase property, plant and equipment $ 445
Decrease future site restoration liability $ (447)
Increase asset retirement obligation $ 897
Increase future income tax liability $ 3
Decrease foreign currency translation adjustment $ (14)
Increase retained earnings $ 6
===========
Adoption of the standard had the following effects on the Company's consolidated
statements of earnings and retained earnings:
Year Ended December 31 2004 2003 2002
- --------------------------------------------------------------------------------------------------------------------------------
Increase opening retained earnings $ 6 $ 10 $ 41
Decrease depletion, depreciation and amortization $ (120) $ (56) $ (16)
Increase asset retirement obligation accretion $ 51 $ 62 $ 68
Increase (decrease) future income tax expense $ 28 $ (2) $ (21)
======= ========== =======
RISK MANAGEMENT ACTIVITIES
Effective January 1, 2004, the Company prospectively adopted the CICA's
Accounting Guideline 13, "Hedging Relationships" and EIC 128, "Accounting for
Trading, Speculative or Non-Hedging Derivative Financial Instruments". Guideline
13 addresses the types of items that qualify for hedge accounting, the formal
documentation required to enable the use of hedge accounting, and the
requirement to evaluate hedges for effectiveness. EIC 128 requires that
financial instruments that are not designated as hedges be recorded at fair
value on the Company's consolidated balance sheet, with subsequent changes in
fair value recorded in earnings. The Company has designated certain of its
derivative financial instruments (note 12) as hedges, including certain crude
oil collars, natural gas collars, the currency swap on the US$125 million senior
unsecured note, and certain interest rate swaps. Adoption of Guideline 13 and
EIC 128 had the following effects on the Company's consolidated balance sheet as
at January 1, 2004:
JANUARY 1, 2004
- --------------------------------------------------------------------------------------------------------------------------------
Increase financial instruments asset $ 40
Increase deferred revenue $ 40
===========
The deferred revenue will be amortized to earnings over the term of the
underlying contracts.
PREFERRED SECURITIES
Effective December 31, 2004, the Company early adopted changes to the CICA's
Section 3860 "Financial Instruments - Presentation and Disclosure" that relate
to contractual obligations that may be settled by delivery of the Company's
common shares. Under the new rules, these obligations must be classified as
liabilities on the Company's consolidated balance sheets. Previously, these
obligations were classified as equity. These changes have been adopted
retroactively and prior periods have been restated. Adoption of the changes had
the following effects on the Company's consolidated financial statements:
2004 2003 2002
- --------------------------------------------------------------------------------------------------------------------------------
Increase long-term debt $ 96 $ 103 $ 126
Decrease preferred securities $ (96) $ (103) $ (126)
Increase interest expense $ 9 $ 9 $ 10
Increase foreign exchange gain $ 7 $ 23 $ 1
(Decrease) increase future income tax expense $ (1) $ 1 $ (4)
Decrease dividend on preferred securities, net of tax $ (5) $ (5) $ (6)
Decrease revaluation of preferred securities, net of tax $ (4) $ (18) $ (1)
======== ======= ============
75
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
FULL COST ACCOUNTING
Effective January 1, 2004, the Company prospectively adopted the CICA's
Accounting Guideline 16, "Oil and Gas Accounting - Full Cost". The guideline
modifies the ceiling test, which limits the aggregate capitalized costs that may
be carried forward to future periods. Specific new guidance was provided on
several issues, including the frequency of conducting cost centre impairment
tests, the testing for cost centre recoverability and the method of determining
fair value. The Guideline recommends that cost centre impairment tests should be
conducted at each annual balance sheet date. Recovery of costs is tested by
comparing the carrying amount of the oil and natural gas assets to their
recoverable amount, calculated as the undiscounted cash flows from those assets
using proved reserves and expected future prices and costs. If the carrying
amount exceeds the recoverable amount, then impairment should be recognized on
the amount by which the carrying amount of the assets exceeds the fair value of
the assets, calculated as the present value of expected cash flows using proved
and probable reserves and expected future prices and costs. The adoption of this
standard had no effect on the Company's consolidated financial statements for
the year ended December 31, 2004.
3. BUSINESS COMBINATIONS
PETROVERA PARTNERSHIP
In February 2004, the Company acquired certain resource properties in its
Northern Plains core region, collectively known as the Petrovera Partnership
("Petrovera"), for $471 million.
The acquisition was accounted for based on the purchase method. Results from
Petrovera are consolidated with the results of the Company effective from the
date of acquisition. The allocation of the purchase price to assets acquired and
liabilities assumed based on their fair values is set out in the following
table:
FEBRUARY 1, 2004
- --------------------------------------------------------------------------------------------------------------------------------
Purchase price:
Cash consideration $ 467
Cash acquired (23)
Non-cash working capital deficit assumed 27
-------
Total purchase price $ 471
=======
Purchase price allocated as follows:
Property, plant and equipment $ 643
Future income tax liability (129)
Asset retirement obligation (43)
-------
$ 471
=======
RIO ALTO EXPLORATION LTD.
In July 2002, the Company paid cash of $850 million and issued 20,016,436 common
shares with an attributed value of $522 million to acquire all of the issued and
outstanding common shares of Rio Alto Exploration Ltd. ("Rio Alto") by way of a
plan of arrangement (the "Plan of Arrangement"). Rio Alto was engaged in the
exploration for and production of oil and natural gas in western Canada and,
through wholly owned subsidiaries, in South America. Under the Plan of
Arrangement, the subsidiaries of Rio Alto that held its South American
properties were sold to a new company, Rio Alto Resources International Inc.
("Rio Alto International"), and each shareholder of Rio Alto received one common
share of Rio Alto International for each Rio Alto common share held.
The acquisition was accounted for based on the purchase method. Results from Rio
Alto are consolidated with the results of the Company effective from the date of
acquisition. The allocation of the purchase price to assets acquired and
liabilities assumed based on their fair values is set out in the following
table:
July 1, 2002
- --------------------------------------------------------------------------------------------------------------------------------
Purchase price:
Cash consideration $ 850
Share consideration 522
Cash acquired (7)
Non-cash working capital deficit assumed 92
Long-term debt assumed 936
--------
Total purchase price $ 2,393
========
Purchase price allocated as follows:
Property, plant and equipment $ 3,412
Future site restoration (44)
Future income tax (975)
--------
$ 2,393
========
76
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
4. OTHER LONG-TERM ASSETS
2004 2003
- --------------------------------------------------------------------------------------------------------------------------------
Risk management (note 12) $ 66 $ -
Deferred charges 76 74
----------- -------
142 74
Less: current portion 34 -
----------- -------
$ 108 $ 74
=========== =======
5. PROPERTY, PLANT AND EQUIPMENT
2004 2003
------------------------------------------ --------------------------------------------
ACCUMULATED Accumulated
DEPLETION AND depletion and
COST DEPRECIATION NET Cost depreciation Net
- --------------------------------------------------------------------------------------------------------------------------------
Oil and natural gas
North America $ 19,750 $ 6,356 $ 13,394 $ 15,914 $ 4,924 $ 10,990
North Sea 2,562 739 1,823 1,971 534 1,437
Offshore West Africa 1,101 192 909 806 139 557
Horizon Project 672 - 672 381 - 381
Midstream 241 32 209 225 25 200
Head office 101 44 57 70 31 39
------------ ------------ ------------ --------- --------- ---------
$ 24,427 $ 7,363 $ 17,064 $ 19,367 $ 5,653 $ 13,714
============ ============ ============ ========= ========= =========
During the year ended December 31, 2004, the Company capitalized administrative
overhead of $19 million (2003 - $12 million, 2002 - $13 million) relating to
exploration and development in the North Sea and Offshore West Africa and $35
million (2003 - $23 million, 2002 - $4 million) relating mainly to the Horizon
Project in North America.
Included in property, plant and equipment are unproved land and major
development projects that are not subject to depletion or depreciation:
2004 2003
- ------------------------------------------------------------------------------------------------------------------------------
Oil and natural gas
North America $ 1,028 $ 789
North Sea 44 56
Offshore West Africa 536 251
Horizon Project 672 381
----------- ---------
$ 2,280 $ 1,477
=========== =========
6. LONG-TERM DEBT
2004 2003
- ------------------------------------------------------------------------------------------------------------------------------
Bank credit facilities
US dollar bankers' acceptances (2004 - US$471 million, 2003 - US$207 million) $ 557 $ 268
Medium-term notes
6.85% unsecured debentures due May 28, 2004 - 125
7.40% unsecured debentures due March 1, 2007 125 125
Senior unsecured notes
6.42% due May 27, 2004 (2004 - US$nil, 2003 - US$40 million) - 52
7.69% due December 19, 2005 (2004 - US$125 million, 2003 - US$125 million) 194 194
Adjustable rate due May 27, 2009 (2004 - US$93 million, 2003 - US$93 million) 112 120
Preferred securities
8.30% due June 25, 2011 (2004 - US$80 million, 2003 - US$80 million) 96 103
US dollar debt securities
6.70% due July 15, 2011 (2004 - US$400 million, 2003 - US$400 million) 482 517
5.45% due October 1, 2012 (2004-US$350 million , 2003 - US$350 million) 421 452
4.90% due December 1,2014 (2004 - US$350 million, 2003 - US$nil) 421 -
7.20% due January 15, 2032 (2004 - US$400 million, 2003 - US$400 million) 482 517
6.45% due June 30, 2033 (2004 - US$350 million, 2003 - US$350 million) 421 452
5.85% due February 1, 2035 (2004 - US$350 million, 2003 - US$nil) 421 -
Obligations under capital leases - 7
----------- ---------
3,732 2,932
Less: current portion of long-term debt 194 184
----------- ---------
$ 3,538 $ 2,748
=========== =========
77
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
BANK CREDIT FACILITIES
The Company has unsecured syndicated bank credit facilities of $3,425 million,
comprised of a $100 million operating demand facility, a revolving credit and
term loan facility of $1,825 million and a revolving and term loan facility of
$1,500 million. The $1,825 million revolving credit and term loan facility is
fully revolving for 364-day periods with a term to June 2005 and a provision for
extension at the mutual agreement of the Company and the lenders. If not
extended, the facility converts to a non-revolving loan with a term of two
years. The full amount of the outstanding principal would be repayable at the
end of year two following the initiation of the term period. The $1,500 million
revolving credit facility has a five-year term, with three, one-year extension
provisions. If the facility is not extended, the amount outstanding would be
repayable in December 2009. The facilities provide that the borrowings may be
made by way of operating advances, prime loans, bankers' acceptances, US base
rate loans or US dollar LIBOR advances, which bear interest at the bank's prime
rates or at money market rates plus applicable margins.
The Company fixed the exchange rate on the repayment of its US dollar bankers'
acceptances using foreign currency financial derivatives (note 12). The US
dollar bankers' acceptances were repaid in January 2005 at a C$/US$ exchange
rate of 1.180.
The weighted average interest rate of the bank credit facilities outstanding at
December 31, 2004, was 3.47% (2003 - 2.32%).
In addition to the outstanding debt, letters of credit aggregating $24 million
have been issued.
MEDIUM-TERM NOTES
In August 2003, the Company filed a short form shelf prospectus that allows for
the issue of up to $1 billion of medium term notes in Canada until September
2005. If issued, these securities will bear interest as determined at the date
of issuance. In May 2004, the Company repaid the $125 million 6.85% unsecured
debentures due May 2004, which were issued under a previous medium-term note
program. The Company has $125 million of unsecured debentures outstanding from a
previous medium-term note program.
SENIOR UNSECURED NOTES
The final principal repayment on the 6.95% senior unsecured notes was made in
September 2003. The 6.42% senior unsecured notes were repaid in May 2004. In May
2003, the Company prepaid the US$50 million 6.50% senior unsecured notes due May
2008. The adjustable rate senior unsecured notes bear interest at 6.54% and have
annual principal repayments of US$31 million commencing in May 2007, through May
2009. These debt instruments contain covenants pertaining to the Company's net
worth, certain financial ratios and the ability to grant security. Through a
currency swap, the principle and interest repayments on the US$125 million,
7.69% notes due December 2005 have been fixed at $194 million and 7.30%,
respectively (note 12).
US DOLLAR DEBT SECURITIES
In December 2004, the Company issued US$350 million of debt securities maturing
December 2014, bearing interest at 4.90% and US$350 million of debt securities
maturing February 2035, bearing interest at 5.85%. Proceeds from the securities
issued were used to repay bankers' acceptances under the Company's bank credit
facilities. The Company has entered into certain interest rate swap contracts to
convert the fixed rate interest coupon into a floating interest rate on the
securities due December 2014 (note 12).
After issuing the above securities, the Company has US$1.3 billion remaining on
a US$2.0 billion shelf prospectus filed in May 2003 that allows for the issue of
debt securities in the United States until June 2005. If issued, these
securities will bear interest as determined at the date of issuance.
PREFERRED SECURITIES
Annual principal repayments of approximately US$27 million are required
commencing June 2009 through June 2011. The notes are subordinated to the other
long-term debt of the Company and contain, among other things, certain financial
covenants restricting the granting of security for new borrowings and the
maintenance of specified financial ratios. The Company has the unrestricted
right to pay interest, principal and principal prepayment amounts by delivering
common shares to the Trustee of the subordinated notes. The semi-annual interest
payments may be deferred at the option of the Company for up to two consecutive
periods, with a maximum of eight deferral periods over the life of the
securities.
REQUIRED DEBT REPAYMENTS
Required debt repayments are as follows:
Year REPAYMENT
- --------------------------------------------------------------------------------------------------------------------------------
2005 $ 194
2006 $ -
2007 $ 162
2008 $ 37
2009 $ 69
Thereafter $ 2,713
No debt repayments are reflected for the bank credit facilities due to the
extendable nature of the facilities.
78
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
7. OTHER LONG-TERM LIABILITIES
2004 2003
- --------------------------------------------------------------------------------------------------------------------------------
Asset retirement obligation $ 1,119 $ 897
Stock-based compensation 323 171
Deferred revenue (note 12) 26 -
1,468 1,068
Less: current portion 260 130
------------ ----------
$ 1,208 $ 938
============ ==========
ASSET RETIREMENT OBLIGATION
At December 31, 2004, the Company's total estimated undiscounted costs to settle
its asset retirement obligations with respect to crude oil and natural gas
properties and facilities was $3,063 million (2003 - $2,281 million). These
costs will be incurred over several years and have been discounted using a
credit-adjusted risk-free interest rate of 6.7%. A reconciliation of the
discounted asset retirement obligation is as follows:
2004 2003
- --------------------------------------------------------------------------------------------------------------------------------
Asset retirement obligation
Balance - beginning of year $ 897 $ 867
Liabilities incurred 339 117
Liabilities settled (32) (40)
Asset retirement obligation accretion 51 62
Revision of estimates (86) (6)
Foreign exchange (50) (103)
----------- ---------
Balance - end of year $ 1,119 $ 897
=========== =========
The Company's pipelines and co-generation plant have indeterminant lives and
therefore the fair values of the related asset retirement obligations cannot be
reasonably determined. The asset retirement obligation for these assets will be
recorded in the year in which the lives of the assets are determinable.
STOCK-BASED COMPENSATION
The Company's Stock Option Plan ("Option Plan") results in the recognition of a
liability for the expected cash settlements under the Option Plan. The current
portion represents the amount of the liability that could be realized within the
next 12 month period if all vested options are surrendered for cash settlement.
2004 2003
- --------------------------------------------------------------------------------------------------------------------------------
Stock-based compensation
Balance - beginning of year $ 171 $ -
Stock-based compensation provision 259 200
Expense relating to share bonus plan (10) -
Cash payment for options surrendered (80) (31)
Transferred to common shares (38) (8)
Capitalized with respect to Horizon Project 21 10
Balance - end of year 323 171
Less: current portion of stock-based compensation 243 130
----------- ---------
$ 80 $ 41
=========== =========
79
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
8. TAXES
TAXES OTHER THAN INCOME TAX
2004 2003 2002
- --------------------------------------------------------------------------------------------------------------------------------
Current petroleum revenue tax $ 190 $ 106 $ 41
Deferred petroleum revenue tax (45) (9) 10
Provincial capital taxes and surcharges 20 10 11
Other - - 1
----------- --------- --------
$ 165 $ 107 $ 63
=========== ========= ========
INCOME TAX
The provision for income tax is as follows:
2004 2003 2002
- --------------------------------------------------------------------------------------------------------------------------------
Current income tax expense
Current income tax - North America $ 89 $ 43 $ -
Large Corporations Tax - North America 11 16 21
Current income tax - North Sea 2 23 (19)
Current income tax - Offshore West Africa 13 10 6
Current income tax - other 1 - -
----------- --------- --------
116 92 8
Future income tax expense 474 338 375
----------- --------- ---------
Income tax $ 590 $ 430 $ 383
=========== ========= =========
The provision for income tax is different from the amount computed by applying
the combined statutory Canadian federal and provincial income tax rates to
earnings before taxes. The reasons for the difference are as follows:
2004 2003 2002
- --------------------------------------------------------------------------------------------------------------------------------
Canadian statutory income tax rate 39.3% 41.1% 42.4%
========= ======== =========
Income tax provision at statutory rate $ 849 $ 797 $ 418
Effect on income taxes of:
Non-deductible portion of Canadian crown payments 221 285 211
Canadian resource allowance (270) (281) (243)
Large Corporations Tax 11 16 21
Deductible UK petroleum revenue tax (57) (40) (22)
Foreign tax rate differentials (31) 20 (1)
Federal income tax rate reductions - (247) -
Provincial income tax rate reductions (66) (31) (21)
UK income tax rate increase - - 34
Non-taxable portion of foreign exchange (36) (103) (21)
Other (31) 14 7
--------- -------- ---------
Income tax $ 590 $ 430 $ 383
========= ======== =========
The following table summarizes the temporary differences that give rise to the
future income tax liability:
2004 2003
- ------------------------------------------------------------------------------------------------------------------------------
Future income tax liabilities
Property, plant and equipment $ 3,760 $ 2,884
Timing of partnership items 1,254 1,095
Foreign exchange gain on long-term debt 102 90
Risk management 19 -
Other 43 14
Future income tax assets
Asset retirement obligation (418) (365)
Capital loss carryforwards (92) -
Attributed Canadian Royalty Income (54) (58)
Stock-based compensation (106) (56)
Deferred petroleum revenue tax (58) (13)
----------- ----------
Future income tax liability $ 4,450 $ 3,591
=========== ==========
80
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
A significant portion of the Company's North American taxable income is
generated by partnerships. Income taxes are incurred on the partnerships'
taxable income in the year following their inclusion in the Company's
consolidated net earnings. Current income tax will vary and is dependent upon
the amount of capital expenditures incurred in Canada and the way it is
deployed.
During 2004, the Government of Alberta passed legislation to reduce its
corporate income tax rate by 1.0% effective April 1, 2004. Accordingly, the
Company's future income tax liability was reduced by $66 million.
During 2003, the Government of Alberta passed legislation to reduce its
corporate income tax rate by 0.5% effective April 1, 2003. Also during 2003, the
Canadian federal government passed legislation to change the taxation of
resource income. The legislation reduces the corporate income tax rate on
resource income from 28% to 21% over five years beginning January 1, 2003. Over
the same period, the deduction for resource allowance is phased out and a
deduction for actual crown royalties paid is phased in. The Company's future
income tax liability was reduced by $31 million with respect to the Alberta
corporate income tax rate reduction and by $247 million with respect to the
Federal resource income tax rate changes.
9. SHARE CAPITAL
AUTHORIZED
200,000 Class 1 preferred shares with a stated value of $10.00 each.
Unlimited number of common shares without par value.
ISSUED
2004 2003
-------------------------- ---------------------------
COMMON SHARES NUMBER OF Number of
SHARES shares
(thousands) AMOUNT (thousands) Amount
- --------------------------------------------------------------------------------------------------------------------------------
Balance - beginning of year 267,463 $ 2,353 267,552 $ 2,304
Issued upon exercise of stock options 1,591 24 5,381 89
Previously recognized liability on stock
options exercised for common shares - 38 - 8
Purchase of common shares under Normal Course Issuer Bid (873) (7) (5,470) (48)
------- ---------- ------- ----------
Balance - end of year 268,181 $ 2,408 267,463 $ 2,353
======= ========== ======= ==========
SHARE SPLIT
The Company's shareholders approved a subdivision or share split of its issued
and outstanding common shares on a two-for-one basis at the Company's Annual and
Special Meeting held on May 6, 2004. All common share and per common share
amounts have been restated to retroactively reflect the share split.
NORMAL COURSE ISSUER BID
During 2004, the Company purchased 873,400 common shares at an average price of
$38.01 per common share for a total cost of $33 million. The excess cost over
book value of the common shares purchased was applied to reduce retained
earnings.
During 2003, the Company purchased 5,469,600 common shares at an average price
of $26.26 per common share for a total cost of $144 million. The excess cost
over book value of the common shares purchased was applied to reduce retained
earnings.
In January 2005, the Company renewed its Normal Course Issuer Bid, allowing the
Company to purchase up to 13,409,006 common shares or 5% of the Company's
outstanding common shares on the date of announcement, during the 12-month
period beginning January 24, 2005 and ending January 23, 2006. As at February
18, 2005, the Company had not purchased any additional shares under the renewed
Normal Course Issuer Bid.
DIVIDEND POLICY
The Company pays regular quarterly dividends in January, April, July and October
of each year. On February 18, 2005, the Board of Directors set the Company's
regular quarterly dividend at $0.1125 per common share (2004 - $0.10 per common
share, 2003 - $0.075 per common share, 2002 - $0.0625 per common share)
commencing with the April 1, 2005 payment.
STOCK OPTIONS
The Company's Option Plan provides for granting of stock options to directors,
officers and employees. Stock options granted under the Option Plan have a
maximum term of six years to expiry and vest equally over a five-year period
starting on the first anniversary date of the grant. The exercise price of each
stock option granted is determined as the closing market price of the common
shares on the Toronto Stock Exchange on the day prior to the grant. Each stock
option granted permits the holder to purchase one common share of the Company at
the stated exercise price.
81
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
In June 2003, the Company approved a modification to its Option Plan providing
the stock option holder the right to elect to receive a cash payment equal to
the difference between the exercise price of the stock option and the market
price of the Company's common shares on the date of surrender, multiplied by the
number of common shares covered by the stock options surrendered, in lieu of
receiving common shares. The modification to the Option Plan was accounted for
prospectively.
For the year ended December 31, 2004, the Company recorded compensation expense
of $249 million (2003 - $200 million). As at December 31, 2004, the total
liability for expected cash settlements under the Option Plan is $323 million
(2003 - $171 million), of which $243 million (2003 - $130 million) is included
as a current liability. During the year ended December 31, 2004, cash payments
of $80 million were made for 3,781,000 stock options surrendered (2003 - cash
payments of $31 million for 2,674,000 stock options surrendered).
Prior to the modification, the Company disclosed pro-forma measures of net
earnings and net earnings per common share as if stock options had been
recognized as compensation expense estimated on the date of grant using the
Black-Scholes option pricing model. As stock-based compensation is now reflected
in the consolidated statement of earnings, the pro-forma disclosures are no
longer required.
The following table summarizes information relating to stock options outstanding
at December 31, 2004 and 2003:
2004 2003
-------------------------- ---------------------------
STOCK WEIGHTED Stock Weighted
OPTIONS AVERAGE options average
(thousands) EXERCISE (thousands) exercise
PRICE price
- --------------------------------------------------------------------------------------------------------------------------------
Outstanding - beginning of year 17,789 $ 19.72 25,765 $ 18.57
Granted 4,861 $ 35.89 1,336 $ 26.16
Exercised for common shares (1,591) $ 15.10 (5,381) $ 16.57
Surrendered for cash settlement (3,781) $ 18.71 (2,674) $ 17.36
Forfeited (1,017) $ 27.72 (1,257) $ 21.39
------ ------------ ------ ---------
Outstanding - end of year 16,261 $ 24.74 17,789 $ 19.72
------ ------------ ------ ---------
Exercisable - end of year 3,816 $ 19.85 4,646 $ 17.33
====== ============ ====== =========
The range of exercise prices of stock options outstanding and exercisable at
December 31, 2004 is as follows:
STOCK OPTIONS OUTSTANDING STOCK OPTIONS EXERCISABLE
-------------------------------------------- ------------------------------
WEIGHTED
STOCK AVERAGE WEIGHTED STOCK WEIGHTED
OPTIONS REMAINING AVERAGE OPTIONS AVERAGE
OUTSTANDING TERM EXERCISE EXERCISABLE EXERCISE
RANGE OF EXERCISE PRICES (thousands) (years) PRICE (thousands) PRICE
- --------------------------------------------------------------------------------------------------------------------------------
$10.50 - $14.99 15 0.40 $ 13.16 15 $ 13.16
$15.00 - $19.99 7,175 2.10 $ 18.82 2,586 $ 18.41
$20.00-$24.99 3,830 3.05 $ 22.50 1,082 $ 22.39
$25.00-$29.99 862 4.71 $ 26.86 112 $ 26.82
$30.00-$34.99 2,978 5.12 $ 33.80 21 $ 33.93
$35.00-$39.99 645 5.17 $ 35.79 - $ -
$40.00-$44.99 318 5.60 $ 40.99 - $ -
$45.00-$48.99 438 5.90 $ 47.87 - $ -
------ ---- ---------- ----- -----------
16,261 3.30 $ 24.74 3,816 $ 19.85
====== ==== ========== ===== ===========
10. FOREIGN CURRENCY TRANSLATION ADJUSTMENT
The foreign currency translation adjustment represents the unrealized gain
(loss) on the Company's net investment in self-sustaining foreign operations.
Effective July 1, 2002, the Company designated certain US dollar denominated
debt as a hedge against its net investment in US dollar-based self-sustaining
foreign operations. Accordingly, translation gains and losses on this US dollar
denominated debt are included in the foreign currency translation adjustment.
2004 2003
- --------------------------------------------------------------------------------------------------------------------------------
Balance - beginning of year as previously reported $ 17 $ 24
Change in accounting policy (note 2) (14) 2
----------- -------
Balance - beginning of year as restated 3 26
Unrealized loss on translation of net investment (24) (124)
Hedge of net investment with US dollar denominated debt, net of tax 15 101
Balance - end of year $ (6) $ 3
=========== =======
82
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
11. NET EARNINGS PER COMMON SHARE
The following table provides a reconciliation between basic and diluted amounts
per common share:
(thousands of shares) 2004 2003 2002
- -------------------------------------------------------------------------------------------------------------------------------
Weighted average common shares outstanding - basic 268,112 268,470 255,766
Effect of dilutive stock options (1) - 2,444 5,488
Assumed settlement of preferred securities with common shares 2,230 3,908 5,362
-------- ------- -------
Weighted average common shares outstanding - diluted 270,342 274,822 266,616
-------- ------- -------
Net earnings $ 1,405 $ 1,403 $ 539
Interest on preferred securities, net of tax 5 5 6
Revaluation of preferred securities, net of tax (4) (18) (1)
------- ------- -------
Diluted net earnings $ 1,406 $ 1,390 $ 544
------- ------- -------
Net earnings per common share
Basic $ 5.24 $ 5.23 $ 2.11
Diluted $ 5.20 $ 5.06 $ 2.04
======= ======= =======
(1) The modification of the Option Plan described in note 9 results in a
liability and expense for all outstanding stock options. As such, the
potential common shares associated with the stock options are not included
in diluted earnings per share effective from June 2003, the date of the
modification.
For the year ended December 31, 2002, 639,832 stock options with a weighted
average exercise price of $24.17, were excluded from the calculation as their
effect on per common share amounts was not dilutive.
12. FINANCIAL INSTRUMENTS
RISK MANAGEMENT
On January 1, 2004, the fair values of all outstanding derivative financial
instruments that were not designated as hedges for accounting purposes were
recorded on the consolidated balance sheet, with an offsetting net deferred
revenue amount (note 2). Subsequent changes in fair value are recognized on the
consolidated balance sheet and in net earnings. The estimated fair value for all
derivative financial instruments is based on third party indications. The
following table reconciles the change in derivative financial instruments:
ASSET (LIABILITY) RISK MANAGEMENT DEFERRED TOTAL UNREALIZED
MARK-TO-MARKET REVENUE GAIN/(LOSS)
- -------------------------------------------------------------------------------------------------------------------------------
Balance - beginning of year $ 40 $(40) $ -
Change in fair value of existing financial instruments at
beginning of year and new financial instruments entered in 2004 468 - 468
Put premiums 32 - 32
Realized risk management activities (474) - (474)
Amortization of deferred revenue - 14 14
----- ---- -----
Balance - end of year 66 (26) $ 40
=====
Less: current portion 34 (17)
----- ----
$ 32 $ (9)
===== ====
FINANCIAL CONTRACTS
The Company's financial instruments recognized in the consolidated balance
sheets consist of cash, accounts receivable, accounts payable, accrued
liabilities, risk management activities, stock-based compensation and long-term
debt.
The estimated fair values of financial instruments have been determined based on
the Company's assessment of available market information and appropriate
valuation methodologies; however, these estimates may not necessarily be
indicative of the amounts that could be realized or settled in a current market
transaction.
The carrying value of cash, accounts receivable, accounts payable, accrued
liabilities, stock-based compensation and long-term debt with variable interest
rates approximate their fair value.
83
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
The estimated fair values of other financial instruments are as follows:
2004 2003
------------------------------ -----------------------------
CARRYING VALUE FAIR VALUE Carrying value Fair Value
- ----------------------------------------------------------------------------------------------------------------------------------
ASSET (LIABILITY)
Derivative financial instruments $ 66 $ 33 $ - $ 16
Fixed rate notes $ (3,175) $ (3,364) $ (2,664) $ (2,880)
============ =========== =========== ===========
The Company uses certain derivative financial instruments to manage its
commodity prices, foreign currency and interest rate exposures. These financial
instruments are entered into solely for hedging purposes and are not used for
trading or other speculative purposes. The following summarizes transactions
outstanding as at December 31, 2004:
REMAINING TERM VOLUME AVERAGE PRICE INDEX
- --------------------------------------------------------------------------------------------------------------------------------
OIL
Oil price collars Jan 2005 - Mar 2005 140,500 bbl/d US$36.09 - US$45.32 WTI
Apr 2005 - Jun 2005 150,500 bbl/d US$39.98 - US$49.39 WTI
Jul 2005 - Sep 2005 139,500 bbl/d US$41.60 - US$51.35 WTI
Oct 2005 - Dec 2005 139,500 bbl/d US$41.60 - US$51.35 WTI
Oil puts Jan 2005 - Mar 2005 99,000 bbl/d US$29.21 WTI
Apr 2005 - Jun 2005 123,000 bbl/d US$29.89 WTI
Jul 2005 - Sep 2005 50,000 bbl/d US$31.09 WTI
Oct 2005 - Dec 2005 50,000 bbl/d US$29.81 WTI
REMAINING TERM VOLUME AVERAGE PRICE INDEX
- --------------------------------------------------------------------------------------------------------------------------------
NATURAL GAS
AECO collars Jan 2005 - Mar 2005 640,000 GJ/d C$6.24 - C$11.69 AECO
Apr 2005 - Jun 2005 740,000 GJ/d C$5.83 - C$7.89 AECO
Jul 2005 - Sep 2005 640,000 GJ/d C$5.88 - C$7.92 AECO
Oct 2005 - Dec 2005 114,500 GJ/d C$6.00 - C$8.08 AECO
REMAINING TERM AMOUNT AVERAGE EXCHANGE RATE
($ millions) (US$/C$)
- --------------------------------------------------------------------------------------------------------------------------------
FOREIGN CURRENCY
Currency collars Jan 2005 - Aug 2005 US$10/month 1.37 - 1.49
REMAINING TERM AMOUNT EXCHANGE RATE INTEREST RATE INTEREST RATE
($ millions) (US$/C$) (US$) (C$)
- --------------------------------------------------------------------------------------------------------------------------------
Currency swap Jan 2005 - Dec 2005 US$125 1.55 7.69% 7.30%
Currency forward Jan 2005 - Jan 2005 US$471 1.18 n/a n/a
REMAINING TERM AMOUNT FIXED RATE FLOATING RATE
($ millions)
- --------------------------------------------------------------------------------------------------------------------------------
INTEREST RATE
Swaps - fixed to floating Jan 2005 - Jan 2005 US$200 7.20% LIBOR(1) + 3.00%
Jan 2005 - Jul 2006 US$200 6.70% LIBOR(1) + 1.65%
Jan 2005 - Jan 2007 US$200 7.20% LIBOR(1) + 2.23%
Jan 2005 - Oct 2012 US$350 5.45% LIBOR(1) + 0.81%
Jan 2005 - Dec 2014 US$350 4.90% LIBOR(1) + 0.38%
Swaps - floating to fixed Jan 2005 - Mar 2007 C$10 7.36% CDOR(2)
(1) London Interbank Offered Rate
(2) Canadian Deposit Overnight Rate
CREDIT RISK
Accounts receivable are mainly with customers in the oil and natural gas
industry and are subject to normal industry credit risks. The Company minimizes
this risk by entering into sales contracts with only highly rated entities. In
addition, the Company reviews its exposure to individual companies on a regular
basis and where appropriate, ensures that parental guarantees or letters of
credit are in place to minimize the impact in the event of default. The Company
is also exposed to possible losses in the event of non-performance by
counterparties to derivative financial instruments; however, the Company
minimizes this credit risk by entering into agreements with only highly rated
financial institutions.
84
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
13. COMMITMENTS
The Company has committed to certain payments as follows:
2005 2006 2007 2008 2009 Thereafter
- --------------------------------------------------------------------------------------------------------------------------------
Natural gas transportation $ 194 $ 147 $ 100 $ 78 $ 37 $ 168
Oil transportation and pipeline $ 11 $ 9 $ 11 $ 12 $ 13 $ 154
Offshore equipment operating lease $ 110 $ 48 $ 48 $ 48 $ 48 $ 184
Baobab Project $ 99 $ - $ - $ - $ - $ -
Offshore drilling and other $ 125 $ 8 $ - $ - $ - $ -
Electricity $ 26 $ 28 $ 20 $ 13 $ 8 $ 34
Office lease $ 21 $ 21 $ 22 $ 23 $ 24 $ 30
Processing $ 5 $ 2 $ - $ - $ - $ -
Horizon Project $ 99 $ - $ - $ - $ - $ -
14. SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Changes in non-cash working capital were as follows:
2004 2003 2002
- --------------------------------------------------------------------------------------------------------------------------------
Decrease (increase) in non-cash working capital
Accounts receivable and other $ (329) $ 35 $ (164)
Accounts payable 39 125 (145)
Accrued liabilities 194 122 154
----------- --------- ----------
Net change in non-cash working capital $ (96) $ 282 $ (155)
----------- --------- ----------
Relating to:
Operating activities $ (14) $ (48) $ (157)
Financing activities 6 (11) 27
Investing activities (88) 341 (25)
----------- --------- ----------
$ (96) $ 282 $ (155)
=========== ========= ==========
Other cash flow information: 2004 2003 2002
- ------------------------------------------------------------------------------------------------------------------------------
Interest paid $ 192 $ 178 $ 132
Taxes paid $ 218 $ 51 $ 160
15. SEGMENTED INFORMATION
The Company's oil and natural gas activities are conducted in three geographic
segments: North America, North Sea and Offshore West Africa. These activities
relate to the exploration, development, production and marketing of oil, natural
gas liquids and natural gas.
The Company's Horizon Project has been classified as a separate segment. As the
bitumen will be recovered through mining operations, this project constitutes a
distinct segment from oil and natural gas activities. There are currently no
revenues for this project and all directly related expenditures have been
capitalized.
Midstream activities include the Company's pipeline operations and an
electricity co-generation system.
Activities that are not included in the above segments are included in the
segmented information as other.
Inter segment eliminations include internal transportation and electricity
charges.
85
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
15. Segmented information (continued)
Oil and Natural Gas
---------------------------------------------------------------------------------------
North America North Sea Offshore West Africa
--------------------------- --------------------------- ---------------------------
2004 2003 2002 2004 2003 2002 2004 2003 2002
------- ------- ------- ------- ------- ------- ------- ------- -------
Revenue $ 5,979 $ 5,021 $ 3,719 $ 1,317 $ 953 $ 620 $ 222 $ 155 $ 102
Less: royalties (1,003) (868) (564) (2) 1 (33) (6) (5) (3)
------- ------- ------- ------- ------- ------- ------- ------- -------
Revenue, net of royalties 4,976 4,153 3,155 1,315 954 587 216 150 99
------- ------- ------- ------- ------- ------- ------- ------- -------
Segmented expenses
Production 976 845 656 370 314 229 36 38 35
Transportation 256 264 273 32 30 20 - - -
Depletion, depreciation and 1,444 1,209 1,022 265 252 188 53 41 80
amortization
Asset retirement obligation accretion 28 26 20 22 36 48 1 - -
Realized risk management activities 362 157 76 112 (9) 7 - - -
------- ------- ------- ------- ------- ------- ------- ------- -------
Total segmented expenses 3,066 2,501 2,047 801 623 492 90 79 115
------- ------- ------- ------- ------- ------- ------- ------- -------
Segmented earnings before the following $ 1,910 $ 1,652 $ 1,108 $ 514 $ 331 $ 95 $ 126 $ 71 $ (16)
======= ======= ======= ======= ======= ======= ======= ======= =======
Non-segmented expenses
Administration
Stock-based compensation
Interest
Unrealized risk management activities
Foreign exchange gain
Total non-segmented expenses
Earnings before taxes
Taxes other than income tax
Current income tax expense
Future income tax expense
Net earnings
Capital expenditures
2004
------------------------------------------------------------------------------
Cash Non-cash Capital Fair value Capitalized
consideration consideration expenditure adjustments(1) costs
------------- ------------- ------------ -------------- -----------
Oil and natural gas
North America $ 3,329 $ 26 $ 3,355 $ 482 $ 3,837
North Sea 608 - 608 172 780
Offshore West Africa 296 - 296 - 296
------- ------- ------- ------- -------
4,233 26 4,259 654 4,913
Horizon Project 291 - 291 - 291
Midstream 16 - 16 - 16
Head office 35 - 35 - 35
------- ------- ------- ------- -------
$ 4,575 $ 26 $ 4,601 $ 654 $ 5,255
======= ======= ======= ======= =======
- ------------
(1) Asset retirement obligations, future income tax adjustments on non tax base
assets, and other fair value adjustments.
86
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
Midstream Other Inter-segment Elimination Total
- ----------------------------- ----------------------------- ----------------------------- -----------------------------
2004 2003 2002 2004 2003 2002 2004 2003 2002 2004 2003 2002
- ------- ------- ------- ------- ------- ------- ------- ------- ------- ------- ------- -------
$ 68 $ 61 $ 52 $ 1 $ - $ - $ (40) $ (35) $ (34) $ 7,547 $ 6,155 $ 4,459
- - - - - - - - - (1,011) (872) (600)
- ------- ------- ------- ------- ------- ------- ------- ------- ------- ------- ------- -------
68 61 52 1 - - (40) (35) (34) 6,536 5,283 3,859
- ------- ------- ------- ------- ------- ------- ------- ------- ------- ------- ------- -------
20 15 14 - - - (2) (3) (3) 1,400 1,209 931
- - - - - - (38) (32) (31) 250 262 262
7 7 8 - - - - - - 1,769 1,509 1,298
- - - - - - - - - 51 62 68
- - - - - - - - - 474 148 83
- ------- ------- ------- ------- ------- ------- ------- ------- ------- ------- ------- -------
27 22 22 - - - (40) (35) (34) 3,944 3,190 2,642
- ------- ------- ------- ------- ------- ------- ------- ------- ------- ------- ------- -------
$ 41 $ 39 $ 30 $ 1 $ - $ - $ - $ - $ - 2,592 2,093 1,217
======= ======= ======= ======= ======= ======= ======= ======= ======= ======= ======= =======
115 87 61
259 200 -
189 201 203
(40) - -
(91) (335) (32)
------- ------- -------
432 153 232
------- ------- -------
2,160 1,940 985
165 107 63
116 92 8
474 338 375
------- ------- -------
$ 1,405 $ 1,403 $ 539
======= ======= =======
2003
------------------------------------------------------------------------------
Cash Non-cash Capital Fair value Capitalized
consideration consideration expenditures adjustments(1) costs
------------- ------------- ------------ -------------- -----------
Oil and natural gas
North America $ 1,769 $ - $ 1,769 $ - $ 1,769
North Sea 338 - 338 25 353
Offshore West Africa 176 - 176 - 176
------- ------- ------- ------- -------
2,283 - 2,283 25 2,308
Horizon Project 152 - 152 - 152
Midstream 11 - 11 - 11
Head office 20 - 20 - 20
------- ------- ------- ------- -------
$ 2,466 $ - $ 2,466 $ 25 $ 2,491
======= ======= ======= ======= =======
87
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
Segmented property, plant and equipment, net 2004 2003
- -------------------------------------------- -------- --------
Oil and natural gas
North America $ 13,394 $ 10,990
North Sea 1,823 1,437
Offshore West Africa 909 667
Horizon Project 672 381
Midstream 209 200
Head office 57 39
-------- --------
$ 17,064 $ 13,714
======== ========
Segmented assets 2004 2003
- ---------------- -------- --------
Oil and natural gas
North America $ 14,455 $ 11,731
North Sea 2,036 1,562
Offshore West Africa 922 703
Horizon Project 672 381
Midstream 268 227
Head office 57 39
-------- --------
$ 18,410 $ 14,643
======== ========
16. Subsequent event
On February 9, 2005, the Company's Board of Directors unanimously authorized the
Company to proceed with Phase 1 of the Horizon Oil Sands Project. The Horizon
Project is designed as a phased development and includes two components: the
mining of bitumen and an onsite upgrader. Phase 1 production is targeted to
begin at 110,000 bbl/d of 34(degree) API light sweet, synthetic crude oil
("SCO"). Phase 2 would increase production to 155,000 bbl/d of SCO. Phase 3
would further increase production to 232,000 bbl/d of SCO. Total expected
capital costs for all three phases of the development are estimated at $10.8
billion. Capital costs for the first phase of the Horizon Project are estimated
at $6.8 billion including a contingency reserve of $700 million, with $1.4
billion to be incurred in 2005, and $2.2 billion, $2.0 billion and $1.2 billion
to be incurred in 2006, 2007 and 2008, respectively.
17. Differences between Canadian and United States generally accepted
accounting principles
The Company's consolidated financial statements have been prepared in accordance
with generally accepted accounting principles in Canada ("Canadian GAAP"). These
principles conform in all material respects with those in the United States ("US
GAAP") except for those noted below. Differences arising from US GAAP disclosure
requirements are not addressed.
The application of US GAAP would have the following effects on consolidated net
earnings as reported:
(millions of Canadian dollars, except per common share amounts) Notes 2004 2003 2002
- --------------------------------------------------------------- ----- ------- ------- -------
Net earnings - Canadian GAAP $ 1,405 $ 1,403 $ 539
Adjustments, net of tax
Depletion (A) 4 4 (5)
Derivative financial instruments (B) (9) (49) 29
Capitalized interest (C) 16 - -
Asset retirement obligation accretion (D) - - 41
Cumulative effect of change in accounting policy (D) - (4) -
Tax effect of flow-through shares (E) - - (1)
------- ------- -------
Net earnings - US GAAP $ 1,416 $ 1,354 603
======= ======= =======
Net earnings - US GAAP per common share
Basic $ 5.28 $ 5.04 $ 2.36
Diluted $ 5.24 $ 4.88 $ 2.28
------- ------- -------
88
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
Comprehensive income under US GAAP would be as follows:
(millions of Canadian dollars) Notes 2004 2003 2002
- ------------------------------ ------ -------- -------- --------
Net earnings- US GAAP $ 1,416 $ 1,354 $ 603
Amortization of FAS 133 adjustment (B) 8 20 31
Foreign currency translation adjustment (F) (9) (23) (49)
-------- -------- --------
Comprehensive income $ 1,415 $ 1,351 $ 585
======== ======== ========
The application of US GAAP would have the following effects on the consolidated
balance sheets as reported:
2004
---------------------------------------------
Canadian Increase
(millions of Canadian dollars) Notes GAAP (Decrease) US GAAP
- ------------------------------ ------ -------- ---------- --------
Property, plant and equipment (A) $ 17,064 $ (27) $ 17,037
Current portion of other long-term assets (B) $ 34 $ (33) $ 1
Current portion of long-term debt (B) $ 194 $ (44) $ 150
Future income tax (A,B,C) $ 4,450 $ 6 4,456
Shareholders' equity $ 7,324 $ (22) $ 7,302
2003
---------------------------------------------
Canadian Increase
(millions of Canadian dollars) Notes GAAP (Decrease) US GAAP
- ------------------------------ ------ -------- ---------- --------
Property, plant and equipment (A) $ 13,714 $ (60) $ 13,654
Current portion of other long-term assets (B) $ - $ 16 $ 16
Future income tax (A,B) $ 3,591 $ (3) $ 3,588
Shareholders' equity $ 6,009 $ (41) $ 5,965
Notes:
(A) Using Canadian full cost accounting rules, costs capitalized in each cost
centre, net of future income taxes, are limited to an amount equal to the
undiscounted, future net revenues from proved reserves using estimated
future prices and costs, plus the carrying amount of unproved properties
and major development projects (the "ceiling test"). Under the full cost
method of accounting as set forth by the US Securities and Exchange
Commission, the ceiling test differs from Canadian GAAP in that future net
revenues from proved reserves are based on prices and costs as at the
balance sheet date and are discounted at 10%.
(B) The Company uses certain derivative financial instruments to manage its
commodity prices and foreign currency exposure in relation to future firmly
committed and anticipated sales transactions. The Company also uses
interest rate swaps to manage its interest rate exposure. Effective January
1, 2004, the Company prospectively adopted Accounting Guideline 13,
"Hedging Relationships" and EIC 128, "Accounting for Trading, Speculative
or Non-hedging Derivative Financial Instruments" for Canadian GAAP. Under
Canadian GAAP, unrealized derivative financial instruments not designated
as hedges are recorded in the consolidated financial statements at their
fair value. Changes in the fair value of the undesignated derivative
financial instruments in subsequent periods are recognized in consolidated
net earnings. Derivative financial instruments designated as hedges are not
recorded in the consolidated financial statements until realized. There is
no requirement to recognize an ineffective portion of derivative financial
instruments designated as hedges.
Effective January 1, 2001, the Company adopted Statement of Financial
Accounting Standards ("FAS") 133 "Accounting for Derivative Instruments and
Hedging Activities" and FAS 138 "Accounting for Certain Derivative
Instruments and Certain Hedging Activities" to account for its commodity
prices and interest rate swap derivative financial instruments under US
GAAP. Under FAS 133, all derivative financial instruments are recognized in
the consolidated balance sheets at their fair value. Changes in the fair
value of derivative financial instruments are recognized in consolidated
net earnings unless specific criteria for hedging are met, in which case
the changes are recognized in comprehensive income. In 2003 and 2002, no
derivative financial instruments were designated as hedges for US GAAP
purposes.
In 2001, the adoption of FAS 133 resulted in the Company recognizing a
derivative financial instruments liability of $183 million and a charge to
comprehensive income of $124 million, net of future income tax recoveries
of $59 million. Of the initial liability recognized on January 1, 2001, a
loss of $8 million, net of future income tax recoveries of $3 million, was
reclassified to net earnings during 2004 (2003 - a loss of $20 million, net
of future income tax recoveries of $9 million; 2002 - a loss of $31
million, net of future income tax recoveries of $15 million).
Under US GAAP, foreign currency swap contracts used to hedge foreign
currency exposure to anticipated, but not firmly committed, transactions
cannot be accounted for as hedges. Accordingly, for US GAAP reporting,
gains and losses from changes in the fair market value of foreign currency
swap contracts related to these anticipated transactions are recognized in
net earnings when those changes in market value occur.
89
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS 2004 ANNUAL REPORT
(C) Under Canadian GAAP, capitalization of interest on projects constructed
over time is discretionary. The Company has determined that the appropriate
time to begin capitalizing interest on the Horizon Project is when sanction
was received in February 2005. For US GAAP, capitalization of interest on
projects constructed over time is mandatory and interest has been
capitalized to the costs of construction in 2004.
(D) Under Canadian GAAP, when the asset retirement obligation standard was
adopted prior period comparative balances were restated to reflect the
effect of the new standard on that year. Under US GAAP, when the asset
retirement obligation standard was adopted the cumulative effect of the new
standard on prior periods was included in earnings in the year adopted.
(E) Under Canadian GAAP, the future income tax effect of flow-through shares is
deducted from share capital. However, under US GAAP, the future income tax
effect of flow-through shares is expensed immediately.
(F) Under US GAAP, exchange gains and losses arising from the translation of
self-sustaining foreign operations are included in comprehensive income.
18. Recently issued accounting standards
Financial Instruments
In January 2005, the CICA issued Section 3855 "Financial Instruments -
Recognition and Measurement". This Section prescribes when a financial asset,
financial liability, or non-financial derivative is to be recognized on the
balance sheet and at what amount - sometimes using fair value; other times using
cost-based measures. This Section also specifies how financial instruments gains
and losses are to be presented. This Section applies to interim and annual
financial statements relating to fiscal years beginning on or after October 31,
2006. Earlier adoption is permitted only as of the beginning of a fiscal year
ending on or after December 31, 2004. The Company plans to adopt this Section on
January 1, 2007. Transitional provisions for this Section are complex and vary
based on the type of financial instruments under consideration. The effect on
the Company's consolidated financial statements cannot be reasonably determined
at this time.
Hedges
In January 2005, the CICA issued Section 3865 "Hedges". This Section expands on
existing Accounting Guideline 13 - Hedging Relationships, and Section 1650
"Foreign Currency Translation", by specifying how hedge accounting is applied
and what disclosure are necessary when it is applied. This Section applies to
interim and annual financial statements relating to fiscal years beginning on or
after October 31, 2006. Earlier adoption is permitted only as of the beginning
of a fiscal year ending on or after December 31, 2004. The Company plans to
adopt this Section on January 1, 2007. Retroactive application of this Section
is not permitted. The effect on the Company's consolidated financial statements
cannot be reasonably determined at this time.
Comprehensive Income
In January 2005, the CICA issued Section 1530 "Comprehensive Income". This
Section introduces new standards for reporting and display of comprehensive
income. Comprehensive income is the change in equity (net assets) of a company
during a reporting period from transactions and other events and circumstances
from non-owner sources. It includes all changes in equity during a period except
those resulting from investments by owners and distributions to owners. This
Section applies to interim and annual financial statements relating to fiscal
years beginning on or after October 31, 2006. Earlier adoption is permitted only
as of the beginning of a fiscal year ending on or after December 31, 2004. The
Company plans to adopt this Section on January 1, 2007. Financial statements of
prior periods are required to be restated for certain comprehensive income
items. In addition, a company is encouraged, but not required to present
reclassification adjustments, in comparative financial statements provided for
earlier periods. The effect on the Company's consolidated financial statements
cannot be reasonably determined at this time.
Equity
In January 2005, the CICA issued Section 3251 "Equity". This Section replaces
Section 3250 "Surplus". It establishes standards for the presentation of equity
and changes in equity during a reporting period. This Section applies to interim
and annual financial statements relating to fiscal years beginning on or after
October 31, 2006. Earlier adoption is permitted only as of the beginning of a
fiscal year ending on or after December 31, 2004. The Company plans to adopt
this Section on January 1, 2007. Financial statements of prior periods are
required to be restated for certain specified adjustments. For all other items,
comparative financial statements are presented are not restated, but an
adjustment to the opening balance of accumulated other comprehensive income may
be required. In addition, a company is encouraged, but not required to present
reclassification adjustments, in comparative financial statements provided for
earlier periods. The effect on the Company's consolidated financial statements
cannot be reasonably determined at this time.
90