Document and Entity Information
Document and Entity Information - shares | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Document and Entity Information | ||
Document Type | 40-F | |
Document Registration Statement | false | |
Document Annual Report | true | |
Current Fiscal Year End Date | --12-31 | |
Document Period End Date | Dec. 31, 2022 | |
Entity File Number | 1-12384 | |
Entity Registrant Name | SUNCOR ENERGY INC | |
Entity Primary SIC Number | 2911 | |
Entity Tax Identification Number | 98-0343201 | |
Entity Incorporation, State or Country Code | Z4 | |
Entity Address, Address Line One | 150 - 6th Avenue S.W. | |
Entity Address, Address Line Two | P.O. Box 2844 | |
Entity Address, City or Town | Calgary | |
Entity Address, State or Province | AB | |
Entity Address, Country | CA | |
Entity Address, Postal Zip Code | T2P 3E3 | |
City Area Code | 403 | |
Local Phone Number | 296-8000 | |
Title of 12(b) Security | Common shares | |
Trading Symbol | SU | |
Security Exchange Name | NYSE | |
Annual Information Form | true | |
Audited Annual Financial Statements | true | |
Entity Common Stock, Shares Outstanding | 1,337,470,739 | |
Entity Current Reporting Status | Yes | |
Entity Interactive Data Current | Yes | |
Entity Emerging Growth Company | false | |
ICFR Auditor Attestation Flag | true | |
Entity Central Index Key | 0000311337 | |
Document Fiscal Year Focus | 2022 | |
Document Fiscal Period Focus | FY | |
Amendment Flag | false | |
Auditor Name | KPMG LLP | KPMG LLP |
Auditor Location | Calgary, Canada | Calgary, Canada |
Auditor Firm ID | 85 | |
Business Contact | ||
Document and Entity Information | ||
Contact Personnel Name | CT Corporation System | |
Entity Address, Address Line One | 28 Liberty St. | |
Entity Address, City or Town | New York | |
Entity Address, State or Province | NY | |
Entity Address, Postal Zip Code | 10005 | |
City Area Code | 212 | |
Local Phone Number | 894-8940 |
Consolidated Statements of Comp
Consolidated Statements of Comprehensive Income - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Revenues and Other Income | ||
Operating revenues, net of royalties | $ 58,336 | $ 39,132 |
Other income (loss) | 131 | (31) |
Revenues and Other Income | 58,467 | 39,101 |
Expenses | ||
Purchases of crude oil and products | 20,775 | 13,791 |
Operating, selling and general | 12,807 | 11,366 |
Transportation and distribution | 1,671 | 1,479 |
Depreciation, depletion, amortization and impairment | 8,786 | 5,850 |
Exploration | 56 | 47 |
Loss (gain) on disposal of assets | 45 | (257) |
Financing expenses | 2,011 | 1,255 |
Expenses | 46,151 | 33,531 |
Earnings (Loss) before Income Taxes | 12,316 | 5,570 |
Income Tax Expense (Recovery) | ||
Current | 4,229 | 1,395 |
Deferred | (990) | 56 |
Total Income Tax Expense (Recovery) | 3,239 | 1,451 |
Net Earnings | 9,077 | 4,119 |
Items That May be Subsequently Reclassified to Earnings: | ||
Foreign currency translation adjustment | 160 | (63) |
Items That Will Not be Reclassified to Earnings: | ||
Actuarial gain on employee retirement benefit plans, net of income taxes | 838 | 856 |
Other Comprehensive Income | 998 | 793 |
Total Comprehensive Income | $ 10,075 | $ 4,912 |
Per Common Share (dollars) | ||
Net earnings - basic | $ 6.54 | $ 2.77 |
Net earnings - diluted | 6.53 | 2.77 |
Cash dividends | $ 1.88 | $ 1.05 |
Consolidated Balance Sheets
Consolidated Balance Sheets - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 |
Current assets | ||
Cash and cash equivalents | $ 1,980 | $ 2,205 |
Accounts receivable | 6,068 | 4,534 |
Inventories | 5,058 | 4,110 |
Income taxes receivable | 244 | 128 |
Assets held for sale | 1,186 | |
Total current assets | 14,536 | 10,977 |
Property, plant and equipment, net | 62,654 | 65,546 |
Exploration and evaluation | 1,995 | 2,226 |
Other assets | 1,766 | 1,307 |
Goodwill and other intangible assets | 3,586 | 3,523 |
Deferred income taxes | 81 | 160 |
Total assets | 84,618 | 83,739 |
Current liabilities | ||
Short-term debt | 2,807 | 1,284 |
Current portion of long-term debt | 231 | |
Current portion of long-term lease liabilities | 317 | 310 |
Accounts payable and accrued liabilities | 8,167 | 6,503 |
Current portion of provisions | 564 | 779 |
Income taxes payable | 484 | 1,292 |
Liabilities associated with assets held for sale | 530 | |
Total current liabilities | 12,869 | 10,399 |
Long-term debt | 9,800 | 13,989 |
Long-term lease liabilities | 2,695 | 2,540 |
Other long-term liabilities | 1,642 | 2,180 |
Provisions | 9,800 | 8,776 |
Deferred income taxes | 8,445 | 9,241 |
Equity | 39,367 | 36,614 |
Total liabilities and shareholders' equity | $ 84,618 | $ 83,739 |
Consolidated Statements of Cash
Consolidated Statements of Cash Flows - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Operating Activities | ||
Net earnings | $ 9,077 | $ 4,119 |
Adjustments for: | ||
Depreciation, depletion, amortization and impairment | 8,786 | 5,850 |
Deferred income tax (recovery) expense | (990) | 56 |
Accretion | 316 | 304 |
Unrealized foreign exchange loss (gain) on U.S. dollar denominated debt | 729 | (113) |
Change in fair value of financial instruments and trading inventory | (38) | (13) |
Loss (gain) on disposal of assets | 45 | (257) |
Loss on extinguishment of long-term debt | 32 | 80 |
Share-based compensation | 328 | 205 |
Settlement of decommissioning and restoration liabilities | (314) | (263) |
Other | 130 | 289 |
(Increase) decrease in non-cash working capital | (2,421) | 1,507 |
Cash flow provided by operating activities | 15,680 | 11,764 |
Investing Activities | ||
Capital and exploration expenditures | (4,987) | (4,555) |
Capital expenditures classified as assets held for sale | (133) | |
Proceeds from disposal of assets | 315 | 335 |
Other investments and acquisitions | (36) | (28) |
Decrease in non-cash working capital | 52 | 271 |
Cash flow used in investing activities | (4,789) | (3,977) |
Financing Activities | ||
Net increase (decrease) in short-term debt | 1,473 | (2,256) |
Repayment of long-term debt | (5,128) | (2,451) |
Issuance of long-term debt | 1,423 | |
Lease liability payments | (329) | (325) |
Issuance of common shares under share option plans | 496 | 8 |
Repurchase of common shares | (5,135) | (2,304) |
Distributions relating to non-controlling interest | (9) | (9) |
Dividends paid on common shares | (2,596) | (1,550) |
Cash flow used in financing activities | (11,228) | (7,464) |
(Decrease) Increase in Cash and Cash Equivalents | (337) | 323 |
Effect of foreign exchange on cash and cash equivalents | 112 | (3) |
Cash and cash equivalents at beginning of year | 2,205 | 1,885 |
Cash and Cash Equivalents at End of Year | 1,980 | 2,205 |
Supplementary Cash Flow Information | ||
Interest paid | 973 | 980 |
Income taxes paid (received) | $ 4,737 | $ (532) |
Consolidated Statements of Chan
Consolidated Statements of Changes in Equity - CAD ($) shares in Thousands, $ in Millions | Share capital | Contributed surplus | Accumulated Other Comprehensive Income | Retained Earnings | Total |
Beginning balance at Dec. 31, 2020 | $ 25,144 | $ 591 | $ 877 | $ 9,145 | $ 35,757 |
Beginning balance (in share) at Dec. 31, 2020 | 1,525,151 | ||||
Changes in equity | |||||
Net earnings | 4,119 | $ 4,119 | |||
Foreign currency translation adjustment | (63) | (63) | |||
Actuarial gain on employee retirement benefit plans, net of income taxes | 856 | 856 | |||
Total comprehensive (loss) income | (63) | 4,975 | 4,912 | ||
Issued under share option plans | 8 | $ 8 | |||
Issued under share option plans (in shares) | 245 | ||||
Common shares forfeited (in shares) | (186) | ||||
Repurchase of common shares for cancellation | (1,382) | (922) | $ (2,304) | ||
Repurchase of common shares for cancellation (in shares) | (83,959) | ||||
Change in liability for share purchase commitment | (120) | (110) | $ (230) | ||
Share-based compensation | 21 | 21 | |||
Dividends paid on common shares | (1,550) | (1,550) | |||
Ending balance at Dec. 31, 2021 | 23,650 | 612 | 814 | 11,538 | $ 36,614 |
Ending balance (in share) at Dec. 31, 2021 | 1,441,251 | ||||
Changes in equity | |||||
Net earnings | 9,077 | $ 9,077 | |||
Foreign currency translation adjustment | 160 | 160 | |||
Actuarial gain on employee retirement benefit plans, net of income taxes | 838 | 838 | |||
Total comprehensive (loss) income | 160 | 9,915 | 10,075 | ||
Issued under share option plans | 570 | (58) | $ 512 | ||
Issued under share option plans (in shares) | 13,158 | ||||
Common shares forfeited (in shares) | (30) | ||||
Repurchase of common shares for cancellation | (1,947) | (3,188) | $ (5,135) | ||
Repurchase of common shares for cancellation (in shares) | (116,908) | ||||
Change in liability for share purchase commitment | (16) | (104) | $ (120) | ||
Share-based compensation | 17 | 17 | |||
Dividends paid on common shares | (2,596) | (2,596) | |||
Ending balance at Dec. 31, 2022 | $ 22,257 | $ 571 | $ 974 | $ 15,565 | $ 39,367 |
Ending balance (in share) at Dec. 31, 2022 | 1,337,471 |
Consolidated Statements of Ch_2
Consolidated Statements of Changes in Equity (Parenthetical) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Consolidated Statements of Changes in Equity | ||
Taxes on actuarial gain on employee retirement benefit plans | $ 264 | $ 277 |
Reporting Entity and Descriptio
Reporting Entity and Description of the Business | 12 Months Ended |
Dec. 31, 2022 | |
Reporting Entity and Description of the Business | |
Reporting Entity and Description of the Business | Notes to the Consolidated Financial Statements 1. Reporting Entity and Description of the Business Suncor Energy Inc. (Suncor or the company) is an integrated energy company headquartered in Calgary, Alberta, Canada. Suncor's operations include oil sands development, production and upgrading; offshore oil and gas; petroleum refining in Canada and the U.S.; and the company’s Petro-Canada retail and wholesale distribution networks (including Canada’s Electric Highway™, a coast-to-coast network of fast-charging electric vehicle stations). Suncor is developing petroleum resources while advancing the transition to a low-emissions future through investments in power, renewable fuels and hydrogen. Suncor also conducts energy trading activities focused principally on the marketing and trading of crude oil, natural gas, byproducts, refined products and power. Suncor has been recognized for its performance and transparent reporting on the Dow Jones Sustainability World Index, FTSE4Good Index and CDP. Suncor's common shares (symbol: SU) are listed on the Toronto Stock Exchange (TSX) and New York Stock Exchange (NYSE). The address of the company’s registered office is 150 – 6th Avenue S.W., Calgary, Alberta, Canada, T2P 3E3. |
Basis of Preparation
Basis of Preparation | 12 Months Ended |
Dec. 31, 2022 | |
Basis of Preparation | |
Basis of Preparation | 2. Basis of Preparation (a) Statement of Compliance These consolidated financial statements have been prepared in accordance with International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB). Suncor’s accounting policies are based on IFRS issued and outstanding for all periods presented in these consolidated financial statements. These consolidated financial statements were approved by the Board of Directors on March 6, 2023. (b) Basis of Measurement The consolidated financial statements are prepared on a historical cost basis except as detailed in the accounting policies disclosed in note 3. The accounting policies described in note 3 have been applied consistently to all periods presented in these consolidated financial statements. (c) Functional Currency and Presentation Currency These consolidated financial statements are presented in Canadian dollars, which is the company’s functional currency. (d) Use of Estimates, Assumptions and Judgments The timely preparation of financial statements requires that management make estimates and assumptions and use judgment. Accordingly, actual results may differ from estimated amounts as future confirming events occur. Significant estimates and judgments used in the preparation of the consolidated financial statements are described in note 4. |
Summary of Significant Accounti
Summary of Significant Accounting Policies | 12 Months Ended |
Dec. 31, 2022 | |
Summary of Significant Accounting Policies | |
Summary of Significant Accounting Policies | 3. Summary of Significant Accounting Policies (a) Principles of Consolidation The company consolidates its interests in entities it controls. Control comprises the power to govern an entity’s financial and operating policies to obtain benefits from its activities, and is a matter of judgment. All intercompany balances and transactions are eliminated on consolidation. (b) Joint Arrangements Joint arrangements represent arrangements in which two or more parties have joint control established by a contractual agreement. Joint control only exists when decisions about the activities that most significantly affect the returns of the investee are unanimous. Joint arrangements can be classified as either a joint operation or a joint venture. The classification of joint arrangements requires judgment. In determining the classification of its joint arrangements, the company considers the contractual rights and obligations of each investor and whether the legal structure of the joint arrangement gives the entity direct rights to the assets and obligations for the liabilities. Where the company has rights to the assets and obligations for the liabilities of a joint arrangement, such arrangement is classified as a joint operation and the company’s proportionate share of the joint operation’s assets, liabilities, revenues and expenses are included in the consolidated financial statements, on a line-by-line basis. Where the company has rights to the net assets of an arrangement, such arrangement is classified as a joint venture and accounted for using the equity method of accounting. Under the equity method, the company’s initial investment is recognized at cost and subsequently adjusted for the company’s share of the joint venture’s income or loss, less distributions received. (c) Investments in Associates Associates are entities for which the company has significant influence, but not control or joint control over the financial and operational decisions. Investments in associates are accounted for using the equity method of accounting and are initially recognized at cost and adjusted thereafter for the change in the company’s share of the investee’s profit or loss and Other Comprehensive Income (OCI) less distributions received until the date that significant influence ceases. (d) Foreign Currency Translation Functional currencies of the company’s individual entities are the currency of the primary economic environment in which the entity operates. Transactions in foreign currencies are translated to the appropriate functional currency at foreign exchange rates that approximate those on the date of the transaction. Monetary assets and liabilities denominated in foreign currencies are translated to the appropriate functional currency at foreign exchange rates as at the balance sheet date. Foreign exchange differences arising on translation are recognized in net earnings. Non-monetary assets that are measured in a foreign currency at historical cost are translated using the exchange rate at the date of the transaction. In preparing the company’s consolidated financial statements, the financial statements of each entity are translated into Canadian dollars. The assets and liabilities of foreign operations are translated into Canadian dollars at exchange rates as at the balance sheet date. Revenues and expenses of foreign operations are translated into Canadian dollars using foreign exchange rates that approximate those on the date of the underlying transaction. Foreign exchange differences are recognized in OCI. If the company or any of its entities disposes of its entire interest in a foreign operation, or loses control, joint control or significant influence over a foreign operation, the accumulated foreign currency translation gains or losses related to the foreign operation are recognized in net earnings. (e) Revenues Revenue from the sale of crude oil, natural gas, natural gas liquids, purchased products, refined petroleum products and power represent the company’s contractual arrangements with customers. Revenue is recorded when control passes to the customer, in accordance with specified contract terms. All operating revenue is earned at a point in time and is based on the consideration that the company expects to receive for the transfer of the goods to the customer. Revenues are usually collected in the month following delivery except retail gasoline, diesel and ancillary products, which are due upon delivery and, accordingly, the company does not adjust consideration for the effects of a financing component. Revenue from oil and natural gas production is recorded net of royalty expense. International operations conducted pursuant to Production Sharing Contracts (PSCs) are reflected in the consolidated financial statements based on the company’s working interest. Each PSC establishes the exploration, development and operating costs the company is required to fund and establishes specific terms for the company to recover these costs and to share in the production profits. Cost recovery is generally limited to a specified percentage of production during each fiscal year (Cost Recovery Oil). Any Cost Recovery Oil remaining after costs have been recovered is referred to as Excess Petroleum and is shared between the company and the respective government. Assuming collection is reasonably assured, the company’s share of Cost Recovery Oil and Excess Petroleum are reported as revenue when the sale of product to a third party occurs. Revenue also includes income taxes paid on the company’s behalf by government joint partners. (f) Cash and Cash Equivalents Cash and cash equivalents consist primarily of cash in banks, term deposits, certificates of deposit and all other highly liquid investments at the time of purchase. (g) Inventories Inventories of crude oil and refined products, other than inventories held for trading purposes, are valued at the lower of cost, using the first-in, first-out method, and net realizable value. Cost of inventory consists of purchase costs, direct production costs, direct overhead and depreciation, depletion and amortization. Materials and supplies are valued at the lower of average cost and net realizable value. Inventories held for trading purposes are carried at fair value less costs to sell and any changes in fair value are recognized in Other Income within the respective reporting segment to which the trading activity relates. (h) Assets Held for Sale Assets and the associated liabilities are classified as held for sale if their carrying amounts are expected to be recovered through a disposition rather than through continued use. The assets or disposal groups are measured at the lower of their carrying amount or estimated fair value less costs of disposal. Impairment losses on initial classification as well as subsequent gains or losses on remeasurement are recognized in Depreciation, Depletion, Amortization and Impairment. When the assets or disposal groups are sold, the gains or losses on the sale are recognized in Gain on Disposal of Assets. Assets classified as held for sale are not depreciated, depleted or amortized. (i) Exploration and Evaluation Assets The costs to acquire non-producing oil and gas properties or licences to explore, drill exploratory wells and the costs to evaluate the commercial potential of underlying resources, including related borrowing costs, are initially capitalized as Exploration and Evaluation assets. Certain exploration costs, including geological, geophysical and seismic expenditures and delineation on oil sands properties, are charged to Exploration expense as incurred. Exploration and Evaluation assets are subject to technical, commercial and management review to confirm the continued intent to develop and extract the underlying resources. If an area or exploration well is no longer considered commercially viable, the related capitalized costs are charged to Exploration expense. When management determines with reasonable certainty that an Exploration and Evaluation asset will be developed, as evidenced by the classification of proved or probable reserves and the appropriate internal and external approvals, the asset is transferred to Property, Plant and Equipment. (j) Property, Plant and Equipment Property, Plant and Equipment are initially recorded at cost. The costs to acquire developed or producing oil and gas properties, and to develop oil and gas properties, including completing geological and geophysical surveys and drilling development wells, and the costs to construct and install development infrastructure, such as wellhead equipment, well platforms, well pairs, offshore platforms, subsea structures and an estimate of asset retirement costs, are capitalized as oil and gas properties within Property, Plant and Equipment. The costs to construct, install and commission, or acquire, oil and gas production equipment, including oil sands upgraders, extraction plants, mine equipment, processing and power generation facilities, utility plants, and all renewable energy, refining, and marketing assets, are capitalized as plant and equipment within Property, Plant and Equipment. Stripping activity required to access oil sands mining resources incurred in the initial development phase is capitalized as part of the construction cost of the mine. Stripping costs incurred in the production phase are charged to expense as they normally relate to production for the current period. The costs of planned major inspection, overhaul and turnaround activities that maintain Property, Plant and Equipment and benefit future years of operations are capitalized. Recurring planned maintenance activities performed on shorter intervals are expensed as operating costs. Replacements outside of a major inspection, overhaul or turnaround are capitalized when it is probable that future economic benefits will be realized by the company and the associated carrying amount of the replaced component is derecognized. Borrowing costs relating to assets that take over one year to construct are capitalized as part of the asset. Capitalization of borrowing costs ceases when the asset is in the location and condition necessary for its intended use, and is suspended when construction of an asset is ceased for extended periods. (k) Depreciation, Depletion and Amortization Exploration and Evaluation assets are not subject to depreciation, depletion and amortization. Once transferred to oil and gas properties within Property, Plant and Equipment and commercial production commences, these costs are depleted on a unit-of-production basis over proved developed reserves, with the exception of costs associated with oil sands mines, which are depreciated on a straight-line basis over the life of the mine, and property acquisition costs, which are depleted over proved reserves. Capital expenditures are not depreciated or depleted until assets are substantially complete and ready for their intended use. Costs to develop oil and gas properties other than certain oil sands mining assets, including costs of dedicated infrastructure, such as well pads and wellhead equipment, are depleted on a unit-of-production basis over proved developed reserves. A portion of these costs may not be depleted if they relate to undeveloped reserves. Costs related to offshore facilities are depleted over proved and probable reserves. Costs to develop and construct oil sands mines are depreciated on a straight-line basis over the life of the mine. Major components of Property, Plant and Equipment are depreciated on a straight-line basis over their expected useful lives. Oil sands upgraders, extraction plants and mine facilities 20 to 40 years Oil sands mine equipment 5 to 15 years Oil sands in situ processing facilities 30 years Power generation and utility plants 30 to 40 years Refineries and other processing plants 20 to 40 years Marketing and other distribution assets 10 to 40 years The costs of major inspection, overhaul and turnaround activities that are capitalized are depreciated on a straight-line basis over the period to the next scheduled activity, which varies from two Depreciation, depletion and amortization rates are reviewed annually or when events or conditions occur that impact capitalized costs, reserves or estimated service lives. Right-of-use assets within Property, Plant and Equipment are depreciated on a straight-line basis over the shorter of the estimated useful life of the right-of-use asset or the lease term. (l) Goodwill and Other Intangible Assets The company accounts for business combinations using the acquisition method. The excess of the purchase price over the fair value of the identifiable net assets represents goodwill, and is allocated to the groups of cash generating units (CGUs) to which it relates from the business combination. Other intangible assets include acquired customer lists, brand value and certain software costs. Goodwill and brand value have indefinite useful lives and are not subject to amortization. Customer lists are amortized over their expected useful lives, which range from five five (m) Impairment of Assets Non-Financial Assets Property, Plant and Equipment and Exploration and Evaluation assets are reviewed quarterly to assess whether there is any indication of impairment. Goodwill and intangible assets that have an indefinite useful life are tested for impairment annually. Exploration and Evaluation assets are also tested for impairment immediately prior to being transferred to Property, Plant and Equipment. If any indication of impairment exists, an estimate of the asset’s recoverable amount is calculated as the higher of the fair value less costs of disposal and value-in-use. In determining fair value less costs of disposal, recent market transactions are considered, if available. In the absence of such transactions, an appropriate valuation model is used. Value-in-use is assessed using the present value of the expected future cash flows of the relevant asset. If the asset does not generate cash inflows that are largely independent of those from other assets or groups of assets, the asset is tested as part of a CGU, which is the smallest identifiable group of assets that generates cash inflows that are largely independent of the cash inflows from other assets or groups of assets. An impairment loss is the amount by which the carrying amount of the individual asset or CGU exceeds its recoverable amount. Impairments may be reversed for all CGUs and individual assets, other than goodwill, if there has been a change in the estimates and judgments used to determine the asset’s recoverable amount since the last impairment loss was recognized. If such indication exists, the carrying amount of the CGU or asset is increased to its revised recoverable amount, which cannot exceed the carrying amount that would have been determined, net of depletion, depreciation and amortization, had no impairment been recognized. Impairments and impairment reversals are recognized within Depreciation, Depletion, Amortization and Impairment. Financial Assets At each reporting date, the company assesses the expected credit losses associated with its financial assets measured at amortized cost. Expected credit losses are measured as the difference between the cash flows that are due to the company and the cash flows that the company expects to receive, discounted at the effective interest rate determined at initial recognition. For trade accounts receivables, the company applies the simplified approach permitted by IFRS 9 Financial Instruments (n) Provisions Provisions are recognized by the company when it has a legal or constructive obligation as a result of past events, it is probable that an outflow of economic resources will be required to settle the obligation and a reliable estimate can be made of the amount of the obligation. Provisions are recognized for decommissioning and restoration obligations associated with the company’s Exploration and Evaluation assets and Property, Plant and Equipment. Provisions for decommissioning and restoration obligations are measured at the present value of management’s best estimate of the future cash flows required to settle the present obligation, using the credit-adjusted risk-free interest rate. The value of the obligation is added to the carrying amount of the associated asset and amortized over the useful life of the asset. The provision is accreted over time through Financing Expense with actual expenditures charged against the accumulated obligation. Changes in the future cash flow estimates resulting from revisions to the estimated timing or amount of undiscounted cash flows are recognized as a change in the decommissioning and restoration provision and related asset. (o) Income Taxes The company follows the liability method of accounting for income taxes whereby deferred income taxes are recorded for the effect of differences between the accounting and income tax basis of an asset or liability. Deferred income tax assets and liabilities are measured using enacted or substantively enacted income tax rates as at the balance sheet date that are anticipated to apply to taxable income in the years in which temporary differences are expected to be recovered or settled. Changes to these balances are recognized in net earnings or in Other Comprehensive Income in the period they occur. Investment tax credits are recorded as a reduction to the related expenditures. The company recognizes the impact of a tax filing position when it is probable, based on the technical merits, that the position will be sustained upon audit. If it is determined a tax filing position is not considered probable, the company assesses the possible outcomes and their associated probabilities and records a tax provision based on the best estimate of the amount of tax payable. (p) Pensions and Other Post-Retirement Benefits The company sponsors defined benefit pension plans, defined contribution pension plans and other post-retirement benefits. The cost of pension benefits earned by employees in the defined contribution pension plan is expensed as incurred. The cost of defined benefit pension plans and other post-retirement benefits are actuarially determined using the projected unit credit method based on present pay levels and management’s best estimates of demographic and financial assumptions. The liability recognized on the balance sheet is the present value of the defined benefit obligations less the fair value of plan assets. The value of plan assets is limited to the total of unrecognized past service cost and the present value of the economic benefits available in the form of refunds from the plan or reductions in future contributions to the plan (“effect of the asset ceiling”). Any surplus is immediately recognized in Other Comprehensive income. In addition, a minimum liability is recognized when the statutory minimum funding requirement for past service exceeds the economic benefits available in the form of refunds from the plan or reductions in future contributions to the plan. Pension benefits earned during the current year are recorded in Operating, Selling and General expense. Interest costs on the net unfunded obligation are recorded in Financing Expense. Any actuarial gains or losses related to the plan assets and the defined benefit obligation, as well as the change in the asset ceiling and any minimum liability, are recognized immediately through Other Comprehensive Income and transferred directly to Retained Earnings. (q) Share-Based Compensation Plans Under the company’s share-based compensation plans, share-based awards may be granted to executives, employees and non-employee directors. Compensation expense is recorded in Operating, Selling and General expense. Share-based compensation awards that settle in cash or have the option to settle in cash or shares are accounted for as cash-settled plans. These are measured at fair value each reporting period using the Black-Scholes options pricing model. The expense is recognized over the vesting period, with a corresponding adjustment to the outstanding liability. When awards are surrendered for cash, the cash settlement paid reduces the outstanding liability. When awards are exercised for common shares, consideration paid by the holder and the previously recognized liability associated with the options are recorded to Share Capital. Stock options that give the holder the right to purchase common shares are accounted for as equity-settled plans. The expense is based on the fair value of the options at the time of grant using the Black-Scholes options pricing model and is recognized over the vesting periods of the respective options. A corresponding increase is recorded to Contributed Surplus. Consideration paid to the company on exercise of options is credited to Share Capital and the associated amount in Contributed Surplus is reclassified to Share Capital. (r) Financial Instruments The company classifies its financial instruments into one of the following categories: fair value through profit or loss (FVTPL), fair value through other comprehensive income, or at amortized cost. This determination is made at initial recognition. All financial instruments are initially recognized at fair value on the balance sheet, net of any transaction costs except for financial instruments classified as FVTPL, where transaction costs are expensed as incurred. Subsequent measurement of financial instruments is based on their classification. The company classifies its derivative financial instruments and certain investments as FVTPL, cash and cash equivalents and accounts receivable as financial assets at amortized cost, and accounts payable and accrued liabilities, debt, and other long-term liabilities as financial liabilities at amortized cost. In circumstances where the company consolidates a subsidiary in which there are other owners with a non-controlling interest and the subsidiary has a non-discretionary obligation to distribute cash based on a predetermined formula to the non-controlling owners, the non-controlling interest is classified as a financial liability rather than equity in accordance with IAS 32 Financial Instruments: Presentation The company uses derivative financial instruments, such as physical and financial contracts, either to manage certain exposures to fluctuations in interest rates, commodity prices and foreign exchange rates, as part of its overall risk management program. Earnings impacts from derivatives used to manage a particular risk are reported as part of Other Income in the related reporting segment. Certain physical commodity contracts, when used for trading purposes, are deemed to be derivative financial instruments for accounting purposes. Physical commodity contracts entered into for the purpose of receipt or delivery in accordance with the company’s expected purchase, sale or usage requirements are not considered to be derivative financial instruments and are accounted for as executory contracts. Derivatives embedded in other financial instruments or other host contracts are recorded as separate derivatives when their risks and characteristics are not closely related to those of the host contract. (s) Hedging Activities The company may apply hedge accounting to arrangements that qualify for designated hedge accounting treatment. Documentation is prepared at the inception of a hedge relationship in order to qualify for hedge accounting. Designated hedges are assessed at each reporting date to determine if the relationship between the derivative and the underlying hedged item accomplishes the company’s risk management objectives for financial and non-financial risk exposures. If the derivative is designated as a fair value hedge, changes in the fair value of the derivative and in the fair value of the underlying hedged item are recognized in net earnings. If the derivative is designated as a cash flow hedge, the effective portions of the changes in fair value of the derivative are initially recorded in Other Comprehensive Income and are recognized in net earnings when the hedged item is realized. Ineffective portions of changes in the fair value of cash flow hedges are recognized in net earnings immediately. Changes in the fair value of a derivative designated in a fair value or cash flow hedge are recognized in the same line item as the underlying hedged item. The company did not apply hedge accounting to any of its derivative instruments for the years ended December 31, 2022 or 2021. (t) Share Capital Common shares are classified as equity. Incremental costs directly attributable to the issuance of common shares are recognized as a deduction from equity, net of any tax effects. When the company repurchases its own common shares, share capital is reduced by the average carrying value of the shares repurchased. The excess of the purchase price over the average carrying value is recognized as a deduction from Retained Earnings. Shares are cancelled upon repurchase. (u) Dividend Distributions Dividends on common shares are recognized in the period in which the dividends are declared by the company’s Board of Directors. (v) Earnings per Share Basic earnings per share is calculated by dividing the net earnings for the period by the weighted average number of common shares outstanding during the period. Diluted earnings per share is calculated by adjusting the weighted average number of common shares outstanding for dilutive common shares related to the company’s share-based compensation plans. The number of shares included is computed using the treasury stock method. As these awards can be exchanged for common shares of the company, they are considered potentially dilutive and are included in the calculation of the company’s diluted net earnings per share if they have a dilutive impact in the period. (w) Emissions Obligations and Rights Emissions obligations are measured at the weighted average cost per unit of emissions expected to be incurred to settle the obligation and are recorded in the period in which the emissions occur within Operating, Selling and General expense, or Purchases. Purchases of emissions rights are recognized as Other Assets on the balance sheet and are measured at historical cost. Emissions rights received by way of grant are recorded at a nominal amount. (x) Leases At inception of a contract, the company assesses whether a contract is, or contains, a lease based on whether the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. The company recognizes a right-of-use asset and a lease liability at the lease commencement date. The right-of-use asset is initially measured based on the initial amount of the lease liability adjusted for any lease payments made at or before the commencement date, plus any initial direct costs incurred and an estimate of costs to dismantle and remove the underlying asset or to restore the underlying asset on the site on which it is located, less any lease incentives received. The assets are depreciated to the earlier of the end of the useful life of the right-of-use asset or the lease term. Judgment is applied to determine the lease term where a renewal option exists. Right-of-use assets are depreciated using the straight-line method as this most closely reflects the expected pattern of consumption of the future economic benefits. In addition, the right-of-use assets may be reduced by impairment losses or adjusted for certain remeasurements of the lease liability. The company has elected not to recognize right-of-use assets and lease liabilities for short-term leases that have a lease term of twelve months or less. The lease payments are recognized as an expense when incurred over the lease term. As well, the company has accounted for each lease component and any non-lease components as a single lease component for crude oil storage tanks. The lease liability is initially measured at the present value of the lease payments that are not paid at the commencement date, discounted using the interest rate implicit in the lease or, if that rate cannot be readily determined, the company’s incremental borrowing rate. Lease payments include fixed payments, and variable payments that are based on an index or rate. Cash payments for the principal portion of the lease liability are presented within the financing activities section and the interest portion of the lease liability is presented within the operating activities section of the statement of cash flows. Short-term lease payments and variable lease payments not included in the measurement of the lease liability are presented within the operating activities section of the statement of cash flows. The lease liability is measured at amortized cost using the effective interest method. It is remeasured when there is a change in future lease payments arising from a change in an index or rate, if there is a change in the company’s estimate of the amount expected to be payable under a residual value guarantee, or if the company changes its assessment of whether it will exercise a purchase, extension or termination option. When the lease liability is remeasured in this way, a corresponding adjustment is made to the carrying amount of the right-of-use asset, or is recorded in profit or loss if the carrying amount of the right-of-use asset has been reduced to zero. The company has lease contracts which include storage tanks, pipelines, railway cars, vessels, buildings, land, and mobile equipment for the purpose of production, storage and transportation of crude oil and related products. (y) Government Grants Government grants are recognized when the company has reasonable assurance that it has complied with the relevant conditions of the grant and that it will be received. The company recognizes the grants that compensate the company for expenses incurred against the financial statement line item that it is intended to compensate, or to other income if the grant is recognized in a different period than the underlying transaction. |
Significant Accounting Estimate
Significant Accounting Estimates and Judgments | 12 Months Ended |
Dec. 31, 2022 | |
Significant Accounting Estimates and Judgments | |
Significant Accounting Estimates and Judgments | 4. Significant Accounting Estimates and Judgments The preparation of financial statements in accordance with IFRS requires management to make estimates and judgments that affect reported assets, liabilities, revenues, expenses, gains, losses and disclosures of contingencies. These estimates and judgments are subject to change based on experience and new information. Climate Change and Energy Transition Suncor supports the goals of the Paris Agreement and is committed to achieving the long-term target of net zero greenhouse gas (GHG) emissions by 2050 from its facilities, including those in which it has a working interest. Addressing climate change and providing the secure and reliable energy the world needs requires investment, technological advancement, product innovation, regulatory support and collaborative partnerships, such as the Pathway’s Alliance. The rate of change of public policy, consumer behavior, and resulting demand for low carbon options is not certain. Suncor is committed to reducing emissions in our base business, while expanding in complementary low-emissions businesses and working with our customers, governments and partners to realize our shared climate objectives. Climate change and the transition to a low-emissions economy was considered in preparing the consolidated financial statements, primarily in estimating commodity prices used in impairment and reserves analysis. These may have significant impacts on the currently reported amounts of the company’s assets and liabilities discussed below and on similar assets and liabilities that may be recognized in the future. As part of its ongoing business planning, Suncor estimates future costs associated with GHG emissions in its operations and in the evaluation of future projects. The company uses future climate scenarios to test and assess the resilience of its strategy. The financial statement areas that require significant estimates and judgments are as follows: Oil and Gas Reserves The company’s estimate of oil and gas reserves is considered in the measurement of depletion, depreciation, impairment, and decommissioning and restoration obligations. The estimation of reserves is an inherently complex process and involves the exercise of professional judgment. All reserves have been evaluated at December 31, 2022, by independent qualified reserves evaluators. Oil and gas reserves estimates are based on a range of geological, technical and economic factors, including projected future rates of production, projected future commodity prices, engineering data, and the timing and amount of future expenditures, all of which are subject to uncertainty. Estimates reflect market and regulatory conditions existing at December 31, 2022, which could differ significantly from other points in time throughout the year, or future periods. Changes in market and regulatory conditions and assumptions, as well as climate change, and the evolving worldwide demand for energy and global advancement of alternative sources of energy that are not sourced from fossil fuels can materially impact the estimation of net reserves. The timing in which global energy markets transition from carbon-based sources to alternative energy is highly uncertain. Oil and Gas Activities The company is required to apply judgment when designating the nature of oil and gas activities as exploration, evaluation, development or production, and when determining whether the costs of these activities shall be expensed or capitalized. Exploration and Evaluation Costs Certain exploration and evaluation costs are initially capitalized with the intent to establish commercially viable reserves. The company is required to make judgments about future events and circumstances and applies estimates to assess the economic viability of extracting the underlying resources. The costs are subject to technical, commercial and management review to confirm the continued intent to develop the project. Level of drilling success or changes to project economics, resource quantities, expected production techniques, production costs and required capital expenditures are important judgments when making this determination. Management uses judgment to determine when these costs are reclassified to Property, Plant and Equipment based on several factors, including the existence of reserves, appropriate approvals from regulatory bodies, joint arrangement partners and the company’s internal project approval process. Determination of Cash Generating Units (CGUs) A CGU is the lowest grouping of integrated assets that generate identifiable cash inflows that are largely independent of the cash inflows of other assets or groups of assets. The allocation of assets into CGUs requires significant judgment and interpretations with respect to the integration between assets, the existence of active markets, similar exposure to market risks, shared infrastructure and the way in which management monitors the operations. Asset Impairment and Reversals Management applies judgment in assessing the existence of impairment and impairment reversal indicators based on various internal and external factors. The recoverable amount of CGUs and individual assets is determined based on the higher of fair value less costs of disposal or value-in-use calculations. The key estimates the company applies in determining the recoverable amount normally include estimated future commodity prices, discount rates, expected production volumes, future operating and development costs, income taxes and refining margins. In determining the recoverable amount, management may also be required to make judgments regarding the likelihood of occurrence of a future event. Changes to these estimates and judgments will affect the recoverable amounts of CGUs and individual assets and may then require a material adjustment to their related carrying value. In addition, climate change, and the evolving worldwide demand for energy and global advancement of alternative sources of energy that are not sourced from fossil fuels could result in a change in assumptions used in determining the recoverable amount and could affect the carrying value and useful life of the related assets. The timing in which global energy markets transition from carbon-based sources to alternative energy is highly uncertain. Decommissioning and Restoration Costs The company recognizes liabilities for the future decommissioning and restoration of Exploration and Evaluation assets and Property, Plant and Equipment based on estimated future decommissioning and restoration costs. Management applies judgment in assessing the existence and extent as well as the expected method of reclamation of the company’s decommissioning and restoration obligations at the end of each reporting period. Management also uses judgment to determine whether the nature of the activities performed is related to decommissioning and restoration activities or normal operating activities. Actual costs are uncertain and estimates may vary as a result of changes to relevant laws and regulations related to the use of certain technologies, the emergence of new technology, operating experience, prices and closure plans. The estimated timing of future decommissioning and restoration may change due to certain factors, including reserves life. Changes to estimates related to future expected costs, discount rates, inflation assumptions and timing may have a material impact on the amounts presented. In addition, climate change, and the evolving worldwide demand for energy and global advancement of alternative sources of energy that are not sourced from fossil fuels could result in a change in assumptions used in determining the carrying value of the liabilities. The timing in which global energy markets transition from carbon-based sources to alternative energy is highly uncertain. Employee Future Benefits The company provides benefits to employees, including pensions and other post-retirement benefits. The cost of defined benefit pension plans and other post-retirement benefits received by employees is estimated based on actuarial valuation methods that require professional judgment. Estimates typically used in determining these amounts include, as applicable, rates of employee turnover, future claim costs, discount rates, future salary and benefit levels, the return on plan assets, mortality rates and future medical costs. Changes to these estimates may have a material impact on the amounts presented. Other Provisions The determination of other provisions, including, but not limited to, provisions for royalty disputes, onerous contracts, litigation and constructive obligations, is a complex process that involves judgment about the outcomes of future events, the interpretation of laws and regulations, and estimates on the timing and amount of expected future cash flows and discount rates. Income Taxes Management evaluates tax positions, annually or when circumstances require, which involves judgment and could be subject to differing interpretations of applicable tax legislation. The company recognizes a tax provision when a payment to tax authorities is considered probable. However, the results of audits and reassessments and changes in the interpretations of standards may result in changes to those positions and, potentially, a material increase or decrease in the company’s assets, liabilities and net earnings. Deferred tax assets are recognized when it is considered probable that deductible temporary differences will be recovered in the foreseeable future. To the extent that future taxable income and the application of existing tax laws in each jurisdiction differ significantly from the company’s estimate, the ability of the company to realize the deferred tax assets could be impacted. Deferred tax liabilities are recognized when there are taxable temporary differences that will reverse and result in a future outflow of funds to a taxation authority. The company records a provision for the amount that is expected to be settled, which requires judgment as to the ultimate outcome. Deferred tax liabilities could be impacted by changes in the company’s judgment of the likelihood of a future outflow and estimates of the expected settlement amount, timing of reversals, and the tax laws in the jurisdictions in which the company operates. |
New IFRS Standards
New IFRS Standards | 12 Months Ended |
Dec. 31, 2022 | |
New IFRS Standards | |
New IFRS Standards | 5. New IFRS Standards a) Adoption of New IFRS Standards The standards, amendments and interpretations that are adopted up to the date of authorization of the company’s consolidated financial statements, and that may have an impact on the disclosures and financial position of the company are disclosed below. Property, Plant and Equipment: Proceeds before Intended Use In May 2020, the IASB issued Property, Plant and Equipment: Proceeds before Intended Use (Amendments to IAS 16) Onerous Contracts – Cost of Fulfilling a Contract In May 2020, the IASB issued Onerous Contracts – Cost of Fulfilling a Contract (Amendments to IAS 37). Fees in the “10 per cent” Test for Derecognition of Financial Liabilities In May 2020, the IASB issued Fees in the “10 per cent” Test for Derecognition of Financial Liabilities (Amendment to IFRS 9). liability are substantially different from the terms of the original financial liability. The company adopted the amendments prospectively on the effective date January 1, 2022, and there was no impact to the consolidated financial statements as a result of the initial application. b) Recently Announced Accounting Pronouncements The standards, amendments and interpretations that are issued, but not yet effective up to the date of authorization of the company’s consolidated financial statements, and that may have an impact on the disclosures and financial position of the company are disclosed below. The company intends to adopt these standards, amendments and interpretations when they become effective. Non-current Liabilities with Covenants In October 2022, the IASB issued Non-current Liabilities with Covenants (Amendments to IAS 1). Lease Liability in a Sale and Leaseback In September 2022, the IASB issued Lease Liability in a Sale and Leaseback (Amendments to IFRS 16). . |
Segmented Information
Segmented Information | 12 Months Ended |
Dec. 31, 2022 | |
Segmented Information | |
Segmented Information | 6. Segmented Information The company’s operating segments are reported based on the nature of their products and services and management responsibility. The following summary describes the operations in each of the segments: ● Oil Sands includes the company’s wholly owned operations in the Athabasca oil sands in Alberta to explore, develop and produce bitumen, synthetic crude oil and related products, through the recovery and upgrading of bitumen from mining and in situ operations. This segment also includes the company’s joint interest in the Syncrude oil sands mining and upgrading operation, and the company’s joint interest in the Fort Hills partnership as well as the marketing, supply, transportation and risk management of crude oil, natural gas, power and byproducts. The individual operating segments related to mining operations, In Situ, Fort Hills and Syncrude have been aggregated into one reportable segment (Oil Sands) due to the similar nature of their business activities, including the production of bitumen, and the single geographic area and regulatory environment in which they operate. ● Exploration and Production (E&P) includes offshore activity in East Coast Canada, with interests in the Hibernia, Terra Nova, White Rose and Hebron oilfields, the exploration and production of crude oil and natural gas at Buzzard (classified as assets held for sale and subsequent to the fourth quarter of 2022, the company reached an agreement for the sale of its United Kingdom (U.K.) operations - see note 33) and Golden Eagle Area Development in the U.K. (which was sold in 2021 – see note 16), exploration and production of crude oil and gas at Oda and the development of the Fenja field in Norway (the Norway assets were sold on September 30, 2022 – see note 16), as well as the marketing and risk management of crude oil and natural gas. ● Refining and Marketing includes the refining of crude oil products, and the distribution, marketing, transportation and risk management of refined and petrochemical products, and other purchased products through the retail and wholesale networks located in Canada and the United States (U.S.). The segment also includes trading of crude oil, natural gas and power. The company also reports activities not directly attributable to an operating segment under Corporate and Eliminations. This includes renewable projects such as wind and solar power, as well as other investments in clean technology, such as Suncor’s investment in Enerkem Inc., LanzaJet, Inc., Svante Inc., the Varennes Carbon Recycling facility, the Pathways Alliance, and the early-stage design and engineering for the ATCO/Suncor hydrogen project. The wind and solar assets are classified as assets held for sale and subsequent to the fourth quarter of 2022, the company completed the sale of these assets (note 33). Intersegment sales of crude oil and natural gas are accounted for at market values and included, for segmented reporting, in revenues of the segment making the transfer and expenses of the segment receiving the transfer. Intersegment balances are eliminated on consolidation. Intersegment profit is not recognized until the related product has been sold to third parties. Beginning in the first quarter of 2022, to align with how management evaluates segment performance, the company revised its segment presentation to reflect segment results before income tax expense and present tax at a consolidated level. This presentation change has no effect on consolidated net earnings and comparative periods have been revised to reflect this change. Exploration Refining and Corporate and For the years ended December 31 Oil Sands and Production Marketing Eliminations Total ($ millions) 2022 2021 2022 2021 2022 2021 2022 2021 2022 2021 Revenues and Other Income Gross revenues (1) 21 905 15 319 4 331 2 978 36 622 22 808 49 28 62 907 41 133 Intersegment revenues (1) 8 526 4 601 - - 106 107 (8 632) (4 708) - - Less: Royalties (3 963) (1 523) (608) (478) - - - - (4 571) (2 001) Operating revenues, net of royalties 26 468 18 397 3 723 2 500 36 728 22 915 (8 583) (4 680) 58 336 39 132 Other (loss) income (53) 6 164 17 (60) (50) 80 (4) 131 (31) 26 415 18 403 3 887 2 517 36 668 22 865 (8 503) (4 684) 58 467 39 101 Expenses Purchases of crude oil and products (1) 2 050 1 444 - - 27 261 16 807 (8 536) (4 460) 20 775 13 791 Operating, selling and general 9 152 8 056 490 429 2 427 2 019 738 862 12 807 11 366 Transportation and distribution 1 210 1 126 101 112 396 282 (36) (41) 1 671 1 479 Depreciation, depletion, amortization and impairment 7 927 4 585 (105) 324 844 853 120 88 8 786 5 850 Exploration 37 12 19 35 - - - - 56 47 (Gain) loss on disposal of assets (7) (4) 66 (227) (11) (19) (3) (7) 45 (257) Financing expenses 413 359 95 53 57 56 1 446 787 2 011 1 255 20 782 15 578 666 726 30 974 19 998 (6 271) (2 771) 46 151 33 531 Earnings (Loss) before Income Taxes 5 633 2 825 3 221 1 791 5 694 2 867 (2 232) (1 913) 12 316 5 570 Income Tax Expense (Recovery) Current - - - - - - - - 4 229 1 395 Deferred - - - - - - - - (990) 56 - - - - - - - - 3 239 1 451 Net Earnings - - - - - - - - 9 077 4 119 Capital and Exploration Expenditures (2) 3 540 3 168 443 270 816 825 188 292 4 987 4 555 (1) The company revised certain gross revenues and purchases of crude oil and products to align with current period presentation. For the twelve months ended December 31, 2022, gross revenues and purchases of crude oil and products decreased by $150 million, with no effect on net earnings. (2) Excludes capital expenditures related to assets held for sale of $133 million for the year ended December 31, 2022. Disaggregation of Revenue from Contracts with Customers and Intersegment Revenue The company’s revenues are from the following major commodities and geographical regions: For the years ended December 31 2022 2021 ($ millions) North America International Total North America International Total Oil Sands Synthetic crude oil and diesel (1) 22 539 - 22 539 14 452 - 14 452 Bitumen 7 892 - 7 892 5 468 - 5 468 30 431 - 30 431 19 920 - 19 920 Exploration and Production Crude oil and natural gas liquids 2 464 1 834 4 298 1 709 1 257 2 966 Natural gas - 33 33 - 12 12 2 464 1 867 4 331 1 709 1 269 2 978 Refining and Marketing Gasoline 14 540 - 14 540 9 983 - 9 983 Distillate 18 663 - 18 663 9 832 - 9 832 Other 3 525 - 3 525 3 100 - 3 100 36 728 - 36 728 22 915 - 22 915 Corporate and Eliminations (1) (8 583) - (8 583) (4 680) - (4 680) Total Gross Revenue from Contracts with Customers 61 040 1 867 62 907 39 864 1 269 41 133 (1) The company revised certain gross revenues and purchases of crude oil and products to align with current period presentation. For the twelve months ended December 31, 2022, gross revenues and purchases of crude oil and products decreased by $150 million, with no effect on net earnings. Geographical Information Operating Revenues, net of Royalties ($ millions) 2022 2021 Canada 49 169 32 286 United States 7 544 5 818 Other foreign 1 623 1 028 58 336 39 132 Non-Current Assets (1) December 31 December 31 ($ millions) 2022 2021 Canada 66 346 68 900 United States 2 629 2 020 Other foreign 1 026 1 682 70 001 72 602 (1) Excludes deferred income tax assets. |
Other Income
Other Income | 12 Months Ended |
Dec. 31, 2022 | |
Other Income | |
Other Income | 7. Other Income Other income consists of the following: ($ millions) 2022 2021 Energy trading and risk management (209) (165) Investment and interest income 100 64 Insurance proceeds (1) 179 69 Other (2) 61 1 131 (31) (1) 2022 includes $147 million of property damage insurance proceeds related to the company’s assets in Libya, within the Exploration and Production segment, and $32 million of insurance proceeds for the secondary extraction facilities at Oil Sands Base, within the Oil Sands segment. 2021 includes $31 million of insurance proceeds for the outages at Mackay River and $38 million for the secondary extraction facilities at Oil Sands Base, both within the Oil Sands segment. (2) 2022 includes a US $50 million contingent consideration gain related to the sale of the company’s 26.69% working interest in the Golden Eagle Area Development in the fourth quarter of 2021, within the Exploration and Production segment. |
Operating, Selling and General
Operating, Selling and General Expense | 12 Months Ended |
Dec. 31, 2022 | |
Operating, Selling and General Expense | |
Operating, Selling and General Expense | 8. Operating, Selling and General Expense Operating, Selling and General expense consists of the following: ($ millions) 2022 2021 Employee and contract service costs (1) 8 037 7 409 Materials and equipment (1) 1 901 1 931 Commodities (1) 2 196 1 523 Travel, marketing and other (1) 673 503 12 807 11 366 (1) Prior period amounts have been reclassified to align with the current year presentation of Operating, Selling and General expense. For the year ended December 31, 2021, $564 million was reclassified from employee and contract service costs to materials and equipment and $23 million was reclassified from materials and equipment and travel, marketing and other to commodities . This reclassification had no effect on the operating, selling and general expense presentation on the consolidated statements of comprehensive income. |
Financing Expenses
Financing Expenses | 12 Months Ended |
Dec. 31, 2022 | |
Financing Expenses | |
Financing Expenses | 9. Financing Expenses Financing expenses consist of the following: ($ millions) 2022 2021 Interest on debt 815 834 Interest on lease liabilities 167 161 Capitalized interest at 5.2% ( 2021 – 5.0% ) (168) (144) Interest expense 814 851 Interest on partnership liability 51 51 Interest on pension and other post-retirement benefits 41 59 Accretion 316 304 Foreign exchange loss (gain) on U.S. dollar denominated debt 729 (113) Operational foreign exchange and other 28 23 Loss on extinguishment of long-term debt 32 80 2 011 1 255 |
Income Taxes
Income Taxes | 12 Months Ended |
Dec. 31, 2022 | |
Income Taxes | |
Income Taxes | 10. Income Taxes Income Tax Expense (Recovery) ($ millions) 2022 2021 Current: Current year 4 333 1 353 Adjustments in respect of current income tax of prior years (104) 42 Deferred: Origination and reversal of temporary differences (1 063) 29 Adjustments in respect of deferred income tax of prior years 54 23 Changes in tax rates and legislation (27) 8 Movement in unrecognized deferred income tax assets 46 (4) Total income tax expense 3 239 1 451 Reconciliation of Effective Tax Rate The provision for income taxes reflects an effective tax rate that differs from the statutory tax rate. A reconciliation of the difference is as follows: ($ millions) 2022 2021 Earnings before income tax 12 316 5 570 Canadian statutory tax rate 24.16% 24.24% Statutory tax 2 976 1 350 Add (deduct) the tax effect of: Non-taxable component of capital losses (gains) 67 (12) Share-based compensation and other permanent items - 3 Assessments and adjustments (49) 65 Impact of income tax rates and legislative changes (1) (84) 8 Non-taxable component of dispositions (25) (66) Foreign tax rate differential (2) 290 111 Movement in unrecognized deferred income tax assets 46 (4) Other 18 (4) Total income tax expense 3 239 1 451 Effective tax rate 26.3% 26.1% (1) The twelve months ended December 31, 2022 includes a current income tax recovery of $39 million related to the sale of the company’s wind and solar assets (note 33). (2) The twelve months ended December 31, 2022 includes a deferred income tax recovery of $171 million related to the sale of the company’s UK assets (note 33) Deferred Income Tax Balances The significant components of the company’s deferred income tax (assets) liabilities and deferred income tax expense (recovery) are comprised of the following: Deferred Income Tax Expense (Recovery) Deferred Income Tax Liability (Asset) December 31 December 31 ($ millions) 2022 2021 2022 2021 Property, plant and equipment (729) (260) 11 093 11 477 Decommissioning and restoration provision (10) 141 (2 292) (1 936) Employee retirement benefit plans (92) (142) (297) (470) Tax loss carry-forwards (14) 161 (29) (15) Other (145) 156 (111) 25 Net deferred income tax (recovery) / expense and liability (990) 56 8 364 9 081 Change in Deferred Income Tax Balances ($ millions) 2022 2021 Net deferred income tax liability, beginning of year 9 081 8 758 Recognized in deferred income tax (recovery) / expense (990) 56 Recognized in other comprehensive income 264 277 Foreign exchange, acquisition and other 9 (10) Net deferred income tax liability, end of year 8 364 9 081 Deferred Tax in Shareholders’ Equity ($ millions) 2022 2021 Deferred Tax in Other Comprehensive Income Actuarial gain on employment retirement benefit plans 264 277 Total income tax expense reported in equity 264 277 Deferred income tax assets are recognized for tax loss carry-forwards to the extent that the realization of the related tax benefit is probable based on estimated future earnings. Suncor has not recognized a $120 million (2021 – $74 million) deferred income tax asset on $986 million (2021 – $606 million) of capital losses related to unrealized foreign exchange on U.S. dollar denominated debt, which can only be utilized against future capital gains. No |
Earnings per Common Share
Earnings per Common Share | 12 Months Ended |
Dec. 31, 2022 | |
Earnings per Common Share | |
Earnings per Common Share | 11. Earnings per Common Share ($ millions) 2022 2021 Net earnings 9 077 4 119 (millions of common shares) Weighted average number of common shares 1 387 1 488 Dilutive securities: Effect of share options 3 1 Weighted average number of diluted common shares 1 390 1 489 (dollars per common share) Basic earnings per share 6.54 2.77 Diluted earnings per share 6.53 2.77 |
Cash and Cash Equivalents
Cash and Cash Equivalents | 12 Months Ended |
Dec. 31, 2022 | |
Cash and Cash Equivalents | |
Cash and Cash Equivalents | 12. Cash and Cash Equivalents December 31 December 31 ($ millions) 2022 2021 Cash 1 782 1 971 Cash equivalents 198 234 1 980 2 205 |
Supplemental Cash Flow Informat
Supplemental Cash Flow Information | 12 Months Ended |
Dec. 31, 2022 | |
Supplemental Cash Flow Information | |
Supplemental Cash Flow Information | 13. Supplemental Cash Flow Information The (increase) decrease in non-cash working capital is comprised of: ($ millions) 2022 2021 Accounts receivable (1 750) (1 324) Inventories (1 128) (551) Accounts payable and accrued liabilities 1 512 1 588 Current portion of provisions (286) 235 Income taxes payable (net) (1) (717) 1 830 (2 369) 1 778 Relating to: Operating activities (2 421) 1 507 Investing activities 52 271 (2 369) 1 778 (1) During the twelve months ended December 31, 2022, the decrease in taxes payable was primarily related to the company’s tax installment payments, net of the current income tax expense. During the twelve months ended December 31, 2021, the increase in taxes payable was primarily related to the company’s 2021 current income tax expense, which was paid in the first quarter of 2022. Reconciliation of movements of liabilities to cash flows arising from financing activities: Current Portion Current Portion Short-Term of Long-Term Long-Term of Long-Term Long-Term Partnership Dividends ($ millions) Debt Lease Liabilities Lease Liabilities Debt Debt Liability Payable At December 31, 2020 3 566 272 2 636 1 413 13 812 436 - Changes from financing cash flows: Reduction of commercial paper (2 256) - - - - - - Gross proceeds from issuance of long-term debt - - - - 1 446 - - Debt issuance costs - - - - (23) - - Repayment of long-term debt - - - (2 451) - - - Loss on extinguishment of long-term debt - - - 80 - - - Realized foreign exchange (gains) and losses (79) - - 128 - - - Dividends paid on common shares - - - - - - 1 550 Lease liability payments - (325) - - - - - Distributions to non-controlling interest - - - - - (9) - Other - - - 25 - - - Non-cash changes: Dividends declared on common shares - - - - - - (1 550) Unrealized foreign exchange losses and (gains) 53 - - (47) (168) - - Reclassification of debt - - - 1 083 (1 083) - - Lease derecognition - - (41) - - - - Reclassification of lease obligations - 363 (363) - - - - Deferred financing costs - - - - 5 - - New lease liabilities - - 308 - - - - At December 31, 2021 1 284 310 2 540 231 13 989 427 - Changes from financing cash flows: Net issuance of commercial paper 1 473 - - - - - - Repayment of long-term debt - - - (233) (4 895) - - Loss on extinguishment of long-term debt - - - 32 - - Realized foreign exchange (gains) and losses (19) 15 - 2 (91) - - Dividends paid on common shares - - - - - - (2 596) Lease liability payments - (329) - - - - - Distributions to non-controlling interest - - - - - (14) - Other - - - - (13) - - Non-cash changes: Dividends declared on common shares - - - - - - 2 596 Unrealized foreign exchange losses and (gains) 69 - (25) - 778 - - Lease derecognition - - (22) - - - - Reclassification of lease obligations - 321 (321) - - - - Deferred financing costs - - - - - - - New lease liabilities - - 523 - - - - At December 31, 2022 2 807 317 2 695 - 9 800 413 - |
Inventories
Inventories | 12 Months Ended |
Dec. 31, 2022 | |
Inventories | |
Inventories | 14. Inventories December 31 December 31 ($ millions) 2022 2021 Crude oil (1) 2 373 1 501 Refined products 2 014 1 820 Materials, supplies and merchandise 685 789 Reclassified to assets held for sale (note 33) (14) - 5 058 4 110 (1) Includes $131 million of inventories held for trading purposes (2021 – $110 million), which are measured at fair value less costs to sell based on Level 1 and Level 2 fair value inputs. During 2022, purchased product inventories of $21.7 billion (2021 – $14.7 billion) were recorded as an expense. |
Property, Plant and Equipment
Property, Plant and Equipment | 12 Months Ended |
Dec. 31, 2022 | |
Property, Plant and Equipment | |
Property, Plant and Equipment | 15. Property, Plant and Equipment Oil and Gas Plant and ($ millions) Properties Equipment Total Cost At December 31, 2020 (1) 43 622 84 036 127 658 Additions 755 3 901 4 656 Transfers from exploration and evaluation - - - Changes in decommissioning and restoration (1 127) (5) (1 132) Disposals and derecognition (1 902) (2 652) (4 554) Foreign exchange adjustments (118) 49 (69) At December 31, 2021 (1) 41 230 85 329 126 559 Additions 1 149 4 261 5 410 Transfers from exploration and evaluation 34 - 34 Changes in decommissioning and restoration 1 321 (10) 1 311 Disposals and derecognition (585) (884) (1 469) Foreign exchange adjustments 101 218 319 Reclassified to assets held for sale (note 33) (4 475) (480) (4 955) At December 31, 2022 38 775 88 434 127 209 Accumulated provision At December 31, 2020 (1) (25 757) (33 771) (59 528) Depreciation, depletion, amortization and impairment (1 216) (4 465) (5 681) Disposals and derecognition 1 676 2 452 4 128 Foreign exchange adjustments 70 (2) 68 At December 31, 2021 (1) (25 227) (35 786) (61 013) Depreciation, depletion, amortization and impairment (1 049) (7 347) (8 396) Disposals and derecognition 510 338 848 Foreign exchange adjustments (60) (107) (167) Reclassified to assets held for sale (note 33) 4 111 62 4 173 At December 31, 2022 (21 715) (42 840) (64 555) Net property, plant and equipment December 31, 2021 (1) 16 003 49 543 65 546 December 31, 2022 17 060 45 594 62 654 (1) For the years ended December 31, 2020 and December 31, 2021, the company reclassified certain balances between oil and gas properties and plant and equipment. This reclassification had no effect on net property, plant and equipment. December 31, 2022 December 31, 2021 Accumulated Net Book Accumulated Net Book ($ millions) Cost Provision Value Cost Provision Value Oil Sands 92 601 (45 288) 47 313 87 849 (37 971) 49 878 Exploration and Production 16 541 (11 360) 5 181 21 495 (15 999) 5 496 Refining and Marketing 17 101 (7 435) 9 666 15 989 (6 596) 9 393 Corporate and Eliminations 966 (472) 494 1 226 (447) 779 127 209 (64 555) 62 654 126 559 (61 013) 65 546 At December 31, 2022, the balance of assets under construction and not subject to depreciation or depletion was $6.3 billion (December 31, 2021 – $4.6 billion). |
Asset Impairments and Transacti
Asset Impairments and Transactions | 12 Months Ended |
Dec. 31, 2022 | |
Asset Impairments and Transactions | |
Asset Impairments and Transactions | 16. Asset Impairments and Transactions No indicators of impairment or reversals of impairment were identified at December 31, 2022. Oil Sands Fort Hills assets: During the fourth quarter of 2022, the company entered into an agreement to acquire Teck Resources Limited’s (Teck) 21.3% interest in the Fort Hills Project (Fort Hills) and its associated sales and logistics agreements for $1.0 billion, subject to working capital and other closing adjustments. Subsequent to the fourth quarter of 2022, TotalEnergies EP Canada Ltd. provided notice of the exercise of its contractual right of first refusal to acquire from Teck a 6.65% interest in Fort Hills, which reduced the amount of working interest available for Suncor to purchase. As a result, on February 2, 2023, Suncor completed the acquisition of an additional 14.65% working interest in Fort Hills for $688 million, before working capital and other closing adjustments, bringing the company’s and its affiliate’s total aggregate working interest in Fort Hills to 68.76% . Due to the limited time between the acquisition and the preparation of these consolidated financial statements, the timing of closing adjustments, the value of the assets acquired and the liabilities assumed on the acquisition were not finalized to complete the purchase price allocation. Prior to entering the agreement with Teck, the company also updated its long-range plan for Fort Hills, which incorporated lower gross production and increased operating costs per barrel for the next three years . Management considered these indicators of impairment and performed an asset impairment test using recoverable amounts based on fair value less costs of disposal. An impairment charge of $2.6 billion (net of taxes of $0.8 billion) was recognized on its share of Fort Hills in the Oil Sands segment in the third quarter of 2022. An expected cash flow approach with the following asset specific assumptions (Level 3 fair value inputs note 27) were applied: ● Western Canada Select (WCS) price forecast of US $69.00 /bbl in 2023, US $62.00 /bbl in 2024, and an average price of US $50.00 /bbl between 2025 and 2031, escalating at 2% per year thereafter over the life of the project up to 2060, adjusted for asset-specific location and quality differentials; ● the company’s share of production ranging from 87,000 to 106,000 bbls/d over the life of the project; ● cash operating costs averaging approximately $25.00 /bbl over the life of the project (expressed in real dollars), which reflects operating, selling and general expenses adjusted for non-production costs, including share-based compensation, research costs, and excess power revenue; ● foreign exchange rate of US $0.76 per one Canadian dollar; and ● risk adjusted discount rate of 8.25% (after-tax). The recoverable amount of the Fort Hills cash generating unit (CGU) was $2.8 billion (net of taxes) as at September 30, 2022. The recoverable amount estimate is most sensitive to price and discount rate. A 5% average decrease in price over the life of the project would have resulted in an additional impairment charge of approximately $1.0 billion (after-tax) on the company’s share of the Fort Hills assets. A 1% increase in the discount rate would have resulted in an additional impairment charge of approximately $0.2 billion (after-tax) on the company’s share of the Fort Hills assets. Exploration and Production White Rose assets: In the second quarter of 2022, the company announced that concurrent with the decision to restart the West White Rose project by the joint venture owners, Suncor increased its ownership in the White Rose asset by 12.5% to approximately 39% (previously approximately 26% ). The decision to restart was driven by a revised royalty structure and development plan. The company received $38 million (net of taxes of $12 million) in cash consideration to acquire the additional working interest, which was primarily allocated to the asset retirement obligation and property, plant and equipment of the project. As a result of these events, during the second quarter of 2022, the company performed an impairment reversal test on the White Rose CGU as the recoverable amount of this CGU was sensitive to the restart decision. The impairment reversal test was performed using a recoverable amount based on the fair value less cost of disposal. An expected cash flow approach was used with the key assumptions discussed below (Level 3 fair value inputs note 27). As a result of the impairment reversal test, the recoverable amounts were determined to be greater than the carrying values of the White Rose CGU and the company recorded an impairment reversal of $542 million (net of taxes of $173 million) on its previous share of the White Rose assets in the Exploration and Production segment. The recoverable amount was determined based on the following asset-specific assumptions: ● Brent price forecast of US $85.00 /bbl in 2023, US $68.00 in 2024 and US $69.00 in 2025, escalating at 2% per year thereafter over the life of the project to 2038 and adjusted for asset-specific location and quality differentials; ● anticipated first oil for the West White Rose project in the first half of 2026 and the company’s share of production of approximately 9,800 bbls/d (based on its previous working interest of approximately 26% ) over the life of the project; ● the company’s share of future capital expenditures of $1.5 billion, including the West White Rose expansion; and ● risk-adjusted discount rate of 9.0% (after-tax). Norway assets: During the third quarter of 2022, the company completed the sale of its Norway assets, including its 30% working interest in Oda and its 17.5% working interest in the Fenja Development Joint Operations, for net proceeds of $297 million (net of cash disposed of $133 million), resulting in a $65 million loss including foreign exchange impacts. The company completed the sale on September 30, 2022. The Norway assets are reported in the Exploration and Production segment. In the second quarter of 2022, the company reclassified the assets and liabilities related to its Norway operations as assets held for sale and performed an impairment test on the Norway assets held for sale as at June 30, 2022. The impairment test was performed using the lower of its carrying amount and fair value less costs to sell (Level 2 fair value inputs note 27). As a result of the impairment test, the company recorded a $47 million charge related to the impairment on its share of the Norway operations, net of a $23 million deferred tax adjustment associated with the assets held for sale. Asset Impairments and Transactions in 2021 Oil Sands Fort Hills assets: During the fourth quarter of 2021, the company performed an asset impairment test on its Fort Hills CGU due to changes in its mine plan. The impairment test was performed using recoverable amounts based on fair value less cost of disposal. An expected cash flow approach was used with the following asset-specific assumptions (Level 3 fair value inputs note 27): ● WCS price forecast of US $55.00 /bbl in 2022, US $54.57 /bbl in 2023, and an average price of US $50.86 /bbl between 2024 and 2031, escalating at 2% per year thereafter over the life of the project up to 2058, adjusted for asset-specific location and quality differentials; ● the company’s share of production ranging from 94,000 to 111,000 bbls/d over the life of the project; ● cash operating costs averaging $22.00 /bbl to $23.00 /bbl over the life of the project (expressed in real dollars), which reflects operating, selling and general expenses adjusted for non-production costs, including share-based compensation, research costs, and excess power revenue; ● foreign exchange rate of US $0.80 per one Canadian dollar; and ● risk-adjusted discount rate of 7.5% (after-tax). Factors including an improved WCS price forecast in the next two years and optimization of the mine plan to exclude certain high strip ratio zones were offset by higher operating and capital costs. The recoverable amount of the Fort Hills CGU was $5.5 billion as at December 31, 2021, which indicated that no impairment loss or reversal The recoverable amount estimate is most sensitive to price and discount rate. A 5% average decrease in price over the life of the project would have resulted in an impairment charge of approximately $1.0 billion (after-tax) on the company’s share of the Fort Hills assets. A 1% increase in the discount rate would have resulted in an impairment charge of approximately $0.5 billion (after-tax) on the company’s share of the Fort Hills assets. Exploration and Production Terra Nova assets: During the third quarter of 2021, the company finalized an agreement with the co-owners of the Terra Nova Project to restructure the project ownership and move forward with the Asset Life Extension Project. The agreement increased the company’s working interest to 48% (previously approximately 38% ) and includes royalty and financial support from the Government of Newfoundland and Labrador. The company received $26 million (net of taxes of $8 million) in cash consideration to acquire the additional 10% working interest, which was primarily allocated to the asset retirement obligation and property, plant and equipment of the project. As a result of these events, during the third quarter of 2021, the company performed an impairment reversal test on the Terra Nova CGU as the recoverable amount of this CGU was sensitive to the financial support from the Government of Newfoundland and Labrador and revised royalty structure resulting in increased profitability and economic value. The impairment reversal test was performed using recoverable amounts based on the fair value less cost of disposal. An expected cash flow approach was used with the key assumptions discussed below (Level 3 fair value inputs note 27). As a result of the impairment reversal test, the recoverable amounts were determined to be greater than the carrying values of the Terra Nova CGU and the company recorded an impairment reversal of $168 million (net of taxes of $53 million) on its share of the Terra Nova assets in the Exploration and Production segment in the third quarter of 2021. In addition to the financial support from the government, the recoverable amount was determined based on the following asset-specific assumptions: ● Brent price forecast of US $65.00 /bbl in 2023 and US $68.00 /bbl in 2024, escalating at 2% per year thereafter over the life of the project to 2033 and adjusted for asset-specific location and quality differentials; ● the anticipated return to operations before the end of 2022 and the company’s share of production of approximately 6,000 bbls/d (based on its previous 38% working interest) over the life of the project; and ● risk-adjusted discount rate of 9.0% (after-tax). The recoverable amount of the Terra Nova CGU was $177 million as at September 30, 2021. No indicators of impairment or reversals of impairment were identified as at December 31, 2021. United Kingdom assets: During the fourth quarter of 2021, the company completed the sale of its 26.69% working interest in the Golden Eagle Area Development, reported within the Exploration and Production segment, for gross proceeds of US$250 million net of closing adjustments and other closing costs, resulting in a gain on sale of $227 million ($227 million after-tax). The company recognized US$50 million of contingent consideration in 2022 related to the asset disposal. |
Right-of-Use Assets and Leases
Right-of-Use Assets and Leases | 12 Months Ended |
Dec. 31, 2022 | |
Right-of-Use Assets and Leases | |
Right-of-Use Assets and Leases | 17. Right-of-Use Assets and Leases Right-of-use (ROU) assets within Property, Plant and Equipment: December 31 December 31 ($ millions) 2022 2021 Property, plant and equipment, net – excluding ROU assets 59 778 62 821 ROU assets 2 876 2 725 62 654 65 546 The following table presents the ROU assets by asset class: Plant and ($ millions) Equipment Cost At January 1, 2021 3 786 Additions and adjustments 307 Disposals (232) Foreign exchange - At December 31, 2021 3 861 Additions and adjustments 523 Disposals (156) Foreign exchange 20 At December 31, 2022 4 248 Accumulated provision At January 1, 2021 (962) Depreciation (396) Disposals 221 Foreign exchange 1 At December 31, 2021 (1 136) Depreciation (356) Disposals 126 Foreign exchange (6) At December 31, 2022 (1 372) Net ROU assets At December 31, 2021 2 725 At December 31, 2022 2 876 Other lease-related items recognized in the Consolidated Statements of Comprehensive Income (Loss): There were no leases with residual value guarantees. For the year ended December 31, 2022, total cash outflow for leases, excluding short-term lease expense and variable lease expense, was $496 million (2021 – $486 million). |
Exploration and Evaluation Asse
Exploration and Evaluation Assets | 12 Months Ended |
Dec. 31, 2022 | |
Exploration and Evaluation Assets | |
Exploration and Evaluation Assets | 18. Exploration and Evaluation Assets December 31 December 31 ($ millions) 2022 2021 Beginning of year 2 226 2 286 Acquisitions and additions 41 2 Transfers to oil and gas assets (34) - Disposals and derecognition - (54) Reclassified to assets held for sale (note 33) (239) - Foreign exchange adjustments 1 (8) End of year 1 995 2 226 |
Other Assets
Other Assets | 12 Months Ended |
Dec. 31, 2022 | |
Other Assets | |
Other Assets | 19. Other Assets December 31 December 31 ($ millions) 2022 2021 Investments 758 391 Prepaids and other 796 916 Pension (note 23) 212 - 1 766 1 307 Investments includes the company’s investments in clean technology, such as Suncor’s investment in Enerkem Inc., LanzaJet, Inc., Svante Inc. and the Varennes Carbon Recycling facility, in addition to the company’s investments in various pipelines. Prepaids and other includes long-term accounts receivable related to deposits paid on account to support reclamation activities into the Syncrude Reclamation Trust, Notices of Reassessments that have been received from the Canada Revenue Agency, and emissions credits and are unlikely to be settled within one year. |
Goodwill and Other Intangible A
Goodwill and Other Intangible Assets | 12 Months Ended |
Dec. 31, 2022 | |
Goodwill and Other Intangible Assets | |
Goodwill and Other Intangible Assets | 20. Goodwill and Other Intangible Assets Refining and Oil Sands Marketing Other ($ millions) Goodwill Goodwill Intangibles Total At December 31, 2020 2 752 140 436 3 328 Additions - - 213 213 Amortization - - (18) (18) At December 31, 2021 2 752 140 631 3 523 Additions - - 140 140 Amortization - - (57) (57) Reclassified to assets held for sale (note 33) - - (20) (20) At December 31, 2022 2 752 140 694 3 586 The company performed a goodwill impairment test at December 31, 2022 on its Oil Sands segment. Recoverable amounts were based on fair value less costs of disposal calculated using the present value of the segment’s expected future cash flows. Cash flow forecasts are based on past experience, historical trends, third-party evaluations of the company’s reserves and resources to estimate production profiles and volumes, and estimates of operating costs, maintenance and capital expenditures. These estimates are validated against the estimates approved through the company’s annual reserves evaluation process and determine the duration of the underlying cash flows used in the discounted cash flow test. Projected cash flows reflect current market assessments of key assumptions, including climate change, long-term forecasts of commodity prices, inflation rates, foreign exchange rates and discount rates (Level 3 fair value inputs note 27). Future cash flow estimates are discounted using after-tax risk-adjusted discount rates. The after-tax discount rate applied to cash flow projections was an average of 7.8% (2021 – 7.5%). The company based its cash flow projections on a West Texas Intermediate price of US$80.00/bbl in 2023, US$71.40/bbl in 2024, US$62.42/bbl in 2025 and escalating at an average of 2% thereafter, adjusted for applicable quality and location differentials. The forecast cash flow period ranged from 50 years to 55 years. As a result of this analysis, management did not identify any impairment of goodwill within the Oil Sands operating segment. The company also performed a goodwill impairment test of its Refining and Marketing CGUs. The recoverable amounts are based on fair value less costs of disposal calculated using the present value of the CGUs’ expected future cash flows, based primarily on historical results adjusted for current economic conditions. As a result of this analysis, management did not identify any impairment of goodwill within the Refining and Marketing segment. |
Debt and Credit Facilities
Debt and Credit Facilities | 12 Months Ended |
Dec. 31, 2022 | |
Debt and Credit Facilities | |
Debt and Credit Facilities | 21. Debt and Credit Facilities Debt and credit facilities are comprised of the following: Short-Term Debt December 31 December 31 ($ millions) 2022 2021 Commercial paper (1) 2 807 1 284 (1) The commercial paper is supported by a revolving credit facility with a syndicate of lenders. The company is authorized to issue commercial paper to a maximum of $5.0 billion having a term not to exceed 365 days . The weighted average interest rate as at December 31, 2022 was 4.93% (December 31, 2021 - 0.33% ). Long-Term Debt December 31 December 31 ($ millions) 2022 2021 Fixed-term debt (2)(3) 4.50% Notes, due 2022 ( US$182 ) (4) - 231 2.80% Notes, due 2023 ( US$450 ) - 569 3.10% Notes, due 2025 ( US$550 ) - 696 3.00% Series 5 Medium Term Notes, due 2026 115 699 7.875% Debentures, due 2026 ( US$275 ) 381 359 8.20% Notes, due 2027 ( US$59 ) (4) 61 78 7.00% Debentures, due 2028 ( US$250 ) 342 320 3.10% Series 6 Medium Term Notes, due 2029 79 748 5.00% Series 7 Medium Term Notes, due 2030 154 1 247 7.15% Notes, due 2032 ( US$500 ) 676 631 5.35% Notes, due 2033 ( US$300 ) 161 355 5.95% Notes, due 2034 ( US$500 ) 675 630 5.95% Notes, due 2035 ( US$600 ) 268 731 5.39% Series 4 Medium Term Notes, due 2037 279 599 6.50% Notes, due 2038 ( US$1 150 ) 1 553 1 451 6.80% Notes, due 2038 ( US$900 ) 1 235 1 156 6.85% Notes, due 2039 ( US$750 ) 1 013 946 6.00% Notes, due 2042 ( US$152 ) (4) 35 149 4.34% Series 5 Medium Term Notes, due 2046 300 300 4.00% Notes, due 2047 ( US$750 ) 1 011 945 3.95% Series 8 Medium Term Notes, due 2051 493 493 3.75% Notes, due 2051 ( US$750 ) 1 009 945 Total unsecured long-term debt 9 840 14 278 Lease liabilities (5) 3 012 2 850 Deferred financing costs (40) (58) 12 812 17 070 Current portion of long-term debt and lease liabilities Lease liabilities (317) (310) Long-term debt - (231) (317) (541) Total long-term lease liabilities 2 695 2 540 Total long-term debt 9 800 13 989 (2) The value of debt includes the unamortized balance of premiums or discounts. (3) Certain securities are redeemable at the option of the company. (4) Debt acquired through the acquisition of Canadian Oil Sands Limited (COS). (5) Interest rates range from 0.4% to 13.4% and maturity dates range from 2023 to 2062. In the fourth quarter of 2022, the company executed a debt tender offer pursuant to which it repaid $3.6 billion aggregate principal amount of debt at an amount below par of $51 million plus accrued and unpaid interest. As a result of the extinguishment, the company incurred non-cash charges of $83 million related to accelerated amortization. This resulted in a total loss on extinguishment of long-term debt of $32 million. The general terms of the notes that were extinguished are as follows: ● 3.00% Series 5 Medium Term Notes, due 2026, with a principal amount of $700 million (partial repayment of $585 million); ● 8.20% Notes, due 2027, with a principal amount of US $59 million (partial repayment of US $16 million); ● 3.10% Series 6 Medium Term Notes, due 2029, with a principal amount of $750 million (partial repayment of $671 million); ● 5.00% Series 7 Medium Term Notes, due 2030, with a principal amount of $1.3 billion (partial repayment of $1.1 billion); ● 5.35% Notes, due 2033, with a principal amount of US $300 million (partial repayment of US $178 million); ● 5.95% Notes, due 2035, with a principal amount of US $600 million (partial repayment of US $401 million); ● 5.39% Series 4 Medium Term Notes, due 2037, with a principal amount of $600 million (partial repayment of $321 million); and ● 6.00% Notes, due 2042, with a principal amount of US $142 million (partial repayment of US $110 million). In the second quarter of 2022, the company completed an early redemption, at par, of its outstanding US$450 million 2.80% notes and US $550 million 3.10% notes, originally due in 2023 and 2025, respectively. The company also completed a partial redemption, at par, for US$10.2 million of its outstanding US$152 million 6.00% notes, due in 2042. In the first quarter of 2022, the company completed an early redemption of its outstanding US $182 million 4.50% notes, originally scheduled to mature in the second quarter of 2022. During the fourth quarter of 2021, the company repaid its US$300 million (book value of $371 million) senior unsecured notes at maturity with a coupon of 9.25%, for US$314 million ($388 million), including US$14 million ($17 million) of accrued interest. In the third quarter of 2021, the company completed an early redemption of its US$750 million (book value of $951 million) senior unsecured notes with a coupon interest of 3.60% originally scheduled to mature on December 1, 2024, for US$822 million ($1.0 billion), including US$9 million ($11 million) of accrued interest, resulting in a debt extinguishment loss of $80 million ($60 million after tax). On March 4, 2021, the company issued US$750 million of senior unsecured notes maturing on March 4, 2051. The notes have a coupon of 3.75% and were priced at US$99.518 per US$100 principal amount for an effective yield of 3.777%. The company also issued $500 million of senior unsecured Series 8 medium-term notes on March 4, 2021, maturing on March 4, 2051. The notes have a coupon of 3.95% and were priced at $98.546 per $100 principal amount for an effective yield of 4.034%. Interest on the 3.75% and 3.95% notes is paid semi-annually. In the first quarter of 2021, the company completed an early redemption of its $750 million senior unsecured Series 5 medium-term notes with a coupon of 3.10%, originally scheduled to mature on November 26, 2021, for $770 million, including $8 million of accrued interest, resulting in a debt extinguishment loss of $12 million ($9 million after-tax). The company also completed an early redemption of its US$220 million (book value of $278 million) senior unsecured notes with a coupon of 9.40%, originally scheduled to mature on September 1, 2021, for US$230 million ($290 million), including US$2 million ($2 million) of accrued interest, resulting in a debt extinguishment loss of $10 million ($8 million after-tax). Scheduled Debt Repayments Scheduled principal repayments as at December 31, 2022 for lease liabilities, short-term debt and long-term debt are as follows: ($ millions) Repayment 2023 3 124 2024 264 2025 241 2026 691 2027 244 Thereafter 11 101 15 665 Credit Facilities A summary of available and unutilized credit facilities is as follows: ($ millions) 2022 Fully revolving and expires in 2026 3 000 Fully revolving and expires in 2025 2 707 Can be terminated at any time at the option of the lenders 1 520 Total credit facilities 7 227 Credit facilities supporting outstanding commercial paper (2 807) Credit facilities supporting standby letters of credit (1 148) Total unutilized credit facilities (1) 3 272 (1) Available credit facilities for liquidity purposes at December 31, 2022 decreased to $2.900 billion, compared to $4.247 billion at December 31, 2021. |
Other Long Term Liabilities
Other Long Term Liabilities | 12 Months Ended |
Dec. 31, 2022 | |
Other Long Term Liabilities | |
Other Long Term Liabilities | 22. Other Long-Term Liabilities December 31 December 31 ($ millions) 2022 2021 Pensions and other post-retirement benefits (note 23) 564 1 207 Share-based compensation plans (note 26) 469 291 Partnership liability (note 27) (1) 413 427 Deferred revenue 22 29 Libya Exploration and Production Sharing Agreement (EPSA) signature bonus (2) 80 74 Other 94 152 1 642 2 180 (1) The company paid $60 million in 2022 (2021 – $60 million) in distributions to the partners of the East Tank Farm Development, of which $51 million (2021 – $51 million) was allocated to interest expense and $9 million (2021 – $9 million) to the principal. (2) The company has a US $500 million obligation for a signature bonus relating to Petro-Canada’s ratification of six EPSAs in Libya. At December 31, 2022, the carrying amount of the Libya EPSAs’ signature bonus so was $85 million (December 31, 2021 – $78 million). The current portion is $5 million (December 31, 2021 – $4 million) and is recorded in Accounts Payable and Accrued Liabilities. |
Pensions and Other Post Retirem
Pensions and Other Post Retirement Benefits | 12 Months Ended |
Dec. 31, 2022 | |
Pensions and Other Post Retirement Benefits | |
Pensions and Other Post Retirement Benefits | 23. Pensions and Other Post-Retirement Benefits The company’s defined benefit pension plans provide pension benefits at retirement based on years of service and final average earnings (if applicable). These obligations are met through funded registered retirement plans and through unregistered supplementary pensions that are funded through retirement compensation arrangements, and/or paid directly to recipients. The company’s contributions to the funded plans are deposited with independent trustees who act as custodians of the plans’ assets, as well as the disbursing agents of the benefits to recipients. Plan assets are managed by a pension committee on behalf of beneficiaries. The committee retains independent managers and advisors. Asset-liability matching studies are performed by a third-party consultant to set the asset mix by quantifying the risk-and-return characteristics of possible asset mix strategies. Investment and contribution policies are integrated within this study, and areas of focus include asset mix as well as interest rate sensitivity. Funding of the registered retirement plans complies with applicable regulations that require actuarial valuations of the pension funds at least once every three years in Canada and the U.K., and every year in the United States and Germany. The most recent valuations for the registered Canadian plans and U.K. plans were performed as at December 31, 2022. The company uses a measurement date of December 31 to value the plan assets and remeasure the accrued benefit obligation for accounting purposes. The company’s other post-retirement benefits programs are unfunded and include certain health care and life insurance benefits provided to retired employees and eligible surviving dependants. The company reports its share of Syncrude’s defined benefit and defined contribution pension plans and Syncrude’s other post-retirement benefits plan. The company also provides a number of defined contribution plans, including a U.S. 401(k) savings plan, that provide for an annual contribution of 5% to 11.5% of each participating employee’s pensionable earnings. Defined Benefit Obligations and Funded Status Other Post-Retirement Pension Benefits Benefits ($ millions) 2022 2021 2022 2021 Change in benefit obligation Benefit obligation at beginning of year 8 303 8 682 672 690 Current service costs 263 302 19 19 Plan participants’ contributions 17 17 - - Benefits paid (367) (350) (28) (27) Interest costs 246 222 20 18 Foreign exchange (2) (6) - - Settlements 10 11 - - Actuarial remeasurement: Experience (gain) loss arising on plan liabilities (86) (1) 3 (1) Actuarial gain arising from changes in demographic assumptions - (2) - - Actuarial gain arising from changes in financial assumptions (2 229) (572) (167) (27) Benefit obligation at end of year 6 155 8 303 519 672 Change in plan assets Fair value of plan assets at beginning of year 7 701 7 305 - - Employer contributions 61 (11) - - Plan participants’ contributions 17 17 - - Benefits paid (347) (325) - - Foreign exchange (4) (5) - - Settlements 10 11 - - Administrative costs (2) (2) - - Income on plan assets 225 181 - - Actuarial remeasurement: Return on plan assets greater / (less) than discount rate (1 190) 530 - - Fair value of plan assets at end of year 6 471 7 701 - - Effect of the asset ceiling 187 - - - Net surplus / (unfunded obligation) at end of year 129 (602) (519) (672) The defined benefit asset (liability) is included as follows in the Consolidated Balance Sheet: December 31 December 31 ($ millions) 2022 2021 Amounts charged to Other assets (note 19) 212 - Accounts payable and accrued liabilities (38) (67) Other long-term liabilities (note 22) (564) (1 207) (390) (1 274) In June 2020, the Government of Alberta issued an amendment to the Employment Pension Plans Regulation to provide additional forms of relief to administrators of Alberta-registered pension plans. The company was approved for funding relief starting in late 2020 for both the defined benefit plan and the defined contribution plan based on funding levels in the defined benefit plan. In 2021, employer contributions reflect the contribution holiday and a transfer of funds from the defined benefit plan to the defined contribution plan, with the company resuming cash contributions near the end of 2021. In 2022, upon filing of the new actuarial funding valuations, the company entered into another contribution holiday for the defined benefit plans with the company anticipating to fully resume cash contributions in 2024. Of the total net obligations as at December 31, 2022, 96% relates to Canadian pension plans and other post-retirement benefits obligation (December 31, 2021 – 98%). The weighted average duration of the defined benefit obligation under the Canadian pension plans and other post-retirement plans is 16.4 years (2021 – 15.1 years). Other Post-Retirement Pension Benefits Benefits ($ millions) 2022 2021 2022 2021 Analysis of amount charged to earnings: Current service costs 263 302 19 19 Interest costs 21 41 20 18 Defined benefit plans expense 284 343 39 37 Defined contribution plans expense 95 94 - - Total benefit plans expense charged to earnings 379 437 39 37 Components of defined benefit costs recognized in Other Comprehensive Income: Other Post-Retirement Pension Benefits Benefits ($ millions) 2022 2021 2022 2021 Actuarial (gain) / loss arising from changes in experience (86) (1) 3 (1) Actuarial gain arising from changes in financial assumptions (2 229) (572) (167) (27) Actuarial gain arising from changes in demographic assumptions - (2) - - Benefit Obligation gains (2 315) (575) (164) (28) Return on plan assets (greater) / less than discount rate (excluding amounts included in net interest expense) 1 190 (530) - - Effect of the asset ceiling 187 - - - Plan assets loss / (gain) 1 377 (530) - - Actuarial gain recognized in other comprehensive income (938) (1 105) (164) (28) Actuarial Assumptions The cost of the defined benefit pension plans and other post-retirement benefits received by employees is actuarially determined using the projected unit credit method of valuation that includes employee service to date and present pay levels, as well as the projection of salaries and service to retirement. The significant weighted average actuarial assumptions were as follows: Other Post-Retirement Pension Benefits Benefits December 31 December 31 December 31 December 31 (%) 2022 2021 2022 2021 Discount rate 5.10 2.90 5.10 2.90 Rate of compensation increase 3.00 3.00 3.00 3.00 The discount rate assumption is based on the interest rate on high-quality bonds with maturity terms equivalent to the benefit obligations. The defined benefit obligation reflects the best estimate of the mortality of plan participants both during and after their employment. The mortality assumption is based on a standard mortality table adjusted for actual experience over the past five years. In order to measure the expected cost of other post-retirement benefits, it was assumed that the health care costs would increase annually by 5%. Assumed discount rates and health care cost trend rates may have a significant effect on the amounts reported for pensions and other post-retirement benefits obligations for the company’s Canadian plans. A change of these assumptions would have the following effects: Pension Benefits ($ millions) Increase Decrease 1% change in discount rate Effect on the aggregate service and interest costs (25) 32 Effect on the benefit obligations (693) 871 Other Post-Retirement Benefits ($ millions) Increase Decrease 1% change in discount rate Effect on the benefit obligations (53) 64 1% change in health care cost Effect on the aggregate service and interest costs 1 (1) Effect on the benefit obligations 27 (23) Plan Assets and Investment Objectives The company’s long-term investment objective is to secure the defined pension benefits while managing the variability and level of its contributions. The portfolio is rebalanced periodically, as required, to the plans’ target asset allocation as prescribed in the Statement of Investment Policies and Procedures approved by the Board of Directors. Plan assets are restricted to those permitted by legislation, where applicable. Investments are made through pooled, mutual, segregated or exchange traded funds. The company’s weighted average pension plan asset allocations, based on market values as at December 31, are as follows: (%) 2022 2021 Equities 52 48 Fixed income 27 38 Plan assets, comprised of: – Real Estate 21 14 Total 100 100 Equity securities do not include any direct investments in Suncor shares. The fair value of equity and fixed income securities is based on the trading price of the underlying fund. The fair value of real estate investments is based on independent third-party appraisals. |
Provisions
Provisions | 12 Months Ended |
Dec. 31, 2022 | |
Provisions | |
Provisions | 24. Provisions Decommissioning ($ millions) and Restoration (1) Royalties Other (2) Total At December 31, 2020 10 044 71 467 10 582 Liabilities incurred 104 137 171 412 Change in discount rate (1 260) - - (1 260) Changes in estimates (76) (12) (13) (101) Liabilities settled (263) 26 (84) (321) Accretion 304 - - 304 Foreign exchange (61) - - (61) At December 31, 2021 8 792 222 541 9 555 Less: current portion (266) (222) (291) (779) 8 526 - 250 8 776 At December 31, 2021 8 792 222 541 9 555 Liabilities incurred 114 89 3 206 Change in discount rate (2 456) - - (2 456) Changes in estimates 3 596 (4) 69 3 661 Liabilities settled (314) (125) (332) (771) Accretion 316 - - 316 Asset disposals 62 - - 62 Reclassified to assets held for sale (note 33) (226) - - (226) Foreign exchange 17 - - 17 At December 31, 2022 9 901 182 281 10 364 Less: current portion (337) (182) (45) (564) 9 564 - 236 9 800 (1) Represents decommissioning and restoration provisions associated with the retirement of Property, Plant and Equipment and Exploration and Evaluation assets. The total undiscounted and uninflated amount of estimated future cash flows required to settle the obligations at December 31, 2022 was approximately $22.4 billion (December 31, 2021 – $13.8 billion). A $3.6 billion increase in the estimated discounted cash flows was recognized at December 31, 2022, and was primarily related to water treatment costs for mining assets. A weighted average credit-adjusted risk-free interest rate of 5.50% was used to discount the provision recognized at December 31, 2022 (December 31, 2021 – 3.70% ). The credit-adjusted risk-free interest rate used reflects the expected time frame of the provisions. Payments to settle the decommissioning and restoration provisions occur on an ongoing basis and will continue over the lives of the operating assets, which can exceed 50 years . (2) Includes legal and environmental provisions, a restructuring provision remaining for $11 million (December 31, 2021 - $88 million). Liabilities settled in 2022 include a payment to the Keystone XL pipeline project for $187 million (after-tax $142 million). Sensitivities Changes to the discount rate would have the following impact on Decommissioning and Restoration liabilities: As at December 31 2022 2021 1% Increase (1 594) (1 497) 1% Decrease 2 131 2 113 |
Share Capital
Share Capital | 12 Months Ended |
Dec. 31, 2022 | |
Share Capital | |
Share Capital | 25. Share Capital Authorized Common Shares The company is authorized to issue an unlimited number of common shares without nominal or par value. Preferred Shares The company is authorized to issue an unlimited number of senior and junior preferred shares in series, without nominal or par value. Normal Course Issuer Bid During the first quarter of 2022, the TSX accepted a notice filed by Suncor to renew its normal course issuer bid (NCIB) to purchase the company’s common shares through the facilities of the TSX, New York Stock Exchange (NYSE) and/or alternative trading systems. The notice provided that, beginning February 8, 2022, and ending February 7, 2023, Suncor may purchase for cancellation up to 71,650,000 common shares, which is equal to approximately 5% of Suncor’s issued and outstanding common shares as at the date hereof. During the second quarter of 2022, Suncor received approval from the TSX to amend its existing NCIB effective as of the close of markets on May 11, 2022, to increase the maximum number of common shares that may be repurchased in the period beginning February 8, 2022, and ending February 7, 2023, from 71,650,000 common shares, or approximately 5% of Suncor’s issued and outstanding common shares as at January 31, 2022, to 143,500,000 , or approximately 10% of Suncor’s public float as at January 31, 2022. No other terms of the NCIB were amended. For the twelve months ended December 31, 2022, the company repurchased 7.1 million common shares under the previous 2021 NCIB and 109.8 million under the 2022 renewed NCIB at an average price of $43.92 per share, for a total repurchase cost of $5.1 billion. Subsequent to the fourth quarter of 2022, the TSX accepted a notice filed by Suncor to renew its NCIB to purchase the company’s common shares through the facilities of the TSX, NYSE and/or alternative trading systems. The notice provides that, beginning February 17, 2023, and ending February 16, 2024, Suncor may purchase for cancellation up to 132,900,000 common shares, which is equal to approximately 10% of Suncor’s public float as at February 3, 2023. As at February 3, 2023, Suncor had 1,330,006,760 common shares issued and outstanding. During the first quarter of 2021, the company announced its intention to commence a new Normal Course Issuer Bid (the 2021 NCIB) to repurchase common shares through the facilities of the TSX, NYSE and/or alternative trading systems. Pursuant to the 2021 NCIB, the company may repurchase for cancellation up to 44,000,000 common shares between February 8, 2021, and February 7, 2022. During the third quarter of 2021, Suncor received approval from the TSX to amend the 2021 NCIB effective as of the close of markets on July 30, 2021. The amended notice provides that Suncor may increase the maximum number of common shares that may be repurchased under the 2021 NCIB from February 8, 2021, and ending February 7, 2022, from 44,000,000 common shares, or approximately 2.9% of Suncor’s issued and outstanding common shares as at January 31, 2021, to 76,250,000 common shares, or approximately 5% of Suncor’s issued and outstanding common shares as at January 31, 2021. No other terms of the NCIB were amended. During the fourth quarter of 2021, Suncor received approval from the TSX to amend its existing NCIB effective as of the close of markets on October 29, 2021. The notice provides that Suncor may increase the maximum number of common shares that may be repurchased in the period beginning February 8, 2021, and ending February 7, 2022, from 76,250,000 shares, or approximately 5% of Suncor’s issued and outstanding common shares as at January 31, 2021, to 106,700,000, or approximately 7% of Suncor’s public float as at January 31, 2021. No other terms of the NCIB were amended. For the twelve months ended December 31, 2021, the company repurchased 84.0 million common shares under the 2021 NCIB at an average price of $27.45 per share, for a total repurchase cost of $2.3 billion. The following table summarizes the share repurchase activities during the period: ($ millions, except as noted) 2022 2021 Share repurchase activities (thousands of common shares) Shares repurchased 116 908 83 959 Amounts charged to Share capital 1 947 1 382 Retained earnings 3 188 922 Share repurchase cost 5 135 2 304 Average repurchase cost per share 43.92 27.45 Under an automatic repurchase plan agreement with an independent broker, the company has recorded the following liability for share repurchases that may take place during its internal blackout period: December 31 December 31 ($ millions) 2022 2021 Amounts charged to Share capital 136 120 Retained earnings 214 110 Liability for share purchase commitment 350 230 |
Share Based Compensation
Share Based Compensation | 12 Months Ended |
Dec. 31, 2022 | |
Share Based Compensation | |
Share Based Compensation | 26. Share-Based Compensation Share-Based Compensation Expense Included in the Consolidated Statements of Comprehensive Income within Operating, Selling and General expense are the following share-based compensation amounts: ($ millions) 2022 2021 Equity-settled plans 17 21 Cash-settled plans 484 301 Total share-based compensation expense 501 322 Liability Recognized for Share-Based Compensation Included in the Consolidated Balance Sheets within accounts payable and accrued liabilities and other long-term liabilities are the following fair value amounts for the company’s cash-settled plans: December 31 December 31 ($ millions) 2022 2021 Current liability 326 153 Long-term liability (note 22) 469 291 Total Liability 795 444 The intrinsic value of the vested awards at December 31, 2022 was $415 million (December 31, 2021 – $200 million). Stock Option Plans Suncor grants stock option awards as a form of retention and incentive compensation. Stock options granted by the company provide the holder with the right to purchase common shares at the market price on the grant date, subject to fulfilling vesting terms. Options granted have a seven three The weighted average fair value of options granted during the period and the weighted average assumptions used in their determination are as noted below: 2022 2021 Annual dividend per share (dollars) 1.88 1.05 Risk-free interest rate 1.73% 0.49% Expected life 5 years 5 years Expected volatility 42% 40% Weighted average fair value per option (dollars) 9.27 5.40 The expected life is based on historical stock option exercise data and current expectations. The expected volatility considers the historical volatility in the price of Suncor’s common shares over a period similar to the life of the options, and is indicative of future trends. The following table presents a summary of the activity related to Suncor’s stock option plans: 2022 2021 Weighted Weighted Average Average Number Exercise Price Number Exercise Price (thousands) ($) (thousands) ($) Outstanding, beginning of year 37 090 38.39 38 373 39.65 Granted 2 191 37.22 3 457 22.71 Exercised as options for common shares (13 158) 37.69 (245) 29.82 Forfeited/expired (5 055) 38.99 (4 495) 37.62 Outstanding, end of year 21 068 38.55 37 090 38.39 Exercisable, end of year 16 407 40.19 28 421 39.87 For the options outstanding at December 31, 2022, the exercise price ranges and weighted average remaining contractual lives are shown below: Outstanding Exercisable Weighted Average Weighted Weighted Remaining Average Average Number Contractual Life Exercise Number Exercise Exercise Prices ($) (thousands) (years) Price ($) (thousands) Price ($) 22.63 - 24.99 2 658 5 22.65 1 064 22.65 25.00 - 29.99 9 5 29.31 3 29.34 30.00 - 34.99 731 - 30.30 718 30.28 35.00 - 39.99 6 176 4 38.37 3 255 38.85 40.00 - 44.99 11 298 2 42.73 11 235 42.75 45.00 - 49.99 101 5 48.05 44 48.41 50.00 - 54.27 95 3 52.78 88 52.85 Total 21 068 3 38.55 16 407 40.19 Common shares authorized for issuance by the Board of Directors that remain available for the granting of future options: (thousands) 2022 2021 27 901 25 037 Share Unit Plans Suncor grants share units as a form of retention and incentive compensation. Share unit plans are accounted for as cash-settled awards. (a) Performance Share Units (PSUs) A PSU is a time-vested award entitling employees to receive varying degrees of cash (0%–200% of the company’s share price at time of vesting) contingent upon Suncor’s total shareholder return (stock price appreciation and dividend income) relative to a peer group of companies. Cash payments for awards granted in 2019 and onwards are contingent upon Suncor’s total shareholder return and annual return on capital employed performance. PSUs vest approximately three years after the grant date. (b) Restricted Share Units (RSUs) A RSU is a time-vested award entitling employees to receive cash calculated based on an average of the company’s share price leading up to vesting. RSUs vest approximately three years after the grant date. In 2022, Syncrude’s Long Term Incentive Plans (LTIP) of approximately $123 million were converted into Suncor RSUs at a conversion price of $30.93. (c) Deferred Share Units (DSUs) A DSU is redeemable for cash or a common share for a period of time after a unitholder ceases employment or Board membership. The DSU Plan is limited to executives and members of the Board of Directors. Members of the Board of Directors receive an annual grant of DSUs as part of their compensation and may elect to receive their fees in cash only or in increments of 50% or 100% allocated to DSUs. Executives may elect to receive their annual incentive bonus in cash only or in increments of 25%, 50%, 75% or 100% allocated to DSUs. The following table presents a summary of the activity related to Suncor’s share unit plans: (thousands) PSU RSU DSU Outstanding, December 31, 2020 2 285 15 095 1 385 Granted 1 285 11 954 164 Redeemed for cash (751) (4 609) (167) Forfeited/expired (53) (1 003) - Outstanding, December 31, 2021 2 766 21 437 1 382 Granted 947 13 235 187 Redeemed for cash (794) (4 533) (238) Forfeited/expired (710) (1 877) - Outstanding, December 31, 2022 2 209 28 262 1 331 Stock Appreciation Rights (SARs) A SAR entitles the holder to receive a cash payment equal to the difference between the stated exercise price and the market price of the company’s common shares on the date the SAR is exercised, and is accounted for as a cash-settled award. SARs have a seven three 2022 2021 Weighted Weighted Average Average Number Exercise Price Number Exercise Price (thousands) ($) (thousands) ($) Outstanding, beginning of year 463 39.06 509 39.25 Granted 10 36.76 10 22.63 Exercised (121) 37.18 — — Forfeited/expired (65) 38.25 (56) 37.78 Outstanding, end of year 287 39.95 463 39.06 Exercisable, end of year 242 40.82 357 39.68 |
Financial Instruments and Risk
Financial Instruments and Risk Management | 12 Months Ended |
Dec. 31, 2022 | |
Financial Instruments and Risk Management | |
Financial Instruments and Risk Management | 27. Financial Instruments and Risk Management The company’s financial instruments consist of cash and cash equivalents, accounts receivable, derivative contracts, substantially all accounts payable and accrued liabilities, debt, and certain portions of other assets and other long-term liabilities. Non-Derivative Financial Instruments The fair values of cash and cash equivalents, accounts receivable, short-term debt, and accounts payable and accrued liabilities approximate their carrying values due to the short-term maturities of those instruments. The company’s long-term debt and long-term financial liabilities are recorded at amortized cost using the effective interest method. At December 31, 2022, the carrying value of fixed-term debt accounted for under amortized cost was $9.8 billion (December 31, 2021 – $14.2 Suncor entered into a partnership with Fort McKay First Nation (FMFN) and Mikisew Cree First Nation (MCFN) in 2018 where FMFN and MCFN acquired a combined 49% partnership interest in the East Tank Farm Development. The partnership liability is recorded at amortized cost using the effective interest method. At December 31, 2022, the carrying value of the Partnership liability accounted for under amortized cost was $427 million (December 31, 2021 – $436 million). Derivative Financial Instruments (a) Non-Designated Derivative Financial Instruments The company uses derivative financial instruments, such as physical and financial contracts, to manage certain exposures to fluctuations in interest rates, commodity prices and foreign currency exchange rates, as part of its overall risk management program, as well as for trading purposes. The changes in the fair value of non-designated derivatives are as follows: ($ millions) 2022 2021 Fair value outstanding, beginning of year (98) (121) Cash settlements – paid during the year 220 178 Changes in fair value recognized in earnings during the year (note 7) (187) (155) Fair value outstanding, end of year (65) (98) (b) Fair Value Hierarchy To estimate the fair value of derivatives, the company uses quoted market prices when available, or third-party models and valuation methodologies that utilize observable market data. In addition to market information, the company incorporates transaction-specific details that market participants would utilize in a fair value measurement, including the impact of non-performance risk. However, these fair value estimates may not necessarily be indicative of the amounts that could be realized or settled in a current market transaction. The company characterizes inputs used in determining fair value using a hierarchy that prioritizes inputs depending on the degree to which they are observable. The three levels of the fair value hierarchy are as follows: ● Level 1 consists of instruments with a fair value determined by an unadjusted quoted price in an active market for identical assets or liabilities. An active market is characterized by readily and regularly available quoted prices where the prices are representative of actual and regularly occurring market transactions to assure liquidity. ● Level 2 consists of instruments with a fair value that is determined by quoted prices in an inactive market, prices with observable inputs, or prices with insignificant non-observable inputs. The fair value of these positions is determined using observable inputs from exchanges, pricing services, third-party independent broker quotes, and published transportation tolls. The observable inputs may be adjusted using certain methods, which include extrapolation over the quoted price term and quotes for comparable assets and liabilities. ● Level 3 consists of instruments with a fair value that is determined by prices with significant unobservable inputs. As at December 31, 2022, the company does not have any derivative instruments measured at fair value Level 3. In forming estimates, the company utilizes the most observable inputs available for valuation purposes. If a fair value measurement reflects inputs of different levels within the hierarchy, the measurement is categorized based upon the lowest level of input that is significant to the fair value measurement. The following table presents the company’s derivative financial instrument assets and liabilities measured at fair value for each hierarchy level as at December 31, 2022 and 2021. ($ millions) Level 1 Level 2 Level 3 Total Fair Value Accounts receivable 35 88 - 123 Accounts payable (134) (87) - (221) Balance at December 31, 2021 (99) 1 - (98) Accounts receivable 36 107 - 143 Accounts payable (85) (123) - (208) Balance at December 31, 2022 (49) (16) - (65) During the year ended December 31, 2022, there were no transfers Offsetting Financial Assets and Liabilities The company enters into arrangements that allow for offsetting of derivative financial instruments and accounts receivable (payable), which are presented on a net basis on the balance sheet, as shown in the table below as at December 31, 2022 and 2021. Financial Assets Gross Gross Liabilities Net Amounts ($ millions) Assets Offset Presented Fair value of derivative assets 6 527 (6 404) 123 Accounts receivable 5 048 (2 734) 2 314 Balance at December 31, 2021 11 575 (9 138) 2 437 Fair value of derivative assets 4 305 (4 162) 143 Accounts receivable 10 349 (8 633) 1 716 Balance at December 31, 2022 14 654 (12 795) 1 859 Financial Liabilities Gross Gross Assets Net Amounts ($ millions) Liabilities Offset Presented Fair value of derivative liabilities (6 625) 6 404 (221) Accounts payable (4 205) 2 734 (1 471) Balance at December 31, 2021 (10 830) 9 138 (1 692) Fair value of derivative liabilities (4 370) 4 162 (208) Accounts payable (10 036) 8 633 (1 403) Balance at December 31, 2022 (14 406) 12 795 (1 611) Risk Management The company is exposed to a number of different risks arising from financial instruments. These risk factors include market risks, comprising commodity price risk, foreign currency risk and interest rate risk, as well as liquidity risk and credit risk. The company maintains a formal governance process to manage its financial risks. The company’s Commodity Risk Management Committee (CRMC) is charged with the oversight of the company’s trading and credit risk management activities. These activities are intended to manage risk associated with open price exposure of specific volumes in transit or storage, enhance the company’s operations, and enhance profitability through informed market calls, market diversification, economies of scale, improved transportation access, and leverage of assets, both physical and contractual. The CRMC, acting under the authority of the company’s Board of Directors, meets regularly to monitor limits on risk exposures, review policy compliance and validate risk-related methodologies and procedures. 1) Market Risk Market risk is the risk or uncertainty arising from market price movements and their impact on the future performance of the business. The market price movements that could adversely affect the value of the company’s financial assets, liabilities and expected future cash flows include commodity price risk, foreign currency exchange risk and interest rate risk. (a) Commodity Price Risk Suncor’s financial performance is closely linked to crude oil and refined product prices (including pricing differentials for various product types) and, to a lesser extent, natural gas and electricity prices. The company may reduce its exposure to commodity price risk through a number of strategies. These strategies include entering into derivative contracts to limit exposure to changes in crude oil and refined product prices during transportation and natural gas prices. An increase of US$10/bbl of crude oil as at December 31, 2022 would increase pre-tax earnings for the company’s outstanding derivative financial instruments by approximately $70 million (2021 – $58 million increase). (b) Foreign Currency Exchange Risk The company is exposed to foreign currency exchange risk on revenues, capital expenditures, or financial instruments that are denominated in a currency other than the company’s functional currency (Canadian dollars). As crude oil is priced in U.S. dollars, fluctuations in US$/Cdn$ exchange rates may have a significant impact on revenues. This exposure is partially offset through the issuance of U.S. dollar denominated debt. A 1% strengthening in the Cdn$ relative to the US$ as at December 31, 2022 would increase pre-tax earnings related to the company’s U.S. dollar denominated long-term debt, commercial paper and working capital by approximately $100 million (2021 – $133 million). (c) Interest Rate Risk The company is exposed to interest rate risk as changes in interest rates may affect future cash flows and the fair values of its financial instruments. The primary exposure is related to its revolving-term debt of commercial paper and future debt issuances. To manage the company’s exposure to interest rate volatility, the company may periodically enter into interest rate swap contracts to fix the interest rate of future debt issuances. As at December 31, 2022, the company had no outstanding forward interest rate swaps. The simple average interest rate on total debt, including lease liabilities, for the year ended December 31, 2022 was 5.8% (2021 – 5.0%). The company’s net earnings are sensitive to changes in interest rates on the floating rate portion of the company’s debt, which are offset by cash balances. To the extent interest expense is not capitalized, if interest rates applicable to floating rate instruments increased by 1%, it is estimated that the company’s pre-tax earnings would decrease by approximately $8 million primarily due to a lower cash balance compared to the short-term debt balance (2021 – approximately $9 million increase). This assumes that the amount and mix of fixed and floating rate debt remains unchanged from December 31, 2022. The proportion of floating interest rate exposure at December 31, 2022 was 18.0% of total debt outstanding (2021 – 7.0%). 2) Liquidity Risk Liquidity risk is the risk that Suncor will not be able to meet its financial obligations when due. The company mitigates this risk by forecasting spending requirements as well as cash flow from operating activities, and maintaining sufficient cash, credit facilities, and debt shelf prospectuses to meet these requirements. Suncor’s cash and cash equivalents and total credit facilities at December 31, 2022 were $2.0 billion and $7.2 billion, respectively. Of Suncor’s $7.2 billion in total credit facilities, $3.3 billion were unutilized at December 31, 2022. In addition, Suncor has unused capacity under the Board of Directors authority of US$5.0 billion to issue debt. The ability of the company to raise additional capital utilizing these shelf prospectuses is dependent on market conditions. The company believes it has sufficient funding through the use of these facilities and access to capital markets to meet its future capital requirements. Surplus cash is invested into a range of short-dated money market securities. Investments are only permitted in high credit quality government or corporate securities. Diversification of these investments is managed through counterparty credit limits. The following table shows the timing of cash outflows related to trade and other payables and debt. December 31, 2021 Trade and Gross Derivative Lease ($ millions) Other Payables (1) Liabilities (2) Debt (3) Liabilities Within one year 6 282 6 466 2 253 459 2 to 3 years 37 159 2 015 779 4 to 5 years 37 - 3 127 660 Over 5 years - - 18 836 2 633 6 356 6 625 26 231 4 531 December 31, 2022 Trade and Gross Derivative Lease ($ millions) Other Payables (1) Liabilities (2) Debt (3) Liabilities Within one year 7 959 3 824 3 375 477 2 to 3 years 39 546 1 066 807 4 to 5 years 39 - 1 541 652 Over 5 years - - 16 317 3 047 8 037 4 370 22 299 4 983 (1) Trade and other payables exclude net derivative liabilities of $208 million (2021 – $221 million). (2) Gross derivative liabilities of $4.370 billion (2021 – $6.625 billion) are offset by gross derivative assets of $4.162 billion (2021 – $6.404 billion), resulting in a net amount of $208 million (2021 – $221 million). (3) Debt includes short-term debt, long-term debt and interest payments on fixed-term debt. 3) Credit Risk Credit risk is the risk that a customer or counterparty will fail to perform an obligation or fail to pay amounts due, causing a financial loss. The company’s credit policy is designed to ensure there is a standard credit practice throughout the company to measure and monitor credit risk. The policy outlines delegation of authority, the due diligence process required to approve a new customer or counterparty and the maximum amount of credit exposure per single entity. Before transactions begin with a new customer or counterparty, its creditworthiness is assessed, and a credit rating and a maximum credit limit are assigned. The assessment process is outlined in the credit policy and considers both quantitative and qualitative factors. The company constantly monitors the exposure to any single customer or counterparty along with the financial position of the customer or counterparty. If it is deemed that a customer or counterparty has become materially weaker, the company will work to reduce the credit exposure and lower the assigned credit limit. Regular reports are generated to monitor credit risk and the Credit Committee meets quarterly to ensure compliance with the credit policy and review the exposures. A substantial portion of the company’s accounts receivable are with customers in the oil and gas industry and are subject to normal industry credit risk. At December 31, 2022, substantially all of the company’s trade receivables were current. The company may be exposed to certain losses in the event that counterparties to derivative financial instruments are unable to meet the terms of the contracts. The company’s exposure is limited to those counterparties holding derivative contracts owing to the company at the reporting date. At December 31, 2022, the company’s net exposure was $143 million (December 31, 2021 – $123 million). |
Capital Structure Financial Pol
Capital Structure Financial Policies | 12 Months Ended |
Dec. 31, 2022 | |
Capital Structure Financial Policies | |
Capital Structure Financial Policies | 28. Capital Structure Financial Policies The company’s primary capital management strategy is to maintain a conservative balance sheet, which supports a solid investment grade credit rating profile. This objective affords the company the financial flexibility and access to the capital it requires to execute on its growth objectives. The company’s capital is primarily monitored by reviewing the ratios of net debt to adjusted funds from operations (2) Net debt to adjusted funds from operations (2) Total debt to total debt plus shareholders’ equity is calculated as short-term debt plus total long-term debt divided by short-term debt plus total long-term debt plus shareholders’ equity. This financial covenant under the company’s various banking and debt agreements shall not be greater than 65%. The company’s financial covenant is reviewed regularly and controls are in place to maintain compliance with the covenant. The company complied with financial covenants for the years ended December 31, 2022 and 2021. The company’s financial measures, as set out in the following schedule, were unchanged from 2021. The company believes that achieving its capital target helps to provide the company access to capital at a reasonable cost by maintaining solid investment grade credit ratings. Total debt to total debt plus shareholders’ equity was 28.4% at December 31, 2022 and decreased due to lower debt levels and higher shareholders’ equity as a result of increased net earnings. The company operates in a fluctuating business environment and ratios may periodically fall outside of management’s targets. The company addresses these fluctuations by capital expenditure reductions and sales of non-core assets to ensure net debt achieves management’s targets. Capital Measure December 31 December 31 ($ millions) Target 2022 2021 Components of ratios Short-term debt 2 807 1 284 Current portion of long-term debt - 231 Current portion of long-term lease liabilities 317 310 Long-term debt 9 800 13 989 Long-term lease liabilities 2 695 2 540 Total debt (1) 15 619 18 354 Less: Cash and cash equivalents 1 980 2 205 Net debt (1) 13 639 16 149 Shareholders’ equity 39 367 36 614 Total capitalization (total debt plus shareholders’ equity) 54 986 54 968 Adjusted funds from operations (2) 18 101 10 257 Net debt to adjusted funds from operations < 3.0 times 0.8 1.6 Total debt to total debt plus shareholders’ equity 20% - 35% 28.4% 33.4% (1) Total debt and net debt are non-GAAP financial measures. (2) Adjusted funds from operations is calculated as cash flow from operating activities before changes in non-cash working capital, and is a non-GAAP financial measure. |
Joint Arrangements
Joint Arrangements | 12 Months Ended |
Dec. 31, 2022 | |
Joint Arrangements | |
Joint Arrangements | 29. Joint Arrangements Joint Operations The company’s material joint operations as at December 31 are set out below: Country of Incorporation and Principal Place of Ownership % Ownership % Material Joint Operations Principal Activity Business 2022 2021 Oil Sands Operated by Suncor: Fort Hills Energy Limited Partnership (1) Oil sands development Canada 54.11 54.11 Meadow Creek Oil sands development Canada 75.00 75.00 Syncrude Oil sands development Canada 58.74 58.74 Exploration and Production Operated by Suncor: Terra Nova Oil and gas production Canada 48.00 48.00 Non-operated: Buzzard (2) Oil and gas production United Kingdom 29.89 29.89 Fenja Development JV (3) Oil and gas production Norway — 17.50 Hibernia and the Hibernia South Extension Unit Oil and gas production Canada 19.48 - 20.00 19.48 - 20.00 Hebron Oil and gas production Canada 21.03 21.03 Harouge Oil Operations Oil and gas production Libya 49.00 49.00 North Sea Rosebank Project (2) Oil and gas production United Kingdom 40.00 40.00 Oda (3) Oil and gas production Norway — 30.00 White Rose and the White Rose Extensions (4) Oil and gas production Canada 38.625 - 40.00 26.13 - 27.50 (1) Subsequent to December 31, 2022, Suncor acquired an additional 14.65% working interest in Fort Hills, bringing the company’s and its affiliate’s total aggregate working interest to 68.76% . (2) In the third quarter of 2022, Suncor reclassified the assets and liabilities related to its United Kingdom (U.K.) operations as assets held for sale, including its interests in Buzzard and Rosebank. Subsequent to the fourth quarter of 2022, the company reached an agreement for the sale of its U.K operations. The sale is expected to close in mid-2023. (3) In the third quarter of 2022, Suncor completed the sale of its Norway assets, including its 30% working interest in Oda and its 17.5% working interest in the Fenja Development Joint Operations. (4) In the second quarter of 2022, Suncor announced that concurrent with the decision to restart the West White Rose project by the joint venture owners, Suncor increased its ownership in the White Rose asset 12.50% to approximately 40.00% . Joint Ventures and Associates The company does not have any joint ventures or associates that are considered individually material. Summarized aggregate financial information of the joint ventures and associates, which are all included in the company’s Refining and Marketing operations, are shown below: Joint ventures Associates ($ millions) 2022 2021 2022 2021 Net earnings (loss) (25) 5 (1) (2) Total comprehensive earnings (loss) (25) 5 (1) (2) Carrying amount as at December 31 39 63 63 66 |
Subsidiaries
Subsidiaries | 12 Months Ended |
Dec. 31, 2022 | |
Subsidiaries | |
Subsidiaries | 30. Subsidiaries Material subsidiaries, either directly or indirectly, by the company as at December 31, 2022 are shown below: Material Subsidiaries Principal Activity Canadian Operations Suncor Energy Oil Sands Limited Partnership This partnership holds most of the company’s Oil Sands operations assets. Suncor Energy Ventures Corporation A subsidiary which indirectly owns a 36.74% ownership in the Syncrude joint operation. Suncor Energy Ventures Partnership A subsidiary which owns a 22% ownership in the Syncrude joint operation. Suncor Energy Products Partnership This partnership holds substantially all of the company’s Canadian refining and marketing assets. Suncor Energy Marketing Inc. Through this subsidiary, production from the upstream Canadian businesses is marketed. This subsidiary also administers Suncor’s energy trading activities and power business, markets certain third-party products, procures crude oil feedstock and natural gas for its downstream business, and procures and markets natural gas liquids (NGLs) and liquefied petroleum gas (LPG) for its downstream business. U.S. Operations Suncor Energy (U.S.A.) Marketing Inc. A subsidiary that procures, markets and trades crude oil, in addition to procuring crude oil feedstock for the company’s refining operations. Suncor Energy (U.S.A.) Inc. A subsidiary through which the company’s U.S. refining and marketing operations are conducted. International Operations Suncor Energy UK Limited A subsidiary through which the majority of the company’s North Sea operations are conducted. The table does not include wholly owned subsidiaries that are immediate holding companies of the operating subsidiaries. For certain foreign operations of the company, there are restrictions on the sale or transfer of production licences, which would require approval of the applicable foreign government. |
Related Party Disclosures
Related Party Disclosures | 12 Months Ended |
Dec. 31, 2022 | |
Related Party Disclosures | |
Related Party Disclosures | 31. Related Party Disclosures Related Party Transactions The company enters into transactions with related parties in the normal course of business, which includes purchases of feedstock, distribution of refined products, and the sale of refined products and byproducts. These transactions are with joint ventures and associated entities in the company’s Refining and Marketing operations, including pipeline, refined product and petrochemical companies. A summary of the significant related party transactions as at and for the years ended December 31, 2022 and 2021 are as follows: ($ millions) 2022 2021 Sales (1) 1 616 1 011 Purchases 265 247 Accounts receivable 135 70 Accounts payable and accrued liabilities 69 17 (1) Includes sales to Petroles Cadeko Inc. of $645 million (2021 - $411 million) and Parachem Chemicals Inc. of $487 million (2021 – $343 million). Compensation of Key Management Personnel Compensation of the company’s Board of Directors and members of the Executive Leadership Team for the years ended December 31 is as follows: ($ millions) 2022 2021 Salaries and other short-term benefits 20 8 Pension and other post-retirement benefits 4 3 Share based compensation 73 47 97 58 |
Commitments, Contingencies and
Commitments, Contingencies and Guarantees | 12 Months Ended |
Dec. 31, 2022 | |
Commitments, Contingencies and Guarantees | |
Commitments, Contingencies and Guarantees | 32. Commitments, Contingencies and Guarantees (a) Commitments Future payments under the company’s commitments, including service arrangements for pipeline transportation agreements and for other property and equipment, are as follows: Payment Due by Period ($ millions) 2023 2024 2025 2026 2027 Thereafter Total Commitments Product transportation and storage 1 146 1 252 1 201 1 024 1 165 7 410 13 198 Energy services 101 101 119 77 71 77 546 Exploration work commitments - - 53 1 - 486 540 Other 471 269 149 115 73 191 1 268 1 718 1 622 1 522 1 217 1 309 8 164 15 552 In addition to the commitments in the above table, the company has other obligations for goods and services and raw materials entered into in the normal course of business, which may terminate on short notice. Such obligations include commodity purchase obligations which are transacted at market prices. (b) Contingencies Legal and Environmental Contingent Liabilities and Assets The company is defendant and plaintiff in a number of legal actions that arise in the normal course of business. The company believes that any liabilities or assets that might arise pertaining to such matters would not have a material effect on its consolidated financial position. The company may also have environmental contingent liabilities, beyond decommissioning and restoration liabilities (recognized in note 24), which are reviewed individually and are reflected in the company’s consolidated financial statements if material and more likely than not to be incurred. These contingent environmental liabilities primarily relate to the mitigation of contamination at sites where the company has had operations. For any unrecognized environmental contingencies, the company believes that any liabilities that might arise pertaining to such matters would not have a material effect on its consolidated financial position. Costs attributable to these commitments and contingencies are expected to be incurred over an extended period of time and to be funded from the company’s cash flow from operating activities. Although the ultimate impact of these matters on net earnings cannot be determined at this time, the impact is not expected to be material. Contingent assets are only disclosed when the inflow of economic benefits is probable. When the economic benefit becomes virtually certain, the asset is no longer contingent and is recognized in the consolidated financial statements. (c) Guarantees At December 31, 2022, the company has provided loan guarantees to certain retail licensees and wholesale marketers. Suncor’s maximum potential amount payable under these loan guarantees is $125 million. The company has also agreed to indemnify holders of all notes and debentures and the company’s credit facility lenders (see note 21) for added costs relating to withholding taxes. Similar indemnity terms apply to certain facility and equipment leases. There is no limit to the maximum amount payable under these indemnification agreements. The company is unable to determine the maximum potential amount payable as government regulations and legislation are subject to change without notice. Under these agreements, the company has the option to redeem or terminate these contracts if additional costs are incurred. The company also has guaranteed its working-interest share of certain joint operation undertakings related to transportation services agreements entered into with third parties. The guaranteed amount is limited to the company’s share in the joint arrangement. As at December 31, 2022, the probability is remote that these guarantee commitments will impact the company. |
Assets Held for Sale
Assets Held for Sale | 12 Months Ended |
Dec. 31, 2022 | |
Assets Held for Sale | |
Assets Held for Sale | 33. Assets Held for Sale In the third quarter of 2022, the company reclassified the assets and liabilities related to its United Kingdom (U.K.) operations, including its interests in Buzzard and Rosebank located in the U.K. sector of the North Sea. The U.K. operations are reported within the Exploration and Production segment. Subsequent to the fourth quarter of 2022, on March 2, 2023, the company reached an agreement for the sale of its U.K. operations for gross proceeds of approximately $ 1.2 b illion, including a contingent consideration of approximately $338 million, before closing adjustments and other closing costs. The sale is pending regulatory approval, and is expected to close in mid-2023. The table below details the assets and liabilities held for sale as at December 31, 2022: ($ millions) Assets Currents assets 83 Property, plant and equipment, net 364 Exploration and evaluation 239 Total Assets 686 Liabilities Current liabilities (241) Provisions (217) Total Liabilities (458) Net Assets 228 Subsequent to the fourth quarter of 2022, the company completed the sale of its wind and solar assets (Forty Mile, Adelaide, Magrath and Chin Chute) for gross proceeds of approximately $730 million, before closing adjustments and other closing costs, resulting in an estimated after-tax gain on sale of approximately $260 million. The company completed the sale of its Forty Mile and Adelaide assets on January 3, 2023 and its Magrath and Chin Chute assets on January 10, 2023. The renewable energy business is reported within the Corporate segment. The table below details the assets and liabilities held for sale as at December 31, 2022: ($ millions) Assets Current assets 62 Property, plant and equipment, net and intangible assets 438 Total Assets 500 Liabilities Current liabilities (32) Other long-term liabilities and provisions (40) Total Liabilities (72) Net Assets 428 |
Summary of Significant Accoun_2
Summary of Significant Accounting Policies (Policies) | 12 Months Ended |
Dec. 31, 2022 | |
Summary of Significant Accounting Policies | |
Principles of Consolidation | (a) Principles of Consolidation The company consolidates its interests in entities it controls. Control comprises the power to govern an entity’s financial and operating policies to obtain benefits from its activities, and is a matter of judgment. All intercompany balances and transactions are eliminated on consolidation. |
Joint Arrangements | (b) Joint Arrangements Joint arrangements represent arrangements in which two or more parties have joint control established by a contractual agreement. Joint control only exists when decisions about the activities that most significantly affect the returns of the investee are unanimous. Joint arrangements can be classified as either a joint operation or a joint venture. The classification of joint arrangements requires judgment. In determining the classification of its joint arrangements, the company considers the contractual rights and obligations of each investor and whether the legal structure of the joint arrangement gives the entity direct rights to the assets and obligations for the liabilities. Where the company has rights to the assets and obligations for the liabilities of a joint arrangement, such arrangement is classified as a joint operation and the company’s proportionate share of the joint operation’s assets, liabilities, revenues and expenses are included in the consolidated financial statements, on a line-by-line basis. Where the company has rights to the net assets of an arrangement, such arrangement is classified as a joint venture and accounted for using the equity method of accounting. Under the equity method, the company’s initial investment is recognized at cost and subsequently adjusted for the company’s share of the joint venture’s income or loss, less distributions received. |
Investments in Associates | (c) Investments in Associates Associates are entities for which the company has significant influence, but not control or joint control over the financial and operational decisions. Investments in associates are accounted for using the equity method of accounting and are initially recognized at cost and adjusted thereafter for the change in the company’s share of the investee’s profit or loss and Other Comprehensive Income (OCI) less distributions received until the date that significant influence ceases. |
Foreign Currency Translation | (d) Foreign Currency Translation Functional currencies of the company’s individual entities are the currency of the primary economic environment in which the entity operates. Transactions in foreign currencies are translated to the appropriate functional currency at foreign exchange rates that approximate those on the date of the transaction. Monetary assets and liabilities denominated in foreign currencies are translated to the appropriate functional currency at foreign exchange rates as at the balance sheet date. Foreign exchange differences arising on translation are recognized in net earnings. Non-monetary assets that are measured in a foreign currency at historical cost are translated using the exchange rate at the date of the transaction. In preparing the company’s consolidated financial statements, the financial statements of each entity are translated into Canadian dollars. The assets and liabilities of foreign operations are translated into Canadian dollars at exchange rates as at the balance sheet date. Revenues and expenses of foreign operations are translated into Canadian dollars using foreign exchange rates that approximate those on the date of the underlying transaction. Foreign exchange differences are recognized in OCI. If the company or any of its entities disposes of its entire interest in a foreign operation, or loses control, joint control or significant influence over a foreign operation, the accumulated foreign currency translation gains or losses related to the foreign operation are recognized in net earnings. |
Revenues | (e) Revenues Revenue from the sale of crude oil, natural gas, natural gas liquids, purchased products, refined petroleum products and power represent the company’s contractual arrangements with customers. Revenue is recorded when control passes to the customer, in accordance with specified contract terms. All operating revenue is earned at a point in time and is based on the consideration that the company expects to receive for the transfer of the goods to the customer. Revenues are usually collected in the month following delivery except retail gasoline, diesel and ancillary products, which are due upon delivery and, accordingly, the company does not adjust consideration for the effects of a financing component. Revenue from oil and natural gas production is recorded net of royalty expense. International operations conducted pursuant to Production Sharing Contracts (PSCs) are reflected in the consolidated financial statements based on the company’s working interest. Each PSC establishes the exploration, development and operating costs the company is required to fund and establishes specific terms for the company to recover these costs and to share in the production profits. Cost recovery is generally limited to a specified percentage of production during each fiscal year (Cost Recovery Oil). Any Cost Recovery Oil remaining after costs have been recovered is referred to as Excess Petroleum and is shared between the company and the respective government. Assuming collection is reasonably assured, the company’s share of Cost Recovery Oil and Excess Petroleum are reported as revenue when the sale of product to a third party occurs. Revenue also includes income taxes paid on the company’s behalf by government joint partners. |
Cash and Cash Equivalents | (f) Cash and Cash Equivalents Cash and cash equivalents consist primarily of cash in banks, term deposits, certificates of deposit and all other highly liquid investments at the time of purchase. |
Inventories | (g) Inventories Inventories of crude oil and refined products, other than inventories held for trading purposes, are valued at the lower of cost, using the first-in, first-out method, and net realizable value. Cost of inventory consists of purchase costs, direct production costs, direct overhead and depreciation, depletion and amortization. Materials and supplies are valued at the lower of average cost and net realizable value. Inventories held for trading purposes are carried at fair value less costs to sell and any changes in fair value are recognized in Other Income within the respective reporting segment to which the trading activity relates. |
Assets Held for Sale | (h) Assets Held for Sale Assets and the associated liabilities are classified as held for sale if their carrying amounts are expected to be recovered through a disposition rather than through continued use. The assets or disposal groups are measured at the lower of their carrying amount or estimated fair value less costs of disposal. Impairment losses on initial classification as well as subsequent gains or losses on remeasurement are recognized in Depreciation, Depletion, Amortization and Impairment. When the assets or disposal groups are sold, the gains or losses on the sale are recognized in Gain on Disposal of Assets. Assets classified as held for sale are not depreciated, depleted or amortized. |
Exploration and Evaluation Assets | (i) Exploration and Evaluation Assets The costs to acquire non-producing oil and gas properties or licences to explore, drill exploratory wells and the costs to evaluate the commercial potential of underlying resources, including related borrowing costs, are initially capitalized as Exploration and Evaluation assets. Certain exploration costs, including geological, geophysical and seismic expenditures and delineation on oil sands properties, are charged to Exploration expense as incurred. Exploration and Evaluation assets are subject to technical, commercial and management review to confirm the continued intent to develop and extract the underlying resources. If an area or exploration well is no longer considered commercially viable, the related capitalized costs are charged to Exploration expense. When management determines with reasonable certainty that an Exploration and Evaluation asset will be developed, as evidenced by the classification of proved or probable reserves and the appropriate internal and external approvals, the asset is transferred to Property, Plant and Equipment. |
Property, Plant and Equipment | (j) Property, Plant and Equipment Property, Plant and Equipment are initially recorded at cost. The costs to acquire developed or producing oil and gas properties, and to develop oil and gas properties, including completing geological and geophysical surveys and drilling development wells, and the costs to construct and install development infrastructure, such as wellhead equipment, well platforms, well pairs, offshore platforms, subsea structures and an estimate of asset retirement costs, are capitalized as oil and gas properties within Property, Plant and Equipment. The costs to construct, install and commission, or acquire, oil and gas production equipment, including oil sands upgraders, extraction plants, mine equipment, processing and power generation facilities, utility plants, and all renewable energy, refining, and marketing assets, are capitalized as plant and equipment within Property, Plant and Equipment. Stripping activity required to access oil sands mining resources incurred in the initial development phase is capitalized as part of the construction cost of the mine. Stripping costs incurred in the production phase are charged to expense as they normally relate to production for the current period. The costs of planned major inspection, overhaul and turnaround activities that maintain Property, Plant and Equipment and benefit future years of operations are capitalized. Recurring planned maintenance activities performed on shorter intervals are expensed as operating costs. Replacements outside of a major inspection, overhaul or turnaround are capitalized when it is probable that future economic benefits will be realized by the company and the associated carrying amount of the replaced component is derecognized. Borrowing costs relating to assets that take over one year to construct are capitalized as part of the asset. Capitalization of borrowing costs ceases when the asset is in the location and condition necessary for its intended use, and is suspended when construction of an asset is ceased for extended periods. |
Depreciation, Depletion and Amortization | (k) Depreciation, Depletion and Amortization Exploration and Evaluation assets are not subject to depreciation, depletion and amortization. Once transferred to oil and gas properties within Property, Plant and Equipment and commercial production commences, these costs are depleted on a unit-of-production basis over proved developed reserves, with the exception of costs associated with oil sands mines, which are depreciated on a straight-line basis over the life of the mine, and property acquisition costs, which are depleted over proved reserves. Capital expenditures are not depreciated or depleted until assets are substantially complete and ready for their intended use. Costs to develop oil and gas properties other than certain oil sands mining assets, including costs of dedicated infrastructure, such as well pads and wellhead equipment, are depleted on a unit-of-production basis over proved developed reserves. A portion of these costs may not be depleted if they relate to undeveloped reserves. Costs related to offshore facilities are depleted over proved and probable reserves. Costs to develop and construct oil sands mines are depreciated on a straight-line basis over the life of the mine. Major components of Property, Plant and Equipment are depreciated on a straight-line basis over their expected useful lives. Oil sands upgraders, extraction plants and mine facilities 20 to 40 years Oil sands mine equipment 5 to 15 years Oil sands in situ processing facilities 30 years Power generation and utility plants 30 to 40 years Refineries and other processing plants 20 to 40 years Marketing and other distribution assets 10 to 40 years The costs of major inspection, overhaul and turnaround activities that are capitalized are depreciated on a straight-line basis over the period to the next scheduled activity, which varies from two Depreciation, depletion and amortization rates are reviewed annually or when events or conditions occur that impact capitalized costs, reserves or estimated service lives. Right-of-use assets within Property, Plant and Equipment are depreciated on a straight-line basis over the shorter of the estimated useful life of the right-of-use asset or the lease term. |
Goodwill and Other Intangible Assets | (l) Goodwill and Other Intangible Assets The company accounts for business combinations using the acquisition method. The excess of the purchase price over the fair value of the identifiable net assets represents goodwill, and is allocated to the groups of cash generating units (CGUs) to which it relates from the business combination. Other intangible assets include acquired customer lists, brand value and certain software costs. Goodwill and brand value have indefinite useful lives and are not subject to amortization. Customer lists are amortized over their expected useful lives, which range from five five |
Impairment of Assets | (m) Impairment of Assets Non-Financial Assets Property, Plant and Equipment and Exploration and Evaluation assets are reviewed quarterly to assess whether there is any indication of impairment. Goodwill and intangible assets that have an indefinite useful life are tested for impairment annually. Exploration and Evaluation assets are also tested for impairment immediately prior to being transferred to Property, Plant and Equipment. If any indication of impairment exists, an estimate of the asset’s recoverable amount is calculated as the higher of the fair value less costs of disposal and value-in-use. In determining fair value less costs of disposal, recent market transactions are considered, if available. In the absence of such transactions, an appropriate valuation model is used. Value-in-use is assessed using the present value of the expected future cash flows of the relevant asset. If the asset does not generate cash inflows that are largely independent of those from other assets or groups of assets, the asset is tested as part of a CGU, which is the smallest identifiable group of assets that generates cash inflows that are largely independent of the cash inflows from other assets or groups of assets. An impairment loss is the amount by which the carrying amount of the individual asset or CGU exceeds its recoverable amount. Impairments may be reversed for all CGUs and individual assets, other than goodwill, if there has been a change in the estimates and judgments used to determine the asset’s recoverable amount since the last impairment loss was recognized. If such indication exists, the carrying amount of the CGU or asset is increased to its revised recoverable amount, which cannot exceed the carrying amount that would have been determined, net of depletion, depreciation and amortization, had no impairment been recognized. Impairments and impairment reversals are recognized within Depreciation, Depletion, Amortization and Impairment. Financial Assets At each reporting date, the company assesses the expected credit losses associated with its financial assets measured at amortized cost. Expected credit losses are measured as the difference between the cash flows that are due to the company and the cash flows that the company expects to receive, discounted at the effective interest rate determined at initial recognition. For trade accounts receivables, the company applies the simplified approach permitted by IFRS 9 Financial Instruments |
Provisions | (n) Provisions Provisions are recognized by the company when it has a legal or constructive obligation as a result of past events, it is probable that an outflow of economic resources will be required to settle the obligation and a reliable estimate can be made of the amount of the obligation. Provisions are recognized for decommissioning and restoration obligations associated with the company’s Exploration and Evaluation assets and Property, Plant and Equipment. Provisions for decommissioning and restoration obligations are measured at the present value of management’s best estimate of the future cash flows required to settle the present obligation, using the credit-adjusted risk-free interest rate. The value of the obligation is added to the carrying amount of the associated asset and amortized over the useful life of the asset. The provision is accreted over time through Financing Expense with actual expenditures charged against the accumulated obligation. Changes in the future cash flow estimates resulting from revisions to the estimated timing or amount of undiscounted cash flows are recognized as a change in the decommissioning and restoration provision and related asset. |
Income Taxes | (o) Income Taxes The company follows the liability method of accounting for income taxes whereby deferred income taxes are recorded for the effect of differences between the accounting and income tax basis of an asset or liability. Deferred income tax assets and liabilities are measured using enacted or substantively enacted income tax rates as at the balance sheet date that are anticipated to apply to taxable income in the years in which temporary differences are expected to be recovered or settled. Changes to these balances are recognized in net earnings or in Other Comprehensive Income in the period they occur. Investment tax credits are recorded as a reduction to the related expenditures. The company recognizes the impact of a tax filing position when it is probable, based on the technical merits, that the position will be sustained upon audit. If it is determined a tax filing position is not considered probable, the company assesses the possible outcomes and their associated probabilities and records a tax provision based on the best estimate of the amount of tax payable. |
Pensions and Other Post-Retirement Benefits | (p) Pensions and Other Post-Retirement Benefits The company sponsors defined benefit pension plans, defined contribution pension plans and other post-retirement benefits. The cost of pension benefits earned by employees in the defined contribution pension plan is expensed as incurred. The cost of defined benefit pension plans and other post-retirement benefits are actuarially determined using the projected unit credit method based on present pay levels and management’s best estimates of demographic and financial assumptions. The liability recognized on the balance sheet is the present value of the defined benefit obligations less the fair value of plan assets. The value of plan assets is limited to the total of unrecognized past service cost and the present value of the economic benefits available in the form of refunds from the plan or reductions in future contributions to the plan (“effect of the asset ceiling”). Any surplus is immediately recognized in Other Comprehensive income. In addition, a minimum liability is recognized when the statutory minimum funding requirement for past service exceeds the economic benefits available in the form of refunds from the plan or reductions in future contributions to the plan. Pension benefits earned during the current year are recorded in Operating, Selling and General expense. Interest costs on the net unfunded obligation are recorded in Financing Expense. Any actuarial gains or losses related to the plan assets and the defined benefit obligation, as well as the change in the asset ceiling and any minimum liability, are recognized immediately through Other Comprehensive Income and transferred directly to Retained Earnings. |
Share-Based Compensation Plans | (q) Share-Based Compensation Plans Under the company’s share-based compensation plans, share-based awards may be granted to executives, employees and non-employee directors. Compensation expense is recorded in Operating, Selling and General expense. Share-based compensation awards that settle in cash or have the option to settle in cash or shares are accounted for as cash-settled plans. These are measured at fair value each reporting period using the Black-Scholes options pricing model. The expense is recognized over the vesting period, with a corresponding adjustment to the outstanding liability. When awards are surrendered for cash, the cash settlement paid reduces the outstanding liability. When awards are exercised for common shares, consideration paid by the holder and the previously recognized liability associated with the options are recorded to Share Capital. Stock options that give the holder the right to purchase common shares are accounted for as equity-settled plans. The expense is based on the fair value of the options at the time of grant using the Black-Scholes options pricing model and is recognized over the vesting periods of the respective options. A corresponding increase is recorded to Contributed Surplus. Consideration paid to the company on exercise of options is credited to Share Capital and the associated amount in Contributed Surplus is reclassified to Share Capital. |
Financial Instruments | (r) Financial Instruments The company classifies its financial instruments into one of the following categories: fair value through profit or loss (FVTPL), fair value through other comprehensive income, or at amortized cost. This determination is made at initial recognition. All financial instruments are initially recognized at fair value on the balance sheet, net of any transaction costs except for financial instruments classified as FVTPL, where transaction costs are expensed as incurred. Subsequent measurement of financial instruments is based on their classification. The company classifies its derivative financial instruments and certain investments as FVTPL, cash and cash equivalents and accounts receivable as financial assets at amortized cost, and accounts payable and accrued liabilities, debt, and other long-term liabilities as financial liabilities at amortized cost. In circumstances where the company consolidates a subsidiary in which there are other owners with a non-controlling interest and the subsidiary has a non-discretionary obligation to distribute cash based on a predetermined formula to the non-controlling owners, the non-controlling interest is classified as a financial liability rather than equity in accordance with IAS 32 Financial Instruments: Presentation The company uses derivative financial instruments, such as physical and financial contracts, either to manage certain exposures to fluctuations in interest rates, commodity prices and foreign exchange rates, as part of its overall risk management program. Earnings impacts from derivatives used to manage a particular risk are reported as part of Other Income in the related reporting segment. Certain physical commodity contracts, when used for trading purposes, are deemed to be derivative financial instruments for accounting purposes. Physical commodity contracts entered into for the purpose of receipt or delivery in accordance with the company’s expected purchase, sale or usage requirements are not considered to be derivative financial instruments and are accounted for as executory contracts. Derivatives embedded in other financial instruments or other host contracts are recorded as separate derivatives when their risks and characteristics are not closely related to those of the host contract. |
Hedging Activities | (s) Hedging Activities The company may apply hedge accounting to arrangements that qualify for designated hedge accounting treatment. Documentation is prepared at the inception of a hedge relationship in order to qualify for hedge accounting. Designated hedges are assessed at each reporting date to determine if the relationship between the derivative and the underlying hedged item accomplishes the company’s risk management objectives for financial and non-financial risk exposures. If the derivative is designated as a fair value hedge, changes in the fair value of the derivative and in the fair value of the underlying hedged item are recognized in net earnings. If the derivative is designated as a cash flow hedge, the effective portions of the changes in fair value of the derivative are initially recorded in Other Comprehensive Income and are recognized in net earnings when the hedged item is realized. Ineffective portions of changes in the fair value of cash flow hedges are recognized in net earnings immediately. Changes in the fair value of a derivative designated in a fair value or cash flow hedge are recognized in the same line item as the underlying hedged item. The company did not apply hedge accounting to any of its derivative instruments for the years ended December 31, 2022 or 2021. |
Share Capital | (t) Share Capital Common shares are classified as equity. Incremental costs directly attributable to the issuance of common shares are recognized as a deduction from equity, net of any tax effects. When the company repurchases its own common shares, share capital is reduced by the average carrying value of the shares repurchased. The excess of the purchase price over the average carrying value is recognized as a deduction from Retained Earnings. Shares are cancelled upon repurchase. |
Dividend Distributions | (u) Dividend Distributions Dividends on common shares are recognized in the period in which the dividends are declared by the company’s Board of Directors. |
Earnings per Share | (v) Earnings per Share Basic earnings per share is calculated by dividing the net earnings for the period by the weighted average number of common shares outstanding during the period. Diluted earnings per share is calculated by adjusting the weighted average number of common shares outstanding for dilutive common shares related to the company’s share-based compensation plans. The number of shares included is computed using the treasury stock method. As these awards can be exchanged for common shares of the company, they are considered potentially dilutive and are included in the calculation of the company’s diluted net earnings per share if they have a dilutive impact in the period. |
Emissions Obligations and Rights | (w) Emissions Obligations and Rights Emissions obligations are measured at the weighted average cost per unit of emissions expected to be incurred to settle the obligation and are recorded in the period in which the emissions occur within Operating, Selling and General expense, or Purchases. Purchases of emissions rights are recognized as Other Assets on the balance sheet and are measured at historical cost. Emissions rights received by way of grant are recorded at a nominal amount. |
Leases | (x) Leases At inception of a contract, the company assesses whether a contract is, or contains, a lease based on whether the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. The company recognizes a right-of-use asset and a lease liability at the lease commencement date. The right-of-use asset is initially measured based on the initial amount of the lease liability adjusted for any lease payments made at or before the commencement date, plus any initial direct costs incurred and an estimate of costs to dismantle and remove the underlying asset or to restore the underlying asset on the site on which it is located, less any lease incentives received. The assets are depreciated to the earlier of the end of the useful life of the right-of-use asset or the lease term. Judgment is applied to determine the lease term where a renewal option exists. Right-of-use assets are depreciated using the straight-line method as this most closely reflects the expected pattern of consumption of the future economic benefits. In addition, the right-of-use assets may be reduced by impairment losses or adjusted for certain remeasurements of the lease liability. The company has elected not to recognize right-of-use assets and lease liabilities for short-term leases that have a lease term of twelve months or less. The lease payments are recognized as an expense when incurred over the lease term. As well, the company has accounted for each lease component and any non-lease components as a single lease component for crude oil storage tanks. The lease liability is initially measured at the present value of the lease payments that are not paid at the commencement date, discounted using the interest rate implicit in the lease or, if that rate cannot be readily determined, the company’s incremental borrowing rate. Lease payments include fixed payments, and variable payments that are based on an index or rate. Cash payments for the principal portion of the lease liability are presented within the financing activities section and the interest portion of the lease liability is presented within the operating activities section of the statement of cash flows. Short-term lease payments and variable lease payments not included in the measurement of the lease liability are presented within the operating activities section of the statement of cash flows. The lease liability is measured at amortized cost using the effective interest method. It is remeasured when there is a change in future lease payments arising from a change in an index or rate, if there is a change in the company’s estimate of the amount expected to be payable under a residual value guarantee, or if the company changes its assessment of whether it will exercise a purchase, extension or termination option. When the lease liability is remeasured in this way, a corresponding adjustment is made to the carrying amount of the right-of-use asset, or is recorded in profit or loss if the carrying amount of the right-of-use asset has been reduced to zero. The company has lease contracts which include storage tanks, pipelines, railway cars, vessels, buildings, land, and mobile equipment for the purpose of production, storage and transportation of crude oil and related products. |
Government Grants | (y) Government Grants Government grants are recognized when the company has reasonable assurance that it has complied with the relevant conditions of the grant and that it will be received. The company recognizes the grants that compensate the company for expenses incurred against the financial statement line item that it is intended to compensate, or to other income if the grant is recognized in a different period than the underlying transaction. |
Summary of Significant Accoun_3
Summary of Significant Accounting Policies (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Summary of Significant Accounting Policies | |
Schedule of useful life for property, plant and equipment | Oil sands upgraders, extraction plants and mine facilities 20 to 40 years Oil sands mine equipment 5 to 15 years Oil sands in situ processing facilities 30 years Power generation and utility plants 30 to 40 years Refineries and other processing plants 20 to 40 years Marketing and other distribution assets 10 to 40 years |
Segmented Information (Tables)
Segmented Information (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Segmented Information | |
Schedule of segmented information | Exploration Refining and Corporate and For the years ended December 31 Oil Sands and Production Marketing Eliminations Total ($ millions) 2022 2021 2022 2021 2022 2021 2022 2021 2022 2021 Revenues and Other Income Gross revenues (1) 21 905 15 319 4 331 2 978 36 622 22 808 49 28 62 907 41 133 Intersegment revenues (1) 8 526 4 601 - - 106 107 (8 632) (4 708) - - Less: Royalties (3 963) (1 523) (608) (478) - - - - (4 571) (2 001) Operating revenues, net of royalties 26 468 18 397 3 723 2 500 36 728 22 915 (8 583) (4 680) 58 336 39 132 Other (loss) income (53) 6 164 17 (60) (50) 80 (4) 131 (31) 26 415 18 403 3 887 2 517 36 668 22 865 (8 503) (4 684) 58 467 39 101 Expenses Purchases of crude oil and products (1) 2 050 1 444 - - 27 261 16 807 (8 536) (4 460) 20 775 13 791 Operating, selling and general 9 152 8 056 490 429 2 427 2 019 738 862 12 807 11 366 Transportation and distribution 1 210 1 126 101 112 396 282 (36) (41) 1 671 1 479 Depreciation, depletion, amortization and impairment 7 927 4 585 (105) 324 844 853 120 88 8 786 5 850 Exploration 37 12 19 35 - - - - 56 47 (Gain) loss on disposal of assets (7) (4) 66 (227) (11) (19) (3) (7) 45 (257) Financing expenses 413 359 95 53 57 56 1 446 787 2 011 1 255 20 782 15 578 666 726 30 974 19 998 (6 271) (2 771) 46 151 33 531 Earnings (Loss) before Income Taxes 5 633 2 825 3 221 1 791 5 694 2 867 (2 232) (1 913) 12 316 5 570 Income Tax Expense (Recovery) Current - - - - - - - - 4 229 1 395 Deferred - - - - - - - - (990) 56 - - - - - - - - 3 239 1 451 Net Earnings - - - - - - - - 9 077 4 119 Capital and Exploration Expenditures (2) 3 540 3 168 443 270 816 825 188 292 4 987 4 555 (1) The company revised certain gross revenues and purchases of crude oil and products to align with current period presentation. For the twelve months ended December 31, 2022, gross revenues and purchases of crude oil and products decreased by $150 million, with no effect on net earnings. (2) Excludes capital expenditures related to assets held for sale of $133 million for the year ended December 31, 2022. |
Schedule of disaggregation of revenue from contracts with customers and intersegment revenue | The company’s revenues are from the following major commodities and geographical regions: For the years ended December 31 2022 2021 ($ millions) North America International Total North America International Total Oil Sands Synthetic crude oil and diesel (1) 22 539 - 22 539 14 452 - 14 452 Bitumen 7 892 - 7 892 5 468 - 5 468 30 431 - 30 431 19 920 - 19 920 Exploration and Production Crude oil and natural gas liquids 2 464 1 834 4 298 1 709 1 257 2 966 Natural gas - 33 33 - 12 12 2 464 1 867 4 331 1 709 1 269 2 978 Refining and Marketing Gasoline 14 540 - 14 540 9 983 - 9 983 Distillate 18 663 - 18 663 9 832 - 9 832 Other 3 525 - 3 525 3 100 - 3 100 36 728 - 36 728 22 915 - 22 915 Corporate and Eliminations (1) (8 583) - (8 583) (4 680) - (4 680) Total Gross Revenue from Contracts with Customers 61 040 1 867 62 907 39 864 1 269 41 133 (1) The company revised certain gross revenues and purchases of crude oil and products to align with current period presentation. For the twelve months ended December 31, 2022, gross revenues and purchases of crude oil and products decreased by $150 million, with no effect on net earnings. |
Schedule of operating revenues and non-current assets by geographic area | Operating Revenues, net of Royalties ($ millions) 2022 2021 Canada 49 169 32 286 United States 7 544 5 818 Other foreign 1 623 1 028 58 336 39 132 Non-Current Assets (1) December 31 December 31 ($ millions) 2022 2021 Canada 66 346 68 900 United States 2 629 2 020 Other foreign 1 026 1 682 70 001 72 602 (1) Excludes deferred income tax assets. |
Other Income (Tables)
Other Income (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Other Income | |
Schedule of other income | ($ millions) 2022 2021 Energy trading and risk management (209) (165) Investment and interest income 100 64 Insurance proceeds (1) 179 69 Other (2) 61 1 131 (31) (1) 2022 includes $147 million of property damage insurance proceeds related to the company’s assets in Libya, within the Exploration and Production segment, and $32 million of insurance proceeds for the secondary extraction facilities at Oil Sands Base, within the Oil Sands segment. 2021 includes $31 million of insurance proceeds for the outages at Mackay River and $38 million for the secondary extraction facilities at Oil Sands Base, both within the Oil Sands segment. (2) 2022 includes a US $50 million contingent consideration gain related to the sale of the company’s 26.69% working interest in the Golden Eagle Area Development in the fourth quarter of 2021, within the Exploration and Production segment. |
Operating, Selling and Genera_2
Operating, Selling and General Expense (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Operating, Selling and General Expense | |
Schedule of operating, selling and general expenses | ($ millions) 2022 2021 Employee and contract service costs (1) 8 037 7 409 Materials and equipment (1) 1 901 1 931 Commodities (1) 2 196 1 523 Travel, marketing and other (1) 673 503 12 807 11 366 (1) Prior period amounts have been reclassified to align with the current year presentation of Operating, Selling and General expense. For the year ended December 31, 2021, $564 million was reclassified from employee and contract service costs to materials and equipment and $23 million was reclassified from materials and equipment and travel, marketing and other to commodities . This reclassification had no effect on the operating, selling and general expense presentation on the consolidated statements of comprehensive income. |
Financing Expenses (Tables)
Financing Expenses (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Financing Expenses | |
Schedule of financing expenses | ($ millions) 2022 2021 Interest on debt 815 834 Interest on lease liabilities 167 161 Capitalized interest at 5.2% ( 2021 – 5.0% ) (168) (144) Interest expense 814 851 Interest on partnership liability 51 51 Interest on pension and other post-retirement benefits 41 59 Accretion 316 304 Foreign exchange loss (gain) on U.S. dollar denominated debt 729 (113) Operational foreign exchange and other 28 23 Loss on extinguishment of long-term debt 32 80 2 011 1 255 |
Income Taxes (Tables)
Income Taxes (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Income Taxes | |
Schedule of income tax expense (recovery) | ($ millions) 2022 2021 Current: Current year 4 333 1 353 Adjustments in respect of current income tax of prior years (104) 42 Deferred: Origination and reversal of temporary differences (1 063) 29 Adjustments in respect of deferred income tax of prior years 54 23 Changes in tax rates and legislation (27) 8 Movement in unrecognized deferred income tax assets 46 (4) Total income tax expense 3 239 1 451 |
Reconciliation of Effective Tax Rate | ($ millions) 2022 2021 Earnings before income tax 12 316 5 570 Canadian statutory tax rate 24.16% 24.24% Statutory tax 2 976 1 350 Add (deduct) the tax effect of: Non-taxable component of capital losses (gains) 67 (12) Share-based compensation and other permanent items - 3 Assessments and adjustments (49) 65 Impact of income tax rates and legislative changes (1) (84) 8 Non-taxable component of dispositions (25) (66) Foreign tax rate differential (2) 290 111 Movement in unrecognized deferred income tax assets 46 (4) Other 18 (4) Total income tax expense 3 239 1 451 Effective tax rate 26.3% 26.1% (1) The twelve months ended December 31, 2022 includes a current income tax recovery of $39 million related to the sale of the company’s wind and solar assets (note 33). (2) The twelve months ended December 31, 2022 includes a deferred income tax recovery of $171 million related to the sale of the company’s UK assets (note 33) |
Schedule of deferred income tax balances | Deferred Income Tax Expense (Recovery) Deferred Income Tax Liability (Asset) December 31 December 31 ($ millions) 2022 2021 2022 2021 Property, plant and equipment (729) (260) 11 093 11 477 Decommissioning and restoration provision (10) 141 (2 292) (1 936) Employee retirement benefit plans (92) (142) (297) (470) Tax loss carry-forwards (14) 161 (29) (15) Other (145) 156 (111) 25 Net deferred income tax (recovery) / expense and liability (990) 56 8 364 9 081 |
Summary of changes in deferred income tax balances | ($ millions) 2022 2021 Net deferred income tax liability, beginning of year 9 081 8 758 Recognized in deferred income tax (recovery) / expense (990) 56 Recognized in other comprehensive income 264 277 Foreign exchange, acquisition and other 9 (10) Net deferred income tax liability, end of year 8 364 9 081 |
Schedule of deferred tax in shareholders' equity | ($ millions) 2022 2021 Deferred Tax in Other Comprehensive Income Actuarial gain on employment retirement benefit plans 264 277 Total income tax expense reported in equity 264 277 |
Earnings per Common Share (Tabl
Earnings per Common Share (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Earnings per Common Share | |
Schedule of earnings per common share | ($ millions) 2022 2021 Net earnings 9 077 4 119 (millions of common shares) Weighted average number of common shares 1 387 1 488 Dilutive securities: Effect of share options 3 1 Weighted average number of diluted common shares 1 390 1 489 (dollars per common share) Basic earnings per share 6.54 2.77 Diluted earnings per share 6.53 2.77 |
Cash and Cash Equivalents (Tabl
Cash and Cash Equivalents (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Cash and Cash Equivalents | |
Schedule of cash and cash equivalents | December 31 December 31 ($ millions) 2022 2021 Cash 1 782 1 971 Cash equivalents 198 234 1 980 2 205 |
Supplemental Cash Flow Inform_2
Supplemental Cash Flow Information (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Supplemental Cash Flow Information | |
Schedule of supplemental cash flow information | The (increase) decrease in non-cash working capital is comprised of: ($ millions) 2022 2021 Accounts receivable (1 750) (1 324) Inventories (1 128) (551) Accounts payable and accrued liabilities 1 512 1 588 Current portion of provisions (286) 235 Income taxes payable (net) (1) (717) 1 830 (2 369) 1 778 Relating to: Operating activities (2 421) 1 507 Investing activities 52 271 (2 369) 1 778 (1) During the twelve months ended December 31, 2022, the decrease in taxes payable was primarily related to the company’s tax installment payments, net of the current income tax expense. During the twelve months ended December 31, 2021, the increase in taxes payable was primarily related to the company’s 2021 current income tax expense, which was paid in the first quarter of 2022. Reconciliation of movements of liabilities to cash flows arising from financing activities: Current Portion Current Portion Short-Term of Long-Term Long-Term of Long-Term Long-Term Partnership Dividends ($ millions) Debt Lease Liabilities Lease Liabilities Debt Debt Liability Payable At December 31, 2020 3 566 272 2 636 1 413 13 812 436 - Changes from financing cash flows: Reduction of commercial paper (2 256) - - - - - - Gross proceeds from issuance of long-term debt - - - - 1 446 - - Debt issuance costs - - - - (23) - - Repayment of long-term debt - - - (2 451) - - - Loss on extinguishment of long-term debt - - - 80 - - - Realized foreign exchange (gains) and losses (79) - - 128 - - - Dividends paid on common shares - - - - - - 1 550 Lease liability payments - (325) - - - - - Distributions to non-controlling interest - - - - - (9) - Other - - - 25 - - - Non-cash changes: Dividends declared on common shares - - - - - - (1 550) Unrealized foreign exchange losses and (gains) 53 - - (47) (168) - - Reclassification of debt - - - 1 083 (1 083) - - Lease derecognition - - (41) - - - - Reclassification of lease obligations - 363 (363) - - - - Deferred financing costs - - - - 5 - - New lease liabilities - - 308 - - - - At December 31, 2021 1 284 310 2 540 231 13 989 427 - Changes from financing cash flows: Net issuance of commercial paper 1 473 - - - - - - Repayment of long-term debt - - - (233) (4 895) - - Loss on extinguishment of long-term debt - - - 32 - - Realized foreign exchange (gains) and losses (19) 15 - 2 (91) - - Dividends paid on common shares - - - - - - (2 596) Lease liability payments - (329) - - - - - Distributions to non-controlling interest - - - - - (14) - Other - - - - (13) - - Non-cash changes: Dividends declared on common shares - - - - - - 2 596 Unrealized foreign exchange losses and (gains) 69 - (25) - 778 - - Lease derecognition - - (22) - - - - Reclassification of lease obligations - 321 (321) - - - - Deferred financing costs - - - - - - - New lease liabilities - - 523 - - - - At December 31, 2022 2 807 317 2 695 - 9 800 413 - |
Inventories (Tables)
Inventories (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Inventories | |
Schedule of inventories | December 31 December 31 ($ millions) 2022 2021 Crude oil (1) 2 373 1 501 Refined products 2 014 1 820 Materials, supplies and merchandise 685 789 Reclassified to assets held for sale (note 33) (14) - 5 058 4 110 (1) Includes $131 million of inventories held for trading purposes (2021 – $110 million), which are measured at fair value less costs to sell based on Level 1 and Level 2 fair value inputs. |
Property, Plant and Equipment (
Property, Plant and Equipment (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Property, Plant and Equipment | |
Disclosure of changes in property, plant and equipment | Oil and Gas Plant and ($ millions) Properties Equipment Total Cost At December 31, 2020 (1) 43 622 84 036 127 658 Additions 755 3 901 4 656 Transfers from exploration and evaluation - - - Changes in decommissioning and restoration (1 127) (5) (1 132) Disposals and derecognition (1 902) (2 652) (4 554) Foreign exchange adjustments (118) 49 (69) At December 31, 2021 (1) 41 230 85 329 126 559 Additions 1 149 4 261 5 410 Transfers from exploration and evaluation 34 - 34 Changes in decommissioning and restoration 1 321 (10) 1 311 Disposals and derecognition (585) (884) (1 469) Foreign exchange adjustments 101 218 319 Reclassified to assets held for sale (note 33) (4 475) (480) (4 955) At December 31, 2022 38 775 88 434 127 209 Accumulated provision At December 31, 2020 (1) (25 757) (33 771) (59 528) Depreciation, depletion, amortization and impairment (1 216) (4 465) (5 681) Disposals and derecognition 1 676 2 452 4 128 Foreign exchange adjustments 70 (2) 68 At December 31, 2021 (1) (25 227) (35 786) (61 013) Depreciation, depletion, amortization and impairment (1 049) (7 347) (8 396) Disposals and derecognition 510 338 848 Foreign exchange adjustments (60) (107) (167) Reclassified to assets held for sale (note 33) 4 111 62 4 173 At December 31, 2022 (21 715) (42 840) (64 555) Net property, plant and equipment December 31, 2021 (1) 16 003 49 543 65 546 December 31, 2022 17 060 45 594 62 654 (1) For the years ended December 31, 2020 and December 31, 2021, the company reclassified certain balances between oil and gas properties and plant and equipment. This reclassification had no effect on net property, plant and equipment. December 31, 2022 December 31, 2021 Accumulated Net Book Accumulated Net Book ($ millions) Cost Provision Value Cost Provision Value Oil Sands 92 601 (45 288) 47 313 87 849 (37 971) 49 878 Exploration and Production 16 541 (11 360) 5 181 21 495 (15 999) 5 496 Refining and Marketing 17 101 (7 435) 9 666 15 989 (6 596) 9 393 Corporate and Eliminations 966 (472) 494 1 226 (447) 779 127 209 (64 555) 62 654 126 559 (61 013) 65 546 |
Right-of-Use Assets and Leases
Right-of-Use Assets and Leases (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Right-of-Use Assets and Leases | |
Schedule of right-of-use assets | December 31 December 31 ($ millions) 2022 2021 Property, plant and equipment, net – excluding ROU assets 59 778 62 821 ROU assets 2 876 2 725 62 654 65 546 The following table presents the ROU assets by asset class: Plant and ($ millions) Equipment Cost At January 1, 2021 3 786 Additions and adjustments 307 Disposals (232) Foreign exchange - At December 31, 2021 3 861 Additions and adjustments 523 Disposals (156) Foreign exchange 20 At December 31, 2022 4 248 Accumulated provision At January 1, 2021 (962) Depreciation (396) Disposals 221 Foreign exchange 1 At December 31, 2021 (1 136) Depreciation (356) Disposals 126 Foreign exchange (6) At December 31, 2022 (1 372) Net ROU assets At December 31, 2021 2 725 At December 31, 2022 2 876 |
Exploration and Evaluation As_2
Exploration and Evaluation Assets (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Exploration and Evaluation Assets | |
Exploration and Evaluation Assets rollforward | December 31 December 31 ($ millions) 2022 2021 Beginning of year 2 226 2 286 Acquisitions and additions 41 2 Transfers to oil and gas assets (34) - Disposals and derecognition - (54) Reclassified to assets held for sale (note 33) (239) - Foreign exchange adjustments 1 (8) End of year 1 995 2 226 |
Other Assets (Tables)
Other Assets (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Other Assets | |
Other Assets | December 31 December 31 ($ millions) 2022 2021 Investments 758 391 Prepaids and other 796 916 Pension (note 23) 212 - 1 766 1 307 |
Goodwill and Other Intangible_2
Goodwill and Other Intangible Assets (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Goodwill and Other Intangible Assets | |
Segment breakdown of Goodwill and Other Intangible Assets | Refining and Oil Sands Marketing Other ($ millions) Goodwill Goodwill Intangibles Total At December 31, 2020 2 752 140 436 3 328 Additions - - 213 213 Amortization - - (18) (18) At December 31, 2021 2 752 140 631 3 523 Additions - - 140 140 Amortization - - (57) (57) Reclassified to assets held for sale (note 33) - - (20) (20) At December 31, 2022 2 752 140 694 3 586 |
Debt and Credit Facilities (Tab
Debt and Credit Facilities (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Debt and Credit Facilities | |
Schedule of short and long term debt | Short-Term Debt December 31 December 31 ($ millions) 2022 2021 Commercial paper (1) 2 807 1 284 (1) The commercial paper is supported by a revolving credit facility with a syndicate of lenders. The company is authorized to issue commercial paper to a maximum of $5.0 billion having a term not to exceed 365 days . The weighted average interest rate as at December 31, 2022 was 4.93% (December 31, 2021 - 0.33% ). Long-Term Debt December 31 December 31 ($ millions) 2022 2021 Fixed-term debt (2)(3) 4.50% Notes, due 2022 ( US$182 ) (4) - 231 2.80% Notes, due 2023 ( US$450 ) - 569 3.10% Notes, due 2025 ( US$550 ) - 696 3.00% Series 5 Medium Term Notes, due 2026 115 699 7.875% Debentures, due 2026 ( US$275 ) 381 359 8.20% Notes, due 2027 ( US$59 ) (4) 61 78 7.00% Debentures, due 2028 ( US$250 ) 342 320 3.10% Series 6 Medium Term Notes, due 2029 79 748 5.00% Series 7 Medium Term Notes, due 2030 154 1 247 7.15% Notes, due 2032 ( US$500 ) 676 631 5.35% Notes, due 2033 ( US$300 ) 161 355 5.95% Notes, due 2034 ( US$500 ) 675 630 5.95% Notes, due 2035 ( US$600 ) 268 731 5.39% Series 4 Medium Term Notes, due 2037 279 599 6.50% Notes, due 2038 ( US$1 150 ) 1 553 1 451 6.80% Notes, due 2038 ( US$900 ) 1 235 1 156 6.85% Notes, due 2039 ( US$750 ) 1 013 946 6.00% Notes, due 2042 ( US$152 ) (4) 35 149 4.34% Series 5 Medium Term Notes, due 2046 300 300 4.00% Notes, due 2047 ( US$750 ) 1 011 945 3.95% Series 8 Medium Term Notes, due 2051 493 493 3.75% Notes, due 2051 ( US$750 ) 1 009 945 Total unsecured long-term debt 9 840 14 278 Lease liabilities (5) 3 012 2 850 Deferred financing costs (40) (58) 12 812 17 070 Current portion of long-term debt and lease liabilities Lease liabilities (317) (310) Long-term debt - (231) (317) (541) Total long-term lease liabilities 2 695 2 540 Total long-term debt 9 800 13 989 (2) The value of debt includes the unamortized balance of premiums or discounts. (3) Certain securities are redeemable at the option of the company. (4) Debt acquired through the acquisition of Canadian Oil Sands Limited (COS). (5) Interest rates range from 0.4% to 13.4% and maturity dates range from 2023 to 2062. |
Scheduled principal repayments for leases liabilities, short term debt and long term debt | Scheduled principal repayments as at December 31, 2022 for lease liabilities, short-term debt and long-term debt are as follows: ($ millions) Repayment 2023 3 124 2024 264 2025 241 2026 691 2027 244 Thereafter 11 101 15 665 |
Summary of available and unutilized credit facilities | A summary of available and unutilized credit facilities is as follows: ($ millions) 2022 Fully revolving and expires in 2026 3 000 Fully revolving and expires in 2025 2 707 Can be terminated at any time at the option of the lenders 1 520 Total credit facilities 7 227 Credit facilities supporting outstanding commercial paper (2 807) Credit facilities supporting standby letters of credit (1 148) Total unutilized credit facilities (1) 3 272 (1) Available credit facilities for liquidity purposes at December 31, 2022 decreased to $2.900 billion, compared to $4.247 billion at December 31, 2021. |
Other Long Term Liabilities (Ta
Other Long Term Liabilities (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Other Long Term Liabilities | |
Schedule of other long-term liabilities | December 31 December 31 ($ millions) 2022 2021 Pensions and other post-retirement benefits (note 23) 564 1 207 Share-based compensation plans (note 26) 469 291 Partnership liability (note 27) (1) 413 427 Deferred revenue 22 29 Libya Exploration and Production Sharing Agreement (EPSA) signature bonus (2) 80 74 Other 94 152 1 642 2 180 (1) The company paid $60 million in 2022 (2021 – $60 million) in distributions to the partners of the East Tank Farm Development, of which $51 million (2021 – $51 million) was allocated to interest expense and $9 million (2021 – $9 million) to the principal. (2) The company has a US $500 million obligation for a signature bonus relating to Petro-Canada’s ratification of six EPSAs in Libya. At December 31, 2022, the carrying amount of the Libya EPSAs’ signature bonus so was $85 million (December 31, 2021 – $78 million). The current portion is $5 million (December 31, 2021 – $4 million) and is recorded in Accounts Payable and Accrued Liabilities. |
Pensions and Other Post Retir_2
Pensions and Other Post Retirement Benefits (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Pensions and Other Post Retirement Benefits | |
Schedule of changes in benefit obligations and plan assets | Other Post-Retirement Pension Benefits Benefits ($ millions) 2022 2021 2022 2021 Change in benefit obligation Benefit obligation at beginning of year 8 303 8 682 672 690 Current service costs 263 302 19 19 Plan participants’ contributions 17 17 - - Benefits paid (367) (350) (28) (27) Interest costs 246 222 20 18 Foreign exchange (2) (6) - - Settlements 10 11 - - Actuarial remeasurement: Experience (gain) loss arising on plan liabilities (86) (1) 3 (1) Actuarial gain arising from changes in demographic assumptions - (2) - - Actuarial gain arising from changes in financial assumptions (2 229) (572) (167) (27) Benefit obligation at end of year 6 155 8 303 519 672 Change in plan assets Fair value of plan assets at beginning of year 7 701 7 305 - - Employer contributions 61 (11) - - Plan participants’ contributions 17 17 - - Benefits paid (347) (325) - - Foreign exchange (4) (5) - - Settlements 10 11 - - Administrative costs (2) (2) - - Income on plan assets 225 181 - - Actuarial remeasurement: Return on plan assets greater / (less) than discount rate (1 190) 530 - - Fair value of plan assets at end of year 6 471 7 701 - - Effect of the asset ceiling 187 - - - Net surplus / (unfunded obligation) at end of year 129 (602) (519) (672) |
Schedule of defined benefit plan expenses | Other Post-Retirement Pension Benefits Benefits ($ millions) 2022 2021 2022 2021 Analysis of amount charged to earnings: Current service costs 263 302 19 19 Interest costs 21 41 20 18 Defined benefit plans expense 284 343 39 37 Defined contribution plans expense 95 94 - - Total benefit plans expense charged to earnings 379 437 39 37 Components of defined benefit costs recognized in Other Comprehensive Income: Other Post-Retirement Pension Benefits Benefits ($ millions) 2022 2021 2022 2021 Actuarial (gain) / loss arising from changes in experience (86) (1) 3 (1) Actuarial gain arising from changes in financial assumptions (2 229) (572) (167) (27) Actuarial gain arising from changes in demographic assumptions - (2) - - Benefit Obligation gains (2 315) (575) (164) (28) Return on plan assets (greater) / less than discount rate (excluding amounts included in net interest expense) 1 190 (530) - - Effect of the asset ceiling 187 - - - Plan assets loss / (gain) 1 377 (530) - - Actuarial gain recognized in other comprehensive income (938) (1 105) (164) (28) |
Schedule of weighted average actuarial assumptions | Other Post-Retirement Pension Benefits Benefits December 31 December 31 December 31 December 31 (%) 2022 2021 2022 2021 Discount rate 5.10 2.90 5.10 2.90 Rate of compensation increase 3.00 3.00 3.00 3.00 |
Summary of sensitivity analysis for actuarial assumptions | Pension Benefits ($ millions) Increase Decrease 1% change in discount rate Effect on the aggregate service and interest costs (25) 32 Effect on the benefit obligations (693) 871 Other Post-Retirement Benefits ($ millions) Increase Decrease 1% change in discount rate Effect on the benefit obligations (53) 64 1% change in health care cost Effect on the aggregate service and interest costs 1 (1) Effect on the benefit obligations 27 (23) |
Schedule of weighted average pension plan asset allocations based on market value | The company’s weighted average pension plan asset allocations, based on market values as at December 31, are as follows: (%) 2022 2021 Equities 52 48 Fixed income 27 38 Plan assets, comprised of: – Real Estate 21 14 Total 100 100 |
Provisions (Tables)
Provisions (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Provisions | |
Schedule of provisions | Decommissioning ($ millions) and Restoration (1) Royalties Other (2) Total At December 31, 2020 10 044 71 467 10 582 Liabilities incurred 104 137 171 412 Change in discount rate (1 260) - - (1 260) Changes in estimates (76) (12) (13) (101) Liabilities settled (263) 26 (84) (321) Accretion 304 - - 304 Foreign exchange (61) - - (61) At December 31, 2021 8 792 222 541 9 555 Less: current portion (266) (222) (291) (779) 8 526 - 250 8 776 At December 31, 2021 8 792 222 541 9 555 Liabilities incurred 114 89 3 206 Change in discount rate (2 456) - - (2 456) Changes in estimates 3 596 (4) 69 3 661 Liabilities settled (314) (125) (332) (771) Accretion 316 - - 316 Asset disposals 62 - - 62 Reclassified to assets held for sale (note 33) (226) - - (226) Foreign exchange 17 - - 17 At December 31, 2022 9 901 182 281 10 364 Less: current portion (337) (182) (45) (564) 9 564 - 236 9 800 (1) Represents decommissioning and restoration provisions associated with the retirement of Property, Plant and Equipment and Exploration and Evaluation assets. The total undiscounted and uninflated amount of estimated future cash flows required to settle the obligations at December 31, 2022 was approximately $22.4 billion (December 31, 2021 – $13.8 billion). A $3.6 billion increase in the estimated discounted cash flows was recognized at December 31, 2022, and was primarily related to water treatment costs for mining assets. A weighted average credit-adjusted risk-free interest rate of 5.50% was used to discount the provision recognized at December 31, 2022 (December 31, 2021 – 3.70% ). The credit-adjusted risk-free interest rate used reflects the expected time frame of the provisions. Payments to settle the decommissioning and restoration provisions occur on an ongoing basis and will continue over the lives of the operating assets, which can exceed 50 years . (2) Includes legal and environmental provisions, a restructuring provision remaining for $11 million (December 31, 2021 - $88 million). Liabilities settled in 2022 include a payment to the Keystone XL pipeline project for $187 million (after-tax $142 million). |
Schedule of impact of changes in discount rate on decommissioning and restoration liabilities. | Changes to the discount rate would have the following impact on Decommissioning and Restoration liabilities: As at December 31 2022 2021 1% Increase (1 594) (1 497) 1% Decrease 2 131 2 113 |
Share Capital (Tables)
Share Capital (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Share Capital | |
Schedule of share repurchase activities | The following table summarizes the share repurchase activities during the period: ($ millions, except as noted) 2022 2021 Share repurchase activities (thousands of common shares) Shares repurchased 116 908 83 959 Amounts charged to Share capital 1 947 1 382 Retained earnings 3 188 922 Share repurchase cost 5 135 2 304 Average repurchase cost per share 43.92 27.45 |
Schedule of liability for share repurchases | Under an automatic repurchase plan agreement with an independent broker, the company has recorded the following liability for share repurchases that may take place during its internal blackout period: December 31 December 31 ($ millions) 2022 2021 Amounts charged to Share capital 136 120 Retained earnings 214 110 Liability for share purchase commitment 350 230 |
Share Based Compensation (Table
Share Based Compensation (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Share Based Compensation | |
Schedule of share-based compensation expense | Included in the Consolidated Statements of Comprehensive Income within Operating, Selling and General expense are the following share-based compensation amounts: ($ millions) 2022 2021 Equity-settled plans 17 21 Cash-settled plans 484 301 Total share-based compensation expense 501 322 |
Schedule of liability recognized for share-based compensation | Included in the Consolidated Balance Sheets within accounts payable and accrued liabilities and other long-term liabilities are the following fair value amounts for the company’s cash-settled plans: December 31 December 31 ($ millions) 2022 2021 Current liability 326 153 Long-term liability (note 22) 469 291 Total Liability 795 444 |
Schedule of weighted average fair value of options granted during the period and the weighted average assumptions used in their determination | The weighted average fair value of options granted during the period and the weighted average assumptions used in their determination are as noted below: 2022 2021 Annual dividend per share (dollars) 1.88 1.05 Risk-free interest rate 1.73% 0.49% Expected life 5 years 5 years Expected volatility 42% 40% Weighted average fair value per option (dollars) 9.27 5.40 |
Summary of activity of stock option plans | The following table presents a summary of the activity related to Suncor’s stock option plans: 2022 2021 Weighted Weighted Average Average Number Exercise Price Number Exercise Price (thousands) ($) (thousands) ($) Outstanding, beginning of year 37 090 38.39 38 373 39.65 Granted 2 191 37.22 3 457 22.71 Exercised as options for common shares (13 158) 37.69 (245) 29.82 Forfeited/expired (5 055) 38.99 (4 495) 37.62 Outstanding, end of year 21 068 38.55 37 090 38.39 Exercisable, end of year 16 407 40.19 28 421 39.87 |
Schedule of exercise price ranges and weighted average remaining contractual lives | For the options outstanding at December 31, 2022, the exercise price ranges and weighted average remaining contractual lives are shown below: Outstanding Exercisable Weighted Average Weighted Weighted Remaining Average Average Number Contractual Life Exercise Number Exercise Exercise Prices ($) (thousands) (years) Price ($) (thousands) Price ($) 22.63 - 24.99 2 658 5 22.65 1 064 22.65 25.00 - 29.99 9 5 29.31 3 29.34 30.00 - 34.99 731 - 30.30 718 30.28 35.00 - 39.99 6 176 4 38.37 3 255 38.85 40.00 - 44.99 11 298 2 42.73 11 235 42.75 45.00 - 49.99 101 5 48.05 44 48.41 50.00 - 54.27 95 3 52.78 88 52.85 Total 21 068 3 38.55 16 407 40.19 |
Summary of common shares available for granting future options | Common shares authorized for issuance by the Board of Directors that remain available for the granting of future options: (thousands) 2022 2021 27 901 25 037 |
Share Units | |
Share Based Compensation | |
Summary of activity of equity awards | The following table presents a summary of the activity related to Suncor’s share unit plans: (thousands) PSU RSU DSU Outstanding, December 31, 2020 2 285 15 095 1 385 Granted 1 285 11 954 164 Redeemed for cash (751) (4 609) (167) Forfeited/expired (53) (1 003) - Outstanding, December 31, 2021 2 766 21 437 1 382 Granted 947 13 235 187 Redeemed for cash (794) (4 533) (238) Forfeited/expired (710) (1 877) - Outstanding, December 31, 2022 2 209 28 262 1 331 |
Stock Appreciation Rights (SARs) | |
Share Based Compensation | |
Summary of activity of equity awards | SARs have a seven three 2022 2021 Weighted Weighted Average Average Number Exercise Price Number Exercise Price (thousands) ($) (thousands) ($) Outstanding, beginning of year 463 39.06 509 39.25 Granted 10 36.76 10 22.63 Exercised (121) 37.18 — — Forfeited/expired (65) 38.25 (56) 37.78 Outstanding, end of year 287 39.95 463 39.06 Exercisable, end of year 242 40.82 357 39.68 |
Financial Instruments and Ris_2
Financial Instruments and Risk Management (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Financial Instruments and Risk Management | |
Summary of changes in the fair value of non designated derivatives | The changes in the fair value of non-designated derivatives are as follows: ($ millions) 2022 2021 Fair value outstanding, beginning of year (98) (121) Cash settlements – paid during the year 220 178 Changes in fair value recognized in earnings during the year (note 7) (187) (155) Fair value outstanding, end of year (65) (98) |
Schedule of derivative financial instrument assets and liabilities and assets available for sale measured at fair value | The following table presents the company’s derivative financial instrument assets and liabilities measured at fair value for each hierarchy level as at December 31, 2022 and 2021. ($ millions) Level 1 Level 2 Level 3 Total Fair Value Accounts receivable 35 88 - 123 Accounts payable (134) (87) - (221) Balance at December 31, 2021 (99) 1 - (98) Accounts receivable 36 107 - 143 Accounts payable (85) (123) - (208) Balance at December 31, 2022 (49) (16) - (65) |
Schedule of offsetting financial assets | Financial Assets Gross Gross Liabilities Net Amounts ($ millions) Assets Offset Presented Fair value of derivative assets 6 527 (6 404) 123 Accounts receivable 5 048 (2 734) 2 314 Balance at December 31, 2021 11 575 (9 138) 2 437 Fair value of derivative assets 4 305 (4 162) 143 Accounts receivable 10 349 (8 633) 1 716 Balance at December 31, 2022 14 654 (12 795) 1 859 |
Schedule of offsetting financial liabilities | Financial Liabilities Gross Gross Assets Net Amounts ($ millions) Liabilities Offset Presented Fair value of derivative liabilities (6 625) 6 404 (221) Accounts payable (4 205) 2 734 (1 471) Balance at December 31, 2021 (10 830) 9 138 (1 692) Fair value of derivative liabilities (4 370) 4 162 (208) Accounts payable (10 036) 8 633 (1 403) Balance at December 31, 2022 (14 406) 12 795 (1 611) |
Schedule of maturities for trade and other payables and debt | The following table shows the timing of cash outflows related to trade and other payables and debt. December 31, 2021 Trade and Gross Derivative Lease ($ millions) Other Payables (1) Liabilities (2) Debt (3) Liabilities Within one year 6 282 6 466 2 253 459 2 to 3 years 37 159 2 015 779 4 to 5 years 37 - 3 127 660 Over 5 years - - 18 836 2 633 6 356 6 625 26 231 4 531 December 31, 2022 Trade and Gross Derivative Lease ($ millions) Other Payables (1) Liabilities (2) Debt (3) Liabilities Within one year 7 959 3 824 3 375 477 2 to 3 years 39 546 1 066 807 4 to 5 years 39 - 1 541 652 Over 5 years - - 16 317 3 047 8 037 4 370 22 299 4 983 (1) Trade and other payables exclude net derivative liabilities of $208 million (2021 – $221 million). (2) Gross derivative liabilities of $4.370 billion (2021 – $6.625 billion) are offset by gross derivative assets of $4.162 billion (2021 – $6.404 billion), resulting in a net amount of $208 million (2021 – $221 million). (3) Debt includes short-term debt, long-term debt and interest payments on fixed-term debt. |
Capital Structure Financial P_2
Capital Structure Financial Policies (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Capital Structure Financial Policies | |
Schedule of components of ratios | Capital Measure December 31 December 31 ($ millions) Target 2022 2021 Components of ratios Short-term debt 2 807 1 284 Current portion of long-term debt - 231 Current portion of long-term lease liabilities 317 310 Long-term debt 9 800 13 989 Long-term lease liabilities 2 695 2 540 Total debt (1) 15 619 18 354 Less: Cash and cash equivalents 1 980 2 205 Net debt (1) 13 639 16 149 Shareholders’ equity 39 367 36 614 Total capitalization (total debt plus shareholders’ equity) 54 986 54 968 Adjusted funds from operations (2) 18 101 10 257 Net debt to adjusted funds from operations < 3.0 times 0.8 1.6 Total debt to total debt plus shareholders’ equity 20% - 35% 28.4% 33.4% (1) Total debt and net debt are non-GAAP financial measures. (2) Adjusted funds from operations is calculated as cash flow from operating activities before changes in non-cash working capital, and is a non-GAAP financial measure. |
Joint Arrangements (Tables)
Joint Arrangements (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Joint Arrangements | |
Schedule of joint operations | Country of Incorporation and Principal Place of Ownership % Ownership % Material Joint Operations Principal Activity Business 2022 2021 Oil Sands Operated by Suncor: Fort Hills Energy Limited Partnership (1) Oil sands development Canada 54.11 54.11 Meadow Creek Oil sands development Canada 75.00 75.00 Syncrude Oil sands development Canada 58.74 58.74 Exploration and Production Operated by Suncor: Terra Nova Oil and gas production Canada 48.00 48.00 Non-operated: Buzzard (2) Oil and gas production United Kingdom 29.89 29.89 Fenja Development JV (3) Oil and gas production Norway — 17.50 Hibernia and the Hibernia South Extension Unit Oil and gas production Canada 19.48 - 20.00 19.48 - 20.00 Hebron Oil and gas production Canada 21.03 21.03 Harouge Oil Operations Oil and gas production Libya 49.00 49.00 North Sea Rosebank Project (2) Oil and gas production United Kingdom 40.00 40.00 Oda (3) Oil and gas production Norway — 30.00 White Rose and the White Rose Extensions (4) Oil and gas production Canada 38.625 - 40.00 26.13 - 27.50 (1) Subsequent to December 31, 2022, Suncor acquired an additional 14.65% working interest in Fort Hills, bringing the company’s and its affiliate’s total aggregate working interest to 68.76% . (2) In the third quarter of 2022, Suncor reclassified the assets and liabilities related to its United Kingdom (U.K.) operations as assets held for sale, including its interests in Buzzard and Rosebank. Subsequent to the fourth quarter of 2022, the company reached an agreement for the sale of its U.K operations. The sale is expected to close in mid-2023. (3) In the third quarter of 2022, Suncor completed the sale of its Norway assets, including its 30% working interest in Oda and its 17.5% working interest in the Fenja Development Joint Operations. (4) In the second quarter of 2022, Suncor announced that concurrent with the decision to restart the West White Rose project by the joint venture owners, Suncor increased its ownership in the White Rose asset 12.50% to approximately 40.00% . |
Schedule of joint ventures and associates | Joint ventures Associates ($ millions) 2022 2021 2022 2021 Net earnings (loss) (25) 5 (1) (2) Total comprehensive earnings (loss) (25) 5 (1) (2) Carrying amount as at December 31 39 63 63 66 |
Subsidiaries (Tables)
Subsidiaries (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Subsidiaries | |
Schedule of material subsidiaries | Material subsidiaries, either directly or indirectly, by the company as at December 31, 2022 are shown below: Material Subsidiaries Principal Activity Canadian Operations Suncor Energy Oil Sands Limited Partnership This partnership holds most of the company’s Oil Sands operations assets. Suncor Energy Ventures Corporation A subsidiary which indirectly owns a 36.74% ownership in the Syncrude joint operation. Suncor Energy Ventures Partnership A subsidiary which owns a 22% ownership in the Syncrude joint operation. Suncor Energy Products Partnership This partnership holds substantially all of the company’s Canadian refining and marketing assets. Suncor Energy Marketing Inc. Through this subsidiary, production from the upstream Canadian businesses is marketed. This subsidiary also administers Suncor’s energy trading activities and power business, markets certain third-party products, procures crude oil feedstock and natural gas for its downstream business, and procures and markets natural gas liquids (NGLs) and liquefied petroleum gas (LPG) for its downstream business. U.S. Operations Suncor Energy (U.S.A.) Marketing Inc. A subsidiary that procures, markets and trades crude oil, in addition to procuring crude oil feedstock for the company’s refining operations. Suncor Energy (U.S.A.) Inc. A subsidiary through which the company’s U.S. refining and marketing operations are conducted. International Operations Suncor Energy UK Limited A subsidiary through which the majority of the company’s North Sea operations are conducted. |
Related Party Disclosures (Tabl
Related Party Disclosures (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Related Party Disclosures | |
Summary of significant related party transactions | A summary of the significant related party transactions as at and for the years ended December 31, 2022 and 2021 are as follows: ($ millions) 2022 2021 Sales (1) 1 616 1 011 Purchases 265 247 Accounts receivable 135 70 Accounts payable and accrued liabilities 69 17 (1) Includes sales to Petroles Cadeko Inc. of $645 million (2021 - $411 million) and Parachem Chemicals Inc. of $487 million (2021 – $343 million). |
Schedule of compensation of Key Management Personnel | Compensation of the company’s Board of Directors and members of the Executive Leadership Team for the years ended December 31 is as follows: ($ millions) 2022 2021 Salaries and other short-term benefits 20 8 Pension and other post-retirement benefits 4 3 Share based compensation 73 47 97 58 |
Commitments, Contingencies an_2
Commitments, Contingencies and Guarantees (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Commitments, Contingencies and Guarantees | |
Schedule of commitments | Future payments under the company’s commitments, including service arrangements for pipeline transportation agreements and for other property and equipment, are as follows: Payment Due by Period ($ millions) 2023 2024 2025 2026 2027 Thereafter Total Commitments Product transportation and storage 1 146 1 252 1 201 1 024 1 165 7 410 13 198 Energy services 101 101 119 77 71 77 546 Exploration work commitments - - 53 1 - 486 540 Other 471 269 149 115 73 191 1 268 1 718 1 622 1 522 1 217 1 309 8 164 15 552 |
Assets Held for Sale (Tables)
Assets Held for Sale (Tables) | 12 Months Ended |
Dec. 31, 2022 | |
Held-for-sale, U.K. Operations | |
Assets Held for Sale | |
Schedule of assets and liabilities held for sale | The table below details the assets and liabilities held for sale as at December 31, 2022: ($ millions) Assets Currents assets 83 Property, plant and equipment, net 364 Exploration and evaluation 239 Total Assets 686 Liabilities Current liabilities (241) Provisions (217) Total Liabilities (458) Net Assets 228 |
Held-for-sale, wind and solar assets | |
Assets Held for Sale | |
Schedule of assets and liabilities held for sale | The table below details the assets and liabilities held for sale as at December 31, 2022: ($ millions) Assets Current assets 62 Property, plant and equipment, net and intangible assets 438 Total Assets 500 Liabilities Current liabilities (32) Other long-term liabilities and provisions (40) Total Liabilities (72) Net Assets 428 |
Summary of Significant Accoun_4
Summary of Significant Accounting Policies - Useful lives of PP&E (Details) | 12 Months Ended |
Dec. 31, 2022 | |
Oil sands upgraders, extraction plants and mine facilities | Minimum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 20 years |
Oil sands upgraders, extraction plants and mine facilities | Maximum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 40 years |
Oil sands mine equipment | Minimum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 5 years |
Oil sands mine equipment | Maximum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 15 years |
Oil sands in situ processing facilities | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 30 years |
Power generation and utility plants | Minimum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 30 years |
Power generation and utility plants | Maximum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 40 years |
Refineries and other processing plants | Minimum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 20 years |
Refineries and other processing plants | Maximum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 40 years |
Marketing and other distribution assets | Minimum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 10 years |
Marketing and other distribution assets | Maximum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 40 years |
Inspection, overhaul and turnaround activities | Minimum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 2 years |
Inspection, overhaul and turnaround activities | Maximum | |
Property, Plant and Equipment | |
Property, Plant and Equipment, Expected Useful Life | 5 years |
Summary of Significant Accoun_5
Summary of Significant Accounting Policies - Goodwill and Other Intangible Assets (Details) | 12 Months Ended |
Dec. 31, 2022 | |
Minimum | Customer Lists | |
Summary of Significant Accounting Policies | |
Estimated useful lives of intangible assets | 5 years |
Minimum | Software costs | |
Summary of Significant Accounting Policies | |
Estimated useful lives of intangible assets | 5 years |
Maximum | Customer Lists | |
Summary of Significant Accounting Policies | |
Estimated useful lives of intangible assets | 10 years |
Maximum | Software costs | |
Summary of Significant Accounting Policies | |
Estimated useful lives of intangible assets | 6 years |
Segmented Information - Summary
Segmented Information - Summary (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Revenues and Other Income | ||
Less : Royalties | $ (4,571) | $ (2,001) |
Operating revenues, net of royalties | 58,336 | 39,132 |
Other (loss) income | 131 | (31) |
Revenues and Other Income | 58,467 | 39,101 |
Expenses | ||
Purchases of crude oil and products | 20,775 | 13,791 |
Operating, selling and general | 12,807 | 11,366 |
Transportation and distribution | 1,671 | 1,479 |
Depreciation, depletion, amortization and impairment | 8,786 | 5,850 |
Exploration | 56 | 47 |
(Gain) loss on disposal of assets | 45 | (257) |
Financing expenses | 2,011 | 1,255 |
Expenses | 46,151 | 33,531 |
Earnings (Loss) before Income Taxes | 12,316 | 5,570 |
Income Tax Expense (Recovery) | ||
Current | 4,229 | 1,395 |
Deferred | (990) | 56 |
Total Income Tax Expense (Recovery) | 3,239 | 1,451 |
Net Earnings | 9,077 | 4,119 |
Capital and Exploration Expenditures | 4,987 | 4,555 |
Capital expenditures classified as assets held for sale | 133 | |
Reclassification adjustment | ||
Revenues and Other Income | ||
Gross revenues | (150) | |
Expenses | ||
Purchases of crude oil and products | (150) | |
Operating segments | ||
Revenues and Other Income | ||
Gross revenues | 62,907 | 41,133 |
Oil Sands | ||
Revenues and Other Income | ||
Less : Royalties | (3,963) | (1,523) |
Operating revenues, net of royalties | 26,468 | 18,397 |
Other (loss) income | (53) | 6 |
Revenues and Other Income | 26,415 | 18,403 |
Expenses | ||
Purchases of crude oil and products | 2,050 | 1,444 |
Operating, selling and general | 9,152 | 8,056 |
Transportation and distribution | 1,210 | 1,126 |
Depreciation, depletion, amortization and impairment | 7,927 | 4,585 |
Exploration | 37 | 12 |
(Gain) loss on disposal of assets | (7) | (4) |
Financing expenses | 413 | 359 |
Expenses | 20,782 | 15,578 |
Earnings (Loss) before Income Taxes | 5,633 | 2,825 |
Income Tax Expense (Recovery) | ||
Capital and Exploration Expenditures | 3,540 | 3,168 |
Oil Sands | Operating segments | ||
Revenues and Other Income | ||
Gross revenues | 21,905 | 15,319 |
Oil Sands | Intersegment revenues | ||
Revenues and Other Income | ||
Gross revenues | 8,526 | 4,601 |
Exploration and Production | ||
Revenues and Other Income | ||
Less : Royalties | (608) | (478) |
Operating revenues, net of royalties | 3,723 | 2,500 |
Other (loss) income | 164 | 17 |
Revenues and Other Income | 3,887 | 2,517 |
Expenses | ||
Operating, selling and general | 490 | 429 |
Transportation and distribution | 101 | 112 |
Depreciation, depletion, amortization and impairment | (105) | 324 |
Exploration | 19 | 35 |
(Gain) loss on disposal of assets | 66 | (227) |
Financing expenses | 95 | 53 |
Expenses | 666 | 726 |
Earnings (Loss) before Income Taxes | 3,221 | 1,791 |
Income Tax Expense (Recovery) | ||
Capital and Exploration Expenditures | 443 | 270 |
Exploration and Production | Operating segments | ||
Revenues and Other Income | ||
Gross revenues | 4,331 | 2,978 |
Refining and Marketing | ||
Revenues and Other Income | ||
Operating revenues, net of royalties | 36,728 | 22,915 |
Other (loss) income | (60) | (50) |
Revenues and Other Income | 36,668 | 22,865 |
Expenses | ||
Purchases of crude oil and products | 27,261 | 16,807 |
Operating, selling and general | 2,427 | 2,019 |
Transportation and distribution | 396 | 282 |
Depreciation, depletion, amortization and impairment | 844 | 853 |
(Gain) loss on disposal of assets | (11) | (19) |
Financing expenses | 57 | 56 |
Expenses | 30,974 | 19,998 |
Earnings (Loss) before Income Taxes | 5,694 | 2,867 |
Income Tax Expense (Recovery) | ||
Capital and Exploration Expenditures | 816 | 825 |
Refining and Marketing | Operating segments | ||
Revenues and Other Income | ||
Gross revenues | 36,622 | 22,808 |
Refining and Marketing | Intersegment revenues | ||
Revenues and Other Income | ||
Gross revenues | 106 | 107 |
Corporate and Eliminations | ||
Revenues and Other Income | ||
Operating revenues, net of royalties | (8,583) | (4,680) |
Other (loss) income | 80 | (4) |
Revenues and Other Income | (8,503) | (4,684) |
Expenses | ||
Purchases of crude oil and products | (8,536) | (4,460) |
Operating, selling and general | 738 | 862 |
Transportation and distribution | (36) | (41) |
Depreciation, depletion, amortization and impairment | 120 | 88 |
(Gain) loss on disposal of assets | (3) | (7) |
Financing expenses | 1,446 | 787 |
Expenses | (6,271) | (2,771) |
Earnings (Loss) before Income Taxes | (2,232) | (1,913) |
Income Tax Expense (Recovery) | ||
Capital and Exploration Expenditures | 188 | 292 |
Corporate and Eliminations | Operating segments | ||
Revenues and Other Income | ||
Gross revenues | 49 | 28 |
Corporate and Eliminations | Intersegment revenues | ||
Revenues and Other Income | ||
Gross revenues | $ (8,632) | $ (4,708) |
Segmented Information - Disaggr
Segmented Information - Disaggregation of Revenue (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | $ 62,907 | $ 41,133 |
North America | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 61,040 | 39,864 |
International | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 1,867 | 1,269 |
Elimination of intersegment amounts | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | (8,583) | (4,680) |
Elimination of intersegment amounts | North America | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | (8,583) | (4,680) |
Oil Sands | Operating segments | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 30,431 | 19,920 |
Oil Sands | Operating segments | Synthetic crude oil and diesel | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 22,539 | 14,452 |
Oil Sands | Operating segments | Bitumen | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 7,892 | 5,468 |
Oil Sands | Operating segments | North America | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 30,431 | 19,920 |
Oil Sands | Operating segments | North America | Synthetic crude oil and diesel | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 22,539 | 14,452 |
Oil Sands | Operating segments | North America | Bitumen | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 7,892 | 5,468 |
Exploration and Production | Operating segments | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 4,331 | 2,978 |
Exploration and Production | Operating segments | Crude oil and natural gas liquids | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 4,298 | 2,966 |
Exploration and Production | Operating segments | Natural gas | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 33 | 12 |
Exploration and Production | Operating segments | North America | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 2,464 | 1,709 |
Exploration and Production | Operating segments | North America | Crude oil and natural gas liquids | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 2,464 | 1,709 |
Exploration and Production | Operating segments | International | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 1,867 | 1,269 |
Exploration and Production | Operating segments | International | Crude oil and natural gas liquids | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 1,834 | 1,257 |
Exploration and Production | Operating segments | International | Natural gas | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 33 | 12 |
Refining and Marketing | Operating segments | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 36,728 | 22,915 |
Refining and Marketing | Operating segments | Gasoline | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 14,540 | 9,983 |
Refining and Marketing | Operating segments | Distillate | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 18,663 | 9,832 |
Refining and Marketing | Operating segments | Other | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 3,525 | 3,100 |
Refining and Marketing | Operating segments | North America | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 36,728 | 22,915 |
Refining and Marketing | Operating segments | North America | Gasoline | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 14,540 | 9,983 |
Refining and Marketing | Operating segments | North America | Distillate | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | 18,663 | 9,832 |
Refining and Marketing | Operating segments | North America | Other | ||
Segmented Information | ||
Total Gross Revenue from Contracts with Customers | $ 3,525 | $ 3,100 |
Segmented Information - Geograp
Segmented Information - Geographical information (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Segmented Information | ||
Operating Revenues, net of Royalties | $ 58,336 | $ 39,132 |
Non-Current Assets | 70,001 | 72,602 |
Canada | ||
Segmented Information | ||
Operating Revenues, net of Royalties | 49,169 | 32,286 |
Non-Current Assets | 66,346 | 68,900 |
United States | ||
Segmented Information | ||
Operating Revenues, net of Royalties | 7,544 | 5,818 |
Non-Current Assets | 2,629 | 2,020 |
Other foreign | ||
Segmented Information | ||
Operating Revenues, net of Royalties | 1,623 | 1,028 |
Non-Current Assets | $ 1,026 | $ 1,682 |
Other Income (Details)
Other Income (Details) $ in Millions, $ in Millions | 3 Months Ended | 12 Months Ended | ||
Dec. 31, 2021 | Dec. 31, 2022 CAD ($) | Dec. 31, 2022 USD ($) | Dec. 31, 2021 CAD ($) | |
Other Income | ||||
Energy trading and risk management | $ (209) | $ (165) | ||
Investment and interest income | 100 | 64 | ||
Insurance proceeds | 179 | 69 | ||
Other | 61 | 1 | ||
Total other income | 131 | (31) | ||
Golden Eagle Area Development | ||||
Other Income | ||||
Ownership interest sold (as percent) | 26.69% | |||
Exploration and Production | Libya | ||||
Other Income | ||||
Insurance proceeds | 147 | |||
Exploration and Production | Golden Eagle Area Development | ||||
Other Income | ||||
Contingent consideration gain | $ 50 | |||
Oil Sands | Mackay River | ||||
Other Income | ||||
Insurance proceeds | 31 | |||
Oil Sands | Secondary extraction facilities | ||||
Other Income | ||||
Insurance proceeds | $ 32 | $ 38 |
Operating, Selling and Genera_3
Operating, Selling and General Expense (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Operating, Selling and General Expense | ||
Employee and contract service costs | $ 8,037 | $ 7,409 |
Materials and equipment | 1,901 | 1,931 |
Commodities | 2,196 | 1,523 |
Travel, marketing and other | 673 | 503 |
Operating, Selling and General Expense | $ 12,807 | 11,366 |
Reclassification adjustment | ||
Operating, Selling and General Expense | ||
Employee and contract service costs | (564) | |
Materials and equipment | 564 | |
Commodities | 23 | |
Materials and Travel, marketing and other | $ (23) |
Financing Expenses (Details)
Financing Expenses (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Financing Expenses | ||
Interest on debt | $ 815 | $ 834 |
Interest on lease liabilities | 167 | 161 |
Capitalized interest at 5.2% ( 2021 - 5.0%) | $ (168) | $ (144) |
Interest rate | 5.20% | 5% |
Interest expense | $ 814 | $ 851 |
Interest on partnership liability | 51 | 51 |
Interest on pension and other post-retirement benefits | 41 | 59 |
Accretion | 316 | 304 |
Foreign exchange loss (gain) on U.S. dollar denominated debt | 729 | (113) |
Operational foreign exchange and other | 28 | 23 |
Loss on extinguishment of long-term debt | 32 | 80 |
Financing Expenses | $ 2,011 | $ 1,255 |
Income Taxes - Income Tax Expen
Income Taxes - Income Tax Expense (Recovery) (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Current: | ||
Current year | $ 4,333 | $ 1,353 |
Adjustments to current income tax of prior years | (104) | 42 |
Deferred: | ||
Origination and reversal of temporary differences | (1,063) | 29 |
Adjustments in respect of deferred income tax of prior years | 54 | 23 |
Changes in tax rates and legislation | (27) | 8 |
Movement in unrecognized deferred income tax assets | 46 | (4) |
Total Income Tax Expense (Recovery) | $ 3,239 | $ 1,451 |
Income Taxes - Reconciliation o
Income Taxes - Reconciliation of Effective Tax Rate (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Income Taxes | ||
Earnings before income tax | $ 12,316 | $ 5,570 |
Canadian statutory tax rate | 24.16% | 24.24% |
Statutory tax | $ 2,976 | $ 1,350 |
Add (deduct) the tax effect of: | ||
Non-taxable component of capital losses (gains) | 67 | (12) |
Share-based compensation and other permanent items | 3 | |
Assessments and adjustments | (49) | 65 |
Impact of income tax rates and legislative changes | (84) | 8 |
Non-taxable component of dispositions | (25) | (66) |
Foreign tax rate differential | 290 | 111 |
Movement in unrecognized deferred income tax assets | 46 | (4) |
Other | 18 | (4) |
Total Income Tax Expense (Recovery) | $ 3,239 | $ 1,451 |
Effective tax rate | 26.30% | 26.10% |
Current income tax recovery | $ 39 | |
Deferred income tax recovery | $ 171 |
Income Taxes - Deferred Income
Income Taxes - Deferred Income Tax Balances (Details) - CAD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | |
Income Taxes | |||
Recognized in deferred income tax (recovery) / expense | $ (990) | $ 56 | |
Deferred Income Tax Liability (Asset) | 8,364 | 9,081 | $ 8,758 |
Property, plant and equipment | |||
Income Taxes | |||
Recognized in deferred income tax (recovery) / expense | (729) | (260) | |
Deferred Income Tax Liability (Asset) | 11,093 | 11,477 | |
Decommissioning and restoration provision | |||
Income Taxes | |||
Recognized in deferred income tax (recovery) / expense | (10) | 141 | |
Deferred Income Tax Liability (Asset) | (2,292) | (1,936) | |
Employee retirement benefit plans | |||
Income Taxes | |||
Recognized in deferred income tax (recovery) / expense | (92) | (142) | |
Deferred Income Tax Liability (Asset) | (297) | (470) | |
Tax loss carry-forwards | |||
Income Taxes | |||
Recognized in deferred income tax (recovery) / expense | (14) | 161 | |
Deferred Income Tax Liability (Asset) | (29) | (15) | |
Other | |||
Income Taxes | |||
Recognized in deferred income tax (recovery) / expense | (145) | 156 | |
Deferred Income Tax Liability (Asset) | $ (111) | $ 25 |
Income Taxes - Change in Deferr
Income Taxes - Change in Deferred Income Tax Balances (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Income Taxes | ||
Net deferred tax income tax liability, beginning of year | $ 9,081 | $ 8,758 |
Recognized in deferred income tax (recovery) / expense | (990) | 56 |
Recognized in other comprehensive income | 264 | 277 |
Foreign exchange, acquisition and other | 9 | (10) |
Net deferred income tax liability, end of year | $ 8,364 | $ 9,081 |
Income Taxes - Deferred Tax in
Income Taxes - Deferred Tax in Shareholders' Equity (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Deferred Tax in Other Comprehensive Income | ||
Actuarial gain on employment retirement benefit plans | $ 264 | $ 277 |
Total income tax expense reported in equity | 264 | 277 |
Deferred income taxes | 81 | 160 |
Capital losses on unrealized foreign exchange | 986 | 606 |
Unremitted net earnings of foreign subsidiaries | 0 | |
Tax loss carry-forwards | ||
Deferred Tax in Other Comprehensive Income | ||
Deferred income taxes | $ 120 | $ 74 |
Earnings per Common Share (Deta
Earnings per Common Share (Details) - CAD ($) $ / shares in Units, shares in Millions, $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Earnings per Common Share | ||
Net earnings | $ 9,077 | $ 4,119 |
Weighted average number of common shares | 1,387 | 1,488 |
Dilutive securities: | ||
Effect of share options | 3 | 1 |
Weighted average number of diluted common shares | 1,390 | 1,489 |
Basic earnings per share (dollars per common share) | $ 6.54 | $ 2.77 |
Diluted earnings per share (dollars per common share) | $ 6.53 | $ 2.77 |
Cash and Cash Equivalents (Deta
Cash and Cash Equivalents (Details) - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 |
Cash and Cash Equivalents | |||
Cash | $ 1,782 | $ 1,971 | |
Cash equivalents | 198 | 234 | |
Cash and Cash Equivalents | $ 1,980 | $ 2,205 | $ 1,885 |
Supplemental Cash Flow Inform_3
Supplemental Cash Flow Information - Changes in non cash working capital (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Supplemental Cash Flow Information | ||
Accounts receivable | $ (1,750) | $ (1,324) |
Inventories | (1,128) | (551) |
Accounts payable and accrued liabilities | 1,512 | 1,588 |
Current portion of provisions | (286) | 235 |
Income taxes payable (net) | (717) | 1,830 |
Total (increase) decrease in non-cash working capital | (2,369) | 1,778 |
Relating to : | ||
(Increase) decrease in non-cash working capital | (2,421) | 1,507 |
Decrease in non-cash working capital | 52 | 271 |
Total (increase) decrease in non-cash working capital | $ (2,369) | $ 1,778 |
Supplemental Cash Flow Inform_4
Supplemental Cash Flow Information - Reconciliation of movements of liabilities to cash flows (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Short-Term Debt | ||
Reconciliation of movements of liabilities to cash flows arising from financing activities | ||
Liabilities arising from financing activities at beginning of period | $ 1,284 | $ 3,566 |
Changes from financing cash flows: | ||
(Reduction) Issuance of commercial paper | 1,473 | (2,256) |
Realized foreign exchange (gains) and losses | (19) | (79) |
Non-cash changes: | ||
Unrealized foreign exchange losses and (gains) | 69 | 53 |
Liabilities arising from financing activities at end of period | 2,807 | 1,284 |
Current Portion of Long-Term Lease Liabilities | ||
Reconciliation of movements of liabilities to cash flows arising from financing activities | ||
Liabilities arising from financing activities at beginning of period | 310 | 272 |
Changes from financing cash flows: | ||
Realized foreign exchange (gains) and losses | 15 | |
Lease liability payments | (329) | (325) |
Non-cash changes: | ||
Reclassification of lease obligations | 321 | 363 |
Liabilities arising from financing activities at end of period | 317 | 310 |
Long-Term Lease Liabilities | ||
Reconciliation of movements of liabilities to cash flows arising from financing activities | ||
Liabilities arising from financing activities at beginning of period | 2,540 | 2,636 |
Non-cash changes: | ||
Unrealized foreign exchange losses and (gains) | (25) | |
Lease derecognition | (22) | (41) |
Reclassification of lease obligations | (321) | (363) |
New lease liabilities | 523 | 308 |
Liabilities arising from financing activities at end of period | 2,695 | 2,540 |
Current Portion of Long-Term Debt | ||
Reconciliation of movements of liabilities to cash flows arising from financing activities | ||
Liabilities arising from financing activities at beginning of period | 231 | 1,413 |
Changes from financing cash flows: | ||
Repayment of long-term debt | (233) | (2,451) |
Loss on extinguishment of long-term debt | 80 | |
Realized foreign exchange (gains) and losses | 2 | 128 |
Other | 25 | |
Non-cash changes: | ||
Unrealized foreign exchange losses and (gains) | (47) | |
Reclassification of debt | 1,083 | |
Liabilities arising from financing activities at end of period | 0 | 231 |
Long-Term Debt | ||
Reconciliation of movements of liabilities to cash flows arising from financing activities | ||
Liabilities arising from financing activities at beginning of period | 13,989 | 13,812 |
Changes from financing cash flows: | ||
Gross proceeds from issuance of long-term debt | 1,446 | |
Debt issuance costs | (23) | |
Repayment of long-term debt | (4,895) | |
Loss on extinguishment of long-term debt | 32 | |
Realized foreign exchange (gains) and losses | (91) | |
Other | (13) | |
Non-cash changes: | ||
Unrealized foreign exchange losses and (gains) | 778 | (168) |
Reclassification of debt | (1,083) | |
Deferred financing costs | 5 | |
Liabilities arising from financing activities at end of period | 9,800 | 13,989 |
Partnership Liability | ||
Reconciliation of movements of liabilities to cash flows arising from financing activities | ||
Liabilities arising from financing activities at beginning of period | 427 | 436 |
Changes from financing cash flows: | ||
Distributions to non-controlling interest | (14) | (9) |
Non-cash changes: | ||
Liabilities arising from financing activities at end of period | 413 | 427 |
Dividends Payable | ||
Reconciliation of movements of liabilities to cash flows arising from financing activities | ||
Liabilities arising from financing activities at beginning of period | 0 | 0 |
Changes from financing cash flows: | ||
Dividends paid on common shares | (2,596) | 1,550 |
Non-cash changes: | ||
Dividends declared on common shares | 2,596 | (1,550) |
Liabilities arising from financing activities at end of period | $ 0 | $ 0 |
Inventories (Details)
Inventories (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Inventories | ||
Crude oil | $ 2,373 | $ 1,501 |
Refined products | 2,014 | 1,820 |
Materials, supplies and merchandise | 685 | 789 |
Reclassified to assets held for sale (note 33) | (14) | |
Total current inventories | 5,058 | 4,110 |
Crude oil held for trading purpose | 131 | 110 |
Product inventory expensed | $ 21,700 | $ 14,700 |
Property, Plant and Equipment -
Property, Plant and Equipment - Summary (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Changes in property, plant and equipment | ||
Beginning balance | $ 65,546 | |
Depreciation, depletion, amortization and impairment | (8,786) | $ (5,850) |
Ending balance | 62,654 | 65,546 |
Cost | ||
Changes in property, plant and equipment | ||
Beginning balance | 126,559 | 127,658 |
Additions | 5,410 | 4,656 |
Transfers from exploration and evaluation | 34 | |
Changes in decommissioning and restoration | 1,311 | (1,132) |
Disposals and derecognition | (1,469) | (4,554) |
Foreign exchange adjustments | 319 | (69) |
Reclassified to assets held for sale (note 33) | (4,955) | |
Ending balance | 127,209 | 126,559 |
Accumulated provision | ||
Changes in property, plant and equipment | ||
Beginning balance | (61,013) | (59,528) |
Depreciation, depletion, amortization and impairment | (8,396) | (5,681) |
Disposals and derecognition | 848 | 4,128 |
Foreign exchange adjustments | (167) | 68 |
Reclassified to assets held for sale (note 33) | 4,173 | |
Ending balance | (64,555) | (61,013) |
Oil and Gas Properties | ||
Changes in property, plant and equipment | ||
Beginning balance | 16,003 | |
Ending balance | 17,060 | 16,003 |
Oil and Gas Properties | Cost | ||
Changes in property, plant and equipment | ||
Beginning balance | 41,230 | 43,622 |
Additions | 1,149 | 755 |
Transfers from exploration and evaluation | 34 | |
Changes in decommissioning and restoration | 1,321 | (1,127) |
Disposals and derecognition | (585) | (1,902) |
Foreign exchange adjustments | 101 | (118) |
Reclassified to assets held for sale (note 33) | (4,475) | |
Ending balance | 38,775 | 41,230 |
Oil and Gas Properties | Accumulated provision | ||
Changes in property, plant and equipment | ||
Beginning balance | (25,227) | (25,757) |
Depreciation, depletion, amortization and impairment | (1,049) | (1,216) |
Disposals and derecognition | 510 | 1,676 |
Foreign exchange adjustments | (60) | 70 |
Reclassified to assets held for sale (note 33) | 4,111 | |
Ending balance | (21,715) | (25,227) |
Plant and Equipment | ||
Changes in property, plant and equipment | ||
Beginning balance | 49,543 | |
Ending balance | 45,594 | 49,543 |
Plant and Equipment | Cost | ||
Changes in property, plant and equipment | ||
Beginning balance | 85,329 | 84,036 |
Additions | 4,261 | 3,901 |
Changes in decommissioning and restoration | (10) | (5) |
Disposals and derecognition | (884) | (2,652) |
Foreign exchange adjustments | 218 | 49 |
Reclassified to assets held for sale (note 33) | (480) | |
Ending balance | 88,434 | 85,329 |
Plant and Equipment | Accumulated provision | ||
Changes in property, plant and equipment | ||
Beginning balance | (35,786) | (33,771) |
Depreciation, depletion, amortization and impairment | (7,347) | (4,465) |
Disposals and derecognition | 338 | 2,452 |
Foreign exchange adjustments | (107) | (2) |
Reclassified to assets held for sale (note 33) | 62 | |
Ending balance | $ (42,840) | $ (35,786) |
Property, Plant and Equipment_2
Property, Plant and Equipment - by segment (Details) - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 |
Property, Plant and Equipment | |||
Property, plant and equipment | $ 62,654 | $ 65,546 | |
Assets under construction and not subject to depreciation | 6,300 | 4,600 | |
Oil Sands | |||
Property, Plant and Equipment | |||
Property, plant and equipment | 47,313 | 49,878 | |
Exploration and Production | |||
Property, Plant and Equipment | |||
Property, plant and equipment | 5,181 | 5,496 | |
Refining and Marketing | |||
Property, Plant and Equipment | |||
Property, plant and equipment | 9,666 | 9,393 | |
Corporate and Eliminations | |||
Property, Plant and Equipment | |||
Property, plant and equipment | 494 | 779 | |
Cost | |||
Property, Plant and Equipment | |||
Property, plant and equipment | 127,209 | 126,559 | $ 127,658 |
Cost | Oil Sands | |||
Property, Plant and Equipment | |||
Property, plant and equipment | 92,601 | 87,849 | |
Cost | Exploration and Production | |||
Property, Plant and Equipment | |||
Property, plant and equipment | 16,541 | 21,495 | |
Cost | Refining and Marketing | |||
Property, Plant and Equipment | |||
Property, plant and equipment | 17,101 | 15,989 | |
Cost | Corporate and Eliminations | |||
Property, Plant and Equipment | |||
Property, plant and equipment | 966 | 1,226 | |
Accumulated provision | |||
Property, Plant and Equipment | |||
Property, plant and equipment | (64,555) | (61,013) | $ (59,528) |
Accumulated provision | Oil Sands | |||
Property, Plant and Equipment | |||
Property, plant and equipment | (45,288) | (37,971) | |
Accumulated provision | Exploration and Production | |||
Property, Plant and Equipment | |||
Property, plant and equipment | (11,360) | (15,999) | |
Accumulated provision | Refining and Marketing | |||
Property, Plant and Equipment | |||
Property, plant and equipment | (7,435) | (6,596) | |
Accumulated provision | Corporate and Eliminations | |||
Property, Plant and Equipment | |||
Property, plant and equipment | $ (472) | $ (447) |
Asset Impairments and Transac_2
Asset Impairments and Transactions - Fort Hills assets (Details) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Feb. 02, 2023 CAD ($) | Dec. 31, 2022 CAD ($) | Sep. 30, 2022 CAD ($) $ / bbl $ / bbl $ / $ | Dec. 31, 2021 CAD ($) bbl / d $ / bbl $ / bbl $ / $ | Sep. 30, 2022 CAD ($) $ / bbl | |
Sensitivity analysis increase In discount rate | |||||
Asset Impairments and Transactions | |||||
Impairment loss, net of tax | $ 200 | ||||
Fort Hills | |||||
Asset Impairments and Transactions | |||||
Recoverable amount of CGU net of tax | $ 2,800 | 2,800 | |||
Fort Hills | Sensitivity analysis, decrease in price | |||||
Asset Impairments and Transactions | |||||
Impairment loss, net of tax | $ 1,000 | ||||
Reasonably possible decrease in unobservable input (as a percent) | 5% | ||||
Fort Hills | Sensitivity analysis increase In discount rate | |||||
Asset Impairments and Transactions | |||||
Reasonably possible increase in unobservable input (as a percent) | 1% | ||||
Oil Sands | Fort Hills | |||||
Asset Impairments and Transactions | |||||
Acquisition price | $ 688 | ||||
Term of long-range plan | 3 years | ||||
Impairment loss, net of tax | $ 2,600 | ||||
Impairment loss | $ 0 | ||||
Reversal of impairment loss | $ 0 | ||||
Tax effect from asset impairment | $ 800 | ||||
Impairment testing assumption, foreign exchange rate | $ / $ | 0.76 | 0.80 | |||
Impairment testing assumption, risk-adjusted discount rate, after tax | 8.25% | 7.50% | 8.25% | ||
Recoverable amount of CGU net of tax | $ 5,500 | ||||
Oil Sands | Fort Hills | Minimum | |||||
Asset Impairments and Transactions | |||||
Impairment testing assumption, share of barrels per day of crude oil produced | 87,000 | 94,000 | |||
Impairment testing assumption, average cash operating costs per bbl | $ / bbl | 22 | ||||
Oil Sands | Fort Hills | Maximum | |||||
Asset Impairments and Transactions | |||||
Impairment testing assumption, share of barrels per day of crude oil produced | 106,000 | 111,000 | |||
Impairment testing assumption, average cash operating costs per bbl | $ / bbl | 25 | 23 | |||
Oil Sands | Fort Hills | Sensitivity analysis, decrease in price | |||||
Asset Impairments and Transactions | |||||
Impairment loss, net of tax | $ 1,000 | ||||
Reasonably possible decrease in unobservable input (as a percent) | 5% | ||||
Oil Sands | Fort Hills | Sensitivity analysis increase In discount rate | |||||
Asset Impairments and Transactions | |||||
Impairment loss, net of tax | $ 500 | ||||
Reasonably possible increase in unobservable input (as a percent) | 1% | ||||
Oil Sands | Fort Hills | Acquisition of Teck's interest in Fort Hills | |||||
Asset Impairments and Transactions | |||||
Percentage of ownership interests to be purchased under agreement | 21.3 | ||||
Amount of agreement to purchase business interests | $ 1,000 | ||||
Additional interest acquired (as a percent) | 14.65% | ||||
Ownership interest (as percent) | 68.76% | ||||
Oil Sands | Fort Hills | WCS | Forecast for 2022 | |||||
Asset Impairments and Transactions | |||||
Impairment testing assumption, price per barrel | $ / bbl | 55 | ||||
Oil Sands | Fort Hills | WCS | Forecast for 2023 | |||||
Asset Impairments and Transactions | |||||
Impairment testing assumption, price per barrel | $ / bbl | 69 | 54.57 | 69 | ||
Oil Sands | Fort Hills | WCS | Forecast for 2024 | |||||
Asset Impairments and Transactions | |||||
Impairment testing assumption, price per barrel | $ / bbl | 62 | 62 | |||
Oil Sands | Fort Hills | WCS | Forecast for 2024 to 2031 | |||||
Asset Impairments and Transactions | |||||
Impairment testing assumption, price per barrel | $ / bbl | 50.86 | ||||
Oil Sands | Fort Hills | WCS | Forecast for 2025 to 2031 | Average | |||||
Asset Impairments and Transactions | |||||
Impairment testing assumption, price per barrel | $ / bbl | 50 | 50 | |||
Oil Sands | Fort Hills | WCS | Forecast for 2032 to 2058 | |||||
Asset Impairments and Transactions | |||||
Impairment testing assumption, price per barrel escalation percentage | 2% | 2% | 2% | ||
TotalEnergies EP Canada Ltd. | Oil Sands | Fort Hills | |||||
Asset Impairments and Transactions | |||||
Percentage of ownership interests disallowed under rights of refusal | 6.65 |
Asset Impairments and Transac_3
Asset Impairments and Transactions - White Rose assets (Details) - Exploration and Production - White Rose $ in Millions | 3 Months Ended | |
Jun. 30, 2022 CAD ($) $ / bbl bbl / d | Mar. 31, 2022 | |
Asset Impairments and Transactions | ||
Additional interest acquired (as a percent) | 12.50% | |
Ownership interest (as percent) | 39% | 26% |
Cash received in transaction to acquire additional ownership interest | $ 38 | |
Tax effect of transaction to acquire additional ownership interest | 12 | |
Reversal of impairment loss, net of tax | 542 | |
Tax effect of the reversal of impairment loss | 173 | |
Company's share of future capital expenditures | $ 1,500 | |
Impairment testing assumption, risk-adjusted discount rate, after tax | 9% | |
Forecast for the first half of 2026 | ||
Asset Impairments and Transactions | ||
Impairment testing assumption, share of barrels per day of crude oil produced | bbl / d | 9,800 | |
Brent crude oil | Forecast for 2023 | ||
Asset Impairments and Transactions | ||
Impairment testing assumption, price per barrel | $ / bbl | 85 | |
Brent crude oil | Forecast for 2024 | ||
Asset Impairments and Transactions | ||
Impairment testing assumption, price per barrel | $ / bbl | 68 | |
Brent crude oil | Forecast for 2025 | ||
Asset Impairments and Transactions | ||
Impairment testing assumption, price per barrel | $ / bbl | 69 | |
Brent crude oil | Forecast for 2026 to 2038 | ||
Asset Impairments and Transactions | ||
Impairment testing assumption, price per barrel escalation percentage | 2% |
Asset Impairments and Transac_4
Asset Impairments and Transactions - Norway assets (Details) - Exploration and Production - Norway - CAD ($) $ in Millions | 3 Months Ended | |
Sep. 30, 2022 | Jun. 30, 2022 | |
Asset Impairments and Transactions | ||
Consideration received, net of cash disposed | $ 297 | |
Cash disposed | 133 | |
Loss on sale of ownership interest | $ 65 | |
Impairment loss, net of tax | $ 47 | |
Tax effect of impairment loss | $ 23 | |
Oda | ||
Asset Impairments and Transactions | ||
Proportion of ownership interest in joint operation sold during the period | 30% | |
Fenja Development | ||
Asset Impairments and Transactions | ||
Proportion of ownership interest in joint operation sold during the period | 17.50% |
Asset Impairments and Transac_5
Asset Impairments and Transactions -Terra Nova (Details) - Exploration and Production - Terra Nova $ in Millions | 3 Months Ended | 6 Months Ended | |
Sep. 30, 2021 CAD ($) $ / bbl bbl / d | Jun. 30, 2021 | Jun. 30, 2021 | |
Asset Impairments and Transactions | |||
Ownership interest (as percent) | 48% | 38% | 38% |
Consideration received, net of tax | $ 26 | ||
Tax effect of consideration received | $ 8 | ||
Additional interest acquired (as a percent) | 10% | ||
Reversal of impairment loss, net of tax | $ 168 | ||
Tax effect of the reversal of impairment loss | $ 53 | ||
Impairment testing assumption, risk-adjusted discount rate, after tax | 9% | ||
Recoverable amount of CGU | $ 177 | ||
Forecast for the life of the project | |||
Asset Impairments and Transactions | |||
Impairment testing assumption, share of barrels per day of crude oil produced | bbl / d | 6,000 | ||
Brent crude oil | Forecast for 2023 | |||
Asset Impairments and Transactions | |||
Impairment testing assumption, price per barrel | $ / bbl | 65 | ||
Brent crude oil | Forecast for 2024 | |||
Asset Impairments and Transactions | |||
Impairment testing assumption, price per barrel | $ / bbl | 68 | ||
Brent crude oil | Forecast for 2025 to 2033 | |||
Asset Impairments and Transactions | |||
Impairment testing assumption, price per barrel escalation percentage | 2% |
Asset Impairments and Transac_6
Asset Impairments and Transactions -United Kingdom (Details) $ in Millions, $ in Millions | 3 Months Ended | 12 Months Ended | |
Dec. 31, 2021 USD ($) | Dec. 31, 2021 CAD ($) | Dec. 31, 2022 USD ($) | |
Asset Impairments and Transactions | |||
Gross proceeds from sale of assets, net of closing adjustments and other closing costs | $ 250 | ||
Golden Eagle Area Development | |||
Asset Impairments and Transactions | |||
Ownership interest sold (as percent) | 26.69% | 26.69% | |
Disposed of by sale, U.K. Operations | Golden Eagle Area Development | |||
Asset Impairments and Transactions | |||
Ownership interest sold (as percent) | 26.69% | 26.69% | |
Gain on sale of business interests, net of tax | $ 227 | ||
Contingent consideration recognized | $ 50 |
Right-of-Use Assets and Lease_2
Right-of-Use Assets and Leases - ROU assets within Property, Plant and Equipment (Details) - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 |
Right-of-Use Assets and Leases | ||
Property, plant and equipment, net | $ 62,654 | $ 65,546 |
Property, plant and equipment, net - excluding ROU assets | ||
Right-of-Use Assets and Leases | ||
Property, plant and equipment, net | 59,778 | 62,821 |
ROU assets | ||
Right-of-Use Assets and Leases | ||
Property, plant and equipment, net | $ 2,876 | $ 2,725 |
Right-of-Use Assets and Lease_3
Right-of-Use Assets and Leases - ROU assets by asset class (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Changes in ROU assets: | ||
Beginning balance | $ 65,546 | |
Ending balance | 62,654 | $ 65,546 |
Cost | ||
Changes in ROU assets: | ||
Beginning balance | 126,559 | 127,658 |
Additions and adjustments | 5,410 | 4,656 |
Foreign exchange | 319 | (69) |
Ending balance | 127,209 | 126,559 |
Accumulated provision | ||
Changes in ROU assets: | ||
Beginning balance | (61,013) | (59,528) |
Foreign exchange | (167) | 68 |
Ending balance | (64,555) | (61,013) |
ROU assets | ||
Changes in ROU assets: | ||
Beginning balance | 2,725 | |
Ending balance | 2,876 | 2,725 |
ROU assets | Cost | ||
Changes in ROU assets: | ||
Beginning balance | 3,861 | 3,786 |
Additions and adjustments | 523 | 307 |
Disposals | (156) | (232) |
Foreign exchange | 20 | |
Ending balance | 4,248 | 3,861 |
ROU assets | Accumulated provision | ||
Changes in ROU assets: | ||
Beginning balance | (1,136) | (962) |
Depreciation | (356) | (396) |
Disposals | 126 | 221 |
Foreign exchange | 6 | 1 |
Ending balance | $ (1,372) | $ (1,136) |
Right-of-Use Assets and Lease_4
Right-of-Use Assets and Leases - Other Lease Disclosures (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Right-of-Use Assets and Leases | ||
Leases with residual value guarantees | $ 0 | $ 0 |
Cash outflow for leases | $ 496 | $ 486 |
Exploration and Evaluation As_3
Exploration and Evaluation Assets (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Exploration and Evaluation Assets | ||
Beginning balance | $ 631 | $ 436 |
Ending balance | 694 | 631 |
Exploration and Evaluation Assets | ||
Exploration and Evaluation Assets | ||
Beginning balance | 2,226 | 2,286 |
Acquisitions and additions | 41 | 2 |
Transfers to oil and gas assets | (34) | |
Disposals and derecognition | (54) | |
Reclassified to assets held for sale (note 33) | (239) | |
Foreign exchange adjustments | 1 | (8) |
Ending balance | $ 1,995 | $ 2,226 |
Other Assets (Details)
Other Assets (Details) - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 |
Other Assets | ||
Investments | $ 758 | $ 391 |
Prepaids and other | 796 | 916 |
Pension (note 23) | 212 | |
Other assets | $ 1,766 | $ 1,307 |
Goodwill and Other Intangible_3
Goodwill and Other Intangible Assets - Changes (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Other Intangibles | ||
Beginning balance | $ 631 | $ 436 |
Additions | 140 | 213 |
Amortization | (57) | (18) |
Reclassified to assets held for sale (note 33) | (20) | |
Ending balance | 694 | 631 |
Total | ||
Beginning balance | 3,523 | 3,328 |
Additions | 140 | 213 |
Amortization | (57) | (18) |
Reclassified to assets held for sale (note 33) | (20) | |
Ending balance | 3,586 | 3,523 |
Oil Sands | ||
Goodwill | ||
Beginning balance | 2,752 | 2,752 |
Additions | ||
Ending balance | 2,752 | 2,752 |
Refining and Marketing | ||
Goodwill | ||
Beginning balance | 140 | 140 |
Additions | ||
Ending balance | $ 140 | $ 140 |
Goodwill and Other Intangible_4
Goodwill and Other Intangible Assets - Goodwill Impairment (Details) - Oil Sands - CGU-Asset impairment testing - $ / bbl | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Goodwill and Other Intangible Assets | ||
After-tax discount rate applied to cash flow projections | 7.80% | 7.50% |
Cash flow forecast period | P50Y | |
Maximum | ||
Goodwill and Other Intangible Assets | ||
Cash flow forecast period | P55Y | |
Forecast for after 2025 | ||
Goodwill and Other Intangible Assets | ||
Impairment testing assumption, price per barrel escalation percentage | 2% | |
WTI | Forecast for 2022 | ||
Goodwill and Other Intangible Assets | ||
Impairment testing assumption, price per barrel | 80 | |
WTI | Forecast for 2023 | ||
Goodwill and Other Intangible Assets | ||
Impairment testing assumption, price per barrel | 71.40 | |
WTI | Forecast for 2024 | ||
Goodwill and Other Intangible Assets | ||
Impairment testing assumption, price per barrel | 62.42 |
Debt and Credit Facilities - Sh
Debt and Credit Facilities - Short-Term Debt (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Debt and Credit Facilities | ||
Short-term debt | $ 2,807 | $ 1,284 |
Interest rate | 5.20% | 5% |
Commercial paper | ||
Debt and Credit Facilities | ||
Short-term debt | $ 2,807 | $ 1,284 |
Commercial paper | Maximum | ||
Debt and Credit Facilities | ||
Commercial paper authorized to be issued | $ 5,000 | $ 5,000 |
Term of debt | 365 days | 365 days |
Commercial paper | Weighted average | ||
Debt and Credit Facilities | ||
Interest rate | 4.93% | 0.33% |
Debt and Credit Facilities - Lo
Debt and Credit Facilities - Long-Term Debt (Details) $ / shares in Units, $ / shares in Units, $ in Millions, $ in Millions | 3 Months Ended | |||||||||||||||
Dec. 31, 2022 USD ($) | Dec. 31, 2022 CAD ($) | Jun. 30, 2022 USD ($) | Dec. 31, 2021 USD ($) | Dec. 31, 2021 CAD ($) | Sep. 30, 2021 USD ($) | Sep. 30, 2021 CAD ($) | Mar. 31, 2021 USD ($) | Mar. 31, 2021 CAD ($) | Dec. 31, 2022 CAD ($) | Mar. 31, 2022 USD ($) | Dec. 31, 2021 CAD ($) | Sep. 30, 2021 CAD ($) | Mar. 31, 2021 CAD ($) | Mar. 04, 2021 USD ($) $ / shares | Mar. 04, 2021 CAD ($) $ / shares | |
Debt and Credit Facilities | ||||||||||||||||
Interest rate | 5.20% | 5% | 5.20% | 5% | ||||||||||||
Lease liabilities | $ 3,012 | $ 2,850 | ||||||||||||||
Deferred financing costs | (40) | (58) | ||||||||||||||
Total gross debt and lease liabilities | 12,812 | 17,070 | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Current portion of lease liabilities | (317) | (310) | ||||||||||||||
Current portion of long-term debt | (231) | |||||||||||||||
Current portion of long-term debt and lease liabilities | (317) | (541) | ||||||||||||||
Long-term lease liabilities | 2,695 | 2,540 | ||||||||||||||
Long-term debt | $ 9,800 | 13,989 | ||||||||||||||
Minimum | ||||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Interest rate on lease liabilities | 0.40% | 0.40% | ||||||||||||||
Maximum | ||||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Interest rate on lease liabilities | 13.40% | 13.40% | ||||||||||||||
Unsecured long-term debt | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Total unsecured long term debt | $ 9,840 | $ 14,278 | ||||||||||||||
4.50% Notes, due 2022 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 182 | |||||||||||||||
Interest rate | 4.50% | 4.50% | ||||||||||||||
Total unsecured long term debt | $ 231 | |||||||||||||||
2.80% Notes, due 2023 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 450 | |||||||||||||||
Interest rate | 2.80% | 2.80% | ||||||||||||||
Total unsecured long term debt | $ 569 | |||||||||||||||
3.10% Notes, due 2025 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 550 | |||||||||||||||
Interest rate | 3.10% | 3.10% | ||||||||||||||
Total unsecured long term debt | $ 696 | |||||||||||||||
3.00% Series 5 Medium Term Notes, due 2026 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Interest rate | 3% | 3% | 3% | 3% | ||||||||||||
Total unsecured long term debt | $ 115 | $ 699 | ||||||||||||||
7.875% Debentures, due 2026 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 275 | $ 275 | ||||||||||||||
Interest rate | 7.875% | 7.875% | 7.875% | 7.875% | ||||||||||||
Total unsecured long term debt | $ 381 | $ 359 | ||||||||||||||
8.20% Notes, due 2027 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 59 | $ 59 | ||||||||||||||
Interest rate | 8.20% | 8.20% | 8.20% | 8.20% | ||||||||||||
Total unsecured long term debt | $ 61 | $ 78 | ||||||||||||||
7.00% Debentures, due 2028 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 250 | $ 250 | ||||||||||||||
Interest rate | 7% | 7% | 7% | 7% | ||||||||||||
Total unsecured long term debt | $ 342 | $ 320 | ||||||||||||||
3.10% Series 6 Medium Term Notes, due 2029 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Interest rate | 3.10% | 3.10% | 3.10% | 3.10% | ||||||||||||
Total unsecured long term debt | $ 79 | $ 748 | ||||||||||||||
5.00% Series 7 Medium Term Notes, Due 2030 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Interest rate | 5% | 5% | 5% | 5% | ||||||||||||
Total unsecured long term debt | $ 154 | $ 1,247 | ||||||||||||||
7.15% Notes, due 2032 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 500 | $ 500 | ||||||||||||||
Interest rate | 7.15% | 7.15% | 7.15% | 7.15% | ||||||||||||
Total unsecured long term debt | $ 676 | $ 631 | ||||||||||||||
5.35% Notes, due 2033 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 300 | $ 300 | ||||||||||||||
Interest rate | 5.35% | 5.35% | 5.35% | 5.35% | ||||||||||||
Total unsecured long term debt | $ 161 | $ 355 | ||||||||||||||
5.95% Notes, due 2034 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 500 | $ 500 | ||||||||||||||
Interest rate | 5.95% | 5.95% | 5.95% | 5.95% | ||||||||||||
Total unsecured long term debt | $ 675 | $ 630 | ||||||||||||||
5.95% Notes, due 2035 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 600 | $ 600 | ||||||||||||||
Interest rate | 5.95% | 5.95% | 5.95% | 5.95% | ||||||||||||
Total unsecured long term debt | $ 268 | $ 731 | ||||||||||||||
5.39% Series 4 Medium Term Notes, due 2037 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Interest rate | 5.39% | 5.39% | 5.39% | 5.39% | ||||||||||||
Total unsecured long term debt | $ 279 | $ 599 | ||||||||||||||
6.50% Notes, due 2038 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 1,150 | $ 1,150 | ||||||||||||||
Interest rate | 6.50% | 6.50% | 6.50% | 6.50% | ||||||||||||
Total unsecured long term debt | $ 1,553 | $ 1,451 | ||||||||||||||
6.80% Notes, due 2038 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 900 | $ 900 | ||||||||||||||
Interest rate | 6.80% | 6.80% | 6.80% | 6.80% | ||||||||||||
Total unsecured long term debt | $ 1,235 | $ 1,156 | ||||||||||||||
6.85% Notes, due 2039 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 750 | $ 750 | ||||||||||||||
Interest rate | 6.85% | 6.85% | 6.85% | 6.85% | ||||||||||||
Total unsecured long term debt | $ 1,013 | $ 946 | ||||||||||||||
6.00% Notes, due 2042 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 152 | $ 152 | ||||||||||||||
Interest rate | 6% | 6% | 6% | 6% | ||||||||||||
Total unsecured long term debt | $ 35 | $ 149 | ||||||||||||||
4.34% Series 5 Medium Term Notes, due 2046 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Interest rate | 4.34% | 4.34% | 4.34% | 4.34% | ||||||||||||
Total unsecured long term debt | $ 300 | $ 300 | ||||||||||||||
4.00% Notes, due 2047 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 750 | $ 750 | ||||||||||||||
Interest rate | 4% | 4% | 4% | 4% | ||||||||||||
Total unsecured long term debt | $ 1,011 | $ 945 | ||||||||||||||
3.95% Series 8 Medium Term Notes, due 2051 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Interest rate | 3.95% | 3.95% | 3.95% | 3.95% | ||||||||||||
Total unsecured long term debt | $ 493 | $ 493 | ||||||||||||||
3.75% Notes, due 2051 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 750 | $ 750 | ||||||||||||||
Interest rate | 3.75% | 3.75% | 3.75% | 3.75% | ||||||||||||
Total unsecured long term debt | $ 1,009 | $ 945 | ||||||||||||||
Debt tender offer | Unsecured long-term debt | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | 3,600 | |||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Debt discount at repayment date | 51 | |||||||||||||||
Non-cash charges related to accelerated amortization | $ 83 | |||||||||||||||
Loss on extinguishment of long-term debt | 32 | |||||||||||||||
Debt tender offer | 3.00% Series 5 Medium Term Notes, due 2026 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 700 | |||||||||||||||
Interest rate | 3% | 3% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Repayment of notes | 585 | |||||||||||||||
Debt tender offer | 8.20% Notes, due 2027 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 59 | |||||||||||||||
Interest rate | 8.20% | 8.20% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Repayment of notes | $ 16 | |||||||||||||||
Debt tender offer | 3.10% Series 6 Medium Term Notes, due 2029 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 750 | |||||||||||||||
Interest rate | 3.10% | 3.10% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Repayment of notes | 671 | |||||||||||||||
Debt tender offer | 5.00% Series 7 Medium Term Notes, Due 2030 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 1,300 | |||||||||||||||
Interest rate | 5% | 5% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Repayment of notes | 1,100 | |||||||||||||||
Debt tender offer | 5.35% Notes, due 2033 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 300 | |||||||||||||||
Interest rate | 5.35% | 5.35% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Repayment of notes | $ 178 | |||||||||||||||
Debt tender offer | 5.95% Notes, due 2035 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 600 | |||||||||||||||
Interest rate | 5.95% | 5.95% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Repayment of notes | $ 401 | |||||||||||||||
Debt tender offer | 6.00% Notes, due 2042 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 142 | |||||||||||||||
Interest rate | 6% | 6% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Repayment of notes | $ 110 | |||||||||||||||
Debt tender offer | 5.00% Series 4 Medium Term Notes, due 2037 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 600 | |||||||||||||||
Interest rate | 5.39% | 5.39% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Repayment of notes | $ 321 | |||||||||||||||
Early redemption of notes | 4.50% Notes, due 2022 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 182 | |||||||||||||||
Interest rate | 4.50% | |||||||||||||||
Early redemption of notes | 2.80% Notes, due 2023 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 450 | |||||||||||||||
Interest rate | 2.80% | |||||||||||||||
Early redemption of notes | 3.10% Notes, due 2025 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 550 | |||||||||||||||
Interest rate | 3.10% | |||||||||||||||
Early redemption of notes | 6.00% Notes, due 2042 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 152 | |||||||||||||||
Interest rate | 6% | |||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Repayment of notes | $ 10.2 | |||||||||||||||
Early redemption of notes | 3.10% Series 5 Medium Term Notes, due 2021 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 750 | |||||||||||||||
Interest rate | 3.10% | 3.10% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Repayment of notes | $ 770 | |||||||||||||||
Accrued interest | $ 8 | |||||||||||||||
Loss on extinguishment of long-term debt | 12 | |||||||||||||||
Loss on debt extinguishment, net of tax | 9 | |||||||||||||||
Early redemption of notes | 9.40% Notes, due 2021 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 220 | |||||||||||||||
Interest rate | 9.40% | 9.40% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Book value of debt repaid | 278 | |||||||||||||||
Repayment of notes | $ 230 | 290 | ||||||||||||||
Accrued interest | $ 2 | $ 2 | ||||||||||||||
Loss on extinguishment of long-term debt | 10 | |||||||||||||||
Loss on debt extinguishment, net of tax | $ 8 | |||||||||||||||
Early redemption of notes | 3.60% Notes, due 2024 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 750 | |||||||||||||||
Interest rate | 3.60% | 3.60% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Book value of debt repaid | $ 951 | |||||||||||||||
Repayment of notes | $ 822 | 1,000 | ||||||||||||||
Accrued interest | $ 9 | $ 11 | ||||||||||||||
Loss on extinguishment of long-term debt | 80 | |||||||||||||||
Loss on debt extinguishment, net of tax | $ 60 | |||||||||||||||
Repayment of senior unsecured notes | 9.25% Debentures, due 2021 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 300 | |||||||||||||||
Interest rate | 9.25% | 9.25% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Book value of debt repaid | $ 371 | |||||||||||||||
Repayment of notes | $ 314 | $ 388 | ||||||||||||||
Accrued interest | $ 14 | $ 17 | ||||||||||||||
Issuance of senior unsecured notes | 3.95% Series 8 Medium Term Notes, due 2051 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 500 | |||||||||||||||
Interest rate | 3.95% | 3.95% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Issuance price per $100 principal amount | $ / shares | $ 98.546 | |||||||||||||||
Effective yield | 4.034% | 4.034% | ||||||||||||||
Issuance of senior unsecured notes | 3.75% Notes, due 2051 | ||||||||||||||||
Debt and Credit Facilities | ||||||||||||||||
Principal amount of debt | $ 750 | |||||||||||||||
Interest rate | 3.75% | 3.75% | ||||||||||||||
Current portion of longterm debt and lease liabilities | ||||||||||||||||
Issuance price per $100 principal amount | $ / shares | $ 99.518 | |||||||||||||||
Effective yield | 3.777% | 3.777% |
Debt and Credit Facilities - Sc
Debt and Credit Facilities - Scheduled Debt Repayments (Details) $ in Millions | Dec. 31, 2022 CAD ($) |
Debt and Credit Facilities | |
Scheduled principal repayments for lease liabilities, short-term debt and long-term debt | $ 15,665 |
2023 | |
Debt and Credit Facilities | |
Scheduled principal repayments for lease liabilities, short-term debt and long-term debt | 3,124 |
2024 | |
Debt and Credit Facilities | |
Scheduled principal repayments for lease liabilities, short-term debt and long-term debt | 264 |
2025 | |
Debt and Credit Facilities | |
Scheduled principal repayments for lease liabilities, short-term debt and long-term debt | 241 |
2026 | |
Debt and Credit Facilities | |
Scheduled principal repayments for lease liabilities, short-term debt and long-term debt | 691 |
2027 | |
Debt and Credit Facilities | |
Scheduled principal repayments for lease liabilities, short-term debt and long-term debt | 244 |
Thereafter | |
Debt and Credit Facilities | |
Scheduled principal repayments for lease liabilities, short-term debt and long-term debt | $ 11,101 |
Debt and Credit Facilities - Cr
Debt and Credit Facilities - Credit Facilities (Details) - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 |
Debt and Credit Facilities | ||
Credit facilities available | $ 7,227 | |
Credit facilities supporting outstanding commercial paper | (2,807) | |
Credit facilities supporting standby letters of credit | (1,148) | |
Total unutilized credit facilities | 3,272 | |
Available lines of credit for liquidity purposes | 2,900 | $ 4,247 |
Fully revolving and expires in 2026 | ||
Debt and Credit Facilities | ||
Credit facilities available | 3,000 | |
Fully revolving and expires in 2025 | ||
Debt and Credit Facilities | ||
Credit facilities available | 2,707 | |
Can be terminated at any time at the option of the lenders | ||
Debt and Credit Facilities | ||
Credit facilities available | $ 1,520 |
Other Long Term Liabilities (De
Other Long Term Liabilities (Details) $ in Millions, $ in Millions | 12 Months Ended | ||
Dec. 31, 2022 CAD ($) | Dec. 31, 2021 CAD ($) | Dec. 31, 2009 USD ($) agreement | |
Other Long Term Liabilities | |||
Pensions and other post-retirement benefits | $ 564 | $ 1,207 | |
Share-based compensation plans | 469 | 291 | |
Partnership liability | 413 | 427 | |
Deferred revenue | 22 | 29 | |
Libya Exploration and Production Sharing Agreement (EPSA) signature bonus | 80 | 74 | |
Other | 94 | 152 | |
Other long term liabilities | 1,642 | 2,180 | |
Distribution to partners | 60 | 60 | |
Distribution to partners, interest component | 51 | 51 | |
Distribution to partners, principal component | 9 | 9 | |
Petro Canada | |||
Other Long Term Liabilities | |||
Number of EPSA's agreement ratified | agreement | 6 | ||
Signature bonus | 85 | 78 | $ 500 |
Signature bonus current | $ 5 | $ 4 |
Pensions and Other Post Retir_3
Pensions and Other Post Retirement Benefits (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Changes | ||
Net surplus / (unfunded) obligation at end of year | $ (390) | $ (1,274) |
Minimum | ||
Pensions and Other Post Retirement Benefits | ||
Defined contribution plans annual contribution (as a percent) | 5% | |
Maximum | ||
Pensions and Other Post Retirement Benefits | ||
Defined contribution plans annual contribution (as a percent) | 11.50% | |
Pension and Other Post Retirement Benefits | Canada | ||
Changes | ||
Percentage of net unfunded obligations | 96% | 98% |
Pension and Other Post Retirement Benefits | Canada | Weighted average | ||
Changes | ||
Weighted average duration of defined benefit obligation | 16 years 4 months 24 days | 15 years 1 month 6 days |
Pension Benefits | ||
Changes | ||
Current service costs | $ 263 | $ 302 |
Actuarial remeasurement: Experience (gain) loss arising on plan liabilities | (86) | (1) |
Actuarial remeasurement: Actuarial gain arising from changes in demographic assumptions | (2) | |
Actuarial remeasurement: Actuarial gain arising from changes in financial assumptions | (2,229) | (572) |
Return on plan assets greater / (less) than discount rate | (1,190) | 530 |
Effect of the asset ceiling | 187 | |
Pension Benefits | Obligations | ||
Changes | ||
Balance at beginning of year | 8,303 | 8,682 |
Current service costs | 263 | 302 |
Plan participants' contributions | (17) | (17) |
Benefits paid | 367 | 350 |
Interest costs (income) | 246 | 222 |
Foreign exchange | (2) | (6) |
Settlements | 10 | 11 |
Actuarial remeasurement: Experience (gain) loss arising on plan liabilities | (86) | (1) |
Actuarial remeasurement: Actuarial gain arising from changes in demographic assumptions | (2) | |
Actuarial remeasurement: Actuarial gain arising from changes in financial assumptions | (2,229) | (572) |
Balance at end of year | 6,155 | 8,303 |
Pension Benefits | Plan assets | ||
Changes | ||
Balance at beginning of year | (7,701) | (7,305) |
Employer contributions | 61 | (11) |
Plan participants' contributions | 17 | 17 |
Benefits paid | (347) | (325) |
Interest costs (income) | (225) | (181) |
Foreign exchange | 4 | 5 |
Settlements | (10) | (11) |
Administrative costs | (2) | (2) |
Return on plan assets greater / (less) than discount rate | (1,190) | 530 |
Balance at end of year | (6,471) | (7,701) |
Net surplus / (unfunded) obligation at end of year | 129 | (602) |
Pension Benefits | Irrecoverable surplus | ||
Changes | ||
Effect of the asset ceiling | 187 | |
Other Post-Retirement Benefits | ||
Changes | ||
Current service costs | 19 | 19 |
Actuarial remeasurement: Experience (gain) loss arising on plan liabilities | 3 | (1) |
Actuarial remeasurement: Actuarial gain arising from changes in financial assumptions | (167) | (27) |
Other Post-Retirement Benefits | Obligations | ||
Changes | ||
Balance at beginning of year | 672 | 690 |
Current service costs | 19 | 19 |
Benefits paid | 28 | 27 |
Interest costs (income) | 20 | 18 |
Actuarial remeasurement: Experience (gain) loss arising on plan liabilities | 3 | (1) |
Actuarial remeasurement: Actuarial gain arising from changes in financial assumptions | (167) | (27) |
Balance at end of year | 519 | 672 |
Other Post-Retirement Benefits | Plan assets | ||
Changes | ||
Net surplus / (unfunded) obligation at end of year | $ (519) | $ (672) |
Pensions and Other Post Retir_4
Pensions and Other Post Retirement Benefits - Defined benefit asset (liability) (Details) - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 |
Pensions and Other Post Retirement Benefits | ||
Other assets (note 19) | $ 212 | |
Accounts payable and accrued liabilities | (38) | $ (67) |
Other long-term liabilities (note 22) | (564) | (1,207) |
Defined benefit asset (liability) | $ (390) | $ (1,274) |
Pensions and Other Post Retir_5
Pensions and Other Post Retirement Benefits - Expenses (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Pension Benefits | ||
Analysis of amount charged to earnings: | ||
Current service costs | $ 263 | $ 302 |
Interest cost | 21 | 41 |
Defined benefit plans expense | 284 | 343 |
Defined contribution plans expense | 95 | 94 |
Total benefit plans expense charged to earnings | 379 | 437 |
Components of defined benefit costs recognized in Other Comprehensive Income: | ||
Actuarial (gain) / loss arising from changes in experience | (86) | (1) |
Actuarial gain arising from changes in financial assumptions | (2,229) | (572) |
Actuarial gain arising from changes in demographic assumptions | (2) | |
Benefit Obligation gains | (2,315) | (575) |
Return on plan assets greater / (less) than discount rate (excluding amounts included in net interest expense) | 1,190 | (530) |
Effect of the asset ceiling | 187 | |
Plan assets loss / (gain) | 1,377 | (530) |
Actuarial gain recognized in other comprehensive income | (938) | (1,105) |
Other Post-Retirement Benefits | ||
Analysis of amount charged to earnings: | ||
Current service costs | 19 | 19 |
Interest cost | 20 | 18 |
Defined benefit plans expense | 39 | 37 |
Total benefit plans expense charged to earnings | 39 | 37 |
Components of defined benefit costs recognized in Other Comprehensive Income: | ||
Actuarial (gain) / loss arising from changes in experience | 3 | (1) |
Actuarial gain arising from changes in financial assumptions | (167) | (27) |
Benefit Obligation gains | (164) | (28) |
Actuarial gain recognized in other comprehensive income | $ (164) | $ (28) |
Pensions and Other Post Retir_6
Pensions and Other Post Retirement Benefits - Actuarial assumptions (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Pensions and Other Post Retirement Benefits | ||
Actual experience period | 5 years | |
Pension Benefits | ||
Pensions and Other Post Retirement Benefits | ||
Discount rate | 5.10% | 2.90% |
Rate of compensation increase | 3% | 3% |
Pension Benefits | Discount rate | ||
Pensions and Other Post Retirement Benefits | ||
Increase in actuarial assumption (as a percent) | 1% | |
Increase (decrease) in interest and service cost due to increase in actuarial assumption | $ (25) | |
Increase (decrease) in service and interest cost due to decrease in actuarial assumption | 32 | |
Increase (decrease) in net obligation due to increase in actuarial assumption | (693) | |
Increase (decrease) in net obligation due to decrease in actuarial assumption | $ 871 | |
Other Post-Retirement Benefits | ||
Pensions and Other Post Retirement Benefits | ||
Discount rate | 5.10% | 2.90% |
Rate of compensation increase | 3% | 3% |
Assumption of annual percentage of increase of healthcare costs | 5% | |
Other Post-Retirement Benefits | Discount rate | ||
Pensions and Other Post Retirement Benefits | ||
Increase in actuarial assumption (as a percent) | 1% | |
Increase (decrease) in net obligation due to increase in actuarial assumption | $ (53) | |
Increase (decrease) in net obligation due to decrease in actuarial assumption | $ 64 | |
Other Post-Retirement Benefits | Health care cost | ||
Pensions and Other Post Retirement Benefits | ||
Increase in actuarial assumption (as a percent) | 1% | |
Increase (decrease) in interest and service cost due to increase in actuarial assumption | $ 1 | |
Increase (decrease) in service and interest cost due to decrease in actuarial assumption | (1) | |
Increase (decrease) in net obligation due to increase in actuarial assumption | 27 | |
Increase (decrease) in net obligation due to decrease in actuarial assumption | $ (23) |
Pensions and Other Post Retir_7
Pensions and Other Post Retirement Benefits - Plan Assets and Investment Objectives (Details) | Dec. 31, 2022 | Dec. 31, 2021 |
Weighted average pension plan asset allocations | ||
Equities | 52% | 48% |
Fixed income | 27% | 38% |
Plan assets comprised of: - Real estate | 21% | 14% |
Total plan assets | 100% | 100% |
Provisions - Changes (Details)
Provisions - Changes (Details) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 CAD ($) | Dec. 31, 2021 CAD ($) | |
Provisions | ||
Beginning balance | $ 9,555 | $ 10,582 |
Liabilities incurred | 206 | 412 |
Change in discount rate | (2,456) | (1,260) |
Changes in estimates | 3,661 | (101) |
Liabilities settled | (771) | (321) |
Accretion | 316 | 304 |
Asset disposals | 62 | |
Reclassified to assets held for sale (note 33) | (226) | |
Foreign exchange | 17 | (61) |
Ending balance | 10,364 | 9,555 |
Increase in estimated discounted cash flows | 3,600 | |
Restructuring provision | 11 | 88 |
Pipeline project provision | 187 | |
Pipeline project provision after tax | 142 | |
Decommissioning and restoration provision | ||
Provisions | ||
Beginning balance | 8,792 | 10,044 |
Liabilities incurred | 114 | 104 |
Change in discount rate | (2,456) | (1,260) |
Changes in estimates | 3,596 | (76) |
Liabilities settled | (314) | (263) |
Accretion | 316 | 304 |
Asset disposals | 62 | |
Reclassified to assets held for sale (note 33) | (226) | |
Foreign exchange | 17 | (61) |
Ending balance | 9,901 | 8,792 |
Total undiscounted amount of estimated future cash flows required | $ 22,400 | $ 13,800 |
Weighted average credit adjusted risk free interest rate | 5.50 | 3.70 |
Decommissioning and restoration provision settlement term | 50 years | 50 years |
Royalties | ||
Provisions | ||
Beginning balance | $ 222 | $ 71 |
Liabilities incurred | 89 | 137 |
Changes in estimates | (4) | (12) |
Liabilities settled | (125) | 26 |
Ending balance | 182 | 222 |
Other | ||
Provisions | ||
Beginning balance | 541 | 467 |
Liabilities incurred | 3 | 171 |
Changes in estimates | 69 | (13) |
Liabilities settled | (332) | (84) |
Ending balance | $ 281 | $ 541 |
Provisions - By classification
Provisions - By classification (Details) - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 |
Provisions | |||
Current provisions | $ 564 | $ 779 | |
Non-current provisions | 9,800 | 8,776 | |
Total provisions | 10,364 | 9,555 | $ 10,582 |
Decommissioning and restoration provision | |||
Provisions | |||
Current provisions | 337 | 266 | |
Non-current provisions | 9,564 | 8,526 | |
Total provisions | 9,901 | 8,792 | 10,044 |
Royalties | |||
Provisions | |||
Current provisions | 182 | 222 | |
Total provisions | 182 | 222 | 71 |
Other | |||
Provisions | |||
Current provisions | 45 | 291 | |
Non-current provisions | 236 | 250 | |
Total provisions | $ 281 | $ 541 | $ 467 |
Provisions - Sensitivities (Det
Provisions - Sensitivities (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Provisions | ||
Percentage change in discount rate used to arrive at provision for decommissioning, restoration and rehabilitation costs | 1% | 1% |
1% Increase | $ (1,594) | $ (1,497) |
1% Decrease | $ 2,131 | $ 2,113 |
Share Capital - Normal Course I
Share Capital - Normal Course Issuer Bid (Details) - CAD ($) $ / shares in Units, $ in Millions | 12 Months Ended | |||||||
Dec. 31, 2022 | Dec. 31, 2021 | Mar. 31, 2023 | Feb. 03, 2023 | Jun. 30, 2022 | Mar. 31, 2022 | Sep. 30, 2021 | Mar. 31, 2021 | |
Share Capital | ||||||||
Shares repurchased | 116,908,000 | 83,959,000 | ||||||
Average repurchase cost per share | $ 43.92 | $ 27.45 | ||||||
Share repurchase cost | $ 5,135 | $ 2,304 | ||||||
Common shares issued and outstanding | 1,330,006,760 | |||||||
2022 NCIB | ||||||||
Share Capital | ||||||||
Purchase of shares for cancellation, shares authorized | 132,900,000 | 143,500,000 | 71,650,000 | |||||
Percentage of shares issued and outstanding | 10% | 10% | 5% | |||||
Shares repurchased | 109,800,000 | |||||||
2021 NCIB | ||||||||
Share Capital | ||||||||
Purchase of shares for cancellation, shares authorized | 106,700,000 | 76,250,000 | 44,000,000 | |||||
Percentage of shares issued and outstanding | 7% | 5% | 2.90% | |||||
Shares repurchased | 7,100,000 | 84,000,000 | ||||||
Average repurchase cost per share | $ 27.45 | |||||||
Share repurchase cost | $ 2,300 |
Share Capital - Share repurchas
Share Capital - Share repurchases (Details) - CAD ($) $ / shares in Units, shares in Thousands, $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Share Capital | ||
Shares repurchased | 116,908 | 83,959 |
Share repurchase cost | $ 5,135 | $ 2,304 |
Average repurchase cost per share | $ 43.92 | $ 27.45 |
Liability for share purchase commitment | $ 350 | $ 230 |
Share capital | ||
Share Capital | ||
Share repurchase cost | 1,947 | 1,382 |
Liability for share purchase commitment | 136 | 120 |
Retained earnings | ||
Share Capital | ||
Share repurchase cost | 3,188 | 922 |
Liability for share purchase commitment | $ 214 | $ 110 |
Share Based Compensation - Expe
Share Based Compensation - Expense (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Share Based Compensation | ||
Equity-settled plans | $ 17 | $ 21 |
Cash-settled plans | 484 | 301 |
Total share-based compensation expense | $ 501 | $ 322 |
Share Based Compensation - Liab
Share Based Compensation - Liability (Details) - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 |
Share Based Compensation | ||
Current liability | $ 326 | $ 153 |
Long-term liability | 469 | 291 |
Total Liability | 795 | 444 |
Intrinsic value of vested awards | $ 415 | $ 200 |
Share Based Compensation - Assu
Share Based Compensation - Assumptions used to value stock options (Details) - Options | 12 Months Ended | |
Dec. 31, 2022 CAD ($) Y | Dec. 31, 2021 CAD ($) Y | |
Share Based Compensation | ||
Term of awards | 7 years | |
Vesting period | 3 years | |
Annual dividend per share (dollars) | $ 1.88 | $ 1.05 |
Risk-free interest rate | 1.73% | 0.49% |
Expected life | Y | 5 | 5 |
Expected volatility | 42% | 40% |
Weighted average fair value per option (dollars) | $ 9.27 | $ 5.40 |
Share Based Compensation - Stoc
Share Based Compensation - Stock Option Activity (Details) shares in Thousands, Option in Thousands | 12 Months Ended | |
Dec. 31, 2022 Option $ / shares shares | Dec. 31, 2021 Option $ / shares shares | |
Number | ||
Outstanding, beginning of year | Option | 37,090 | 38,373 |
Granted | Option | 2,191 | 3,457 |
Exercised as options for common shares | Option | (13,158) | (245) |
Forfeited/expired | shares | (5,055) | (4,495) |
Outstanding, end of year | Option | 21,068 | 37,090 |
Exercisable, end of year | Option | 16,407 | 28,421 |
Weighted Average Exercise Price | ||
Outstanding, beginning of year | $ 38.39 | $ 39.65 |
Granted | 37.22 | 22.71 |
Exercised as options for common shares | 37.69 | 29.82 |
Forfeited/expired | 38.99 | 37.62 |
Outstanding, end of year | 38.55 | 38.39 |
Exercisable, end of year | $ 40.19 | $ 39.87 |
Share Based Compensation - Exer
Share Based Compensation - Exercise price ranges (Details) shares in Thousands, Option in Thousands | 12 Months Ended | ||
Dec. 31, 2022 Option $ / shares shares | Dec. 31, 2021 Option $ / shares shares | Dec. 31, 2020 Option $ / shares | |
Share Based Compensation | |||
Number of share options | Option | 21,068 | 37,090 | 38,373 |
Weighted average remaining contractual life | 3 years | ||
Weighted Average Exercise Price | $ 38.55 | $ 38.39 | $ 39.65 |
Number of exercisable share option | Option | 16,407 | 28,421 | |
Weighted Average Exercise Price Exercisable | $ 40.19 | $ 39.87 | |
Common shares authorized for issuance | shares | 27,901 | 25,037 | |
22.00-23.27 | |||
Share Based Compensation | |||
Number of share options | Option | 2,658 | ||
Weighted average remaining contractual life | 5 years | ||
Weighted Average Exercise Price | $ 22.65 | ||
Number of exercisable share option | Option | 1,064 | ||
Weighted Average Exercise Price Exercisable | $ 22.65 | ||
22.00-23.27 | Minimum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | 22.63 | ||
22.00-23.27 | Maximum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | $ 24.99 | ||
23.28-24.99 | |||
Share Based Compensation | |||
Number of share options | Option | 9 | ||
Weighted average remaining contractual life | 5 years | ||
Weighted Average Exercise Price | $ 29.31 | ||
Number of exercisable share option | Option | 3 | ||
Weighted Average Exercise Price Exercisable | $ 29.34 | ||
23.28-24.99 | Minimum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | 25 | ||
23.28-24.99 | Maximum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | $ 29.99 | ||
30.00-34.99 | |||
Share Based Compensation | |||
Number of share options | Option | 731 | ||
Weighted Average Exercise Price | $ 30.30 | ||
Number of exercisable share option | Option | 718 | ||
Weighted Average Exercise Price Exercisable | $ 30.28 | ||
30.00-34.99 | Minimum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | 30 | ||
30.00-34.99 | Maximum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | $ 34.99 | ||
35.00-39.99 | |||
Share Based Compensation | |||
Number of share options | Option | 6,176 | ||
Weighted average remaining contractual life | 4 years | ||
Weighted Average Exercise Price | $ 38.37 | ||
Number of exercisable share option | Option | 3,255 | ||
Weighted Average Exercise Price Exercisable | $ 38.85 | ||
35.00-39.99 | Minimum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | 35 | ||
35.00-39.99 | Maximum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | $ 39.99 | ||
40.00-44.99 | |||
Share Based Compensation | |||
Number of share options | Option | 11,298 | ||
Weighted average remaining contractual life | 2 years | ||
Weighted Average Exercise Price | $ 42.73 | ||
Number of exercisable share option | Option | 11,235 | ||
Weighted Average Exercise Price Exercisable | $ 42.75 | ||
40.00-44.99 | Minimum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | 40 | ||
40.00-44.99 | Maximum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | $ 44.99 | ||
45.00-49.99 | |||
Share Based Compensation | |||
Number of share options | Option | 101 | ||
Weighted average remaining contractual life | 5 years | ||
Weighted Average Exercise Price | $ 48.05 | ||
Number of exercisable share option | Option | 44 | ||
Weighted Average Exercise Price Exercisable | $ 48.41 | ||
45.00-49.99 | Minimum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | 45 | ||
45.00-49.99 | Maximum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | $ 49.99 | ||
50.00-54.27 | |||
Share Based Compensation | |||
Number of share options | Option | 95 | ||
Weighted average remaining contractual life | 3 years | ||
Weighted Average Exercise Price | $ 52.78 | ||
Number of exercisable share option | Option | 88 | ||
Weighted Average Exercise Price Exercisable | $ 52.85 | ||
50.00-54.27 | Minimum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | 50 | ||
50.00-54.27 | Maximum | |||
Share Based Compensation | |||
Exercise price (in dollars per share) | $ 54.27 |
Share Based Compensation - Shar
Share Based Compensation - Share Unit Plans (Details) EquityInstruments in Thousands, $ in Thousands | 12 Months Ended | |
Dec. 31, 2022 CAD ($) EquityInstruments $ / shares | Dec. 31, 2021 EquityInstruments CAD ($) | |
Performance Share Units (PSUs) | ||
Share Based Compensation | ||
Vesting period | 3 years | |
Summary of activity of share unit plans: | ||
Outstanding, beginning of year | 2,766 | 2,285 |
Granted | 947 | 1,285 |
Redeemed for cash | (794) | (751) |
Forfeited/expired | $ | (710) | (53) |
Outstanding, end of year | 2,209 | 2,766 |
Performance Share Units (PSUs) | Minimum | ||
Share Based Compensation | ||
Percentage of share price receivable at the time of vesting | 0% | |
Performance Share Units (PSUs) | Maximum | ||
Share Based Compensation | ||
Percentage of share price receivable at the time of vesting | 200% | |
Restricted Stock Units (RSUs) | ||
Share Based Compensation | ||
Vesting period | 3 years | |
Value of shares converted to Suncor RSUs | $ | $ 123,000 | |
Conversion price per share | $ / shares | $ 30.93 | |
Summary of activity of share unit plans: | ||
Outstanding, beginning of year | 21,437 | 15,095 |
Granted | 13,235 | 11,954 |
Redeemed for cash | (4,533) | (4,609) |
Forfeited/expired | $ | (1,877) | (1,003) |
Outstanding, end of year | 28,262 | 21,437 |
Deferred Share Units (DSUs) | ||
Summary of activity of share unit plans: | ||
Outstanding, beginning of year | 1,382 | 1,385 |
Granted | 187 | 164 |
Redeemed for cash | (238) | (167) |
Outstanding, end of year | 1,331 | 1,382 |
Deferred Share Units (DSUs) | Director | Election Tranche One | ||
Share Based Compensation | ||
Percentage of awards elected to be paid in cash | 50% | |
Deferred Share Units (DSUs) | Director | Election Tranche Two | ||
Share Based Compensation | ||
Percentage of awards elected to be paid in cash | 100% | |
Deferred Share Units (DSUs) | Executives | Election Tranche One | ||
Share Based Compensation | ||
Percentage of awards elected to be paid in cash | 25% | |
Deferred Share Units (DSUs) | Executives | Election Tranche Two | ||
Share Based Compensation | ||
Percentage of awards elected to be paid in cash | 50% | |
Deferred Share Units (DSUs) | Executives | Election Tranche Three | ||
Share Based Compensation | ||
Percentage of awards elected to be paid in cash | 75% | |
Deferred Share Units (DSUs) | Executives | Election Tranche Four | ||
Share Based Compensation | ||
Percentage of awards elected to be paid in cash | 100% |
Share Based Compensation - St_2
Share Based Compensation - Stock Appreciation Rights (Details) - Stock Appreciation Rights (SARs) EquityInstruments in Thousands | 12 Months Ended | |
Dec. 31, 2022 EquityInstruments $ / shares | Dec. 31, 2021 EquityInstruments $ / shares | |
Share Based Compensation | ||
Term of awards | 7 years | |
Vesting period | 3 years | |
Number | ||
Outstanding, beginning of year | EquityInstruments | 463 | 509 |
Granted | EquityInstruments | 10 | 10 |
Exercised | EquityInstruments | (121) | |
Forfeited/expired | EquityInstruments | (65) | (56) |
Outstanding, end of year | EquityInstruments | 287 | 463 |
Exercisable, end of year | EquityInstruments | 242 | 357 |
Weighted Average Exercise Price | ||
Outstanding, beginning of year | $ / shares | $ 39.06 | $ 39.25 |
Granted | $ / shares | 36.76 | 22.63 |
Exercised | $ / shares | 37.18 | |
Forfeited/expired | $ / shares | 38.25 | 37.78 |
Outstanding, end of year | $ / shares | 39.95 | 39.06 |
Exercisable, end of year | $ / shares | $ 40.82 | $ 39.68 |
Financial Instruments and Ris_3
Financial Instruments and Risk Management - Non Derivative Financial Instruments (Details) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2022 CAD ($) | Dec. 31, 2021 CAD ($) | |
Non Derivative Financial Instruments | |||
Carrying value of partnership liability | $ 427 | $ 436 | |
Fixed term debt | |||
Non Derivative Financial Instruments | |||
Long-term debt | 9,840 | 14,278 | |
Fair value of long-term debt | $ 9,400 | $ 17,400 | |
Fort McKay First Nation and the Mikisew Cree First Nation Partnership | East Tank Farm Development | |||
Non Derivative Financial Instruments | |||
Percentage of partnership ownership interest acquired | 49 |
Financial Instruments and Ris_4
Financial Instruments and Risk Management - Non Designated Derivative Financial Instruments (Details) - Non-Designated Derivative Financial Instruments - At fair value - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Financial Instruments and Risk Management | ||
Fair value outstanding, beginning of year | $ (98) | $ (121) |
Cash settlements - paid during the year | 220 | 178 |
Changes in fair value recognized in earnings during the year | (187) | (155) |
Fair value outstanding, end of year | $ (65) | $ (98) |
Financial Instruments and Ris_5
Financial Instruments and Risk Management - Fair Value Hierarchy (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
Financial Instruments and Risk Management | ||
Balance, at fair value | $ (65) | $ (98) |
Transfers of financial liabilities from level 1 to 2 | 0 | |
Transfers of financial liabilities from level 2 to 1 | 0 | |
Accounts receivables | ||
Financial Instruments and Risk Management | ||
Financial assets, at fair value | 143 | 123 |
Accounts payable | ||
Financial Instruments and Risk Management | ||
Financial liabilities, at fair value | (208) | (221) |
Level 1 | ||
Financial Instruments and Risk Management | ||
Balance, at fair value | (49) | (99) |
Level 1 | Accounts receivables | ||
Financial Instruments and Risk Management | ||
Financial assets, at fair value | 36 | 35 |
Level 1 | Accounts payable | ||
Financial Instruments and Risk Management | ||
Financial liabilities, at fair value | (85) | (134) |
Level 2 | ||
Financial Instruments and Risk Management | ||
Balance, at fair value | (16) | 1 |
Level 2 | Accounts receivables | ||
Financial Instruments and Risk Management | ||
Financial assets, at fair value | 107 | 88 |
Level 2 | Accounts payable | ||
Financial Instruments and Risk Management | ||
Financial liabilities, at fair value | $ (123) | $ (87) |
Financial Instruments and Ris_6
Financial Instruments and Risk Management - Offsetting Financial Assets (Details) - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 |
Fair value of derivative assets | ||
Financial Instruments and Risk Management | ||
Gross Assets | $ 4,305 | $ 6,527 |
Gross Liabilities Offset | (4,162) | (6,404) |
Net Amounts Presented | 143 | 123 |
Accounts receivables | ||
Financial Instruments and Risk Management | ||
Gross Assets | 10,349 | 5,048 |
Gross Liabilities Offset | (8,633) | (2,734) |
Net Amounts Presented | 1,716 | 2,314 |
Financial assets | ||
Financial Instruments and Risk Management | ||
Gross Assets | 14,654 | 11,575 |
Gross Liabilities Offset | (12,795) | (9,138) |
Net Amounts Presented | $ 1,859 | $ 2,437 |
Financial Instruments and Ris_7
Financial Instruments and Risk Management - Offsetting Financial Liabilities (Details) - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 |
Fair value of derivative liabilities | ||
Financial Instruments and Risk Management | ||
Gross Liabilities | $ (4,370) | $ (6,625) |
Gross Assets Offset | 4,162 | 6,404 |
Net Amounts Presented | (208) | (221) |
Accounts payable | ||
Financial Instruments and Risk Management | ||
Gross Liabilities | (10,036) | (4,205) |
Gross Assets Offset | 8,633 | 2,734 |
Net Amounts Presented | (1,403) | (1,471) |
Financial liabilities | ||
Financial Instruments and Risk Management | ||
Gross Liabilities | (14,406) | (10,830) |
Gross Assets Offset | 12,795 | 9,138 |
Net Amounts Presented | $ (1,611) | $ (1,692) |
Financial Instruments and Ris_8
Financial Instruments and Risk Management - Market Risk (Details) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 CAD ($) item $ / bbl | Dec. 31, 2021 CAD ($) | |
Financial Instruments and Risk Management | ||
Weighted average interest rate on total debt | 5.20% | 5% |
Commodity Price Risk | ||
Financial Instruments and Risk Management | ||
Increase in price per barrel of crude oil | $ / bbl | 10 | |
Increase (decrease) in pre-tax earnings for the company's outstanding derivative financial instruments | $ 70 | $ (58) |
Foreign Currency Exchange Risk | ||
Financial Instruments and Risk Management | ||
Percentage of strengthening in the Cdn$ relative to the US$ | 1% | 1% |
Gains (losses) on change in value of foreign currency basis spreads, net of tax | $ 100 | $ 133 |
Variable interest rates | Interest Rate Risk | ||
Financial Instruments and Risk Management | ||
Increase in interest rates | 1% | 1% |
Increase (decrease) in pre-tax earnings from increase in interest rates | $ (8) | $ 9 |
Proportion of floating interest rate exposure | 18% | 7% |
Interest rate swaps | Interest Rate Risk | ||
Financial Instruments and Risk Management | ||
Number of derivative instruments outstanding | item | 0 | |
Weighted average | Fixed interest rates | Interest Rate Risk | ||
Financial Instruments and Risk Management | ||
Weighted average interest rate on total debt | 5.80% | 5% |
Financial Instruments and Ris_9
Financial Instruments and Risk Management - Liquidity Risk (Details) $ in Millions, $ in Billions | Dec. 31, 2022 CAD ($) | Dec. 31, 2022 USD ($) | Dec. 31, 2021 CAD ($) | Dec. 31, 2020 CAD ($) |
Financial Liabilities | ||||
Cash and cash equivalents | $ 1,980 | $ 2,205 | $ 1,885 | |
Total credit facilities | 7,227 | |||
Total unutilized credit facilities | 3,272 | |||
Unused capacity under the Board of Directors authority | $ 5 | |||
Timing of cash outflows related to trade and other payables and debt | ||||
Trade and other payables undiscounted cash flows | 8,037 | 6,356 | ||
Gross derivative liability undiscounted cash flows | 4,370 | 6,625 | ||
Debt undiscounted cash flows | 22,299 | 26,231 | ||
Lease liabilities | 4,983 | 4,531 | ||
Within one year | ||||
Timing of cash outflows related to trade and other payables and debt | ||||
Trade and other payables undiscounted cash flows | 7,959 | 6,282 | ||
Gross derivative liability undiscounted cash flows | 3,824 | 6,466 | ||
Debt undiscounted cash flows | 3,375 | 2,253 | ||
Lease liabilities | 477 | 459 | ||
2 to 3 years | ||||
Timing of cash outflows related to trade and other payables and debt | ||||
Trade and other payables undiscounted cash flows | 39 | 37 | ||
Gross derivative liability undiscounted cash flows | 546 | 159 | ||
Debt undiscounted cash flows | 1,066 | 2,015 | ||
Lease liabilities | 807 | 779 | ||
4 to 5 years | ||||
Timing of cash outflows related to trade and other payables and debt | ||||
Trade and other payables undiscounted cash flows | 39 | 37 | ||
Debt undiscounted cash flows | 1,541 | 3,127 | ||
Lease liabilities | 652 | 660 | ||
Over 5 years | ||||
Timing of cash outflows related to trade and other payables and debt | ||||
Debt undiscounted cash flows | 16,317 | 18,836 | ||
Lease liabilities | 3,047 | 2,633 | ||
Liquidity Risk | ||||
Financial Liabilities | ||||
Cash and cash equivalents | 2,000 | |||
Total credit facilities | 7,200 | |||
Total unutilized credit facilities | 3,300 | |||
Timing of cash outflows related to trade and other payables and debt | ||||
Derivative financial liabilities | 4,370 | 6,625 | ||
Derivative financial assets | 4,162 | 6,404 | ||
Derivative liabilities, net | $ 208 | $ 221 |
Financial Instruments and Ri_10
Financial Instruments and Risk Management - Credit Risk (Details) - CAD ($) $ in Millions | Dec. 31, 2022 | Dec. 31, 2021 |
Credit Risk | ||
Financial Instruments and Risk Management | ||
Net exposure | $ 143 | $ 123 |
Capital Structure Financial P_3
Capital Structure Financial Policies (Details) $ in Millions | 12 Months Ended | ||
Dec. 31, 2022 CAD ($) | Dec. 31, 2021 CAD ($) | Dec. 31, 2020 CAD ($) | |
Capital Structure Financial Policies | |||
Maximum percentage of total debt to total debt plus shareholders' equity allowed under terms of financial covenants | 65% | ||
Percentage of total debt to total debt plus shareholders' equity | 28.40% | ||
Components of Ratio | |||
Short-term debt | $ 2,807 | $ 1,284 | |
Current portion of long - term debt | 231 | ||
Current portion of long-term lease liabilities | 317 | 310 | |
Long-term debt | 9,800 | 13,989 | |
Long-term lease liabilities | 2,695 | 2,540 | |
Total debt | 15,619 | 18,354 | |
Less: Cash and cash equivalents | 1,980 | 2,205 | $ 1,885 |
Net debt | 13,639 | 16,149 | |
Shareholders' equity | 39,367 | 36,614 | $ 35,757 |
Total capitalization (total debt plus shareholders' equity) | 54,986 | 54,968 | |
Adjusted funds from operations | $ 18,101 | $ 10,257 | |
Net debt to adjusted funds from operations | 0.8 | 1.6 | |
Total debt to total debt plus shareholders' equity | 28.4 | 33.4 | |
Net debt to adjusted funds from operations multiplier | 3 | ||
Minimum | |||
Components of Ratio | |||
Capital measure target, percentage of total debt to total debt plus shareholders' equity | 20% | 20% | |
Maximum | |||
Components of Ratio | |||
Capital measure target, percentage of total debt to total debt plus shareholders' equity | 35% | 35% |
Joint Arrangements - Joint Oper
Joint Arrangements - Joint Operations (Details) | 3 Months Ended | 12 Months Ended | |||
Mar. 31, 2023 | Sep. 30, 2022 | Jun. 30, 2022 | Dec. 31, 2022 | Dec. 31, 2021 | |
Fenja Development JV | Norway | |||||
JOINT ARRANGEMENTS | |||||
Ownership interest sold (as percent) | 17.50% | ||||
Oda | Norway | |||||
JOINT ARRANGEMENTS | |||||
Ownership interest sold (as percent) | 30% | ||||
Oil Sands | Operated by Suncor | Fort Hills Energy Limited Partnership | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | Canada | Canada | |||
Ownership interest (as percent) | 68.76% | 54.11% | 54.11% | ||
Additional interest acquired (as a percent) | 14.65% | ||||
Oil Sands | Operated by Suncor | Meadow Creek | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | Canada | Canada | |||
Ownership interest (as percent) | 75% | 75% | |||
Oil Sands | Operated by Suncor | Syncrude | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | Canada | Canada | |||
Ownership interest (as percent) | 58.74% | 58.74% | |||
Exploration and Production | White Rose Extensions | |||||
JOINT ARRANGEMENTS | |||||
Ownership interest (as percent) | 40% | ||||
Additional interest acquired (as a percent) | 12.50% | ||||
Exploration and Production | Operated by Suncor | Terra Nova | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | Canada | Canada | |||
Ownership interest (as percent) | 48% | 48% | |||
Exploration and Production | Non-operated | Buzzard | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | United Kingdom | United Kingdom | |||
Ownership interest (as percent) | 29.89% | 29.89% | |||
Exploration and Production | Non-operated | Fenja Development JV | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | Norway | ||||
Ownership interest (as percent) | 17.50% | ||||
Exploration and Production | Non-operated | Hibernia and the Hibernia South Extension Unit | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | Canada | Canada | |||
Exploration and Production | Non-operated | Hibernia | |||||
JOINT ARRANGEMENTS | |||||
Ownership interest (as percent) | 19.48% | 19.48% | |||
Exploration and Production | Non-operated | Hibernia South Extension Unit | |||||
JOINT ARRANGEMENTS | |||||
Ownership interest (as percent) | 20% | 20% | |||
Exploration and Production | Non-operated | Hebron | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | Canada | Canada | |||
Ownership interest (as percent) | 21.03% | 21.03% | |||
Exploration and Production | Non-operated | Harouge Oil Operations | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | Libya | Libya | |||
Ownership interest (as percent) | 49% | 49% | |||
Exploration and Production | Non-operated | North Sea Rosebank Project | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | United Kingdom | United Kingdom | |||
Ownership interest (as percent) | 40% | 40% | |||
Exploration and Production | Non-operated | Oda | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | Norway | ||||
Ownership interest (as percent) | 30% | ||||
Exploration and Production | Non-operated | White Rose and the White Rose Extensions | |||||
JOINT ARRANGEMENTS | |||||
Country of Incorporation and Principal Place of Business | Canada | Canada | |||
Exploration and Production | Non-operated | White Rose | |||||
JOINT ARRANGEMENTS | |||||
Ownership interest (as percent) | 38.625% | 26.13% | |||
Exploration and Production | Non-operated | White Rose Extensions | |||||
JOINT ARRANGEMENTS | |||||
Ownership interest (as percent) | 40% | 27.50% |
Joint Arrangements - Joint Vent
Joint Arrangements - Joint Ventures and Associates (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
JOINT ARRANGEMENTS | ||
Net earnings | $ 9,077 | $ 4,119 |
Other comprehensive income | 998 | 793 |
Total Comprehensive Income | 10,075 | 4,912 |
Joint ventures | ||
JOINT ARRANGEMENTS | ||
Net earnings | (25) | 5 |
Total Comprehensive Income | (25) | 5 |
Carrying amount as at December 31 | 39 | 63 |
Associates | ||
JOINT ARRANGEMENTS | ||
Net earnings | (1) | (2) |
Total Comprehensive Income | (1) | (2) |
Carrying amount as at December 31 | $ 63 | $ 66 |
Subsidiaries (Details)
Subsidiaries (Details) | 12 Months Ended |
Dec. 31, 2022 | |
Suncor Energy Venture Holding Corporation | |
Disclosure of subsidiaries | |
Ownership by subsidiaries (as a percent) | 36.74% |
Suncor Energy Ventures Partnership | |
Disclosure of subsidiaries | |
Ownership by subsidiaries (as a percent) | 22% |
Related Party Disclosures (Deta
Related Party Disclosures (Details) - CAD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2022 | Dec. 31, 2021 | |
RELATED PARTY DISCLOSURES | ||
Sales | $ 1,616 | $ 1,011 |
Purchases | 265 | 247 |
Accounts receivable | 135 | 70 |
Accounts payable and accrued liabilities | 69 | 17 |
Compensation of Key Management Personnel | ||
Salaries and other short-term benefits | 20 | 8 |
Pension and other post-retirement benefits | 4 | 3 |
Share-based compensation | 73 | 47 |
Total | 97 | 58 |
Parachem Chemicals Inc | ||
RELATED PARTY DISCLOSURES | ||
Sales | 487 | 343 |
Petroles Cadeko Inc. | ||
RELATED PARTY DISCLOSURES | ||
Sales | $ 645 | $ 411 |
Commitments, Contingencies an_3
Commitments, Contingencies and Guarantees (Details) $ in Millions | Dec. 31, 2022 CAD ($) |
Commitments, Contingencies and guarantees | |
Product transportation and storage | $ 13,198 |
Energy services | 546 |
Exploration work commitments | 540 |
Other | 1,268 |
Total | 15,552 |
Maximum Potential Amount Payable Under Indemnification Agreements | 125 |
2023 | |
Commitments, Contingencies and guarantees | |
Product transportation and storage | 1,146 |
Energy services | 101 |
Other | 471 |
Total | 1,718 |
2024 | |
Commitments, Contingencies and guarantees | |
Product transportation and storage | 1,252 |
Energy services | 101 |
Other | 269 |
Total | 1,622 |
2025 | |
Commitments, Contingencies and guarantees | |
Product transportation and storage | 1,201 |
Energy services | 119 |
Exploration work commitments | 53 |
Other | 149 |
Total | 1,522 |
2026 | |
Commitments, Contingencies and guarantees | |
Product transportation and storage | 1,024 |
Energy services | 77 |
Exploration work commitments | 1 |
Other | 115 |
Total | 1,217 |
2027 | |
Commitments, Contingencies and guarantees | |
Product transportation and storage | 1,165 |
Energy services | 71 |
Other | 73 |
Total | 1,309 |
Thereafter | |
Commitments, Contingencies and guarantees | |
Product transportation and storage | 7,410 |
Energy services | 77 |
Exploration work commitments | 486 |
Other | 191 |
Total | $ 8,164 |
Assets Held for Sale (Details)
Assets Held for Sale (Details) - CAD ($) $ in Millions | 3 Months Ended | ||
Mar. 02, 2023 | Mar. 31, 2023 | Dec. 31, 2022 | |
Held-for-sale, U.K. Operations | |||
Assets | |||
Current assets | $ 83 | ||
Property, plant and equipment, net | 364 | ||
Exploration and evaluation | 239 | ||
Total Assets | 686 | ||
Liabilities | |||
Current liabilities | (241) | ||
Provisions | (217) | ||
Total Liabilities | (458) | ||
Net Assets | 228 | ||
Expected gross proceeds from sale | $ 1,200 | ||
Contingent consideration gain | $ 338 | ||
Held-for-sale, wind and solar assets | |||
Assets | |||
Current assets | 62 | ||
Property, plant and equipment, net and intangible assets | 438 | ||
Total Assets | 500 | ||
Liabilities | |||
Current liabilities | (32) | ||
Other long-term liabilities and provisions | (40) | ||
Total Liabilities | (72) | ||
Net Assets | $ 428 | ||
Disposed of by sale, wind and solar assets | |||
Liabilities | |||
Gross proceeds from sale of non-current assets | $ 730 | ||
Gain (loss) on sale | $ 260 |