Marathon Oil (MRO) 10-K 17 Feb 22 2021 FY Annual report Financial data

Cover Page

Cover Page - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Feb. 11, 2022	Jun. 30, 2021
Cover [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2021
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	1-1513
Entity Registrant Name	Marathon Oil Corporation
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	25-0996816
Entity Address, Address Line One	990 Town and Country Boulevard,
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77024-2217
City Area Code	(713)
Local Phone Number	629-6600
Title of 12(b) Security	Common Stock, par value $1.00
Trading Symbol	MRO
Security Exchange Name	NYSE
Entity Well Known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 10,705
Entity Common Stock, Shares Outstanding		730,765,163
Documents Incorporated by Reference	Portions of the registrant’s proxy statement relating to its 2022 Annual Meeting of Stockholders, to be filed with the Securities and Exchange Commission pursuant to Regulation 14A under the Securities Exchange Act of 1934, are incorporated by reference to the extent set forth in Part III, Items 10-14 of this report.
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2021
Amendment Flag	false
Entity Central Index Key	0000101778

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2021
Audit Information [Abstract]
Auditor Firm ID	238
Auditor Name	PricewaterhouseCoopers LLP
Auditor Location	Houston, Texas

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenues and other income:
Revenues from contracts with customers	$ 5,601	$ 3,097	$ 5,063
Net gain (loss) on commodity derivatives	(383)	116	(72)
Income (loss) from equity method investments	253	(161)	87
Net gain (loss) on disposal of assets	(19)	9	50
Other income	15	25	62
Total revenues and other income	5,467	3,086	5,190
Costs and expenses:
Production	534	555	712
Shipping, handling and other operating	727	596	605
Exploration	136	181	149
Depreciation, depletion and amortization	2,066	2,316	2,397
Impairments	60	144	24
Taxes other than income	345	200	311
General and administrative	291	274	356
Total costs and expenses	4,159	4,266	4,554
Income (loss) from operations	1,308	(1,180)	636
Net interest and other	(188)	(256)	(244)
Other net periodic benefit (costs) credits	5	(1)	3
Loss on early extinguishment of debt	(121)	(28)	(3)
Income (loss) before income taxes	1,004	(1,465)	392
Provision (benefit) for income taxes	58	(14)	(88)
Net income (loss)	$ 946	$ (1,451)	$ 480
Net income (loss) per share:
Basic (in dollars per share)	$ 1.20	$ (1.83)	$ 0.59
Diluted (in dollars per share)	$ 1.20	$ (1.83)	$ 0.59
Weighted average common shares outstanding:
Basic (in shares)	787	792	810
Diluted (in shares)	788	792	810

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 946	$ (1,451)	$ 480
Other comprehensive income (loss), net of tax
Change in actuarial gain (loss) and other for postretirement and postemployment plans	14	(30)	16
Change in derivative hedges unrecognized gain (loss)	23	(2)	2
Reclassification of de-designated forward interest rate swaps	(28)	0	0
Foreign currency translation adjustment related to sale of U.K. business	0	0	23
Other	0	0	1
Other comprehensive income (loss)	9	(32)	42
Comprehensive income (loss)	$ 955	$ (1,483)	$ 522

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 580	$ 742
Receivables, less reserve of $15 and $22	1,142	747
Inventories	77	76
Other current assets	22	47
Total current assets	1,821	1,612
Equity method investments	450	447
Property, plant and equipment, less accumulated depreciation, depletion and amortization of $22,412 and $20,358	14,499	15,638
Other noncurrent assets	224	259
Total assets	16,994	17,956
Current liabilities:
Accounts payable	1,110	837
Payroll and benefits payable	74	57
Accrued taxes	157	72
Other current liabilities	260	247
Long-term debt due within one year	36	0
Current liabilities	1,637	1,213
Long-term debt	3,978	5,404
Deferred tax liabilities	136	163
Defined benefit postretirement plan obligations	137	180
Asset retirement obligations	288	241
Deferred credits and other liabilities	132	194
Total liabilities	6,308	7,395
Commitments and contingencies
Stockholders’ Equity
Preferred stock – no shares issued or outstanding (no par value, 26 million shares authorized)	0	0
Common Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Issued – 937 million shares (par value $1 per share, 1.925 billion shares authorized at December 31, 2021 and December 31, 2020)	937	937
Held in treasury, at cost – 194 million shares and 148 million shares	(4,825)	(4,089)
Additional paid-in capital	7,221	7,174
Retained earnings	7,271	6,466
Accumulated other comprehensive income	82	73
Total stockholders’ equity	10,686	10,561
Total liabilities and stockholders’ equity	$ 16,994	$ 17,956

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Statement of Financial Position [Abstract]
Receivable reserves	$ 15	$ 22
Accumulated depreciation, depletion and amortization	$ 22,412	$ 20,358
Preferred stock issued (shares)	0	0
Preferred stock outstanding (shares)	0	0
Preferred stock par value (in usd per share)	$ 0	$ 0
Preferred stock authorized (shares)	26,000,000	26,000,000
Common stock issued (shares)	937,000,000	937,000,000
Common stock par value (in usd per share)	$ 1	$ 1
Common stock authorized (shares)	1,925,000,000	1,925,000,000
Held in treasury (shares)	194,000,000	148,000,000

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating activities:
Net income (loss)	$ 946	$ (1,451)	$ 480
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	2,066	2,316	2,397
Impairments	60	144	24
Exploratory dry well costs and unproved property impairments	125	159	114
Net (gain) loss on disposal of assets	19	(9)	(50)
Loss on early extinguishment of debt	121	28	3
Deferred income taxes	(27)	(22)	(34)
Unrealized (gain) loss on derivative instruments, net	(16)	27	124
Pension and other post retirement benefits, net	(31)	(43)	(52)
Stock-based compensation	40	57	60
Equity method investments, net	(76)	210	18
Changes in:
Current receivables	(389)	367	52
Inventories	(1)	(4)	3
Current accounts payable and accrued liabilities	369	(381)	(187)
Other current assets and liabilities	46	75	(4)
All other operating, net	(13)	0	(199)
Net cash provided by operating activities	3,239	1,473	2,749
Investing activities:
Additions to property, plant and equipment	(1,046)	(1,343)	(2,550)
Additions to other assets	0	15	36
Acquisitions, net of cash acquired	(47)	(1)	(293)
Disposal of assets, net of cash transferred to the buyer	22	18	(76)
Equity method investments - return of capital	61	7	64
All other investing, net	0	1	1
Net cash used in investing activities	(1,010)	(1,303)	(2,818)
Financing activities:
Borrowings	0	400	600
Debt repayments	(1,400)	(500)	(600)
Debt extinguishment costs	(117)	(27)	(2)
Purchases of common stock	(734)	(92)	(362)
Dividends paid	(141)	(64)	(162)
All other financing, net	1	(3)	(9)
Net cash used in financing activities	(2,391)	(286)	(535)
Net increase (decrease) in cash and cash equivalents	(162)	(116)	(604)
Cash and cash equivalents at beginning of period	742	858	1,462
Cash and cash equivalents at end of period	$ 580	$ 742	$ 858

Consolidated Statements of Stoc

Consolidated Statements of Stockholders’ Equity - USD ($) shares in Millions, $ in Millions	Total	Cumulative-effect adjustment	Preferred Stock	Common Stock	Treasury Stock	Additional Paid-in Capital	Retained Earnings	Retained EarningsCumulative-effect adjustment	Accumulated Other Comprehensive Income (Loss)
Accounting Standards Update [Extensible List]	Accounting Standards Update 2016-02 [Member]
Beginning Balance at Dec. 31, 2018	$ 12,128	$ (31)	$ 0	$ 937	$ (3,816)	$ 7,238	$ 7,706	$ (31)	$ 63
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock-based compensation	63				89	(26)
Shares repurchased	(362)				(362)
Stock-based compensation	(5)					(5)
Net income (loss)	480						480
Other comprehensive income (loss)	42								42
Dividends paid	(162)						(162)
Ending Balance at Dec. 31, 2019	12,153	$ (12)	$ 0	$ 937	$ (4,089)	7,207	7,993	$ (12)	105
Beginning Balance - Outstanding Stock (shares) at Dec. 31, 2018			0	937
Beginning Balance - Treasury Stock (shares) at Dec. 31, 2018					118
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock based compensation (shares)					(2)
Shares repurchased (shares)					25
Ending Balance - Treasury Stock (shares) at Dec. 31, 2019					141
Ending Balance - Outstanding Stock (shares) at Dec. 31, 2019			0	937
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock-based compensation	31				$ 91	(60)
Shares repurchased	(91)				(91)
Stock-based compensation	27					27
Net income (loss)	(1,451)						(1,451)
Other comprehensive income (loss)	(32)								(32)
Dividends paid	(64)						(64)
Ending Balance at Dec. 31, 2020	$ 10,561		$ 0	$ 937	$ (4,089)	7,174	6,466		73
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock based compensation (shares)					(3)
Shares repurchased (shares)					10
Ending Balance - Treasury Stock (shares) at Dec. 31, 2020	148				148
Ending Balance - Outstanding Stock (shares) at Dec. 31, 2020			0	937
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock-based compensation	$ 8				$ (2)	10
Shares repurchased	(734)				(734)
Stock-based compensation	37					37
Net income (loss)	946						946
Other comprehensive income (loss)	9								9
Dividends paid	(141)						(141)
Ending Balance at Dec. 31, 2021	$ 10,686		$ 0	$ 937	$ (4,825)	$ 7,221	$ 7,271		$ 82
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock based compensation (shares)					0
Shares repurchased (shares)	0				46
Ending Balance - Treasury Stock (shares) at Dec. 31, 2021	194				194
Ending Balance - Outstanding Stock (shares) at Dec. 31, 2021			0	937

Consolidated Statements of St_2

Consolidated Statements of Stockholders’ Equity (Parentheticals) - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Statement of Stockholders' Equity [Abstract]
Dividends paid (in dollars per share)	$ 0.18	$ 0.08	$ 0.20

Summary of Principal Accounting

Summary of Principal Accounting Policies	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Summary of Principal Accounting Policies	Summary of Principal Accounting Policies We are an independent exploration and production company engaged in exploration, production and marketing of crude oil and condensate, NGLs and natural gas; as well as production and marketing of products manufactured from natural gas, such as LNG and methanol, in E.G. Basis of presentation and principles applied in consolidation – These consolidated financial statements, including notes, have been prepared in accordance with U.S. GAAP. These consolidated financial statements include the accounts of our controlled subsidiaries. Investments in unincorporated joint ventures and undivided interests in certain operating assets are consolidated on a pro rata basis. Equity method investments – Investments in entities over which we have significant influence, but not control, are accounted for using the equity method of accounting. This includes entities in which we hold majority ownership but the minority stockholders have substantive participating rights in the investee. Income from equity method investments represents our proportionate share of net income generated by the equity method investees and is reflected in revenues and other income in our consolidated statements of income. Equity method investments are included as noncurrent assets on the consolidated balance sheet. Equity method investments are assessed for impairment whenever changes in the facts and circumstances indicate a loss in value may have occurred. When a loss is deemed to have occurred and is other than temporary, the carrying value of the equity method investment is written down to fair value, and the amount of the write-down is included in income. Use of estimates – The preparation of financial statements in accordance with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the consolidated financial statements and the reported amounts of revenues and expenses during the respective reporting periods. Estimated quantities of crude oil and condensate, NGLs and natural gas reserves is a significant estimate that requires judgment. All of the reserve data included in this Form 10-K are estimates. Reservoir engineering is a subjective process of estimating underground accumulations of crude oil and condensate, NGLs and natural gas. There are numerous uncertainties inherent in estimating quantities of proved crude oil and condensate, NGLs and natural gas reserves. The accuracy of any reserves estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. As a result, reserve estimates may be different from the quantities of crude oil and condensate, NGLs and natural gas that are ultimately recovered. See unaudited Supplementary Data – Supplementary Information on Oil and Gas Producing Activities for further detail. Other items subject to estimates and assumptions include the carrying amounts of property, plant and equipment, asset retirement obligations, goodwill, valuation of derivative instruments and valuation allowances for deferred income tax assets, among others. Although we believe these estimates are reasonable, actual results could differ from these estimates. Foreign currency transactions – The U.S. dollar is the functional currency of our foreign operating subsidiaries. Foreign currency transaction gains and losses are included in net income. Revenue recognition – Revenues associated with the sales of crude oil and condensate, NGLs and natural gas are recognized when our performance obligation is satisfied, which typically occurs at the point where control transfers to the customer based on contract terms. Revenue is measured as the amount the company expects to receive in exchange for transferring commodities to the customer. Our hydrocarbon sales are typically based on prevailing market-based prices and may include quality or location differential adjustments. Payment is generally due within 30 days of delivery. We typically incur shipping and handling costs prior to control transferring to the customer and account for these activities as fulfillment costs. These costs are reflected in shipping, handling and other operating expense in our consolidated statement of income. Our U.S. production of crude oil and condensate, NGLs and natural gas is generally sold immediately and transported to market. In our international segment, liquid hydrocarbon production may be stored as inventory and sold at a later time. Cash and cash equivalents – Cash and cash equivalents include cash on hand and on deposit and investments in highly liquid debt instruments with original maturities of three months or less. Accounts receivable – The majority of our receivables are from purchasers of commodities or joint interest owners in properties we operate, both of which are recorded at estimated or invoiced amounts and do not bear interest. We often have the ability to withhold future revenue disbursements to recover any non-payment of joint interest billings. We conduct credit reviews of commodity purchasers prior to making commodity sales to new customers or increasing credit for existing customers. Based on these reviews, we may require a standby letter of credit or a financial guarantee. We routinely assess the collectability of receivable balances to determine if the amount of the reserve for credit losses is sufficient. Inventories – Crude oil and natural gas are recorded at weighted average cost and carried at the lower of cost or net realizable value. Supplies and other items consist principally of tubular goods and equipment, which are valued at weighted average cost and reviewed periodically for obsol escence or impairment when market conditions indicate . We may enter into a contract to sell a particular quantity and quality of crude oil at a specified location and date to a particular counterparty, and simultaneously agree to buy a particular quantity and quality of the same commodity at a specified location on the same or another specified date from the same counterparty. We account for such matching buy/sell arrangements as exchanges of inventory. Derivative instruments – We may use derivatives to manage a portion of our exposure to commodity price risk, commodity locational risk and interest rate risk. All derivative instruments are recorded at fair value. Commodity derivatives and interest rate swaps are reflected on our consolidated balance sheet on a net basis by counterparty, as they are governed by master netting agreements. Cash flows related to derivatives used to manage commodity price risk, and interest rate risk are classified in operating activities. Our derivative instruments contain no significant contingent credit features. Cash flow hedges – We may use interest rate derivative instruments to manage the risk of interest rate changes during the period prior to anticipated borrowings as well as to stabilize future lease payments on our Houston office, and designate them as cash flow hedges. Derivative instruments designated as cash flow hedges are linked to specific assets and liabilities or to specific firm commitments or forecasted transactions. The changes in the fair value of a qualifying cash flow hedge are recorded in other comprehensive income until the hedged transaction affects earnings and are then reclassified into net income. Ineffective portions of a cash flow hedge are no longer measured or disclosed separately. However, if it is determined that the likelihood of the original forecasted transaction occurring is no longer probable or the cash flow hedge is no longer expected to be highly effective, subsequent changes in fair value of the derivatives instrument are recorded in net income. Derivatives not designated as hedges – Derivatives that are not designated as hedges may include commodity derivatives used primarily to manage price and locational risks on the forecasted sale of crude oil, NGLs and natural gas that we produce. Changes in the fair value of derivatives not designated as hedges are recognized immediately in net income. Concentrations of credit risk – All of our financial instruments, including derivatives, involve elements of credit and market risk. The most significant portion of our credit risk relates to nonperformance by counterparties. The counterparties to our financial instruments consist primarily of major financial institutions and companies within the energy industry. To manage counterparty risk associated with financial instruments, we select and monitor counterparties based on our assessment of their financial strength and on credit ratings, if available. Additionally, we limit the level of exposure with any single counterparty. Fair value transfer – We recognize transfers between levels of the fair value hierarchy as of the end of the reporting period. Property, plant and equipment – We use the successful efforts method of accounting for oil and gas producing activities. Property acquisition costs – Costs to acquire mineral interests in oil and natural gas properties, to drill exploratory wells in progress and those that find proved reserves and to drill development wells are capitalized. Costs to drill exploratory wells that do not find proved reserves, geological and geophysical costs and costs of carrying and retaining unproved properties are expensed. Costs incurred for exploratory wells that find reserves but cannot yet be classified as proved are capitalized if (1) the well has found a sufficient quantity of reserves to justify its completion as a producing well and (2) we are making sufficient progress assessing the reserves and the economic and operating viability of the project. The status of suspended exploratory well costs is monitored continuously and reviewed at least quarterly. Depreciation, depletion and amortization – Capitalized costs to acquire oil and natural gas properties are depreciated and depleted on a units-of-production basis based on estimated proved reserves. Capitalized costs of exploratory wells and development costs are depreciated and depleted on a units-of-production basis based on estimated proved developed reserves. Support equipment and other property, plant and equipment related to oil and gas producing activities, as well as property, plant and equipment unrelated to oil and gas producing activities, are recorded at cost and depreciated on a straight-line basis over the estimated useful lives of the assets. The table below summarizes these assets by type, useful life and the net asset balance as of the periods presented. December 31, Type of Asset Range of Useful Lives 2021 2020 (in millions) Office furniture, equipment and computer hardware 4 to 15 years $ 41 $ 52 Pipelines 5 to 40 years $ 10 $ 11 Plants, facilities and infrastructure 3 to 40 years $ 1,496 $ 1,463 Impairments – We evaluate our oil and gas producing properties, including capitalized costs of exploratory wells and development costs, for impairment of value whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If the sum of the expected undiscounted future cash flows from the use of the asset and its eventual disposition is less than the carrying amount of the asset, an impairment loss is recognized based on the fair value of the asset. Oil and gas producing properties are reviewed for impairment on a field-by-field basis or, in certain instances, by logical grouping of assets if there is significant shared infrastructure or contractual terms that cause economic interdependency amongst separate, discrete fields. Oil and gas producing properties deemed to be impaired are written down to their fair value, as determined by discounted future net cash flows or, if available, comparable market value. We evaluate our unproved property investment and record impairment based on time or geologic factors. Information such as drilling results, reservoir performance, seismic interpretation, lease expiration dates or future plans to develop acreage is also considered. When unproved property investments are deemed to be impaired, this amount is reported in exploration expenses in our consolidated statements of income. Dispositions – When property, plant and equipment depreciated on an individual basis is sold or otherwise disposed of, any gains or losses are reflected in net gain (loss) on disposal of assets in our consolidated statements of income. Gains on the disposal of property, plant and equipment are recognized when earned, which is generally at the time of closing. If a loss on disposal is expected, such losses are recognized either when the assets are classified as held for sale, or are measured using a probability weighted income approach based on both the anticipated sales price and a held-for-use model depending on timing of the sale. Proceeds from the disposal of a portion of property, plant and equipment depreciated on a group basis are credited to accumulated depreciation, depletion and amortization with no immediate effect on net income until net book value is reduced to zero. Goodwill – Goodwill represents the excess of the purchase price over the estimated fair value of the net assets acquired in the acquisition of a business. Such goodwill is not amortized, but rather is tested for impairment annually and when events or changes in circumstances indicate that the fair value of a reporting unit with goodwill has been reduced below carrying value. The impairment test requires allocating goodwill and other assets and liabilities to a reporting unit. The fair value of a reporting unit is determined and compared to the book value of the reporting unit. If the fair value of the reporting unit is less than the book value, including goodwill, then the recorded goodwill is impaired to its implied fair value with a charge to impairments. In 2020, our goodwill was fully impaired. See Note 15 for further information. Environmental costs – We provide for remediation costs and penalties when the responsibility to remediate is probable and the amount of associated costs can be reasonably estimated. The timing of remediation accruals coincides with completion of a feasibility study or the commitment to a formal plan of action. Remediation liabilities are accrued based on estimates of known environmental exposure and are discounted when the estimated amounts are reasonably fixed or reliably determinable. Environmental expenditures are capitalized only if the costs mitigate or prevent future contamination or if the costs improve the environmental safety or efficiency of the existing assets. Asset retirement obligations – The fair value of asset retirement obligations is recognized in the period in which the obligations are incurred if a reasonable estimate of fair value can be made. Our asset retirement obligations primarily relate to the abandonment of oil and gas producing facilities. Asset retirement obligations for such facilities include costs to dismantle and relocate or dispose of production platforms, gathering systems, wells and related structures and restoration costs of land, including those leased. Estimates of these costs are developed for each property based on the type of production facilities and equipment, reservoir characteristics, depth of the reservoir, market demand for equipment, currently available procedures and consultations with construction and engineering professionals. Inflation rates and credit-adjusted-risk-free interest rates are used to estimate the fair value of asset retirement obligations. Depreciation of capitalized asset retirement costs and accretion of asset retirement obligations are recorded over time. Depreciation is generally determined on a units-of-production basis based on estimated proved developed reserves for oil and gas production facilities, while accretion of the liability occurs over the useful lives of the assets. Income taxes – Deferred tax assets and liabilities, measured at enacted tax rates, are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying amounts of assets and liabilities and their tax bases as reported in our filings with the respective taxing authorities. We routinely assess the realizability of our deferred tax assets based on several interrelated factors and reduce such assets by a valuation allowance if it is more likely than not that some portion or all of the deferred tax assets will not be realized. These factors include whether we are in a cumulative loss position in recent years, our reversal of temporary differences, and our expectation to generate sufficient future taxable income. We use the liability method in determining our provision and liabilities for our income taxes, under which current and deferred tax liabilities and assets are recorded in accordance with enacted tax laws and rates. Stock-based compensation arrangements – The fair value of stock options is estimated on the date of grant using the Black-Scholes option pricing model. The model employs various assumptions, based on management’s best estimates at the time of grant, which impact the calculation of fair value and ultimately, the amount of expense that is recognized over the life of the stock option award. Of the required assumptions, the expected volatility of our stock price and the stock price in relation to the strike price have the most significant impact on the fair value calculation. We have utilized historical data and analyzed current information which reasonably support these assumptions. The fair value of our restricted stock awards, restricted stock units and Director restricted stock units is determined based on the market value of our common stock on the date of grant. Restricted stock awards, restricted stock units and Director restricted stock units are removed from Treasury Stock at grant, vesting and distribution, respectively. The fair value of our cash-settled stock-based performance units is estimated using the Monte Carlo simulation method. Since these awards are settled in cash at the end of a defined performance period, they are classified as a liability and are re-measured quarterly until settlement. The fair value of our free cash flow cash-settled stock-based performance units is estimated by multiplying the estimated vesting percentage by our common stock’s closing stock price plus accumulated dividend equivalents. Since these awards are settled in cash at the end of a defined performance period, they are classified as a liability and are re-measured quarterly until settlement. The fair value of our stock-settled stock-based performance units is estimated using the Monte Carlo simulation method at grant date only. Since these awards are settled in stock, they are classified as equity.

New Accounting Standards

New Accounting Standards	12 Months Ended
	Dec. 31, 2021
Accounting Standards Update and Change in Accounting Principle [Abstract]
New Accounting Standards	New Accounting StandardsNo new accounting standards were adopted during the year ended 2021 that had a material impact on our consolidated financial statements.

Income (loss) and Dividends per

Income (loss) and Dividends per Common Share	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Income (loss) and Dividends per Common Share	Income (loss) and Dividends per Common Share Basic income (loss) per share is based on the weighted average number of common shares outstanding. Diluted income (loss) per share assumes exercise of stock options in all periods, provided the effect is not antidilutive. The per share calculations below exclude 4 million, 7 million and 6 million stock options for 2021, 2020 and 2019 that were antidilutive. Year Ended December 31, (In millions, except per share data) 2021 2020 2019 Net income (loss) $ 946 $ (1,451) $ 480 Weighted average common shares outstanding 787 792 810 Effect of dilutive securities 1 — — Weighted average common shares, diluted 788 792 810 Net income (loss) per share: Basic $ 1.20 $ (1.83) $ 0.59 Diluted $ 1.20 $ (1.83) $ 0.59 Dividends per share $ 0.18 $ 0.08 $ 0.20

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2021
Business Combination and Asset Acquisition [Abstract]
Acquisitions	Acquisitions United States Segment In the fourth quarter of 2019, we acquired approximately 40,000 net acres in a Texas Delaware oil play in West Texas from multiple sellers for $106 million. We accounted for these transactions as an asset acquisition, allocating the purchase price to unproved property within property, plant and equipment. During the fourth quarter of 2019, we acquired a 100% working interest in approximately 18,000 net acres in the Eagle Ford from Rocky Creek Resources, LLC and RCR Midstream, LLC for $191 million in cash, subject to post-closing adjustments. We accounted for this transaction as a business combination, with the entire purchase price allocated between proved property, unproved property and other assets, all within property, plant and equipment.

Dispositions

Dispositions	12 Months Ended
	Dec. 31, 2021
Discontinued Operations and Disposal Groups [Abstract]
Dispositions	Dispositions International Segment On July 1, 2019, we closed on the sale of our U.K. business (Marathon Oil U.K. LLC and Marathon Oil West of Shetlands Limited) for proceeds of $95 million, which includes the assumption by RockRose Energy PLC (“RoseRock”) of the U.K. business’ cash equivalents, working capital and asset retirement obligation balances. Income before income taxes relating to our U.K. business during the year ended December 31, 2019 was $33 million. See Note 20 for additional details on the defined benefit pension plan as it relates to this disposition.

Revenues

Revenues	12 Months Ended
	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Revenues	Revenues The majority of our revenues are derived from the sale of crude oil and condensate, NGLs and natural gas under spot and term agreements with our customers in the United States and various international locations. As of December 31, 2021 and December 31, 2020, receivables from contracts with customers, included in receivables, less reserves for credit losses were $961 million and $572 million, respectively. The following tables present our revenues from contracts with customers disaggregated by product type and geographic areas. United States Year Ended December 31, 2021 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,435 $ 1,777 $ 299 $ 314 $ 100 $ 3,925 Natural gas liquids 161 239 189 47 17 653 Natural gas 159 119 280 55 19 632 Other 8 — — — 116 124 Revenues from contracts with customers $ 1,763 $ 2,135 $ 768 $ 416 $ 252 $ 5,334 Year Ended December 31, 2020 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 830 $ 984 $ 235 $ 204 $ 69 $ 2,322 Natural gas liquids 74 54 89 20 6 243 Natural gas 86 34 127 18 10 275 Other 6 — — — 78 84 Revenues from contracts with customers $ 996 $ 1,072 $ 451 $ 242 $ 163 $ 2,924 Year Ended December 31, 2019 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,358 $ 1,686 $ 425 $ 316 $ 102 $ 3,887 Natural gas liquids 114 46 116 26 5 307 Natural gas 121 39 156 16 17 349 Other 7 — — — 52 59 Revenues from contracts with customers $ 1,600 $ 1,771 $ 697 $ 358 $ 176 $ 4,602 International Year Ended December 31, 2021 2020 (In millions) E.G. E.G. Crude oil and condensate $ 240 $ 140 Natural gas liquids 2 4 Natural gas 23 29 Other 2 — Revenues from contracts with customers $ 267 $ 173 Year Ended December 31, 2019 (In millions) E.G. U.K. Other Total Crude oil and condensate $ 271 $ 107 $ 20 $ 398 Natural gas liquids 4 1 — 5 Natural gas 32 12 — 44 Other — 14 — 14 Revenues from contracts with customers $ 307 $ 134 $ 20 $ 461 Customers and their respective affiliates who accounted for 10% or more of our total commodity sales were as follows: December 31, 2021 2020 2019 Percentage of Total Commodity Sales Marathon Petroleum Corporation 17 % 13 % 13 % Valero Marketing and Supply 10 % N/A 11 % Koch Resources LLC N/A 12 % 13 % Shell Trading N/A N/A 10 % The pricing in our hydrocarbon sales agreements are variable, determined using various published benchmarks which are adjusted for negotiated quality and location differentials. As a result, revenue collected under our agreements with customers is highly dependent on the market conditions and may fluctuate considerably as the hydrocarbon market prices rise or fall. Typically, our customers pay us monthly, within a short period of time after we deliver the hydrocarbon products. As such, we do not have any financing element associated with our contracts. We do not have any issues related to returns or refunds, as product specifications are standardized for the industry and are typically measured when transferred to a common carrier or midstream entity, and other contractual mechanisms (e.g., price adjustments) are used when products do not meet those specifications. In limited cases, we may also collect advance payments from customers as stipulated in our agreements; payments in excess of recognized revenue are recorded as contract liabilities on our consolidated balance sheet. Under our hydrocarbon sales agreements, the entire consideration amount is variable either due to pricing and/or volumes. We recognize revenue in the amount of variable consideration allocated to distinct units of hydrocarbons transferred to a customer. Such allocation reflects the amount of total consideration we expect to collect for completed deliveries of hydrocarbons and the terms of variable payment relate specifically to our efforts to satisfy the performance obligations under these contracts. Our performance obligations under our hydrocarbon sales agreements are to deliver either the entire production from the dedicated wells or specified contractual volumes of hydrocarbons. We often serve as the operator for jointly owned oil and gas properties. As part of this role, we perform activities to explore, develop and produce oil and gas properties in accordance with the joint operating arrangements. Other working interest owners reimburse us for costs incurred based on our agreements. We determined that these activities are not performed as part of customer relationships and such reimbursements will continue to not be recorded as revenues within the scope of the revenue accounting standard. In addition, we commonly market the share of production belonging to other working interest owners as the operator of jointly owned oil and gas properties. We concluded that those marketing activities are carried out as part of the collaborative arrangement. Therefore, we act as a principal only in regards to the sale of our share of production and recognize revenue for the volumes associated with our net production. Crude oil and condensate For the crude sales agreements, we satisfy our performance obligations and recognize revenue once customers take control of the crude at the designated delivery points, which include pipelines, trucks or vessels. Natural gas and NGLs When selling natural gas and NGLs, we engage midstream entities to process our production stream by separating natural gas from the NGLs. Frequently, these midstream entities also purchase our natural gas and NGLs under the same agreements. In these situations, we determined the performance obligation is complete and satisfied at the tailgate of the processing plant when the natural gas and NGLs become identifiable and measurable products. We determined the plant tailgate is the point in time where control is transferred to midstream entities and they are entitled to significant risks and rewards of ownership of the natural gas and NGLs. The amounts due to midstream entities for gathering and processing services are recognized as shipping and handling cost, since we make those payments in exchange for distinct services. Under some of our natural gas processing agreements, we have an option to take the processed natural gas and NGLs in-kind and sell to customers other than the processing company. In those circumstances, our performance obligations are complete after delivering the processed hydrocarbons to the customer at the designated delivery points, which may be the tailgate of the processing plant or an alternative delivery point requested by the customer. We have “percentage-of-proceeds” arrangements with some midstream entities where they retain a percentage of the proceeds collected for selling our processed natural gas and NGLs as compensation for their processing and marketing services. We recognize revenue for the gross sales volumes and recognize the proceeds retained by midstream companies as shipping and handling cost.

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Segment Information	Segment Information We have two reportable operating segments. Both of these segments are organized and managed based upon geographic location and the nature of the products and services offered. • United States (“U.S.”) – explores for, produces and markets crude oil and condensate, NGLs and natural gas in the United States • International (“Int’l”) – produces and markets crude oil and condensate, NGLs and natural gas outside of the United States as well as produces and markets products manufactured from natural gas, such as LNG and methanol, in E.G. Segment income represents income which excludes certain items not allocated to our operating segments, net of income taxes. A portion of our corporate and operations general and administrative support costs are not allocated to the operating segments. These unallocated costs primarily consist of employment costs (including pension effects), professional services, facilities and other costs associated with corporate and operations support activities. Additionally, items which affect comparability such as: gains or losses on dispositions, impairments of proved and certain unproved properties, goodwill and equity method investments, unrealized gains or losses on commodity derivative instruments, gains or losses on interest rate derivative instruments, effects of pension settlements and curtailments, or other items (as determined by the chief operating decision maker (CODM)) are not allocated to operating segments. Year Ended December 31, 2021 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 5,334 $ 267 $ — $ 5,601 Net gain (loss) on commodity derivatives (399) — 16 (b) (383) Income (loss) from equity method investments — 253 — 253 Net loss on disposal of assets — — (19) (c) (19) Other income 7 4 4 15 Less costs and expenses: Production 480 54 — 534 Shipping, handling and other operating 686 16 25 727 Exploration 65 — 71 (d) 136 Depreciation, depletion and amortization 1,972 68 26 2,066 Impairments — — 60 (e) 60 Taxes other than income 346 — (1) 345 General and administrative 107 13 171 (f) 291 Net interest and other — — 188 (g) 188 Other net periodic benefit (credit) costs — — (5) (5) Loss on early extinguishment of debt — — 121 (h) 121 Income tax provision (benefit) 9 56 (7) 58 Segment income (loss) $ 1,277 $ 317 $ (648) $ 946 Total assets $ 15,339 $ 994 $ 661 $ 16,994 Capital expenditures (a) $ 1,018 $ — $ 14 $ 1,032 (a) Includes accruals and excludes acquisitions. (b) Unrealized gain on commodity derivative instruments (See Note 16 ). (c) Includes a $20 million loss associated with a previously divested non-core conventional asset, a $12 million pre-tax loss associated with a reduction in our ownership interest in EG LNG (See Note 24 ) and an $8 million gain on various well bore assignments in Permian and Bakken. (d) Includes unproved property impairments of $20 million for Louisiana exploration leases and $16 million related to the disposition of a lease in Permian. Also includes $28 million of expense associated with drilled and uncompleted wells, primarily in Permian, due to a change in our plan of development (See Note 1 1 ). (e) Includes impairments of $24 million for central facilities in Eagle Ford (See Note 12 ), $5 million for proved properties in Permian (See Note 1 2 ) and $30 million associated with decommissioning costs for non-producing long-lived assets in GOM (See Note 1 2 , Note 13 , and Note 26 ) (f) Includes $13 million associated with the termination of an aircraft lease agreement and $12 million arising from severance expenses associated with a workforce reduction. (g) Includes a $28 million gain on our 2022 interest rate swaps and a $27 million gain on our 2025 interest rate swaps (See Note 16 ). (h) Represents costs related to a make-whole provision premium and the write off of unamortized discount and issuance costs in regards to the redemption of the 2022 Notes in April 2021 and 2025 Notes in September 2021 (See Note 18 ). Year Ended December 31, 2020 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 2,924 $ 173 $ — $ 3,097 Net gain (loss) on commodity derivatives 143 — (27) (b) 116 Income (loss) from equity method investments — 10 (171) (c) (161) Net gain on disposal of assets — — 9 9 Other income 15 7 3 25 Less costs and expenses: Production 494 59 2 555 Shipping, handling and other operating 534 8 54 596 Exploration 97 — 84 (d) 181 Depreciation, depletion and amortization 2,211 82 23 2,316 Impairments — — 144 (e) 144 Taxes other than income 193 — 7 200 General and administrative 115 14 145 (f) 274 Net interest and other — — 256 256 Other net periodic benefit (credit) cost — — 1 (g) 1 Loss on early extinguishment of debt — — 28 28 Income tax benefit (9) (3) (2) (14) Segment income (loss) $ (553) $ 30 $ (928) $ (1,451) Total assets $ 16,063 $ 1,081 $ 812 $ 17,956 Capital expenditures (a) $ 1,137 $ 1 $ 13 $ 1,151 (a) Includes accruals and excludes acquisitions. (b) Unrealized loss on commodity derivative instruments (See Note 16 ). (c) Partial impairment of investment in equity method investee (See Note 24 ). (d) Primarily related to unproved property impairments of non-core acreage in our United States segment. (e) Includes the full impairment of the International reporting unit goodwill of $95 million (See Note 15 ) and proved property impairments of $49 million related to a damaged well in our United States segment. (f) Includes severance expenses associated with workforce reductions of $17 million. (g) Includes pension settlement loss of $30 million and pension curtailment gain of 17 million (See Note 20 ). Year Ended December 31, 2019 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 4,602 $ 461 $ — $ 5,063 Net gain (loss) on commodity derivatives 52 — (124) (b) (72) Income (loss) from equity method investments — 87 — 87 Net gain on disposal of assets — — 50 (c) 50 Other income 13 9 40 62 Less costs and expenses: Production 588 126 (2) 712 Shipping, handling and other operating 561 26 18 605 Exploration 149 — — 149 Depreciation, depletion and amortization 2,250 121 26 2,397 Impairments — — 24 (d) 24 Taxes other than income 311 — — 311 General and administrative 127 25 204 356 Net interest and other — — 244 244 Other net periodic benefit (credit) cost — (3) — (e) (3) Loss on early extinguishment of debt — — 3 3 Income tax provision (benefit) 6 29 (123) (88) Segment income (loss) $ 675 $ 233 $ (428) $ 480 Total assets $ 17,781 $ 1,530 $ 934 $ 20,245 Capital expenditures (a) $ 2,550 $ 16 $ 25 $ 2,591 (a) Includes accruals and excludes acquisitions. (b) Unrealized loss on commodity derivative instruments (See Note 16 ). (c) Primarily related to the sale of our working interest in the Droshky field (Gulf of Mexico) and the sale of our U.K. business (See Note 5 ). (d) Primarily a result of anticipated sales of non-core proved properties in our International and United States segments (See Note 12 ). (e) Includes pension settlement loss of $12 million (See Note 20 ). The following summarizes property, plant and equipment and equity method investments. December 31, (In millions) 2021 2020 United States $ 14,152 $ 15,224 Equatorial Guinea 797 861 Total long-lived assets $ 14,949 $ 16,085

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes Income (loss) before income taxes were: Year Ended December 31, (In millions) 2021 2020 2019 United States $ 637 $ (1,319) $ 43 Foreign 367 (146) 349 Total $ 1,004 $ (1,465) $ 392 Income tax provisions (benefits) were: Year Ended December 31, 2021 2020 2019 (In millions) Current Deferred Total Current Deferred Total Current Deferred Total Federal $ — $ — $ — $ (5) $ — $ (5) $ (116) $ (3) $ (119) State and local 4 1 5 (2) (8) (10) 4 3 7 Foreign 81 (28) 53 15 (14) 1 58 (34) 24 Total $ 85 $ (27) $ 58 $ 8 $ (22) $ (14) $ (54) $ (34) $ (88) A reconciliation of the federal statutory income tax rate applied to income (loss) before income taxes to the provision (benefit) for income taxes follows: Year Ended December 31, (In millions) 2021 2020 2019 Total pre-tax income (loss) $ 1,004 $ (1,465) $ 392 Total income tax provision (benefit) $ 58 $ (14) $ (88) Effective income tax rate 6 % 1 % (22) % Income taxes at the statutory tax rate $ 211 $ (308) $ 83 Effects of foreign operations (13) 23 (29) Adjustments to valuation allowances (166) 239 (28) State income taxes, net of federal benefit 23 6 11 Tax law change (2) — — Other federal tax effects 5 26 (125) Income tax provision (benefit) $ 58 $ (14) $ (88) The effective income tax rate is influenced by a variety of factors including the geographic and functional sources of income and the relative magnitude of these sources of income. The difference between the total provision and the sum of the amounts allocated to segments is reported in the “Not Allocated to Segments” column of the tables in Note 5 . Effects of foreign operations – The effects of foreign operations decreased our tax provision in 2021 largely due to the income mix within E.G. between equity method investees and subsidiaries which can reduce the effective tax rate below the U.S. statutory tax rate. The effects of foreign operations increased our tax provision in 2020 largely due to book losses in foreign jurisdictions with no corresponding tax benefits. The effects of foreign operations decreased our tax provision in 2019 due to tax benefits related to our U.K. operations and pre-tax income in jurisdictions with effective tax rates lower than the U.S. Adjustments to valuation allowances – Since December 31, 2016, we have maintained a full valuation allowance on our net federal deferred tax assets. In all years, the most significant driver for the change in valuation allowance was due to current year activity in the U.S. We intend to continue a full valuation allowance on these deferred tax assets until there is sufficient evidence to support the reversal of all or some portion of the allowance. However, if current commodity prices are sustained and absent any additional objective negative evidence, we expect it is reasonably possible that sufficient positive evidence will exist within the next 12 months to adjust our current valuation allowance position. Exact timing and amount of the adjustment to the valuation allowance is unknown as this time. Other federal tax effects – In 2020, the increase to other federal tax effects is largely related to non-deductible goodwill impairment. The 2019 decrease in other federal tax effects is primarily related to the settlement of the 2010-2011 U.S. Federal Tax Audit (“IRS Audit”) in the first quarter of 2019. The release of the accrued tax positions resulted in a $126 million tax benefit, primarily related to AMT credits. Deferred tax assets and liabilities resulted from the following: Year Ended December 31, (In millions) 2021 2020 Deferred tax assets: Employee benefits $ 66 $ 77 Operating loss carryforwards 1,541 1,966 Foreign tax credits 611 611 Other (a) 52 67 Subtotal 2,270 2,721 Valuation allowance (780) (948) Total deferred tax assets 1,490 1,773 Deferred tax liabilities: Property, plant and equipment (a) 1,544 1,879 Accrued revenue — 20 Other (a) 82 37 Total deferred tax liabilities 1,626 1,936 Net deferred tax liabilities $ 136 $ 163 Net deferred tax assets $ — $ — (a) 2020 balances were reclassified to conform to current period’s presentation. The total Net deferred tax liabilities balance was not impacted by the change in presentation. Operating loss carryforwards – At December 31, 2021, we have a gross deferred tax asset related to our operating loss carryforwards of $1.5 billion, before valuation allowance. U.S. operating loss carryforwards relating to tax years beginning prior to January 1, 2018, include $1.4 billion ($295 million deferred tax asset) that expire in 2036 - 2037. U.S. operating loss carryforwards for tax years beginning after December 31, 2017, include $5.3 billion ($1.1 billion deferred tax asset) which can be carried forward indefinitely. Foreign operating loss carryforwards include $26 million that expire in 2022 - 2027. State operating loss carryforwards of $3.3 billion ($125 million deferred tax asset) expire in 2022 through 2040. Foreign tax credits – At December 31, 2021, we reflect foreign tax credits of $611 million, which will expire in years 2022 through 2026. Valuation allowances – At December 31, 2021, we reflect a valuation allowance in our consolidated balance sheet of $780 million against our net deferred tax assets in various jurisdictions in which we operate. The decrease in valuation allowance primarily relates to current year activity in the U.S. Property, plant and equipment – At December 31, 2021, we reflected a deferred tax liability of $1.5 billion. The decrease primarily relates to current year activity in the U.S. Net deferred tax assets and liabilities were classified in the consolidated balance sheets as follows: December 31, (In millions) 2021 2020 Assets: Other noncurrent assets $ — $ — Liabilities: Noncurrent deferred tax liabilities 136 163 Net deferred tax liabilities $ 136 $ 163 Net deferred tax assets $ — $ — We are routinely undergoing examinations in the jurisdictions in which we operate. As of December 31, 2021, our income tax returns remain subject to examination in the following major tax jurisdictions for the tax years indicated: United States (a) 2010 - 2020 Equatorial Guinea 2007 - 2020 (a) Includes federal and state jurisdictions. The following table summarizes the activity in unrecognized tax benefits: (In millions) 2021 2020 2019 Beginning balance $ 8 $ 13 $ 263 Additions for tax positions of prior years 2 — 13 Reductions for tax positions of prior years — (5) (152) Settlements — — (111) Ending balance $ 10 $ 8 $ 13 If the unrecognized tax benefits as of December 31, 2021 were recognized, $10 million would affect our effective income tax rate. As of December 31, 2021, we do not expect uncertain tax positions to significantly change within the next twelve months. During the first quarter of 2019, we withdrew our appeal related to the Brae area decommissioning costs in the U.K., thus the uncertain tax positions previously established are now considered effectively settled with no tax provision or benefit impact. Also, in the first quarter of 2019, we settled the 2010-2011 IRS Audit, resulting in a tax benefit of $126 million. Interest and penalties are recorded as part of the tax provision and were immaterial for 2021, a $2 million tax benefit in 2020 and a $6 million tax provision in 2019. As of December 31, 2021 and 2020, we had no significant accrued interest or penalties related to income taxes. For December 31, 2019, $3 million of interest and penalties were accrued related to income taxes. In the third quarter of 2020, we received an $89 million cash refund related to alternative minimum tax credits and interest. This refund was accelerated as a result of the enactment of the Coronavirus Aid, Relief, and Economic Security Act, commonly referred to as the CARES Act, in the first quarter of 2020.

Credit Losses

Credit Losses	12 Months Ended
	Dec. 31, 2021
Credit Loss [Abstract]
Credit Losses	Credit Losses The majority of our receivables are from purchasers of commodities or joint interest owners in properties we operate, both of which are recorded at estimated or invoiced amounts and do not bear interest. The majority of these receivables have payment terms of 30 days or less. At the end of each reporting period, we assess the collectability of our receivables and estimate the expected credit losses using historical data, current market conditions and reasonable and supportable forecasts of future economic conditions and other data as deemed appropriate. We are exposed to credit losses through the receivables generated from sales of crude oil, NGLs and natural gas to our customers. When dealing with the commodity purchasers, we conduct a credit review to assess each counterparty’s ability to pay. The credit review considers our expected billing exposure, timing for payment and the counterparty’s established credit rating with the rating agencies or our internal assessment of the counterparty’s creditworthiness based on our analysis of their financial statements. Our evaluation also considers contract terms and other factors, such as country and/or political risk. A credit limit is established for each counterparty based on the outcome of this review. We may require a bank letter of credit or a prepayment to mitigate credit risk. We monitor our ongoing credit exposure through active review of counterparty balances against contract terms and due dates. The expected credit losses related to receivables with the commodity purchasers were determined using the weighted average probability of default method. We also collect revenues from our non-operated joint properties where other oil and gas exploration and production companies operate the properties and market our share of production and remit payments to us. The current expected credit losses related to these receivables were determined using the loss rate method applied to aging pools. We are exposed to credit losses from joint interest billings to other joint interest owners for properties we operate. For this group of receivables, the expected credit losses are determined using the loss rate method applied to aging pools. Our counterparties in this group include numerous large, mid-size and small oil and gas exploration and production companies. Although we may have the ability to withhold future revenue disbursements to recover any non-payment of joint interest billings or require a prepayment of future costs through cash calls, our credit loss exposure with this group is more significant due to inherent ownership or billing adjustments. Also, some of our counterparties may experience liquidity problems and may not be able to meet their financial obligations to us. Changes in the reserve for credit losses balance for the year were as follows: December 31, (In millions) 2021 2020 Beginning balance as of January 1 $ 22 $ 11 Cumulative-effect adjustment — 12 Current period provision (a) 3 22 Current period write offs (5) (13) Recoveries of amounts previously reserved (5) (10) Ending balance as of December 31 $ 15 $ 22 (a) As of December 31, 2020, the current period provision consisted of $10 million in joint interest receivables and $12 million in trade receivables.

Inventories

Inventories	12 Months Ended
	Dec. 31, 2021
Inventory Disclosure [Abstract]
Inventories	Inventories Crude oil and natural gas are recorded at weighted average cost and carried at the lower of cost or net realizable value. Supplies and other items consist principally of tubular goods and equipment which are valued at weighted average cost and reviewed periodically for obsol escence or impairment when market conditions indicate. December 31, (In millions) 2021 2020 Crude oil and natural gas $ 8 $ 10 Supplies and other items 69 66 Inventories $ 77 $ 76

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2021
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment December 31, (In millions) 2021 2020 United States $ 14,097 $ 15,156 International 347 414 Not allocated to segments 55 68 Net property, plant and equipment $ 14,499 $ 15,638 Changes in our capitalized exploratory well costs were as follows: December 31, (In millions) 2021 2020 2019 Beginning balance as of January 1 $ 210 $ 278 $ 297 Additions 50 97 218 Charges to expense (30) (1) (5) Transfers to development (68) (164) (230) Dispositions — — (2) Ending balance as of December 31 $ 162 $ 210 $ 278 As of December 31, 2021 and 2020, we had $80 million and $98 million, respectively, of exploratory well costs capitalized greater than one year related to suspended wells. Management believes these wells exhibit sufficient quantities of hydrocarbons to justify potential development. The vast majority of the suspended wells require completion activities and installation of infrastructure in order to classify the reserves as proved. Of the $80 million as of December 31, 2021, approximately $40 million pertains to 2020, $34 million to 2019, and the remaining $6 million attributable to 2018 activities.

Impairment

Impairment	12 Months Ended
	Dec. 31, 2021
Impairments and Exploration Expenses [Abstract]
Impairments	Impairments The following table summarizes impairment charges of proved properties, goodwill and equity method investments and their corresponding fair values. 2021 2020 2019 (In millions) Fair Value Impairment Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ — $ 30 $ — $ 49 $ 56 $ 24 Asset retirement costs of long-lived assets — 30 — — — — Goodwill — — — 95 — — Equity method investment $ — $ — $ 119 $ 171 $ — $ — • 2021 – During the second quarter of 2021, we recorded an impairment expense of $24 million associated with two central facilities located in Eagle Ford. Decommissioning activities associated with these central facilities included the re-routing of existing wells. During the third quarter of 2021, we recorded an impairment expense of $5 million associated with our interests in outside operated conventional assets located in New Mexico. During the year ended December 31, 2021, we also recognized an incremental $30 million of impairment expense associated with an increase in the estimated future decommissioning costs of certain non-producing wells, pipelines and production facilities for previously divested offshore assets located in the Gulf of Mexico. In a prior reporting period, we recorded a $7 million liability in our consolidated balance sheet associated with these assets. Thus, the incremental expense in 2021 increased the total recognized asset retirement obligation to $37 million as of December 31, 2021. See Note 13 and Note 26 for further information. The combined effects of these items were recorded within the Impairments line item within our consolidated statements of income. • 2020 – Impairments totaling $49 million of long-lived assets held for use resulted from a damaged, unsalvageable well and related equipment in the Louisiana Austin Chalk. The related fair value was measured based on the salvage value which resulted in a Level 3 classification. We impaired the entire balance of our goodwill in the International reporting unit totaling $95 million of goodwill. See Note 15 for further information. Impairments also include charges recognized for our equity method investments of $171 million. During the second and third quarters of 2020, the continuation of the depressed commodity prices, along with a reduction of our long-term price forecasts of a gas index in which one of our equity method investees transacts, caused us to perform a review of one of our equity method investments. Our review concluded that a loss of our investment value in one was other than temporary and we recorded an impairment. Our remaining investments in equity method investees did not experience losses in value that caused the fair values to be below their carrying values. We estimated the fair value of our equity method investment using an income approach, specifically utilizing a discounted cash flow analysis. The estimated fair value was based on significant inputs not observable in the market, such as the amount of gas processed by the plant, future commodity prices, forecasted operating expenses, discount rate and estimated cash returned to shareholders. Collectively, these inputs represent Level 3 measurements. The impairments of our equity method investments were recognized in income (loss) from equity method investments in our consolidated statements of income. The impairments caused us to incur a basis differential between the net book value of our investment and the amount of our underlying share of equity in the investee’s net assets. The amount of this basis differential was $140 million and is being accreted into income over the remaining useful life of the investee’s primary assets. Finally, we impaired $78 million of unproved property leases in Louisiana Austin Chalk in our United States segment, which was recognized in exploration expense in our consolidated statements of income. The impairment resulted from a combination of factors including our geological assessment, seismic information, timing of lease expiration dates and decisions not to develop acreage deemed non-core. Collectively, these inputs represent Level 3 measurements. • 2019 – Impairments of $24 million, to an aggregate fair value of $56 million, were primarily a result of anticipated sales for certain non-core proved properties in our United States segment and the sale of our non-operated interest in the Atrush block (Kurdistan) in our International segment. The related fair value was measured using the market approach, based upon anticipated sales proceeds less costs to sell which resulted in a Level 2 classification. See Note 5 for discussion of the divestitures in further detail and Note 7 for relevant detail regarding segment presentation.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2021
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations Asset retirement obligations primarily consist of estimated costs to remove, dismantle and restore land or seabed at the end of oil and gas production operations. Changes in asset retirement obligations were as follows: December 31, (In millions) 2021 2020 Beginning balance as of January 1 $ 254 $ 254 Incurred liabilities, including acquisitions 14 6 Settled liabilities, including dispositions (6) (12) Accretion expense (included in depreciation, depletion and amortization) 12 12 Revisions of estimates 42 (6) Ending balance as of December 31 $ 316 $ 254 Ending balance as of December 31, short-term $ 28 $ 13 During the year ended December 31, 2021, we had revisions of estimates totaling $37 million related to anticipated costs for decommissioning certain wells, pipelines and production facilities for previously divested offshore non-producing long-lived assets located in the Gulf of Mexico. As of December 31, 2021, $14 million of these Gulf of Mexico related revisions of estimates were classified as short-term. See Note 26 for further information. Of the $37 million, approximately $30 million was recognized as impairment expense during the year ended December 31, 2021. See Note 12

Leases

Leases	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Leases	Leases Lessee Operating Leases We enter into various lease agreements to support our operations including drilling rigs, well fracturing equipment, compressors, buildings, aircraft, vessels, vehicles and miscellaneous field equipment. We primarily act as a lessee in these transactions and the majority of our existing leases are classified as either short-term or long-term operating leases. The majority of the drilling rig agreements and all of fracturing equipment agreements are classified as short-term leases based on the noncancellable period for which we have the right to use the equipment and assessment of options present in each agreement. We also incur variable lease costs under these agreements primarily related to chemicals and sand used in fracturing operations or various additional on-demand equipment and labor. The lease costs associated with the drilling rigs and fracturing equipment are primarily capitalized as part of the well costs. Our existing long-term leases are comprised of compressors, drilling rigs, vessels, vehicles and miscellaneous field equipment. Our lease agreements may require both fixed and variable payments; none of the variable payments are rate or index-based, therefore only fixed payments were considered for recognizing lease liabilities and right-of-use (‘ROU’) assets related to long-term leases. Also, based on our election not to separate the lease and nonlease components, fixed payments related to equipment, crew and other nonlease components are included in the initial measurement of lease liabilities and ROU assets for all asset classes, except for vessels. For vessels, the contractual consideration was allocated between lease and nonlease components based on estimates provided by service providers. Our leased assets may be used in joint oil and gas operations with other working interest owners. We recognize lease liabilities and ROU assets only when we are the signatory to a contract as an operator of joint properties. Such lease liabilities and ROU assets are determined based on gross contractual obligations. As we use the leased assets for joint operations, we have the contractual right to recover the other working interest owners’ share of lease costs. As a result, our lease costs are presented on a net basis, reduced for any costs recoverable from other working interest owners. Finance Leases In 2018, we signed an agreement with an owner/lessor to construct and lease a new build-to-suit office building in Houston, Texas. As of December 31, 2021, project costs totaled approximately $302 million, including land acquisition and construction costs. The initial lease term is five years and commenced in late September 2021 after the new Houston office was ready for occupancy. In the third quarter of 2021, we recorded a $32 million ROU asset and corresponding lease liability Balance Sheet Information Balance sheet information related to ROU assets and lease liabilities was as follows: December 31, (In millions) 2021 2020 ROU assets: Balance Sheet Location: Operating leases Other noncurrent assets $ 59 $ 133 Finance leases Other noncurrent assets 28 — Total ROU assets $ 87 $ 133 Lease liabilities: Current liabilities Operating leases Other current liabilities $ 40 $ 70 Finance leases Other current liabilities 6 — Noncurrent liabilities Operating leases Deferred credits and other liabilities 23 67 Finance leases Deferred credits and other liabilities 24 — Total lease liabilities $ 93 $ 137 Statements of Income Information The table below presents our net lease costs for the years ended December 31, 2021 and 2020. (In millions) Year Ended December 31, 2021 Year Ended December 31, 2020 Operating lease costs: Short-term lease costs (a) $ 121 $ 170 Long-term lease costs (b) 64 75 Variable lease costs (c) 33 23 Finance lease costs: Amortization of ROU assets 3 — Total lease costs $ 221 $ 268 Other information: Cash paid for amounts included in the measurement of operating lease liabilities $ 73 $ 100 ROU assets obtained in exchange for new operating lease liabilities (d) 15 46 ROU assets obtained in exchange for new finance lease liabilities (e) 28 — Reductions to ROU assets resulting from modifications or cancellations of operating leases $ (13) $ (68) (a) Represents our net share of lease costs arising from leases of less than one year but longer than one month that were not included in the lease liability. (b) Represents our net share of the ROU asset amortization and the interest expense. (c) Represents our net share of variable lease payments that were not included in the lease liability. (d) Represents the cumulative value of operating lease ROU assets recognized at lease inception. This amount is then amortized as we utilize the ROU asset, the net effect of which is the ending ROU asset (first table above). (e) Represents the cumulative value of finance lease ROU assets recognized at lease inception during the year of 2021. This amount is then amortized as we utilize the ROU asset, the net effect of which is the ending ROU asset of $28 million (first table above). Annual Lease Maturities The remaining annual undiscounted cash flows associated with long-term leases and the reconciliation of these cash flows to the lease liabilities recognized on the consolidated balance sheet is summarized below. (In millions) Operating Lease Obligations Finance Lease Obligations Total Lease Obligations 2022 $ 45 $ 7 $ 52 2023 8 7 15 2024 5 7 12 2025 4 7 11 2026 2 4 6 Thereafter — — — Total undiscounted lease payments $ 64 $ 32 $ 96 Less: amount representing interest 1 2 3 Total lease liabilities $ 63 $ 30 $ 93 Less: current portion of lease liability as of December 31, 2021 40 6 46 Long-term lease liability as of December 31, 2021 $ 23 $ 24 $ 47 Other Information We use our periodic incremental borrowing rate to discount future contractual payments to their present values. For our operating leases, the weighted average lease term is two years and the discount rate is 3% as of December 31, 2021. For our finance leases, the weighted-average remaining lease term is five years and the discount rate is 2% as of December 31, 2021. Lessor Our wholly owned subsidiary, Marathon E.G. Production Limited, is a lessor for residential housing in Equatorial Guinea, which is occupied by EGHoldings, a related party equity method investee – see Note 24 . The lease was classified as an operating lease and expires in 2024, with a lessee option to extend through 2034. Lease payments are fixed for the entire duration of the agreement at approximately $6 million per year. Our lease income is reported in other income in our consolidated statements of income for all periods presented. The undiscounted cash flows to be received under this lease agreement are summarized below. (In millions) Operating Lease Future Cash Receipts 2022 $ 6 2023 6 2024 6 2025 6 2026 6 Thereafter 49 Total undiscounted cash flows $ 79
Leases	Leases Lessee Operating Leases We enter into various lease agreements to support our operations including drilling rigs, well fracturing equipment, compressors, buildings, aircraft, vessels, vehicles and miscellaneous field equipment. We primarily act as a lessee in these transactions and the majority of our existing leases are classified as either short-term or long-term operating leases. The majority of the drilling rig agreements and all of fracturing equipment agreements are classified as short-term leases based on the noncancellable period for which we have the right to use the equipment and assessment of options present in each agreement. We also incur variable lease costs under these agreements primarily related to chemicals and sand used in fracturing operations or various additional on-demand equipment and labor. The lease costs associated with the drilling rigs and fracturing equipment are primarily capitalized as part of the well costs. Our existing long-term leases are comprised of compressors, drilling rigs, vessels, vehicles and miscellaneous field equipment. Our lease agreements may require both fixed and variable payments; none of the variable payments are rate or index-based, therefore only fixed payments were considered for recognizing lease liabilities and right-of-use (‘ROU’) assets related to long-term leases. Also, based on our election not to separate the lease and nonlease components, fixed payments related to equipment, crew and other nonlease components are included in the initial measurement of lease liabilities and ROU assets for all asset classes, except for vessels. For vessels, the contractual consideration was allocated between lease and nonlease components based on estimates provided by service providers. Our leased assets may be used in joint oil and gas operations with other working interest owners. We recognize lease liabilities and ROU assets only when we are the signatory to a contract as an operator of joint properties. Such lease liabilities and ROU assets are determined based on gross contractual obligations. As we use the leased assets for joint operations, we have the contractual right to recover the other working interest owners’ share of lease costs. As a result, our lease costs are presented on a net basis, reduced for any costs recoverable from other working interest owners. Finance Leases In 2018, we signed an agreement with an owner/lessor to construct and lease a new build-to-suit office building in Houston, Texas. As of December 31, 2021, project costs totaled approximately $302 million, including land acquisition and construction costs. The initial lease term is five years and commenced in late September 2021 after the new Houston office was ready for occupancy. In the third quarter of 2021, we recorded a $32 million ROU asset and corresponding lease liability Balance Sheet Information Balance sheet information related to ROU assets and lease liabilities was as follows: December 31, (In millions) 2021 2020 ROU assets: Balance Sheet Location: Operating leases Other noncurrent assets $ 59 $ 133 Finance leases Other noncurrent assets 28 — Total ROU assets $ 87 $ 133 Lease liabilities: Current liabilities Operating leases Other current liabilities $ 40 $ 70 Finance leases Other current liabilities 6 — Noncurrent liabilities Operating leases Deferred credits and other liabilities 23 67 Finance leases Deferred credits and other liabilities 24 — Total lease liabilities $ 93 $ 137 Statements of Income Information The table below presents our net lease costs for the years ended December 31, 2021 and 2020. (In millions) Year Ended December 31, 2021 Year Ended December 31, 2020 Operating lease costs: Short-term lease costs (a) $ 121 $ 170 Long-term lease costs (b) 64 75 Variable lease costs (c) 33 23 Finance lease costs: Amortization of ROU assets 3 — Total lease costs $ 221 $ 268 Other information: Cash paid for amounts included in the measurement of operating lease liabilities $ 73 $ 100 ROU assets obtained in exchange for new operating lease liabilities (d) 15 46 ROU assets obtained in exchange for new finance lease liabilities (e) 28 — Reductions to ROU assets resulting from modifications or cancellations of operating leases $ (13) $ (68) (a) Represents our net share of lease costs arising from leases of less than one year but longer than one month that were not included in the lease liability. (b) Represents our net share of the ROU asset amortization and the interest expense. (c) Represents our net share of variable lease payments that were not included in the lease liability. (d) Represents the cumulative value of operating lease ROU assets recognized at lease inception. This amount is then amortized as we utilize the ROU asset, the net effect of which is the ending ROU asset (first table above). (e) Represents the cumulative value of finance lease ROU assets recognized at lease inception during the year of 2021. This amount is then amortized as we utilize the ROU asset, the net effect of which is the ending ROU asset of $28 million (first table above). Annual Lease Maturities The remaining annual undiscounted cash flows associated with long-term leases and the reconciliation of these cash flows to the lease liabilities recognized on the consolidated balance sheet is summarized below. (In millions) Operating Lease Obligations Finance Lease Obligations Total Lease Obligations 2022 $ 45 $ 7 $ 52 2023 8 7 15 2024 5 7 12 2025 4 7 11 2026 2 4 6 Thereafter — — — Total undiscounted lease payments $ 64 $ 32 $ 96 Less: amount representing interest 1 2 3 Total lease liabilities $ 63 $ 30 $ 93 Less: current portion of lease liability as of December 31, 2021 40 6 46 Long-term lease liability as of December 31, 2021 $ 23 $ 24 $ 47 Other Information We use our periodic incremental borrowing rate to discount future contractual payments to their present values. For our operating leases, the weighted average lease term is two years and the discount rate is 3% as of December 31, 2021. For our finance leases, the weighted-average remaining lease term is five years and the discount rate is 2% as of December 31, 2021. Lessor Our wholly owned subsidiary, Marathon E.G. Production Limited, is a lessor for residential housing in Equatorial Guinea, which is occupied by EGHoldings, a related party equity method investee – see Note 24 . The lease was classified as an operating lease and expires in 2024, with a lessee option to extend through 2034. Lease payments are fixed for the entire duration of the agreement at approximately $6 million per year. Our lease income is reported in other income in our consolidated statements of income for all periods presented. The undiscounted cash flows to be received under this lease agreement are summarized below. (In millions) Operating Lease Future Cash Receipts 2022 $ 6 2023 6 2024 6 2025 6 2026 6 Thereafter 49 Total undiscounted cash flows $ 79

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2021
Goodwill Disclosure [Abstract]
Goodwill	Goodwill Goodwill is tested for impairment on an annual basis, or between annual tests when events or changes in circumstances indicate the fair value may have been reduced below its carrying value. During the first quarter of 2020, a global pandemic caused a substantial deterioration in the worldwide demand of hydrocarbons. The commensurate decline in our market capitalization during the first quarter indicated that it was more likely than not that the fair value of the International reporting unit was less than its carrying value. We estimated the fair value of our International reporting unit using a combination of market and income approaches. The market approach referenced observable inputs specific to us and our industry, such as the price of our common equity, our enterprise value and valuation multiples of us and peers from the investor analyst community. The income approach utilized

Derivatives

Derivatives	12 Months Ended
	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives See Note 17 for further information regarding the fair value measurement of derivative instruments. See Note 1 for discussion of the types of derivatives we may use and the reasons for them. All of our commodity derivatives and interest rate derivatives are/were subject to enforceable master netting arrangements or similar agreements under which we report net amounts. The following tables present the gross fair values of our open derivative instruments and the reported net amounts along with where they appear on the consolidated balance sheets. December 31, 2021 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ 1 $ 8 $ (7) Other current liabilities Interest Rate 27 — 27 Other noncurrent assets Total Not Designated as Hedges $ 28 $ 8 $ 20 Cash Flow Hedges Interest Rate $ — $ 3 $ (3) Other current liabilities Interest Rate — 2 (2) Deferred credits and other liabilities Total Designated Hedges $ — $ 5 $ (5) Total $ 28 $ 13 $ 15 December 31, 2020 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ 3 $ 1 $ 2 Other current assets Commodity 7 32 (25) Other current liabilities Interest Rate 10 — 10 Other noncurrent assets Total Not Designated as Hedges $ 20 $ 33 $ (13) Cash Flow Hedges Interest Rate $ 19 $ — $ 19 Other noncurrent assets Interest Rate — 16 (16) Deferred credits and other liabilities Total Designated Hedges $ 19 $ 16 $ 3 Total $ 39 $ 49 $ (10) Derivatives Not Designated as Hedges Commodity Derivatives We have entered into multiple crude oil and natural gas derivatives indexed to the respective indices as noted in the table below, related to a portion of our forecasted United States sales through 2022. These derivatives consist of three-way collars and NYMEX roll basis swaps. Three-way collars consist of a sold call (ceiling), a purchased put (floor) and a sold put. The ceiling price is the maximum we will receive for the contract volumes; the floor is the minimum price we will receive, unless the market price falls below the sold put strike price. In this case, we receive the NYMEX WTI price plus the difference between the floor and the sold put price. Two-way collars only consist of a sold call (ceiling) and a purchased put (floor). These crude oil and natural gas derivatives were not designated as hedges. The following table sets forth outstanding derivative contracts as of December 31, 2021 and the weighted average prices for those contracts: 2022 First Quarter Second Quarter Third Quarter Fourth Quarter Crude Oil NYMEX WTI Three-Way Collars Volume (Bbls/day) 50,000 50,000 20,000 20,000 Weighted average price per Bbl: Ceiling $ 92.26 $ 92.26 $ 92.80 $ 92.80 Floor $ 52.00 $ 52.00 $ 50.00 $ 50.00 Sold put $ 42.00 $ 42.00 $ 40.00 $ 40.00 NYMEX Roll Basis Swaps Volume (Bbls/day) 45,000 45,000 45,000 45,000 Weighted average price per Bbl $ 0.56 $ 0.56 $ 0.56 $ 0.56 Natural Gas Henry Hub (“HH”) Three-Way Collars Volume (MMBtu/day) 50,000 — — — Weighted average price per MMBtu: Ceiling $ 5.14 $ — $ — $ — Floor $ 3.60 $ — $ — $ — Sold Put $ 2.60 $ — $ — $ — The following table sets forth our outstanding derivative contracts as of February 14, 2022, with their weighted average prices, and is inclusive of activity that occurred subsequent to December 31, 2021. 2022 First Quarter Second Quarter Third Quarter Fourth Quarter Crude Oil NYMEX WTI Three-Way Collars Volume (Bbls/day) 50,000 50,000 50,000 50,000 Weighted average price per Bbl: Ceiling $ 96.54 $ 98.79 $ 97.52 $ 97.52 Floor $ 55.93 $ 58.00 $ 56.67 $ 56.67 Sold put $ 45.93 $ 48.00 $ 46.67 $ 46.67 NYMEX Roll Basis Swaps Volume (Bbls/day) 50,167 60,000 60,000 60,000 Weighted average price per Bbl $ 0.60 $ 0.67 $ 0.67 $ 0.67 Natural Gas HH Three-Way Collars Volume (MMBtu/day) 50,000 50,000 50,000 50,000 Weighted average price per MMBtu: Ceiling $ 5.14 $ 6.18 $ 6.18 $ 6.18 Floor $ 3.60 $ 3.50 $ 3.50 $ 3.50 Sold put $ 2.60 $ 2.50 $ 2.50 $ 2.50 The unrealized and realized gain (loss) impact of our commodity derivative instruments appears in the table below and is reflected in net gain (loss) on commodity derivatives in the consolidated statements of income. Year Ended December 31, (In millions) 2021 2020 2019 Unrealized gain (loss) on derivative instruments, net $ 16 $ (27) $ (124) Realized gain (loss) on derivative instruments, net (a) $ (399) $ 143 $ 52 (a) During the year ended 2021, net cash paid for settled derivative positions was $356 million. During the years ended 2020 and 2019, net cash received for settled derivative positions was $123 million and $65 million, respectively. Interest Rate Swaps During 2020, we entered into forward starting interest rate swaps with a notional amount of $500 million to hedge the variations in cash flows as a result of fluctuations in the London Interbank Offered Rate (“LIBOR”) benchmark interest rate related to forecasted interest payments of a future d ebt issuance in 2022. Each respective derivative contract was associated with an anticipated underlying dollar notional amount. During the third quarter of 2020, we de-designated these forward starting interest rate swaps previously designated as cash flow hedges. In the first quarter of 2021, the net deferred loss of $2 million in accumulated other comprehensive income related to these hedges was reclassified from accumulated other comprehensive income into earnings as an adjustment to net interest, as we fully redeemed the remainder of our outstanding 2022 notes in April 2021. See Note 18 for further details about the debt redemption. In November 2021, we closed the positions and settled the interest rate swaps. During the twelve months ended December 31, 2021, our cumulative gains recorded within net interest totaled $28 million for these swaps . During 2020, we entered into forward starting interest rate swaps with a notional amount of $350 million to hedge variations in cash flows arising from fluctuations in the LIBOR benchmark interest rate related to forecasted interest payments of a future debt issuance in 2025. The expected proceeds of the future debt issuance were intended to refinance the $900 million 3.85% Senior Notes due 2025 (“2025 Notes”). During the second quarter of 2021, we de-designated these forward interest rate swaps previously designated as cash flow hedges because we no longer planned to refinance the 2025 Notes. In the second quarter of 2021, we reclassified the $31 million cumulative gain related to these hedges from accumulated other comprehensive income into earnings as an adjustment to net interest. In September 2021, we fully redeemed these 2025 Notes. See Note 18 for further details about the debt redemption. These positions remain open. Subsequent to the de-designation, we recorded additional mark-to-market losses totaling $4 million. Thus, for the twelve months ended December 31, 2021, the total amount recorded within net interest related to these swaps was $27 million. During the second quarter of 2021, we de-designated $25 million of the $320 million Houston office cash flow hedges (discussed further in the Derivatives Designated as Cash Flow Hedges section below), as the construction cost budget estimate was reduced. The $1 million loss of these de-designated cash flow hedges as of June 30, 2021 was reclassified from accumulated other comprehensive income into earnings as an adjustment to net interest. The mark-to-market activity within net interest to reflect the change in value of these interest rate swaps during the year ended December 31, 2021 was immaterial. The following table presents, by maturity date, information about our de-designated forward starting interest rate swap agreements, including the rate. We have the discretion to liquidate the positions should we choose. December 31, 2021 December 31, 2020 Maturity Date Aggregate Notional Amount (in millions) Weighted Average, LIBOR Aggregate Notional Amount (in millions) Weighted Average, LIBOR November 1, 2022 $ — — % $ 500 0.99 % June 1, 2025 $ 350 0.95 % N/A N/A September 9, 2026 $ 25 1.45 % N/A N/A Derivatives Designated as Cash Flow Hedges During 2019, we entered into forward starting interest rate swaps with a total notional amount of $320 million to hedge variations in cash flows related to the 1-month LIBOR component of future lease payments of our future Houston office. Although lease commencement began in September 2021, we expect our first cash lease payment will be in February 2022 and the first settlement date for the interest rate swap will be in January 2022. During the second quarter of 2021, we de-designated $25 million of these hedges as the construction cost budget estimate associated with the project was reduced. The last swap will mature in September 2026. As of December 31, 2021, we expect to reclassify $3 million loss from accumulated other comprehensive income into the income statement over the next twelve months. See Note 14 for further details regarding the lease of the new Houston office. The following table presents information about our interest rate swap agreements, including the weighted average LIBOR-based, fixed rate. December 31, 2021 December 31, 2020 Maturity Date Aggregate Notional Amount (in millions) Weighted Average, LIBOR Aggregate Notional Amount (in millions) Weighted Average, LIBOR June 1, 2025 N/A N/A $ 350 0.95 % September 9, 2026 $ 295 1.52 % $ 320 1.51 %

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements Fair Values – Recurring The following tables present assets and liabilities accounted for at fair value on a recurring basis as of December 31, 2021 and 2020 by hierarchy level. December 31, 2021 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Interest rate - not designated as cash flow hedges $ — $ 27 $ — $ 27 Derivative instruments, assets $ — $ 27 $ — $ 27 Derivative instruments, liabilities Commodity (a) $ (2) $ (5) $ — $ (7) Interest rate - designated as cash flow hedges — (5) — (5) Derivative instruments, liabilities $ (2) $ (10) $ — $ (12) Total $ (2) $ 17 $ — $ 15 December 31, 2020 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Interest rate - not designated as cash flow hedges $ — 10 $ — $ 10 Interest rate - designated as cash flow hedges — 19 — 19 Derivative instruments, assets $ — $ 29 $ — $ 29 Derivative instruments, liabilities Commodity (a) $ — $ (23) $ — $ (23) Interest rate - designated as cash flow hedges $ — $ (16) $ — $ (16) Derivative instruments, liabilities $ — $ (39) $ — $ (39) Total $ — $ (10) $ — $ (10) (a) Derivative instruments are recorded on a net basis in our consolidated balance sheet (See Note 16 ). As of December 31, 2021, our commodity derivatives include three-way collars and NYMEX roll basis swaps. These instruments are measured at fair value using either a Black-Scholes or a modified Black-Scholes Model. For swaps, inputs to the models include only commodity prices and interest rates and are categorized as Level 1 because all assumptions and inputs are observable in active markets throughout the term of the instruments. For three-way collars and two-way collars, inputs to the models include commodity prices, and implied volatility and are categorized as Level 2 because predominantly all assumptions and inputs are observable in active markets throughout the term of the instruments. The forward starting interest rate swaps are measured at fair value with a market approach using actionable broker quotes, which are Level 2 inputs. See Note 16 for details on the forward starting interest swaps. Fair Values – Goodwill See Note 15 for detail information relating to goodwill. Fair Values – Nonrecurring See Note 12 for detail on our fair values related to impairments. Fair Values – Financial Instruments Our current assets and liabilities include financial instruments, the most significant of which are receivables, the current portion of our long-term debt and payables. We believe the carrying values of our receivables and payables approximate fair value. Our fair value assessment incorporates a variety of considerations, including (1) the short-term duration of the instruments, (2) our credit rating and (3) our historical incurrence of and expected future insignificance of bad debt expense, which includes an evaluation of counterparty credit risk. The following table summarizes financial instruments, excluding receivables, payables and derivative financial instruments, and their reported fair values by individual balance sheet line item at December 31, 2021 and 2020. December 31, 2021 2020 (In millions) Fair Carrying Fair Carrying Financial assets Current assets $ 11 $ 10 $ 4 $ 4 Other noncurrent assets 12 27 24 37 Total financial assets $ 23 $ 37 $ 28 $ 41 Financial liabilities Other current liabilities $ 99 $ 136 $ 72 $ 103 Long-term debt, including current portion (a) 4,705 4,033 6,077 5,431 Deferred credits and other liabilities 46 46 82 76 Total financial liabilities $ 4,850 $ 4,215 $ 6,231 $ 5,610 (a) Excludes debt issuance costs. Fair values of our financial assets included in other noncurrent assets, and of our financial liabilities included in other current liabilities and deferred credits and other liabilities, are measured using an income approach and most inputs are internally generated, which results in a Level 3 classification. Estimated future cash flows are discounted using a rate deemed appropriate to obtain the fair value.

Debt

Debt	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Debt	Debt Revolving Credit Facility As of December 31, 2021, we had no borrowings against our $3.1 billion unsecured revolving credit facility (“Credit Facility”). On June 21, 2021, we executed the sixth amendment to our Credit Facility. The primary changes resulting from this amendment are (i) increasing the size of the Credit Facility from $3.0 billion to $3.1 billion, (ii) extending the maturity of the commitments of certain consenting lenders from May 28, 2023 to June 21, 2024 (with the remaining commitment of a single non-consenting lender to mature on May 28, 2023, at which time the size of the Credit Facility will be reduced to $3.0 billion) and (iii) including certain other provisions and revisions, including provisions to provide for the eventual replacement of LIBOR as a benchmark interest rate. The Credit Facility includes a covenant requiring our total debt to total capitalization ratio not to exceed 65% as of the last day of each fiscal quarter. In the event of a default, the lenders holding more than half of the commitments may terminate the commitments under the Credit Facility and require the immediate repayment of all outstanding borrowings and the cash collateralization of all outstanding letters of credit under the Credit Facility. As of December 31, 2021, we were in compliance with this covenant with a ratio of 20%. Long-term debt The following table details our long-term debt: December 31, (In millions) 2021 2020 Senior unsecured notes: 2.800% notes due 2022 $ — $ 500 9.375% notes due 2022 (a) 32 32 Series A notes due 2022 (a) 3 3 8.500% notes due 2023 (a) 70 70 8.125% notes due 2023 (a) 131 131 3.850% notes due 2025 — 900 4.400% notes due 2027 (b) 1,000 1,000 6.800% notes due 2032 (b) 550 550 6.600% notes due 2037 (b) 750 750 5.200% notes due 2045 (b) 500 500 Bonds: (c) 2.00% bonds due 2037 200 200 2.10% bonds due 2037 200 200 2.20% bonds due 2037 200 200 2.125% bonds due 2037 200 200 2.375% bonds due 2037 200 200 Total 4,036 5,436 Unamortized discount (3) (5) Unamortized debt issuance cost (19) (27) Total long-term debt $ 4,014 $ 5,404 (a) In the event of a change in control, as defined in the related agreements, debt obligations totaling $236 million at December 31, 2021 may be declared immediately due and payable (b) These notes contain a make-whole provision allowing us to repay the debt at a premium to market price. (c) Mandatory purchase dates for these bonds: April 1, 2023 for the 2.00% bonds; July 1, 2024 for the 2.10% bonds and 2.125% bonds; July 1, 2026 for the 2.20% bonds and 2.375% bonds. Subsequent to the various mandatory purchase dates, we will also have the right to convert and remarket these any time up to the 2037 maturity date. The following table shows future debt payments: (In millions) 2022 $ 35 2023 401 2024 400 2025 — 2026 400 Thereafter 2,800 Total long-term debt, including current portion $ 4,036 Debt Redemption On March 30, 2021, we sent an irrevocable notice of redemption to the trustee to fully redeem our outstanding $500 million 2.8% Senior Notes due 2022 (“2022 Notes”). The 2022 Notes were redeemed on April 29, 2021 and as a result of the settlement, we incurred $19 million in costs related to a make-whole provision premium and the write off of unamortized discount and issuance costs.

Incentive Based Compensation

Incentive Based Compensation	12 Months Ended
	Dec. 31, 2021
Incentive Based Compensation Plans [Abstract]
Incentive Based Compensation	Incentive Based Compensation Description of stock-based compensation plans – The Marathon Oil Corporation 2019 Incentive Compensation Plan (the “2019 Plan”) was approved by our stockholders in May 2019 and authorizes the Compensation Committee of the Board of Directors to grant stock options, stock appreciation rights (“SARs”), stock awards (including restricted stock and restricted stock unit awards), performance unit awards and cash awards to employees. The 2019 Plan also allows us to provide equity compensation to our non-employee directors. No more than 27.9 million shares of our common stock may be issued under the 2019 Plan. In connection with the granting of an award under the 2019 Plan, the number of shares available for issuance under the 2019 Plan will be reduced by one share for each share of our common stock in respect of which the award is granted, except the awards that by their terms do not permit settlement in shares of our common stock will not reduce the number of shares of common stock available for issuance under the 2019 Plan. Shares subject to awards under the 2019 Plan that are forfeited, terminated or expire unexercised become available for future grants. In addition, the number of shares of our common stock reserved for issuance under the 2019 Plan will not be increased by shares tendered to satisfy the purchase price of an award, exchanged for other awards or withheld to satisfy tax withholding obligations. Shares issued as a result of awards granted under the 2019 Plan are generally funded out of common stock held in treasury, except to the extent there are insufficient treasury shares, in which case new common shares are issued. After approval of the 2019 Plan, no new grants were or will be made from any prior plans. Any awards previously granted under any prior plans shall continue to be exercisable in accordance with their original terms and conditions. Stock-based awards under the plans Stock options – We last granted stock options under the 2019 Plan in 2020. Our stock options represent the right to purchase shares of our common stock at its fair market value on the date of grant. In general, our stock options vest ratably over a three-year period and have a maximum term of ten years from the date they are granted. SARs – At December 31, 2021, there are no SARs outstanding. Restricted stock – We last granted restricted stock under the 2019 Plan in 2020. The restricted stock awards granted to officers generally vest three years from the date of grant, contingent on the recipient’s continued employment. We also grant restricted stock to certain non-officer employees based on their performance within certain guidelines and for retention purposes. The restricted stock awards to non-officers generally vest ratably over a three-year period, contingent on the recipient’s continued employment. Prior to vesting, all restricted stock recipients have the right to vote such stock and receive dividends thereon. The non-vested shares of restricted stock are not transferable and are held by our transfer agent. Stock-based performance unit awards – We grant stock-based performance units to officers under the 2019 Plan. During 2021, we granted 307,473 stock-based performance units to eligible officers, which are settled in shares. The grant date fair value per unit was $18.07, as calculated using a Monte Carlo valuation model. At the grant date, each unit represents the value of one share of our common stock. These units are settled in shares, and the number of shares of our common stock to be paid is based on the vesting percentage, which can be from zero to 200% based on performance achieved during the performance period and as determined by the Compensation Committee of the Board of Directors (“Compensation Committee”). The performance goals are tied to our total shareholder return (“TSR”) as compared to TSR for a group, which is determined by the Compensation Committee and includes peer companies, the S&P Energy Index and the S&P 500 Index. Also, dividend equivalents accrue during the performance period and will be paid in cash following the end of the performance period based on the amount of dividends credited on shares of our common stock over the performance period multiplied by the number of units that vest. During 2021, we introduced a new type of stock-based performance unit award under the 2019 Plan and granted 307,473 units to eligible officers, which are settled in cash. At the grant date for these new stock-based performance units, each unit represents the value of one share of our common stock. The benefit amount to be paid is based on the product of (i) the number of units granted, (ii) the vesting percentage and (iii) the average daily closing price of our common stock during the final 30 calendar days ending on the last trading day of the performance period, subject to the banking feature described below. The vesting percentage can range from zero to 200%, which is based on performance achieved over a two-year performance period. The performance metric is a predetermined amount of cumulative free cash flow, as defined by the award agreement, generated by the Company over the performance period. The units have a banking feature whereby the stock price valuation and vesting percentage are fixed at no less than 50%, and then again at 100%, if achieved during the performance period. Once those milestones are reached, the vesting percentage will not fall below those banked percentage amounts even if cumulative free cash flow subsequently declines during the performance period, subject to the Compensation Committee’s discretion as described below. The fourth quarter 2021 fair value per unit was $15.55, as calculated by multiplying the estimated vesting percentage by our common stock’s closing stock price on December 31, 2021. Also, dividend equivalents accrue during the performance period and would be paid in cash following the end of the performance period based on the amount of dividends credited on shares of our common stock over the performance period multiplied by the number of units that vest. The fourth quarter 2021 fair value of dividend equivalents per unit was $0.18. As set forth in the award agreement terms, the Compensation Committee retains discretion to reduce the vesting percentage and any bank values and determine free cash flow achievement for these awards. Restricted stock units – We maintain an equity compensation program for our non-employee directors. All non-employee directors receive annual grants of common stock units. Any units granted prior to 2012 must be held until completion of board service, at which time the non-employee director will receive common shares. For units granted between 2012 and 2020, common shares will generally vest following completion of board service or three years from the date of grant, whichever is earlier. For units granted in 2021, common shares will generally vest following completion of board services or one year from the date of grant, whichever is earlier. However, for any units granted in 2017 or later, our non-employee directors may elect to defer settlement of their common stock units until after they cease serving on the Board. Under the 2019 Plan, we also grant restricted stock units to officers, which, depending on grant agreement terms, generally vest three years from the date of the grant or vest ratably over a three-year period and restricted stock units to certain non-officer employees, which generally vest ratably over a three-year period. Both awards are contingent on the recipient’s continued employment. Grants of restricted stock units to these non-officer employees are generally based on their performance and for retention purposes. Common shares will be issued for these restricted stock units after vesting. Prior to vesting, recipients of restricted stock units typically receive dividend equivalent payments, but they may not vote. Total stock-based compensation expense – Total employee stock-based compensation expense was $43 million, $55 million and $60 million in 2021, 2020 and 2019. Due to the full valuation allowance on our net federal deferred tax assets, we recognized no tax benefit during these years. Cash received upon exercise of stock option awards was $5 million in 2021 and $1 million in both 2020 and 2019. There were no tax benefits recognized for deductions for stock awards settled during 2021, 2020 and 2019. Stock option awards – During 2020 and 2019 we granted stock option awards to officer employees. The weighted average grant date fair value of these awards was based on the following weighted average Black-Scholes assumptions: 2020 2019 Exercise price per share $ 10.47 $ 16.79 Expected annual dividend yield 1.9 % 1.2 % Expected life in years 6.14 5.82 Expected volatility 44 % 43 % Risk-free interest rate 1.5 % 2.5 % Weighted average grant date fair value of stock option awards granted $ 3.82 $ 6.62 The following is a summary of stock option award activity in 2021. Number of Shares Weighted Average Exercise Price Weighted Average Remaining Contractual Term Aggregate Intrinsic Value (in millions) Outstanding at beginning of year 6,014,255 $ 21.00 Granted — $ — Exercised/Vested (602,842) $ 9.10 Canceled (1,137,109) $ 23.10 Outstanding at end of year 4,274,304 $ 22.13 5 years $ 6,256,356 Exercisable at end of year 3,541,275 $ 24.26 4 years $ 2,816,507 Expected to vest 731,889 $ 11.81 8 years $ 3,433,157 The intrinsic value of stock option awards exercised was $3 million in 2021 and immaterial in both 2020 and 2019. As of December 31, 2021, unrecognized compensation cost related to stock option awards was less than $1 million, almost all of which will be recognized in 2022. Restricted stock awards and restricted stock units – The following is a summary of restricted stock and restricted stock unit award activity in 2021. Awards Weighted Average Grant Date Fair Value Unvested at beginning of year 7,851,754 $ 11.72 Granted 2,306,696 $ 11.21 Vested (3,086,302) $ 12.78 Canceled (1,183,906) $ 11.62 Unvested at end of year 5,888,242 $ 10.98 The vesting date fair value of restricted stock awards and restricted stock units which vested during 2021, 2020 and 2019 was $39 million, $49 million and $48 million. The weighted average grant date fair value of restricted stock awards was $10.98, $11.72 and $15.88 for awards unvested at December 31, 2021, 2020 and 2019. As of December 31, 2021 there was $28 million of unrecognized compensation cost related to restricted stock awards and restricted stock units, which is expected to be recognized over a weighted average period of 1 year. Stock-based performance unit awards – During 2021, 2020 and 2019 we granted 307,473, 1,038,676 and 656,636 stock-based performance unit awards to be settled in shares to officers. At December 31, 2021, there were 1,622,994 units outstanding. During 2021, we also granted 307,473 stock-based performance unit awards to be settled in cash to officers. At December 31, 2021, there were 307,473 units outstanding. Total stock-based performance unit awards expense was $11 million, $5 million and $7 million in 2021, 2020 and 2019. The key assumptions used in the Monte Carlo simulation to determine the grant date fair value of stock-based performance units granted in 2021, 2020 and 2019 were: 2021 2020 2019 Valuation date stock price $ 11.20 $ 10.47 $ 16.79 Expected annual dividend yield 1.1 % 1.9 % 1.2 % Expected volatility 71 % 39 % 43 % Risk-free interest rate 0.3 % 1.4 % 2.5 % Fair value of stock-based performance units outstanding $ 18.07 $ 10.55 $ 20.66

Defined Benefit Postretirement

Defined Benefit Postretirement Plans and Defined Contribution Plan	12 Months Ended
	Dec. 31, 2021
Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract]
Defined Benefit Postretirement Plans and Defined Contribution Plan	Defined Benefit Postretirement Plans and Defined Contribution Plan We have noncontributory defined benefit pension plans covering substantially all domestic employees. Benefits under these plans are based on plan provisions specific to each plan. We also had a noncontributory defined benefit pension plan covering eligible U.K. employees that was transferred to the buyer in connection with the sale of our U.K. business during 2019. See Note 5 for further information on this disposition. During the year ended December 31, 2019, we reclassified $20 million from accumulated other comprehensive income to pension assets upon remeasurement of the plan. We also have plans for other postretirement benefits covering our U.S. employees. Health care benefits are provided up to age 65 through comprehensive hospital, surgical and major medical benefit provisions subject to various cost-sharing features. Post-65 retiree health care benefits have been provided to certain U.S. employees on a defined contribution basis; this program terminated effective as of December 31, 2020. Life insurance benefits are provided to certain retiree beneficiaries. These other postretirement benefits are not funded in advance. Employees hired after 2016 are not eligible for any postretirement health care or life insurance benefits. Obligations and funded status – The following summarizes the obligations and funded status for our defined benefit pension and other postretirement plans. Pension Benefits Other Benefits 2021 2020 2021 2020 (In millions) U.S. U.S. U.S. U.S. Accumulated benefit obligation $ 260 $ 298 $ 73 $ 80 Change in pension benefit obligations: Beginning balance $ 308 $ 354 $ 80 $ 89 Service cost 16 19 — 1 Interest cost 7 9 2 2 Actuarial (gain) loss (15) 36 1 4 Gain due to curtailment (a) — (1) — — Settlements paid (43) (104) — — Benefits paid (4) (5) (10) (16) Ending balance $ 269 $ 308 $ 73 $ 80 Change in fair value of plan assets: Beginning balance $ 194 $ 236 $ — $ — Actual return on plan assets 13 18 — — Employer contributions 32 49 10 16 Settlements paid (43) (104) — — Benefits paid (4) (5) (10) (16) Ending balance $ 192 $ 194 $ — $ — Funded status of plans at December 31 $ (77) $ (114) $ (73) $ (80) Amounts recognized in the consolidated balance sheets: Current liabilities $ (3) $ (4) $ (10) $ (10) Noncurrent liabilities (74) (110) (63) (70) Accrued benefit cost $ (77) $ (114) $ (73) $ (80) Pretax amounts in accumulated other comprehensive loss: Net loss $ 37 $ 72 $ 23 $ 24 Prior service credit (13) (19) (81) (97) (a) Related to workforce reductions, which reduced the future expected years of service for employees participating in the plans. In 2021, the pension plans experienced a net actuarial gain and the postretirement plans experienced a net actuarial loss. Both pension and postretirement plans experienced an increase in discount rate used to measure the plans, which decreased their respective benefit obligations and was the primary source of the actuarial gain for the pension plans. The postretirement plans experienced an overall net actuarial loss due to the mid-year census data update. Components of net periodic benefit costs and other comprehensive (income) loss – The following summarizes the net periodic benefit costs and the amounts recognized as other comprehensive (income) loss for our defined benefit pension and other postretirement plans. Pension Benefits Other Benefits Year Ended December 31, Year Ended December 31, 2021 2020 2019 2021 2020 2019 (In millions) U.S. U.S. U.S. Int’l U.S. U.S. U.S. Components of net periodic benefit costs: Service cost $ 16 $ 19 $ 19 $ — $ — $ 1 $ 1 Interest cost 7 9 12 8 2 2 3 Expected return on plan assets (8) (11) (10) (11) — — — Amortization: - prior service credit (6) (6) (7) — (16) (18) (19) - actuarial loss 5 9 7 — 2 2 1 Net settlement loss (a) 9 30 12 — — — — Net curtailment gain (b) — (3) — — — (14) — Net periodic benefit cost (credit) (c) $ 23 $ 47 $ 33 $ (3) $ (12) $ (27) $ (14) Other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss (pretax): Actuarial loss (gain) $ (21) $ 27 $ 14 $ (21) $ 1 $ 4 $ 9 Settlement loss and amortization of actuarial gain (loss) (14) (40) (19) (41) (2) (2) (1) Prior service cost (credit) — — — — — — — Curtailment gain and amortization of prior service credit (cost) 6 10 7 (6) 16 32 19 Total recognized in other comprehensive (income) loss $ (29) $ (3) $ 2 $ (68) $ 15 $ 34 $ 27 Total recognized in net periodic benefit cost and other comprehensive (income) loss $ (6) $ 44 $ 35 $ (71) $ 3 $ 7 $ 13 (a) Settlements are recognized as they occur, once it is probable that lump sum payments from a plan for a given year will exceed the plan’s total service and interest costs for that year. (b) Related to workforce reductions, which reduced the future expected years of service for employees participating in the plans. (c) Net periodic benefit costs (credits) reflects a calculated market-related value of plan assets, which recognizes changes in fair value over three years. Plan assumptions – The following summarizes the assumptions used to determine the benefit obligations at December 31, and net periodic benefit cost for the defined benefit pension and other postretirement plans for 2021, 2020 and 2019. Pension Benefits Other Benefits 2021 2020 2019 2021 2020 2019 (In millions) U.S. U.S. U.S. U.S. U.S. U.S. Weighted average assumptions used to determine benefit obligation: Discount rate 2.83 % 2.52 % 3.13 % 2.48 % 2.02 % 2.91 % Rate of compensation increase (a) 0.50 % 0.50 % 4.50 % 0.50 % 0.50 % 4.50 % Cash balance interest crediting 3.00 % 3.00 % 3.00 % — % — % — % Weighted average assumptions used to determine net periodic benefit cost: Discount rate 2.77 % 2.90 % 3.70 % 2.02 % 2.63 % 4.09 % Expected long-term return on plan assets 5.75 % 6.00 % 6.25 % — % — % — % Rate of compensation increase (b) 0.50 % 4.50 % 4.00 % 0.50 % 4.50 % 4.00 % Cash balance interest crediting 3.00 % 3.00 % 3.00 % — % — % — % (a) The assumed rate of compensation increase is 5.00% for the year 2022 and 4.50% for future years. (b) The assumed rate of compensation increase is 4.50% for future years. Expected long-term return on plan assets – The expected long-term return on plan assets assumption for our U.S. pension plan is determined based on an internally developed asset rate-of-return modeling tool, which utilizes underlying assumptions based on actual returns by asset category and inflation and takes into account our U.S. pension plan’s asset allocation. The expected return for each asset category is then weighted based on the actual asset allocation to develop the overall expected long-term return on plan assets assumption. Assumed weighted average health care cost trend rates – Employer provided subsidies for post-65 retiree health care coverage were frozen effective January 1, 2017 at January 1, 2016 established amount levels. Company contributions were funded to a Health Reimbursement Account on the retiree’s behalf to subsidize the retiree’s cost of obtaining health care benefits through a private exchange (the “post-65 retiree health benefits”). In the fourth quarter of 2018, we terminated the post-65 retiree health benefits effective as of December 31, 2020. The post-65 retiree health benefits are no longer be provided after that date. In addition, the pre-65 retiree medical coverage subsidy was frozen as of January 1, 2019, and the ability for retirees to opt in and out of this coverage, as well as pre-65 retiree dental and vision coverage, was also eliminated. Retirees must enroll in connection with retirement for such coverage, or they lose eligibility. These plan changes reduced our retiree medical benefit obligation by approximately $99 million at December 31, 2018. Plan investment policies and strategies – The investment policies for our U.S. pension plan assets reflect the funded status of the plan and expectations regarding our future ability to make further contributions. Long-term investment goals are to: (1) manage the assets in accordance with applicable legal requirements; (2) produce investment returns which meet or exceed the rates of return achievable in the capital markets while maintaining the risk parameters set by the plan’s investment committees and protecting the assets from any erosion of purchasing power; and (3) position the portfolios with a long-term risk/return orientation. Investment performance and risk is measured and monitored on an ongoing basis through quarterly investment meetings and periodic asset and liability studies. U.S. plan – The plan’s current targeted asset allocation is comprised of 55% equity securities and 45% other fixed income securities. Over time, as the plan’s funded ratio (as defined by the investment policy) improves, in order to reduce volatility in returns and to better match the plan’s liabilities, the allocation to equity securities will decrease while the amount allocated to fixed income securities will increase. The plan’s assets are managed by a third-party investment manager. International plan – As mentioned above, the plan covering eligible U.K. employees was transferred to the buyer in connection with the sale of our U.K. business during 2019. Fair value measurements – Plan assets are measured at fair value. The following provides a description of the valuation techniques employed for each major plan asset class at December 31, 2021 and 2020. Cash and cash equivalents – Cash and cash equivalents are valued using a market approach and are considered Level 1. Equity securities – Investments in common stock are valued using a market approach at the closing price reported in an active market and are therefore considered Level 1. Private equity investments include interests in limited partnerships which are valued based on the sum of the estimated fair values of the investments held by each partnership, determined using a combination of market, income and cost approaches, plus working capital, adjusted for liabilities, currency translation and estimated performance incentives. These private equity investments are considered Level 3. Other – Other investments are comprised of an unallocated annuity contract, two limited liability companies and real estate. All are considered Level 3, as significant inputs to determine fair value are unobservable. Commingled funds – The investment in the commingled funds are valued using the net asset value of units held as a practical expedient. The commingled funds consist of equity and fixed income portfolios with underlying investments held in U.S. and non-U.S. securities. The following tables present the fair values of our defined benefit pension plan’s assets, by level within the fair value hierarchy, as of December 31, 2021 and 2020. December 31, 2021 (In millions) Level 1 Level 2 Level 3 Total Cash and cash equivalents (a) $ (1) $ — $ — $ (1) Equity securities: Common stock 28 — — 28 Private equity — — 7 7 Other — — 16 16 Total investments, at fair value 27 — 23 50 Commingled funds (b) — — — 142 Total investments $ 27 $ — $ 23 $ 192 December 31, 2020 (In millions) Level 1 Level 2 Level 3 Total Equity securities: Common stock $ 61 $ — $ — $ 61 Private equity — — 8 8 Other — — 18 18 Total investments, at fair value 61 — 26 87 Commingled funds (b) — — — 107 Total investments $ 61 $ — $ 26 $ 194 (a) The negative cash balance was due to the timing of when investment trades occur and when they settle. (b) After the adoption of the FASB update for the fair value hierarchy, we separately report the investments for which fair value was measured using the net asset value per share as a practical expedient. Amounts presented in this table are intended to reconcile the fair value hierarchy to the pension plan assets. The activity during the year ended December 31, 2021 and 2020, for the assets using Level 3 fair value measurements was immaterial. Cash flows Estimated future benefit payments – The following gross benefit payments, which were estimated based on actuarial assumptions applied at December 31, 2021 and reflect expected future services, as appropriate, are to be paid in the years indicated. (In millions) Pension Benefits Other Benefits 2022 $ 29 $ 10 2023 27 9 2024 25 8 2025 23 7 2026 22 6 2027 through 2031 $ 101 $ 22 Contributions to defined benefit plans – We expect to make contributions to the funded pension plan of up to $17 million in 2022. Cash contributions to be paid from our general assets for the unfunded portion of our pension and postretirement plans are expected to be approximately $3 million and $10 million in 2022.

Reclassifications Out of Accumu

Reclassifications Out of Accumulated Other Comprehensive Income (Loss)	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Reclassifications Out of Accumulated Other Comprehensive Income (Loss)	Reclassifications Out of Accumulated Other Comprehensive Income (Loss) The following table presents a summary of amounts reclassified from accumulated other comprehensive income (loss): Year Ended December 31, (In millions) 2021 2020 Income Statement Line Postretirement and postemployment plans Amortization of prior service credit $ 22 $ 24 Other net periodic benefit credits Amortization of actuarial loss (7) (11) Other net periodic benefit credits Net settlement loss (9) (30) Other net periodic benefit credits Net curtailment gain — 17 Other net periodic benefit credits Interest rate swaps Reclassification of de-designated forward interest rate swaps (28) — Net interest and other Total reclassifications of (income) expense, net of tax (a) $ (22) $ — Net income (loss)

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2021
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Year Ended December 31, (In millions) 2021 2020 2019 Included in operating activities: Interest paid, net of amounts capitalized $ 231 $ 251 $ 253 Income taxes paid to (received from) taxing authorities, net of refunds (a) 24 (51) 73 Noncash investing activities: Increase (decrease) in asset retirement costs $ 56 $ — $ 80 Asset retirement obligations assumed by buyer (b) — — 1,082 (a) 2021, 2020 and 2019 includes $2 million, $94 million and $90 million, respectively, related to tax refunds. (b) In 2019, our dispositions include the sale of the Droshky field (Gulf of Mexico), the sale of our non-operated interest in the Atrush block in Kurdistan and the sale of our U.K. business. See Note 5 for further detail on dispositions. Other noncash investing activities include accrued capital expenditures as of December 31, 2021, 2020 and 2019 of $81 million, $95 million and $288 million.

Other Items

Other Items	12 Months Ended
	Dec. 31, 2021
Interest and Other Income [Abstract]
Other Items	Other Items Net interest and other Year Ended December 31, (In millions) 2021 2020 2019 Interest: Interest income $ 1 $ 5 $ 25 Interest expense (257) (279) (280) Gain on interest rate swaps 54 12 — Total interest (202) (262) (255) Other: Net foreign currency gain — — 4 Other 14 6 7 Total other 14 6 11 Net interest and other $ (188) $ (256) $ (244) Foreign currency – For the years ended December 31, 2021 and 2020, there were no aggregate foreign currency gains included in the consolidated statements of income. For the year ended December 31, 2019, the aggregate foreign currency gains included in the consolidated statements of income were immaterial.

Equity Method Investments

Equity Method Investments	12 Months Ended
	Dec. 31, 2021
Equity Method Investments Disclosure [Abstract]
Equity Method Investments	Equity Method Investments During 2021, 2020 and 2019 our equity method investees were considered related parties. Our investment in our equity method investees are summarized in the following table: Ownership as of December 31, (In millions) December 31, 2021 2021 2020 EGHoldings (a) 56% $ 148 $ 113 Alba Plant LLC (b) 52% 154 168 AMPCO (c) 45% 148 166 Total $ 450 $ 447 (a) EGHoldings is engaged in LNG production activity. (b) Alba Plant LLC processes LPG. (c) AMPCO is engaged in methanol production activity. In accordance with agreements related to the processing of third-party Alen Unit gas at EGLNG, additional equity was issued to an equity partner, which is an E.G. government entity, during the fourth quarter of 2021, thereby reducing our ownership interest in EGHoldings from 60% to 56%. As a result, we recorded a $12 million pre-tax loss, which was reflected in Net gain (loss) on disposal of assets in our consolidated statements of income. During the year ended December 31, 2020, we recorded impairments of $171 million to an investment in an equity method investee, which was reflected in income (loss) from equity method investments in our consolidated statements of income. The impairments caused us to incur a basis differential between the net book value of our investment and the amount of our underlying share of equity in the investee’s net assets. As of December 31, 2021, the amount of this basis differential was $112 million, which includes the effects of the current year’s accretion. During 2021, we accreted $22 million of the basis differential into the income (loss) from equity method investments line item. See Note 12 to the consolidated financial statements for further information on the equity method investee impairment. Summarized financial information for equity method investees is as follows: (In millions) 2021 2020 2019 Income data – year: Revenues and other income $ 1,095 $ 586 $ 832 Income from operations 537 16 250 Net income (loss) 440 (3) 187 Balance sheet data – December 31: Current assets $ 556 $ 389 Noncurrent assets 822 941 Current liabilities 247 235 Noncurrent liabilities 231 170 Revenues from related parties were $30 million, $38 million and $42 million in 2021, 2020 and 2019, respectively, with the majority related to EGHoldings in all years. Current receivables from related parties at December 31, 2021 and 2020 were $23 million and $24 million, with the majority related to EGHoldings in both periods. Payables to related parties at December 31, 2021 were $20 million and $13 million at December 31, 2020, with the majority related to Alba Plant LLC in both periods.

Stockholders Equity

Stockholders Equity	12 Months Ended
	Dec. 31, 2021
Stockholders' Equity Attributable to Parent [Abstract]
Stockholders’ Equity	Stockholders’ Equity During the fourth quarter 2021, we resumed our share repurchase program and repurchased 46 million shares of our common stock at a cost of $724 million. Effective November 3, 2021, our Board of Directors increased our remaining share repurchase program authorization from $1.1 billion to $2.5 billion. As of December 31, 2021, $1.9 billion of share repurchase program authorization remains. Additionally, we repurchased $10 million of shares during the year ended December 31, 2021 related to our tax withholding obligation associated with the vesting of employee restricted stock awards; these repurchases do not impact our share repurchase program authorization. During 2020, we acquired approximately 9 million of common shares at a cost of $85 million, which were held as treasury stock. Subsequent to December 31, 2021, we repurchased approximately $258 million of shares of our common stock through February 16, 2022.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies In the second quarter of 2019, Marathon E.G. Production Limited (“MEGPL”), a consolidated and wholly owned subsidiary, signed a series of agreements to process third-party Alen Unit gas through existing infrastructure located in Punta Europa, E.G. Our equity method investee, Alba Plant LLC, is also a party to some of the agreements. These agreements require (subject to certain limitations) MEGPL to indemnify the owners of the Alen Unit against injury to Alba Plant LLC’s personnel and damage to or loss of Alba Plant LLC’s automobiles, as well as third party claims caused by Alba Plant LLC and certain environmental liabilities arising from certain hydrocarbons in the custody of Alba Plant LLC. At this time, we cannot reasonably estimate this obligation as we do not have any history of prior indemnification claims or environmental discharge or contamination. Therefore, we have not recorded a liability with respect to these indemnities since the amount of potential future payments under these indemnification clauses is not determinable. The agreements to process the third-party Alen Unit gas required the execution of third-party guarantees by Marathon Oil Corporation in favor of the Alen Unit’s owners. Two separate guarantees were executed during the second quarter of 2020; one for a maximum of approximately $91 million pertaining to the payment obligations of Equatorial Guinea LNG Operations, S.A. and another for a maximum of $25 million pertaining to the payment obligations of Alba Plant LLC. Payment by us would be required if any of those entities fails to honor its payment obligations pursuant to the relevant agreements with the owners of the Alen Unit. Certain owners of the Alen Unit, or their affiliates, are also direct or indirect shareholders in Equatorial Guinea LNG Operations, S.A. and Alba Plant LLC. Each guarantee expires no later than December 31, 2027. We measured these guarantees at fair value using the net present value of premium payments we expect to receive from our investees. Our liability for these guarantees was approximately $4 million as of December 31, 2021. Each of Equatorial Guinea LNG Operations, S.A. and Equatorial Guinea LNG Train 1, S.A. provided us with a pledge of its receivables as recourse against any payments we may make under the guaranty of Equatorial Guinea LNG Operations, S.A.’s performance. Various groups, including the State of North Dakota and three Indian tribes (the “Three Affiliated Tribes”) represented by the Bureau of Indian Affairs, have been involved in a dispute regarding the ownership of certain lands underlying the Missouri River and Little Missouri River (the “Disputed Land”) from which we currently produce. As a result, as of December 31, 2021, we have a $134 million current liability in suspended royalty and working interest revenue, including interest, of which $122 million was included within accounts payable and $12 million related to accrued interest and was included within other current liabilities on our consolidated balance sheet. Additionally, we have a long-term receivable of $24 million for capital and expenses. The United States Department of the Interior (“DOI”) has addressed the United States’ position with respect to this dispute several times over the past five years with conflicting opinions. In January 2017, the DOI issued an opinion that the Disputed Land is held in trust for the Three Affiliated Tribes, then in June 2018 and May 2020 the DOI issued opinions concluding that the State of North Dakota held title to the Disputed Land. Most recently, on February 4, 2022, the DOI issued an opinion (“M-Opinion”) concluding the DOI’s position that the Disputed Land is held in trust for the Three Affiliated Tribes. While the M-Opinion is binding on all agencies within the DOI, it is not legally binding on third parties, including Marathon Oil, or a court. Depending on the ultimate outcome of this title dispute, the Three Affiliated Tribes could challenge the validity of certain of our leases relating to a portion of the disputed land, and if such challenge were successful it could result in operational delays and additional costs to us. Given the uncertainty in matters such as these, we are unable to predict the ultimate outcome of this matter at this time; however, we believe the resolution of this matter will not have a material adverse effect on our consolidated financial position, results of operations or cash flows. In January 2020, we received a Notice of Violation from the EPA related to the Clean Air Act. We have received an initial draft consent decree from the EPA containing certain proposed injunctive terms relating to this enforcement action, and are actively negotiating the terms of the consent decree at this time. The enforcement action will likely result in monetary sanctions and injunctive terms, which may increase our development costs, operating costs or both. Given the uncertainty in matters such as these, we are unable to predict the ultimate outcome of this matter at this time. However, we believe that any penalties, mitigation costs or corrective actions that may result from this matter will not have a material adverse effect on our consolidated financial position, results of operations or cash flows. We are a defendant in a number of legal and administrative proceedings arising in the ordinary course of business including, but not limited to, royalty claims, contract claims, tax disputes and environmental claims. While the ultimate outcome and impact to us cannot be predicted with certainty, we believe the resolution of these proceedings will not have a material adverse effect on our consolidated financial position, results of operations or cash flows. In addition, we may also be subject to retained liabilities with respect to certain divested assets by operation of law. For example, the declines in commodity prices during 2020 created an environment where there is an increased risk that owners and/or operators of assets purchased from us may no longer be able to satisfy plugging or abandonment obligations that attach to those assets. In that event, due to operation of law, we may be required to assume plugging or abandonment obligations for those assets. Although we have established reserves for such liabilities, we could be required to accrue additional amounts in the future and these amounts could be material. For instance, as the result of the declaration of bankruptcy by a third party that is the indirect successor in title to certain offshore assets that we previously divested, in 2021 we increased our existing reserve to $37 million related to the anticipated cost to decommission certain wells, pipelines and production facilities. We no longer own these assets nor are they related to our current operations. Marathon Oil has been named in various lawsuits alleging royalty underpayments in our domestic operations, and plaintiffs in some of these lawsuits are seeking class certification. For instance, Marathon Oil has been named in a lawsuit alleging improper royalty deductions in certain of our Oklahoma operations, and plaintiffs are seeking class certification. We intend to vigorously defend ourselves against such claims. Although we have accrued for potential liabilities associated with these lawsuits, those accruals are based on currently available information and involve elements of judgment and significant uncertainties. Accordingly, actual losses may exceed our accruals or we could be required to accrue additional amounts in the future and these amounts could be material. Environmental matters – We have incurred and will continue to incur capital, operating and maintenance and remediation expenditures as a result of environmental laws and regulations. If these expenditures, as with all costs, are not ultimately offset by the prices we receive for our products and services, our operating results will be adversely affected. We believe that substantially all of our competitors must comply with similar environmental laws and regulations. However, the specific impact on each competitor may vary depending on a number of factors, including the age and location of its operating facilities, marketing areas and production processes. These laws generally provide for control of pollutants released into the environment and require responsible parties to undertake remediation of hazardous waste disposal sites. Penalties may be imposed for noncompliance. At December 31, 2021 and 2020, accrued liabilities for remediation were not material. It is not presently possible to estimate the ultimate amount of all remediation costs that might be incurred or the penalties that may be imposed. Guarantees – Over the years, we have sold various assets in the normal course of our business. Certain of the related agreements contain performance and general guarantees, including guarantees regarding inaccuracies in representations, warranties, covenants and agreements and environmental and general indemnifications that require us to perform upon the occurrence of a triggering event or condition. These guarantees and indemnifications are part of the normal course of selling assets. We are typically not able to calculate the maximum potential amount of future payments that could be made under such contractual provisions because of the variability inherent in the guarantees and indemnities. Most often, the nature of the guarantees and indemnities is such that there is no appropriate method for quantifying the exposure because the underlying triggering event has little or no past experience upon which a reasonable prediction of the outcome can be based.

Summary of Principal Accounti_2

Summary of Principal Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Basis of presentation and principles applied in consolidation	Basis of presentation and principles applied in consolidation – These consolidated financial statements, including notes, have been prepared in accordance with U.S. GAAP. These consolidated financial statements include the accounts of our controlled subsidiaries. Investments in unincorporated joint ventures and undivided interests in certain operating assets are consolidated on a pro rata basis.
Equity method investments	Equity method investments – Investments in entities over which we have significant influence, but not control, are accounted for using the equity method of accounting. This includes entities in which we hold majority ownership but the minority stockholders have substantive participating rights in the investee. Income from equity method investments represents our proportionate share of net income generated by the equity method investees and is reflected in revenues and other income in our consolidated statements of income. Equity method investments are included as noncurrent assets on the consolidated balance sheet.
Use of estimates	Use of estimates – The preparation of financial statements in accordance with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the consolidated financial statements and the reported amounts of revenues and expenses during the respective reporting periods. Estimated quantities of crude oil and condensate, NGLs and natural gas reserves is a significant estimate that requires judgment. All of the reserve data included in this Form 10-K are estimates. Reservoir engineering is a subjective process of estimating underground accumulations of crude oil and condensate, NGLs and natural gas. There are numerous uncertainties inherent in estimating quantities of proved crude oil and condensate, NGLs and natural gas reserves. The accuracy of any reserves estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. As a result, reserve estimates may be different from the quantities of crude oil and condensate, NGLs and natural gas that are ultimately recovered. See unaudited Supplementary Data – Supplementary Information on Oil and Gas Producing Activities for further detail. Other items subject to estimates and assumptions include the carrying amounts of property, plant and equipment, asset retirement obligations, goodwill, valuation of derivative instruments and valuation allowances for deferred income tax assets, among others. Although we believe these estimates are reasonable, actual results could differ from these estimates.
Foreign currency transactions	Foreign currency transactions – The U.S. dollar is the functional currency of our foreign operating subsidiaries. Foreign currency transaction gains and losses are included in net income.
Revenue recognition	Revenue recognition – Revenues associated with the sales of crude oil and condensate, NGLs and natural gas are recognized when our performance obligation is satisfied, which typically occurs at the point where control transfers to the customer based on contract terms. Revenue is measured as the amount the company expects to receive in exchange for transferring commodities to the customer. Our hydrocarbon sales are typically based on prevailing market-based prices and may include quality or location differential adjustments. Payment is generally due within 30 days of delivery. We typically incur shipping and handling costs prior to control transferring to the customer and account for these activities as fulfillment costs. These costs are reflected in shipping, handling and other operating expense in our consolidated statement of income. Our U.S. production of crude oil and condensate, NGLs and natural gas is generally sold immediately and transported to market. In our international segment, liquid hydrocarbon production may be stored as inventory and sold at a later time.
Cash and cash equivalents	Cash and cash equivalents – Cash and cash equivalents include cash on hand and on deposit and investments in highly liquid debt instruments with original maturities of three months or less.
Accounts receivable	Accounts receivable – The majority of our receivables are from purchasers of commodities or joint interest owners in properties we operate, both of which are recorded at estimated or invoiced amounts and do not bear interest. We often have the
Inventories	Inventories – Crude oil and natural gas are recorded at weighted average cost and carried at the lower of cost or net realizable value. Supplies and other items consist principally of tubular goods and equipment, which are valued at weighted average cost and reviewed periodically for obsol escence or impairment when market conditions indicate . We may enter into a contract to sell a particular quantity and quality of crude oil at a specified location and date to a particular counterparty, and simultaneously agree to buy a particular quantity and quality of the same commodity at a specified location on the same or another specified date from the same counterparty. We account for such matching buy/sell arrangements as exchanges of inventory.
Derivative instruments	Derivative instruments – We may use derivatives to manage a portion of our exposure to commodity price risk, commodity locational risk and interest rate risk. All derivative instruments are recorded at fair value. Commodity derivatives and interest rate swaps are reflected on our consolidated balance sheet on a net basis by counterparty, as they are governed by master netting agreements. Cash flows related to derivatives used to manage commodity price risk, and interest rate risk are classified in operating activities. Our derivative instruments contain no significant contingent credit features.
Fair value hedges and cash flow hedges	Cash flow hedges – We may use interest rate derivative instruments to manage the risk of interest rate changes during the period prior to anticipated borrowings as well as to stabilize future lease payments on our Houston office, and designate them as cash flow hedges. Derivative instruments designated as cash flow hedges are linked to specific assets and liabilities or to specific firm commitments or forecasted transactions. The changes in the fair value of a qualifying cash flow hedge are recorded in other comprehensive income until the hedged transaction affects earnings and are then reclassified into net income. Ineffective portions of a cash flow hedge are no longer measured or disclosed separately. However, if it is determined that the likelihood of the original forecasted transaction occurring is no longer probable or the cash flow hedge is no longer expected to be highly effective, subsequent changes in fair value of the derivatives instrument are recorded in net income.
Derivatives not designated as hedges	Derivatives not designated as hedges – Derivatives that are not designated as hedges may include commodity derivatives used primarily to manage price and locational risks on the forecasted sale of crude oil, NGLs and natural gas that we produce. Changes in the fair value of derivatives not designated as hedges are recognized immediately in net income
Concentrations of credit risk	Concentrations of credit risk – All of our financial instruments, including derivatives, involve elements of credit and market risk. The most significant portion of our credit risk relates to nonperformance by counterparties. The counterparties to our financial instruments consist primarily of major financial institutions and companies within the energy industry. To manage counterparty risk associated with financial instruments, we select and monitor counterparties based on our assessment of their financial strength and on credit ratings, if available. Additionally, we limit the level of exposure with any single counterparty.
Fair value transfer	Fair value transfer – We recognize transfers between levels of the fair value hierarchy as of the end of the reporting period.
Property, plant and equipment	Property, plant and equipment – We use the successful efforts method of accounting for oil and gas producing activities.
Property acquisition costs	Property acquisition costs – Costs to acquire mineral interests in oil and natural gas properties, to drill exploratory wells in progress and those that find proved reserves and to drill development wells are capitalized. Costs to drill exploratory wells that do not find proved reserves, geological and geophysical costs and costs of carrying and retaining unproved properties are expensed. Costs incurred for exploratory wells that find reserves but cannot yet be classified as proved are capitalized if (1) the well has found a sufficient quantity of reserves to justify its completion as a producing well and (2) we are making sufficient progress assessing the reserves and the economic and operating viability of the project. The status of suspended exploratory well costs is monitored continuously and reviewed at least quarterly.
Depreciation, depletion and amortization	Depreciation, depletion and amortization – Capitalized costs to acquire oil and natural gas properties are depreciated and depleted on a units-of-production basis based on estimated proved reserves. Capitalized costs of exploratory wells and development costs are depreciated and depleted on a units-of-production basis based on estimated proved developed reserves. Support equipment and other property, plant and equipment related to oil and gas producing activities, as well as property, plant and equipment unrelated to oil and gas producing activities, are recorded at cost and depreciated on a straight-line basis over the estimated useful lives of the assets. The table below summarizes these assets by type, useful life and the net asset balance as of the periods presented. December 31, Type of Asset Range of Useful Lives 2021 2020 (in millions) Office furniture, equipment and computer hardware 4 to 15 years $ 41 $ 52 Pipelines 5 to 40 years $ 10 $ 11 Plants, facilities and infrastructure 3 to 40 years $ 1,496 $ 1,463
Impairments	Impairments – We evaluate our oil and gas producing properties, including capitalized costs of exploratory wells and development costs, for impairment of value whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If the sum of the expected undiscounted future cash flows from the use of the asset and its eventual disposition is less than the carrying amount of the asset, an impairment loss is recognized based on the fair value of the asset. Oil and gas producing properties are reviewed for impairment on a field-by-field basis or, in certain instances, by logical grouping of assets if there is significant shared infrastructure or contractual terms that cause economic interdependency amongst separate, discrete fields. Oil and gas producing properties deemed to be impaired are written down to their fair value, as determined by discounted future net cash flows or, if available, comparable market value. We evaluate our unproved property investment and record impairment based on time or geologic factors. Information such as drilling results, reservoir performance, seismic interpretation, lease expiration dates or future plans to develop acreage is also considered. When unproved property investments are deemed to be impaired, this amount is reported in exploration expenses in our consolidated statements of income.
Dispositions	Dispositions – When property, plant and equipment depreciated on an individual basis is sold or otherwise disposed of, any gains or losses are reflected in net gain (loss) on disposal of assets in our consolidated statements of income. Gains on the disposal of property, plant and equipment are recognized when earned, which is generally at the time of closing. If a loss on disposal is expected, such losses are recognized either when the assets are classified as held for sale, or are measured using a probability weighted income approach based on both the anticipated sales price and a held-for-use model depending on timing of the sale. Proceeds from the disposal of a portion of property, plant and equipment depreciated on a group basis are credited to accumulated depreciation, depletion and amortization with no immediate effect on net income until net book value is reduced to zero.
Goodwill	Goodwill – Goodwill represents the excess of the purchase price over the estimated fair value of the net assets acquired in the acquisition of a business. Such goodwill is not amortized, but rather is tested for impairment annually and when events or changes in circumstances indicate that the fair value of a reporting unit with goodwill has been reduced below carrying value. The impairment test requires allocating goodwill and other assets and liabilities to a reporting unit. The fair value of a reporting unit is determined and compared to the book value of the reporting unit. If the fair value of the reporting unit is less than the book value, including goodwill, then the recorded goodwill is impaired to its implied fair value with a charge to impairments. In 2020, our goodwill was fully impaired.
Environmental costs	Environmental costs – We provide for remediation costs and penalties when the responsibility to remediate is probable and the amount of associated costs can be reasonably estimated. The timing of remediation accruals coincides with completion of a feasibility study or the commitment to a formal plan of action. Remediation liabilities are accrued based on estimates of known environmental exposure and are discounted when the estimated amounts are reasonably fixed or reliably determinable. Environmental expenditures are capitalized only if the costs mitigate or prevent future contamination or if the costs improve the environmental safety or efficiency of the existing assets.
Asset retirement obligations	Asset retirement obligations – The fair value of asset retirement obligations is recognized in the period in which the obligations are incurred if a reasonable estimate of fair value can be made. Our asset retirement obligations primarily relate to the abandonment of oil and gas producing facilities. Asset retirement obligations for such facilities include costs to dismantle and relocate or dispose of production platforms, gathering systems, wells and related structures and restoration costs of land, including those leased. Estimates of these costs are developed for each property based on the type of production facilities and
Income taxes	Income taxes – Deferred tax assets and liabilities, measured at enacted tax rates, are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying amounts of assets and liabilities and their tax bases as reported in our filings with the respective taxing authorities. We routinely assess the realizability of our deferred tax assets based on several interrelated factors and reduce such assets by a valuation allowance if it is more likely than not that some portion or all of the deferred tax assets will not be realized. These factors include whether we are in a cumulative loss position in recent years, our reversal of temporary differences, and our expectation to generate sufficient future taxable income. We use the liability method in determining our provision and liabilities for our income taxes, under which current and deferred tax liabilities and assets are recorded in accordance with enacted tax laws and rates.
Stock-based compensation arrangements	Stock-based compensation arrangements – The fair value of stock options is estimated on the date of grant using the Black-Scholes option pricing model. The model employs various assumptions, based on management’s best estimates at the time of grant, which impact the calculation of fair value and ultimately, the amount of expense that is recognized over the life of the stock option award. Of the required assumptions, the expected volatility of our stock price and the stock price in relation to the strike price have the most significant impact on the fair value calculation. We have utilized historical data and analyzed current information which reasonably support these assumptions. The fair value of our restricted stock awards, restricted stock units and Director restricted stock units is determined based on the market value of our common stock on the date of grant. Restricted stock awards, restricted stock units and Director restricted stock units are removed from Treasury Stock at grant, vesting and distribution, respectively. The fair value of our cash-settled stock-based performance units is estimated using the Monte Carlo simulation method. Since these awards are settled in cash at the end of a defined performance period, they are classified as a liability and are re-measured quarterly until settlement. The fair value of our free cash flow cash-settled stock-based performance units is estimated by multiplying the estimated vesting percentage by our common stock’s closing stock price plus accumulated dividend equivalents. Since these awards are settled in cash at the end of a defined performance period, they are classified as a liability and are re-measured quarterly until settlement. The fair value of our stock-settled stock-based performance units is estimated using the Monte Carlo simulation method at grant date only. Since these awards are settled in stock, they are classified as equity.

Summary of Principal Accounti_3

Summary of Principal Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Schedule of Property Plant and Equipment	The table below summarizes these assets by type, useful life and the net asset balance as of the periods presented. December 31, Type of Asset Range of Useful Lives 2021 2020 (in millions) Office furniture, equipment and computer hardware 4 to 15 years $ 41 $ 52 Pipelines 5 to 40 years $ 10 $ 11 Plants, facilities and infrastructure 3 to 40 years $ 1,496 $ 1,463 December 31, (In millions) 2021 2020 United States $ 14,097 $ 15,156 International 347 414 Not allocated to segments 55 68 Net property, plant and equipment $ 14,499 $ 15,638

Income (loss) and Dividends p_2

Income (loss) and Dividends per Common Share (Tables)	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The per share calculations below exclude 4 million, 7 million and 6 million stock options for 2021, 2020 and 2019 that were antidilutive. Year Ended December 31, (In millions, except per share data) 2021 2020 2019 Net income (loss) $ 946 $ (1,451) $ 480 Weighted average common shares outstanding 787 792 810 Effect of dilutive securities 1 — — Weighted average common shares, diluted 788 792 810 Net income (loss) per share: Basic $ 1.20 $ (1.83) $ 0.59 Diluted $ 1.20 $ (1.83) $ 0.59 Dividends per share $ 0.18 $ 0.08 $ 0.20

Revenues (Tables)

Revenues (Tables)	12 Months Ended
	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following tables present our revenues from contracts with customers disaggregated by product type and geographic areas. United States Year Ended December 31, 2021 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,435 $ 1,777 $ 299 $ 314 $ 100 $ 3,925 Natural gas liquids 161 239 189 47 17 653 Natural gas 159 119 280 55 19 632 Other 8 — — — 116 124 Revenues from contracts with customers $ 1,763 $ 2,135 $ 768 $ 416 $ 252 $ 5,334 Year Ended December 31, 2020 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 830 $ 984 $ 235 $ 204 $ 69 $ 2,322 Natural gas liquids 74 54 89 20 6 243 Natural gas 86 34 127 18 10 275 Other 6 — — — 78 84 Revenues from contracts with customers $ 996 $ 1,072 $ 451 $ 242 $ 163 $ 2,924 Year Ended December 31, 2019 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,358 $ 1,686 $ 425 $ 316 $ 102 $ 3,887 Natural gas liquids 114 46 116 26 5 307 Natural gas 121 39 156 16 17 349 Other 7 — — — 52 59 Revenues from contracts with customers $ 1,600 $ 1,771 $ 697 $ 358 $ 176 $ 4,602 International Year Ended December 31, 2021 2020 (In millions) E.G. E.G. Crude oil and condensate $ 240 $ 140 Natural gas liquids 2 4 Natural gas 23 29 Other 2 — Revenues from contracts with customers $ 267 $ 173 Year Ended December 31, 2019 (In millions) E.G. U.K. Other Total Crude oil and condensate $ 271 $ 107 $ 20 $ 398 Natural gas liquids 4 1 — 5 Natural gas 32 12 — 44 Other — 14 — 14 Revenues from contracts with customers $ 307 $ 134 $ 20 $ 461
Schedules of Concentration of Risk	Customers and their respective affiliates who accounted for 10% or more of our total commodity sales were as follows: December 31, 2021 2020 2019 Percentage of Total Commodity Sales Marathon Petroleum Corporation 17 % 13 % 13 % Valero Marketing and Supply 10 % N/A 11 % Koch Resources LLC N/A 12 % 13 % Shell Trading N/A N/A 10 %

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Year Ended December 31, 2021 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 5,334 $ 267 $ — $ 5,601 Net gain (loss) on commodity derivatives (399) — 16 (b) (383) Income (loss) from equity method investments — 253 — 253 Net loss on disposal of assets — — (19) (c) (19) Other income 7 4 4 15 Less costs and expenses: Production 480 54 — 534 Shipping, handling and other operating 686 16 25 727 Exploration 65 — 71 (d) 136 Depreciation, depletion and amortization 1,972 68 26 2,066 Impairments — — 60 (e) 60 Taxes other than income 346 — (1) 345 General and administrative 107 13 171 (f) 291 Net interest and other — — 188 (g) 188 Other net periodic benefit (credit) costs — — (5) (5) Loss on early extinguishment of debt — — 121 (h) 121 Income tax provision (benefit) 9 56 (7) 58 Segment income (loss) $ 1,277 $ 317 $ (648) $ 946 Total assets $ 15,339 $ 994 $ 661 $ 16,994 Capital expenditures (a) $ 1,018 $ — $ 14 $ 1,032 (a) Includes accruals and excludes acquisitions. (b) Unrealized gain on commodity derivative instruments (See Note 16 ). (c) Includes a $20 million loss associated with a previously divested non-core conventional asset, a $12 million pre-tax loss associated with a reduction in our ownership interest in EG LNG (See Note 24 ) and an $8 million gain on various well bore assignments in Permian and Bakken. (d) Includes unproved property impairments of $20 million for Louisiana exploration leases and $16 million related to the disposition of a lease in Permian. Also includes $28 million of expense associated with drilled and uncompleted wells, primarily in Permian, due to a change in our plan of development (See Note 1 1 ). (e) Includes impairments of $24 million for central facilities in Eagle Ford (See Note 12 ), $5 million for proved properties in Permian (See Note 1 2 ) and $30 million associated with decommissioning costs for non-producing long-lived assets in GOM (See Note 1 2 , Note 13 , and Note 26 ) (f) Includes $13 million associated with the termination of an aircraft lease agreement and $12 million arising from severance expenses associated with a workforce reduction. (g) Includes a $28 million gain on our 2022 interest rate swaps and a $27 million gain on our 2025 interest rate swaps (See Note 16 ). (h) Represents costs related to a make-whole provision premium and the write off of unamortized discount and issuance costs in regards to the redemption of the 2022 Notes in April 2021 and 2025 Notes in September 2021 (See Note 18 ). Year Ended December 31, 2020 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 2,924 $ 173 $ — $ 3,097 Net gain (loss) on commodity derivatives 143 — (27) (b) 116 Income (loss) from equity method investments — 10 (171) (c) (161) Net gain on disposal of assets — — 9 9 Other income 15 7 3 25 Less costs and expenses: Production 494 59 2 555 Shipping, handling and other operating 534 8 54 596 Exploration 97 — 84 (d) 181 Depreciation, depletion and amortization 2,211 82 23 2,316 Impairments — — 144 (e) 144 Taxes other than income 193 — 7 200 General and administrative 115 14 145 (f) 274 Net interest and other — — 256 256 Other net periodic benefit (credit) cost — — 1 (g) 1 Loss on early extinguishment of debt — — 28 28 Income tax benefit (9) (3) (2) (14) Segment income (loss) $ (553) $ 30 $ (928) $ (1,451) Total assets $ 16,063 $ 1,081 $ 812 $ 17,956 Capital expenditures (a) $ 1,137 $ 1 $ 13 $ 1,151 (a) Includes accruals and excludes acquisitions. (b) Unrealized loss on commodity derivative instruments (See Note 16 ). (c) Partial impairment of investment in equity method investee (See Note 24 ). (d) Primarily related to unproved property impairments of non-core acreage in our United States segment. (e) Includes the full impairment of the International reporting unit goodwill of $95 million (See Note 15 ) and proved property impairments of $49 million related to a damaged well in our United States segment. (f) Includes severance expenses associated with workforce reductions of $17 million. (g) Includes pension settlement loss of $30 million and pension curtailment gain of 17 million (See Note 20 ). Year Ended December 31, 2019 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 4,602 $ 461 $ — $ 5,063 Net gain (loss) on commodity derivatives 52 — (124) (b) (72) Income (loss) from equity method investments — 87 — 87 Net gain on disposal of assets — — 50 (c) 50 Other income 13 9 40 62 Less costs and expenses: Production 588 126 (2) 712 Shipping, handling and other operating 561 26 18 605 Exploration 149 — — 149 Depreciation, depletion and amortization 2,250 121 26 2,397 Impairments — — 24 (d) 24 Taxes other than income 311 — — 311 General and administrative 127 25 204 356 Net interest and other — — 244 244 Other net periodic benefit (credit) cost — (3) — (e) (3) Loss on early extinguishment of debt — — 3 3 Income tax provision (benefit) 6 29 (123) (88) Segment income (loss) $ 675 $ 233 $ (428) $ 480 Total assets $ 17,781 $ 1,530 $ 934 $ 20,245 Capital expenditures (a) $ 2,550 $ 16 $ 25 $ 2,591 (a) Includes accruals and excludes acquisitions. (b) Unrealized loss on commodity derivative instruments (See Note 16 ). (c) Primarily related to the sale of our working interest in the Droshky field (Gulf of Mexico) and the sale of our U.K. business (See Note 5 ). (d) Primarily a result of anticipated sales of non-core proved properties in our International and United States segments (See Note 12 ). (e) Includes pension settlement loss of $12 million (See Note 20 ).
Schedule of Disclosure on Geographic Areas, Long-Lived Assets in Individual Foreign Countries by Country	The following summarizes property, plant and equipment and equity method investments. December 31, (In millions) 2021 2020 United States $ 14,152 $ 15,224 Equatorial Guinea 797 861 Total long-lived assets $ 14,949 $ 16,085

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Schedule of Income before Income Tax, Domestic and Foreign	Income (loss) before income taxes were: Year Ended December 31, (In millions) 2021 2020 2019 United States $ 637 $ (1,319) $ 43 Foreign 367 (146) 349 Total $ 1,004 $ (1,465) $ 392
Schedule of Components of Income Tax Expense (Benefit)	Income tax provisions (benefits) were: Year Ended December 31, 2021 2020 2019 (In millions) Current Deferred Total Current Deferred Total Current Deferred Total Federal $ — $ — $ — $ (5) $ — $ (5) $ (116) $ (3) $ (119) State and local 4 1 5 (2) (8) (10) 4 3 7 Foreign 81 (28) 53 15 (14) 1 58 (34) 24 Total $ 85 $ (27) $ 58 $ 8 $ (22) $ (14) $ (54) $ (34) $ (88)
Schedule of Effective Income Tax Rate Reconciliation	A reconciliation of the federal statutory income tax rate applied to income (loss) before income taxes to the provision (benefit) for income taxes follows: Year Ended December 31, (In millions) 2021 2020 2019 Total pre-tax income (loss) $ 1,004 $ (1,465) $ 392 Total income tax provision (benefit) $ 58 $ (14) $ (88) Effective income tax rate 6 % 1 % (22) % Income taxes at the statutory tax rate $ 211 $ (308) $ 83 Effects of foreign operations (13) 23 (29) Adjustments to valuation allowances (166) 239 (28) State income taxes, net of federal benefit 23 6 11 Tax law change (2) — — Other federal tax effects 5 26 (125) Income tax provision (benefit) $ 58 $ (14) $ (88)
Schedule of Deferred Tax Assets and Liabilities	Deferred tax assets and liabilities resulted from the following: Year Ended December 31, (In millions) 2021 2020 Deferred tax assets: Employee benefits $ 66 $ 77 Operating loss carryforwards 1,541 1,966 Foreign tax credits 611 611 Other (a) 52 67 Subtotal 2,270 2,721 Valuation allowance (780) (948) Total deferred tax assets 1,490 1,773 Deferred tax liabilities: Property, plant and equipment (a) 1,544 1,879 Accrued revenue — 20 Other (a) 82 37 Total deferred tax liabilities 1,626 1,936 Net deferred tax liabilities $ 136 $ 163 Net deferred tax assets $ — $ — (a) 2020 balances were reclassified to conform to current period’s presentation. The total Net deferred tax liabilities balance was not impacted by the change in presentation.
Net Deferred Tax Assets Liabilities Table	Net deferred tax assets and liabilities were classified in the consolidated balance sheets as follows: December 31, (In millions) 2021 2020 Assets: Other noncurrent assets $ — $ — Liabilities: Noncurrent deferred tax liabilities 136 163 Net deferred tax liabilities $ 136 $ 163 Net deferred tax assets $ — $ —
Income Tax Returns Remaining Subject To Examination Table	As of December 31, 2021, our income tax returns remain subject to examination in the following major tax jurisdictions for the tax years indicated: United States (a) 2010 - 2020 Equatorial Guinea 2007 - 2020 (a) Includes federal and state jurisdictions.
Summary Of Activity In Unrecognized Tax Benefits Table	The following table summarizes the activity in unrecognized tax benefits: (In millions) 2021 2020 2019 Beginning balance $ 8 $ 13 $ 263 Additions for tax positions of prior years 2 — 13 Reductions for tax positions of prior years — (5) (152) Settlements — — (111) Ending balance $ 10 $ 8 $ 13

Credit Losses (Tables)

Credit Losses (Tables)	12 Months Ended
	Dec. 31, 2021
Credit Loss [Abstract]
Accounts Receivable, Allowance for Credit Loss	Changes in the reserve for credit losses balance for the year were as follows: December 31, (In millions) 2021 2020 Beginning balance as of January 1 $ 22 $ 11 Cumulative-effect adjustment — 12 Current period provision (a) 3 22 Current period write offs (5) (13) Recoveries of amounts previously reserved (5) (10) Ending balance as of December 31 $ 15 $ 22 (a) As of December 31, 2020, the current period provision consisted of $10 million in joint interest receivables and $12 million in trade receivables.

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2021
Inventory Disclosure [Abstract]
Schedule of Inventory, Current	December 31, (In millions) 2021 2020 Crude oil and natural gas $ 8 $ 10 Supplies and other items 69 66 Inventories $ 77 $ 76

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2021
Property, Plant and Equipment [Abstract]
Schedule of Property Plant and Equipment	The table below summarizes these assets by type, useful life and the net asset balance as of the periods presented. December 31, Type of Asset Range of Useful Lives 2021 2020 (in millions) Office furniture, equipment and computer hardware 4 to 15 years $ 41 $ 52 Pipelines 5 to 40 years $ 10 $ 11 Plants, facilities and infrastructure 3 to 40 years $ 1,496 $ 1,463 December 31, (In millions) 2021 2020 United States $ 14,097 $ 15,156 International 347 414 Not allocated to segments 55 68 Net property, plant and equipment $ 14,499 $ 15,638
Schedule of Projects with Exploratory Well Costs Capitalized for More than One Year	Changes in our capitalized exploratory well costs were as follows: December 31, (In millions) 2021 2020 2019 Beginning balance as of January 1 $ 210 $ 278 $ 297 Additions 50 97 218 Charges to expense (30) (1) (5) Transfers to development (68) (164) (230) Dispositions — — (2) Ending balance as of December 31 $ 162 $ 210 $ 278

Impairment (Tables)

Impairment (Tables)	12 Months Ended
	Dec. 31, 2021
Impairments and Exploration Expenses [Abstract]
Summary of Impaired Assets	The following table summarizes impairment charges of proved properties, goodwill and equity method investments and their corresponding fair values. 2021 2020 2019 (In millions) Fair Value Impairment Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ — $ 30 $ — $ 49 $ 56 $ 24 Asset retirement costs of long-lived assets — 30 — — — — Goodwill — — — 95 — — Equity method investment $ — $ — $ 119 $ 171 $ — $ —

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2021
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	Asset retirement obligations primarily consist of estimated costs to remove, dismantle and restore land or seabed at the end of oil and gas production operations. Changes in asset retirement obligations were as follows: December 31, (In millions) 2021 2020 Beginning balance as of January 1 $ 254 $ 254 Incurred liabilities, including acquisitions 14 6 Settled liabilities, including dispositions (6) (12) Accretion expense (included in depreciation, depletion and amortization) 12 12 Revisions of estimates 42 (6) Ending balance as of December 31 $ 316 $ 254 Ending balance as of December 31, short-term $ 28 $ 13

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Supplemental Balance Sheet Information	Balance sheet information related to ROU assets and lease liabilities was as follows: December 31, (In millions) 2021 2020 ROU assets: Balance Sheet Location: Operating leases Other noncurrent assets $ 59 $ 133 Finance leases Other noncurrent assets 28 — Total ROU assets $ 87 $ 133 Lease liabilities: Current liabilities Operating leases Other current liabilities $ 40 $ 70 Finance leases Other current liabilities 6 — Noncurrent liabilities Operating leases Deferred credits and other liabilities 23 67 Finance leases Deferred credits and other liabilities 24 — Total lease liabilities $ 93 $ 137
Lease Costs	The table below presents our net lease costs for the years ended December 31, 2021 and 2020. (In millions) Year Ended December 31, 2021 Year Ended December 31, 2020 Operating lease costs: Short-term lease costs (a) $ 121 $ 170 Long-term lease costs (b) 64 75 Variable lease costs (c) 33 23 Finance lease costs: Amortization of ROU assets 3 — Total lease costs $ 221 $ 268 Other information: Cash paid for amounts included in the measurement of operating lease liabilities $ 73 $ 100 ROU assets obtained in exchange for new operating lease liabilities (d) 15 46 ROU assets obtained in exchange for new finance lease liabilities (e) 28 — Reductions to ROU assets resulting from modifications or cancellations of operating leases $ (13) $ (68) (a) Represents our net share of lease costs arising from leases of less than one year but longer than one month that were not included in the lease liability. (b) Represents our net share of the ROU asset amortization and the interest expense. (c) Represents our net share of variable lease payments that were not included in the lease liability. (d) Represents the cumulative value of operating lease ROU assets recognized at lease inception. This amount is then amortized as we utilize the ROU asset, the net effect of which is the ending ROU asset (first table above). (e) Represents the cumulative value of finance lease ROU assets recognized at lease inception during the year of 2021. This amount is then amortized as we utilize the ROU asset, the net effect of which is the ending ROU asset of $28 million (first table above).
Operating Lease, Maturity	The remaining annual undiscounted cash flows associated with long-term leases and the reconciliation of these cash flows to the lease liabilities recognized on the consolidated balance sheet is summarized below. (In millions) Operating Lease Obligations Finance Lease Obligations Total Lease Obligations 2022 $ 45 $ 7 $ 52 2023 8 7 15 2024 5 7 12 2025 4 7 11 2026 2 4 6 Thereafter — — — Total undiscounted lease payments $ 64 $ 32 $ 96 Less: amount representing interest 1 2 3 Total lease liabilities $ 63 $ 30 $ 93 Less: current portion of lease liability as of December 31, 2021 40 6 46 Long-term lease liability as of December 31, 2021 $ 23 $ 24 $ 47
Operating Lease, Undiscounted Cash Flows to be Received	The undiscounted cash flows to be received under this lease agreement are summarized below. (In millions) Operating Lease Future Cash Receipts 2022 $ 6 2023 6 2024 6 2025 6 2026 6 Thereafter 49 Total undiscounted cash flows $ 79

Derivatives (Tables)

Derivatives (Tables)	12 Months Ended
	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives as they appear on the Balance Sheet	The following tables present the gross fair values of our open derivative instruments and the reported net amounts along with where they appear on the consolidated balance sheets. December 31, 2021 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ 1 $ 8 $ (7) Other current liabilities Interest Rate 27 — 27 Other noncurrent assets Total Not Designated as Hedges $ 28 $ 8 $ 20 Cash Flow Hedges Interest Rate $ — $ 3 $ (3) Other current liabilities Interest Rate — 2 (2) Deferred credits and other liabilities Total Designated Hedges $ — $ 5 $ (5) Total $ 28 $ 13 $ 15 December 31, 2020 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ 3 $ 1 $ 2 Other current assets Commodity 7 32 (25) Other current liabilities Interest Rate 10 — 10 Other noncurrent assets Total Not Designated as Hedges $ 20 $ 33 $ (13) Cash Flow Hedges Interest Rate $ 19 $ — $ 19 Other noncurrent assets Interest Rate — 16 (16) Deferred credits and other liabilities Total Designated Hedges $ 19 $ 16 $ 3 Total $ 39 $ 49 $ (10) The unrealized and realized gain (loss) impact of our commodity derivative instruments appears in the table below and is reflected in net gain (loss) on commodity derivatives in the consolidated statements of income. Year Ended December 31, (In millions) 2021 2020 2019 Unrealized gain (loss) on derivative instruments, net $ 16 $ (27) $ (124) Realized gain (loss) on derivative instruments, net (a) $ (399) $ 143 $ 52 (a) During the year ended 2021, net cash paid for settled derivative positions was $356 million. During the years ended 2020 and 2019, net cash received for settled derivative positions was $123 million and $65 million, respectively.
Schedule of Notional Amounts of Outstanding Derivative Positions	The following table sets forth outstanding derivative contracts as of December 31, 2021 and the weighted average prices for those contracts: 2022 First Quarter Second Quarter Third Quarter Fourth Quarter Crude Oil NYMEX WTI Three-Way Collars Volume (Bbls/day) 50,000 50,000 20,000 20,000 Weighted average price per Bbl: Ceiling $ 92.26 $ 92.26 $ 92.80 $ 92.80 Floor $ 52.00 $ 52.00 $ 50.00 $ 50.00 Sold put $ 42.00 $ 42.00 $ 40.00 $ 40.00 NYMEX Roll Basis Swaps Volume (Bbls/day) 45,000 45,000 45,000 45,000 Weighted average price per Bbl $ 0.56 $ 0.56 $ 0.56 $ 0.56 Natural Gas Henry Hub (“HH”) Three-Way Collars Volume (MMBtu/day) 50,000 — — — Weighted average price per MMBtu: Ceiling $ 5.14 $ — $ — $ — Floor $ 3.60 $ — $ — $ — Sold Put $ 2.60 $ — $ — $ — The following table sets forth our outstanding derivative contracts as of February 14, 2022, with their weighted average prices, and is inclusive of activity that occurred subsequent to December 31, 2021. 2022 First Quarter Second Quarter Third Quarter Fourth Quarter Crude Oil NYMEX WTI Three-Way Collars Volume (Bbls/day) 50,000 50,000 50,000 50,000 Weighted average price per Bbl: Ceiling $ 96.54 $ 98.79 $ 97.52 $ 97.52 Floor $ 55.93 $ 58.00 $ 56.67 $ 56.67 Sold put $ 45.93 $ 48.00 $ 46.67 $ 46.67 NYMEX Roll Basis Swaps Volume (Bbls/day) 50,167 60,000 60,000 60,000 Weighted average price per Bbl $ 0.60 $ 0.67 $ 0.67 $ 0.67 Natural Gas HH Three-Way Collars Volume (MMBtu/day) 50,000 50,000 50,000 50,000 Weighted average price per MMBtu: Ceiling $ 5.14 $ 6.18 $ 6.18 $ 6.18 Floor $ 3.60 $ 3.50 $ 3.50 $ 3.50 Sold put $ 2.60 $ 2.50 $ 2.50 $ 2.50
Schedule of Interest Rate Derivatives	The following table presents, by maturity date, information about our de-designated forward starting interest rate swap agreements, including the rate. We have the discretion to liquidate the positions should we choose. December 31, 2021 December 31, 2020 Maturity Date Aggregate Notional Amount (in millions) Weighted Average, LIBOR Aggregate Notional Amount (in millions) Weighted Average, LIBOR November 1, 2022 $ — — % $ 500 0.99 % June 1, 2025 $ 350 0.95 % N/A N/A September 9, 2026 $ 25 1.45 % N/A N/A The following table presents information about our interest rate swap agreements, including the weighted average LIBOR-based, fixed rate. December 31, 2021 December 31, 2020 Maturity Date Aggregate Notional Amount (in millions) Weighted Average, LIBOR Aggregate Notional Amount (in millions) Weighted Average, LIBOR June 1, 2025 N/A N/A $ 350 0.95 % September 9, 2026 $ 295 1.52 % $ 320 1.51 %

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following tables present assets and liabilities accounted for at fair value on a recurring basis as of December 31, 2021 and 2020 by hierarchy level. December 31, 2021 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Interest rate - not designated as cash flow hedges $ — $ 27 $ — $ 27 Derivative instruments, assets $ — $ 27 $ — $ 27 Derivative instruments, liabilities Commodity (a) $ (2) $ (5) $ — $ (7) Interest rate - designated as cash flow hedges — (5) — (5) Derivative instruments, liabilities $ (2) $ (10) $ — $ (12) Total $ (2) $ 17 $ — $ 15 December 31, 2020 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Interest rate - not designated as cash flow hedges $ — 10 $ — $ 10 Interest rate - designated as cash flow hedges — 19 — 19 Derivative instruments, assets $ — $ 29 $ — $ 29 Derivative instruments, liabilities Commodity (a) $ — $ (23) $ — $ (23) Interest rate - designated as cash flow hedges $ — $ (16) $ — $ (16) Derivative instruments, liabilities $ — $ (39) $ — $ (39) Total $ — $ (10) $ — $ (10) (a) Derivative instruments are recorded on a net basis in our consolidated balance sheet (See Note 16
Fair Value, by Balance Sheet Grouping	The following table summarizes financial instruments, excluding receivables, payables and derivative financial instruments, and their reported fair values by individual balance sheet line item at December 31, 2021 and 2020. December 31, 2021 2020 (In millions) Fair Carrying Fair Carrying Financial assets Current assets $ 11 $ 10 $ 4 $ 4 Other noncurrent assets 12 27 24 37 Total financial assets $ 23 $ 37 $ 28 $ 41 Financial liabilities Other current liabilities $ 99 $ 136 $ 72 $ 103 Long-term debt, including current portion (a) 4,705 4,033 6,077 5,431 Deferred credits and other liabilities 46 46 82 76 Total financial liabilities $ 4,850 $ 4,215 $ 6,231 $ 5,610 (a) Excludes debt issuance costs.

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Debt Instrument Table	The following table details our long-term debt: December 31, (In millions) 2021 2020 Senior unsecured notes: 2.800% notes due 2022 $ — $ 500 9.375% notes due 2022 (a) 32 32 Series A notes due 2022 (a) 3 3 8.500% notes due 2023 (a) 70 70 8.125% notes due 2023 (a) 131 131 3.850% notes due 2025 — 900 4.400% notes due 2027 (b) 1,000 1,000 6.800% notes due 2032 (b) 550 550 6.600% notes due 2037 (b) 750 750 5.200% notes due 2045 (b) 500 500 Bonds: (c) 2.00% bonds due 2037 200 200 2.10% bonds due 2037 200 200 2.20% bonds due 2037 200 200 2.125% bonds due 2037 200 200 2.375% bonds due 2037 200 200 Total 4,036 5,436 Unamortized discount (3) (5) Unamortized debt issuance cost (19) (27) Total long-term debt $ 4,014 $ 5,404 (a) In the event of a change in control, as defined in the related agreements, debt obligations totaling $236 million at December 31, 2021 may be declared immediately due and payable (b) These notes contain a make-whole provision allowing us to repay the debt at a premium to market price.
Five Year Schedule Of Debt Payments Table	The following table shows future debt payments: (In millions) 2022 $ 35 2023 401 2024 400 2025 — 2026 400 Thereafter 2,800 Total long-term debt, including current portion $ 4,036

Incentive Based Compensation (T

Incentive Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2021
Incentive Based Compensation Plans [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value	The weighted average grant date fair value of these awards was based on the following weighted average Black-Scholes assumptions: 2020 2019 Exercise price per share $ 10.47 $ 16.79 Expected annual dividend yield 1.9 % 1.2 % Expected life in years 6.14 5.82 Expected volatility 44 % 43 % Risk-free interest rate 1.5 % 2.5 % Weighted average grant date fair value of stock option awards granted $ 3.82 $ 6.62
Schedule of Share-based Compensation, Stock Options, Activity	The following is a summary of stock option award activity in 2021. Number of Shares Weighted Average Exercise Price Weighted Average Remaining Contractual Term Aggregate Intrinsic Value (in millions) Outstanding at beginning of year 6,014,255 $ 21.00 Granted — $ — Exercised/Vested (602,842) $ 9.10 Canceled (1,137,109) $ 23.10 Outstanding at end of year 4,274,304 $ 22.13 5 years $ 6,256,356 Exercisable at end of year 3,541,275 $ 24.26 4 years $ 2,816,507 Expected to vest 731,889 $ 11.81 8 years $ 3,433,157
Schedule of Nonvested Restricted Stock Units Activity	The following is a summary of restricted stock and restricted stock unit award activity in 2021. Awards Weighted Average Grant Date Fair Value Unvested at beginning of year 7,851,754 $ 11.72 Granted 2,306,696 $ 11.21 Vested (3,086,302) $ 12.78 Canceled (1,183,906) $ 11.62 Unvested at end of year 5,888,242 $ 10.98
Schedule of Performance Units, Valuation	The key assumptions used in the Monte Carlo simulation to determine the grant date fair value of stock-based performance units granted in 2021, 2020 and 2019 were: 2021 2020 2019 Valuation date stock price $ 11.20 $ 10.47 $ 16.79 Expected annual dividend yield 1.1 % 1.9 % 1.2 % Expected volatility 71 % 39 % 43 % Risk-free interest rate 0.3 % 1.4 % 2.5 % Fair value of stock-based performance units outstanding $ 18.07 $ 10.55 $ 20.66

Defined Benefit Postretiremen_2

Defined Benefit Postretirement Plans and Defined Contribution Plan (Tables)	12 Months Ended
	Dec. 31, 2021
Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract]
Changes in Projected Benefit Obligations, Fair Value of Plan Assets, and Funded Status of Plan	Obligations and funded status – The following summarizes the obligations and funded status for our defined benefit pension and other postretirement plans. Pension Benefits Other Benefits 2021 2020 2021 2020 (In millions) U.S. U.S. U.S. U.S. Accumulated benefit obligation $ 260 $ 298 $ 73 $ 80 Change in pension benefit obligations: Beginning balance $ 308 $ 354 $ 80 $ 89 Service cost 16 19 — 1 Interest cost 7 9 2 2 Actuarial (gain) loss (15) 36 1 4 Gain due to curtailment (a) — (1) — — Settlements paid (43) (104) — — Benefits paid (4) (5) (10) (16) Ending balance $ 269 $ 308 $ 73 $ 80 Change in fair value of plan assets: Beginning balance $ 194 $ 236 $ — $ — Actual return on plan assets 13 18 — — Employer contributions 32 49 10 16 Settlements paid (43) (104) — — Benefits paid (4) (5) (10) (16) Ending balance $ 192 $ 194 $ — $ — Funded status of plans at December 31 $ (77) $ (114) $ (73) $ (80) Amounts recognized in the consolidated balance sheets: Current liabilities $ (3) $ (4) $ (10) $ (10) Noncurrent liabilities (74) (110) (63) (70) Accrued benefit cost $ (77) $ (114) $ (73) $ (80) Pretax amounts in accumulated other comprehensive loss: Net loss $ 37 $ 72 $ 23 $ 24 Prior service credit (13) (19) (81) (97) (a) Related to workforce reductions, which reduced the future expected years of service for employees participating in the plans.
Schedule of Net Benefit Costs	Components of net periodic benefit costs and other comprehensive (income) loss – The following summarizes the net periodic benefit costs and the amounts recognized as other comprehensive (income) loss for our defined benefit pension and other postretirement plans. Pension Benefits Other Benefits Year Ended December 31, Year Ended December 31, 2021 2020 2019 2021 2020 2019 (In millions) U.S. U.S. U.S. Int’l U.S. U.S. U.S. Components of net periodic benefit costs: Service cost $ 16 $ 19 $ 19 $ — $ — $ 1 $ 1 Interest cost 7 9 12 8 2 2 3 Expected return on plan assets (8) (11) (10) (11) — — — Amortization: - prior service credit (6) (6) (7) — (16) (18) (19) - actuarial loss 5 9 7 — 2 2 1 Net settlement loss (a) 9 30 12 — — — — Net curtailment gain (b) — (3) — — — (14) — Net periodic benefit cost (credit) (c) $ 23 $ 47 $ 33 $ (3) $ (12) $ (27) $ (14) Other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss (pretax): Actuarial loss (gain) $ (21) $ 27 $ 14 $ (21) $ 1 $ 4 $ 9 Settlement loss and amortization of actuarial gain (loss) (14) (40) (19) (41) (2) (2) (1) Prior service cost (credit) — — — — — — — Curtailment gain and amortization of prior service credit (cost) 6 10 7 (6) 16 32 19 Total recognized in other comprehensive (income) loss $ (29) $ (3) $ 2 $ (68) $ 15 $ 34 $ 27 Total recognized in net periodic benefit cost and other comprehensive (income) loss $ (6) $ 44 $ 35 $ (71) $ 3 $ 7 $ 13 (a) Settlements are recognized as they occur, once it is probable that lump sum payments from a plan for a given year will exceed the plan’s total service and interest costs for that year. (b) Related to workforce reductions, which reduced the future expected years of service for employees participating in the plans. (c) Net periodic benefit costs (credits) reflects a calculated market-related value of plan assets, which recognizes changes in fair value over three years.
Schedule of Assumptions Used	Plan assumptions – The following summarizes the assumptions used to determine the benefit obligations at December 31, and net periodic benefit cost for the defined benefit pension and other postretirement plans for 2021, 2020 and 2019. Pension Benefits Other Benefits 2021 2020 2019 2021 2020 2019 (In millions) U.S. U.S. U.S. U.S. U.S. U.S. Weighted average assumptions used to determine benefit obligation: Discount rate 2.83 % 2.52 % 3.13 % 2.48 % 2.02 % 2.91 % Rate of compensation increase (a) 0.50 % 0.50 % 4.50 % 0.50 % 0.50 % 4.50 % Cash balance interest crediting 3.00 % 3.00 % 3.00 % — % — % — % Weighted average assumptions used to determine net periodic benefit cost: Discount rate 2.77 % 2.90 % 3.70 % 2.02 % 2.63 % 4.09 % Expected long-term return on plan assets 5.75 % 6.00 % 6.25 % — % — % — % Rate of compensation increase (b) 0.50 % 4.50 % 4.00 % 0.50 % 4.50 % 4.00 % Cash balance interest crediting 3.00 % 3.00 % 3.00 % — % — % — % (a) The assumed rate of compensation increase is 5.00% for the year 2022 and 4.50% for future years. (b) The assumed rate of compensation increase is 4.50% for future years.
Schedule of Allocation of Plan Assets	The following tables present the fair values of our defined benefit pension plan’s assets, by level within the fair value hierarchy, as of December 31, 2021 and 2020. December 31, 2021 (In millions) Level 1 Level 2 Level 3 Total Cash and cash equivalents (a) $ (1) $ — $ — $ (1) Equity securities: Common stock 28 — — 28 Private equity — — 7 7 Other — — 16 16 Total investments, at fair value 27 — 23 50 Commingled funds (b) — — — 142 Total investments $ 27 $ — $ 23 $ 192 December 31, 2020 (In millions) Level 1 Level 2 Level 3 Total Equity securities: Common stock $ 61 $ — $ — $ 61 Private equity — — 8 8 Other — — 18 18 Total investments, at fair value 61 — 26 87 Commingled funds (b) — — — 107 Total investments $ 61 $ — $ 26 $ 194 (a) The negative cash balance was due to the timing of when investment trades occur and when they settle. (b) After the adoption of the FASB update for the fair value hierarchy, we separately report the investments for which fair value was measured using the net asset value per share as a practical expedient. Amounts presented in this table are intended to reconcile the fair value hierarchy to the pension plan assets.
Schedule of Expected Benefit Payments	Estimated future benefit payments – The following gross benefit payments, which were estimated based on actuarial assumptions applied at December 31, 2021 and reflect expected future services, as appropriate, are to be paid in the years indicated. (In millions) Pension Benefits Other Benefits 2022 $ 29 $ 10 2023 27 9 2024 25 8 2025 23 7 2026 22 6 2027 through 2031 $ 101 $ 22

Reclassifications Out of Accu_2

Reclassifications Out of Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Reclassification out of AOCI	The following table presents a summary of amounts reclassified from accumulated other comprehensive income (loss): Year Ended December 31, (In millions) 2021 2020 Income Statement Line Postretirement and postemployment plans Amortization of prior service credit $ 22 $ 24 Other net periodic benefit credits Amortization of actuarial loss (7) (11) Other net periodic benefit credits Net settlement loss (9) (30) Other net periodic benefit credits Net curtailment gain — 17 Other net periodic benefit credits Interest rate swaps Reclassification of de-designated forward interest rate swaps (28) — Net interest and other Total reclassifications of (income) expense, net of tax (a) $ (22) $ — Net income (loss)

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2021
Supplemental Cash Flow Information [Abstract]
Schedule of Supplemental Cash Flow Information	Year Ended December 31, (In millions) 2021 2020 2019 Included in operating activities: Interest paid, net of amounts capitalized $ 231 $ 251 $ 253 Income taxes paid to (received from) taxing authorities, net of refunds (a) 24 (51) 73 Noncash investing activities: Increase (decrease) in asset retirement costs $ 56 $ — $ 80 Asset retirement obligations assumed by buyer (b) — — 1,082 (a) 2021, 2020 and 2019 includes $2 million, $94 million and $90 million, respectively, related to tax refunds. (b) In 2019, our dispositions include the sale of the Droshky field (Gulf of Mexico), the sale of our non-operated interest in the Atrush block in Kurdistan and the sale of our U.K. business. See Note 5 for further detail on dispositions.

Other Items (Tables)

Other Items (Tables)	12 Months Ended
	Dec. 31, 2021
Interest and Other Income [Abstract]
Schedule of Net Interest And Other Financing Table	Net interest and other Year Ended December 31, (In millions) 2021 2020 2019 Interest: Interest income $ 1 $ 5 $ 25 Interest expense (257) (279) (280) Gain on interest rate swaps 54 12 — Total interest (202) (262) (255) Other: Net foreign currency gain — — 4 Other 14 6 7 Total other 14 6 11 Net interest and other $ (188) $ (256) $ (244)
Schedule of Foreign Currency Transactions Table	Foreign currency – For the years ended December 31, 2021 and 2020, there were no aggregate foreign currency gains included in the consolidated statements of income. For the year ended December 31, 2019, the aggregate foreign currency gains included in the consolidated statements of income were immaterial.

Equity Method Investments (Tabl

Equity Method Investments (Tables)	12 Months Ended
	Dec. 31, 2021
Equity Method Investments Disclosure [Abstract]
Schedule of Equity Method Investments	Ownership as of December 31, (In millions) December 31, 2021 2021 2020 EGHoldings (a) 56% $ 148 $ 113 Alba Plant LLC (b) 52% 154 168 AMPCO (c) 45% 148 166 Total $ 450 $ 447 (a) EGHoldings is engaged in LNG production activity. (b) Alba Plant LLC processes LPG. (c) AMPCO is engaged in methanol production activity.
Income And Balance Sheet Information of Equity Investees Table	Summarized financial information for equity method investees is as follows: (In millions) 2021 2020 2019 Income data – year: Revenues and other income $ 1,095 $ 586 $ 832 Income from operations 537 16 250 Net income (loss) 440 (3) 187 Balance sheet data – December 31: Current assets $ 556 $ 389 Noncurrent assets 822 941 Current liabilities 247 235 Noncurrent liabilities 231 170

Summary of Principal Accounti_4

Summary of Principal Accounting Policies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 14,499	$ 15,638
Office furniture, equipment and computer hardware
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 41	52
Office furniture, equipment and computer hardware | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	4 years
Office furniture, equipment and computer hardware | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	15 years
Pipelines
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 10	11
Pipelines | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	5 years
Pipelines | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	40 years
Plants, facilities and infrastructure
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 1,496	$ 1,463
Plants, facilities and infrastructure | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	3 years
Plants, facilities and infrastructure | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	40 years

New Accounting Standards (Detai

New Accounting Standards (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative-effect adjustment	$ 10,686	$ 10,561	$ 12,153	$ 12,128
Cumulative-effect adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative-effect adjustment			(12)	(31)
Retained Earnings
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative-effect adjustment	$ 7,271	$ 6,466	7,993	7,706
Retained Earnings | Cumulative-effect adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative-effect adjustment			$ (12)	$ (31)

Income (loss) and Dividends p_3

Income (loss) and Dividends per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share [Abstract]
Antidilutive securities excluded from computation of earnings per share (in shares)	4	7	6
Net income (loss)	$ 946	$ (1,451)	$ 480
Weighted average common shares outstanding (in shares)	787	792	810
Effect of dilutive securities (in shares)	1	0	0
Weighted average common shares, diluted (in shares)	788	792	810
Basic (in dollars per share)	$ 1.20	$ (1.83)	$ 0.59
Diluted (in dollars per share)	1.20	(1.83)	0.59
Dividends paid (in dollars per share)	$ 0.18	$ 0.08	$ 0.20

Acquisitions (Details)

Acquisitions (Details) - U.S. a in Thousands, $ in Millions	3 Months Ended
	Dec. 31, 2019USD ($)a
Texas Delaware
Business Acquisition [Line Items]
Oil and gas acres, undeveloped, net | a	40
Payments to acquire oil and gas property | $	$ 106
Eagle Ford
Business Acquisition [Line Items]
Oil and gas acres, undeveloped, net | a	18
Payments to acquire oil and gas property | $	$ 191
Working interest percentage acquired	100.00%

Dispositions (Details)

Dispositions (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended	12 Months Ended
	Jul. 31, 2019	Jun. 30, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income from continuing operations before income taxes			$ 1,004	$ (1,465)	$ 392
International | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income from continuing operations before income taxes					$ 33
International | U.K. Business | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal of assets, net of cash transferred to the buyer	$ 95
International | Atrush Block in Kurdistan | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal of assets, net of cash transferred to the buyer		$ 63
Percentage interest in property		15.00%

Revenues - Narrative (Details)

Revenues - Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Revenue from Contract with Customer [Abstract]
Contract with customer, receivable, net	$ 961	$ 572

Revenues - Revenues from Contra

Revenues - Revenues from Contracts with Customers by Product Type and Geographic Areas (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 5,601	$ 3,097	$ 5,063
U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,334	2,924	4,602
U.S. | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,763	996	1,600
U.S. | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,135	1,072	1,771
U.S. | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	768	451	697
U.S. | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	416	242	358
U.S. | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	252	163	176
U.S. | Crude oil and condensate
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,925	2,322	3,887
U.S. | Crude oil and condensate | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,435	830	1,358
U.S. | Crude oil and condensate | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,777	984	1,686
U.S. | Crude oil and condensate | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	299	235	425
U.S. | Crude oil and condensate | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	314	204	316
U.S. | Crude oil and condensate | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	100	69	102
U.S. | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	653	243	307
U.S. | Natural gas liquids | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	161	74	114
U.S. | Natural gas liquids | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	239	54	46
U.S. | Natural gas liquids | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	189	89	116
U.S. | Natural gas liquids | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	47	20	26
U.S. | Natural gas liquids | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	17	6	5
U.S. | Natural gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	632	275	349
U.S. | Natural gas | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	159	86	121
U.S. | Natural gas | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	119	34	39
U.S. | Natural gas | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	280	127	156
U.S. | Natural gas | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	55	18	16
U.S. | Natural gas | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	19	10	17
U.S. | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	124	84	59
U.S. | Other | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8	6	7
U.S. | Other | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
U.S. | Other | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
U.S. | Other | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
U.S. | Other | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	116	78	52
International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			461
International | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	267	173	307
International | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			134
International | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			20
International | Crude oil and condensate
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			398
International | Crude oil and condensate | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	240	140	271
International | Crude oil and condensate | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			107
International | Crude oil and condensate | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			20
International | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			5
International | Natural gas liquids | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2	4	4
International | Natural gas liquids | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			1
International | Natural gas liquids | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			0
International | Natural gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			44
International | Natural gas | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	23	29	32
International | Natural gas | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			12
International | Natural gas | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			0
International | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			14
International | Other | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 2	$ 0	0
International | Other | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			14
International | Other | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers			$ 0

Revenues - Customer Concentrati

Revenues - Customer Concentration Risk (Details) - Revenue Benchmark - Customer Concentration Risk	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Marathon Petroleum Corporation
Concentration Risk [Line Items]
Concentration risk, percentage	17.00%	13.00%	13.00%
Valero Marketing and Supply
Concentration Risk [Line Items]
Concentration risk, percentage	10.00%		11.00%
Koch Resources LLC
Concentration Risk [Line Items]
Concentration risk, percentage		12.00%	13.00%
Shell Trading
Concentration Risk [Line Items]
Concentration risk, percentage			10.00%

Segment Information (Details)

Segment Information (Details) $ in Millions	3 Months Ended			12 Months Ended
	Sep. 30, 2021USD ($)	Jun. 30, 2021USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2021USD ($)segment	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segment				2
Revenues from contracts with customers				$ 5,601	$ 3,097	$ 5,063
Net gain (loss) on commodity derivatives				(383)	116	(72)
Income (loss) from equity method investments				253	(161)	87
Net gain (loss) on disposal of assets				(19)	9	50
Other income				15	25	62
Production				534	555	712
Shipping, handling and other operating				727	596	605
Exploration				136	181	149
Depreciation, depletion and amortization				2,066	2,316	2,397
Impairments				60	144	24
Taxes other than income				345	200	311
General and administrative				291	274	356
Net interest and other				188	256	244
Other net periodic benefit (costs) credits				5	(1)	3
Loss on early extinguishment of debt				121	28	3
Income tax provision (benefit)				58	(14)	(88)
Segment income (loss)				946	(1,451)	480
Total assets				16,994	17,956	20,245
Capital expenditures				1,032	1,151	2,591
Long-lived assets held for use impairment		$ 24		30	49	24
Asset retirement costs of long-lived assets, impairment				60	144	24
Loss on lease termination				13
Severance costs				12	17
Goodwill, impairment loss			$ 95	0	95	0
Interest Rate Contract, Maturing June 1, 2025 | Not Designated as Hedges
Segment Reporting Information [Line Items]
Gain on interest rate swap				27
Permian Basin
Segment Reporting Information [Line Items]
Dry well cost				28
Gulf Of Mexico
Segment Reporting Information [Line Items]
Impairments				30
Asset retirement costs of long-lived assets, impairment				30
Unproved Property Impairments
Segment Reporting Information [Line Items]
Long-lived assets held for use impairment				20
Oil And Gas Lease | Permian Basin
Segment Reporting Information [Line Items]
Long-lived assets held for use impairment				16
Central Facilities | Eagle Ford
Segment Reporting Information [Line Items]
Long-lived assets held for use impairment				24
Proved Property | Permian Basin
Segment Reporting Information [Line Items]
Long-lived assets held for use impairment	$ 5			5
Non-Producing Property | Gulf Of Mexico
Segment Reporting Information [Line Items]
Impairments				30
Asset retirement costs of long-lived assets, impairment				30
Pension Benefits
Segment Reporting Information [Line Items]
Net curtailment gain					(17)
Pension Benefits | Foreign Plan
Segment Reporting Information [Line Items]
Other net periodic benefit (costs) credits						0
Net curtailment gain						0
Pension Benefits | U.S.
Segment Reporting Information [Line Items]
Other net periodic benefit (costs) credits				(9)	(30)	(12)
Net curtailment gain				0	3	0
Non-Core Conventional Assets
Segment Reporting Information [Line Items]
Net gain (loss) on disposal of assets				(20)
Equity method investment
Segment Reporting Information [Line Items]
Net gain (loss) on disposal of assets				(12)
Well Bore Assignments
Segment Reporting Information [Line Items]
Net gain (loss) on disposal of assets				8
U.S.
Segment Reporting Information [Line Items]
Revenues from contracts with customers				5,334	2,924	4,602
U.S. | Eagle Ford
Segment Reporting Information [Line Items]
Revenues from contracts with customers				1,763	996	1,600
Int’l
Segment Reporting Information [Line Items]
Revenues from contracts with customers						461
Operating Segments | U.S.
Segment Reporting Information [Line Items]
Revenues from contracts with customers				5,334	2,924	4,602
Net gain (loss) on commodity derivatives				(399)	143	52
Income (loss) from equity method investments				0	0	0
Net gain (loss) on disposal of assets				0	0	0
Other income				7	15	13
Production				480	494	588
Shipping, handling and other operating				686	534	561
Exploration				65	97	149
Depreciation, depletion and amortization				1,972	2,211	2,250
Impairments				0	0	0
Taxes other than income				346	193	311
General and administrative				107	115	127
Net interest and other				0	0	0
Other net periodic benefit (costs) credits				0	0	0
Loss on early extinguishment of debt				0	0	0
Income tax provision (benefit)				9	(9)	6
Segment income (loss)				1,277	(553)	675
Total assets				15,339	16,063	17,781
Capital expenditures				1,018	1,137	2,550
Asset retirement costs of long-lived assets, impairment				0	0	0
Operating Segments | Int’l
Segment Reporting Information [Line Items]
Revenues from contracts with customers				267	173	461
Net gain (loss) on commodity derivatives				0	0	0
Income (loss) from equity method investments				253	10	87
Net gain (loss) on disposal of assets				0	0	0
Other income				4	7	9
Production				54	59	126
Shipping, handling and other operating				16	8	26
Exploration				0	0	0
Depreciation, depletion and amortization				68	82	121
Impairments				0	0	0
Taxes other than income				0	0	0
General and administrative				13	14	25
Net interest and other				0	0	0
Other net periodic benefit (costs) credits				0	0	3
Loss on early extinguishment of debt				0	0	0
Income tax provision (benefit)				56	(3)	29
Segment income (loss)				317	30	233
Total assets				994	1,081	1,530
Capital expenditures				0	1	16
Asset retirement costs of long-lived assets, impairment				0	0	0
Not Allocated to Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers				0	0	0
Net gain (loss) on commodity derivatives				16	(27)	(124)
Income (loss) from equity method investments				0	(171)	0
Net gain (loss) on disposal of assets				(19)	9	50
Other income				4	3	40
Production				0	2	(2)
Shipping, handling and other operating				25	54	18
Exploration				71	84	0
Depreciation, depletion and amortization				26	23	26
Impairments				60	144	24
Taxes other than income				(1)	7	0
General and administrative				171	145	204
Net interest and other				188	256	244
Other net periodic benefit (costs) credits				5	(1)	0
Loss on early extinguishment of debt				121	28	3
Income tax provision (benefit)				(7)	(2)	(123)
Segment income (loss)				(648)	(928)	(428)
Total assets				661	812	934
Capital expenditures				14	13	25
Asset retirement costs of long-lived assets, impairment				60	$ 144	24
Not Allocated to Segments | Interest Rate Contract, Maturing June 1, 2025 | Not Designated as Hedges
Segment Reporting Information [Line Items]
Gain on interest rate swap				$ 27
Not Allocated to Segments | Pension Benefits | U.S.
Segment Reporting Information [Line Items]
Other net periodic benefit (costs) credits						$ (12)

Segment Information - Geographi

Segment Information - Geographical (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Revenues from External Customers and Long-Lived Assets [Line Items]
Long-lived assets	$ 14,949	$ 16,085
United States
Revenues from External Customers and Long-Lived Assets [Line Items]
Long-lived assets	14,152	15,224
Equatorial Guinea
Revenues from External Customers and Long-Lived Assets [Line Items]
Long-lived assets	$ 797	$ 861

Income Taxes - Schedule of Inco

Income Taxes - Schedule of Income (Loss) Before Tax Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
United States	$ 637	$ (1,319)	$ 43
Foreign	367	(146)	349
Income (loss) before income taxes	$ 1,004	$ (1,465)	$ 392

Income Taxes - Income Tax Expen

Income Taxes - Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Federal
Current	$ 0	$ (5)	$ (116)
Deferred	0	0	(3)
Total	0	(5)	(119)
State and local
Current	4	(2)	4
Deferred	1	(8)	3
Total	5	(10)	7
Foreign
Current	81	15	58
Deferred	(28)	(14)	(34)
Total	53	1	24
Total
Current	85	8	(54)
Deferred	(27)	(22)	(34)
Total income tax provision (benefit)	$ 58	$ (14)	$ (88)

Income Taxes - Schedule of Effe

Income Taxes - Schedule of Effective Tax Rate Reconciliation (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income (loss) before income taxes		$ 1,004	$ (1,465)	$ 392
Total income tax provision (benefit)		$ 58	$ (14)	$ (88)
Effective income tax rate		6.00%	1.00%	(22.00%)
Income taxes at the statutory tax rate		$ 211	$ (308)	$ 83
Effects of foreign operations		(13)	23	(29)
Adjustments to valuation allowances		(166)	239	(28)
State income taxes, net of federal benefit		23	6	11
Tax law change	$ 0	(2)	0
Other federal tax effects		$ 5	$ 26	$ (125)

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Sep. 30, 2020	Mar. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Jan. 01, 2018	Dec. 31, 2017
Operating Loss Carryforwards [Line Items]
Tax benefit from release of foreign tax accruals		$ 126
Operating loss carryforwards			$ 1,541	$ 1,966
Foreign tax credits			611	611
Valuation allowance			(780)	(948)
Deferred tax liabilities			1,626	1,936
Unrecognized tax benefits that would impact effective tax rate			10	8	$ 13	$ 263
Interest and penalties recorded			0	(2)	6
Interest and penalties accrued					3
Proceeds from tax refunds	$ 89		2	94	$ 90
Deferred tax liability, property, plant and equipment			1,544	$ 1,879
United States
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards							$ 5,300	$ 1,400
Operating loss carryforwards, subject to expiration			295
Operating loss carryforwards, not subject to expiration			1,100
Foreign
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards, subject to expiration			26
State
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards			3,300
Operating loss carryforwards, subject to expiration			$ 125

Income Taxes - Schedule of Net

Income Taxes - Schedule of Net Deferred Tax Asset/Liability (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Deferred tax assets:
Employee benefits	$ 66	$ 77
Operating loss carryforwards	1,541	1,966
Foreign tax credits	611	611
Other	52	67
Subtotal	2,270	2,721
Valuation allowance	(780)	(948)
Total deferred tax assets	1,490	1,773
Deferred tax liabilities:
Property, plant and equipment	1,544	1,879
Accrued revenue	0	20
Other	82	37
Total deferred tax liabilities	1,626	1,936
Net deferred tax liabilities	136	163
Net deferred tax assets	$ 0	$ 0

Income Taxes - Balance Sheet Cl

Income Taxes - Balance Sheet Classification (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Assets
Other noncurrent assets	$ 0	$ 0
Liabilities
Noncurrent deferred tax liabilities	136	163
Net deferred tax liabilities	136	163
Net deferred tax assets	$ 0	$ 0

Income Taxes - Unrecognized Tax

Income Taxes - Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Unrecognized Tax Benefit Rollforward [Abstract]
Beginning balance	$ 8	$ 13	$ 263
Additions for tax positions of prior years	2	0	13
Reductions for tax positions of prior years	0	(5)	(152)
Settlements	0	0	(111)
Ending balance	$ 10	$ 8	$ 13

Credit Losses (Details)

Credit Losses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance as of January 1	$ 22	$ 11
Current period provision	3	22
Current period write offs	(5)	(13)
Recoveries of amounts previously reserved	(5)	(10)
Ending balance as of December 31	15	22
JIB Receivables
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Current period provision		10
Trade Receivables
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Current period provision		12
Cumulative-effect adjustment
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance as of January 1	$ 0	12
Ending balance as of December 31		$ 0

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Inventory Disclosure [Abstract]
Crude oil and natural gas	$ 8	$ 10
Supplies and sundry items	69	66
Inventories at cost	$ 77	$ 76

Property, Plant and Equipment -

Property, Plant and Equipment - Schedule of Property Plant and Equipment (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Property, plant and equipment, net	$ 14,499	$ 15,638
Not Allocated to Segments
Segment Reporting Information [Line Items]
Property, plant and equipment, net	55	68
U.S. | Operating Segments
Segment Reporting Information [Line Items]
Property, plant and equipment, net	14,097	15,156
Int’l | Operating Segments
Segment Reporting Information [Line Items]
Property, plant and equipment, net	$ 347	$ 414

Property, Plant and Equipment_2

Property, Plant and Equipment - Rollforward (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Increase (Decrease) in Capitalized Exploratory Well Costs that are Pending Determination of Proved Reserves [Roll Forward]
Beginning balance as of January 1	$ 210	$ 278	$ 297
Additions	50	97	218
Charges to expense	(30)	(1)	(5)
Transfers to development	(68)	(164)	(230)
Dispositions	0	0	(2)
Ending balance as of December 31	$ 162	$ 210	$ 278

Property, Plant and Equipment_3

Property, Plant and Equipment - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Schedule Of Property Plant And Equipment By Segment [Line Items]
Amounts capitalized greater than one year after completion of drilling	$ 80	$ 98
Exploratory well cost capitalized during the year		$ 40	$ 34	$ 6
Permian Basin
Schedule Of Property Plant And Equipment By Segment [Line Items]
Dry well cost	$ 28

Impairments - Schedule of Impai

Impairments - Schedule of Impaired Assets (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Jun. 30, 2021	Mar. 31, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Impaired Long-Lived Assets Held and Used [Line Items]
Long-lived assets			$ 14,949	$ 16,085
Long-lived assets held for use impairment	$ 24		30	49	$ 24
Asset retirement costs of long-lived assets, impairment			30	0	0
Goodwill, impairment loss		$ 95	0	95	0
Impairment			0	171	0
Fair Value
Impaired Long-Lived Assets Held and Used [Line Items]
Long-lived assets			0	0	56
Asset retirement costs of long-lived assets			0	0	0
Goodwill			0	0	0
Equity method investment			$ 0	$ 119	$ 0

Impairment - Narrative (Details

Impairment - Narrative (Details) $ in Millions	3 Months Ended			12 Months Ended
	Sep. 30, 2021USD ($)	Jun. 30, 2021USD ($)facility	Mar. 31, 2020USD ($)	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Impaired Long-Lived Assets Held and Used [Line Items]
Long-lived assets held for use impairment		$ 24		$ 30	$ 49	$ 24
Number of impaired assets | facility		2
Impairments				60	144	24
Asset retirement obligation				316	254	254
Goodwill impairment			$ 95	0	95	0
Equity method investment, impairment				0	171	0
Equity method investment, difference between carrying amount and underlying equity				112	140
Long-lived assets				14,949	16,085
Gulf Of Mexico
Impaired Long-Lived Assets Held and Used [Line Items]
Impairments				30
Asset retirement obligation				37	7
Fair Value
Impaired Long-Lived Assets Held and Used [Line Items]
Long-lived assets				0	0	$ 56
Unproved Property
Impaired Long-Lived Assets Held and Used [Line Items]
Impairments					$ 78
Proved Property | Permian Basin
Impaired Long-Lived Assets Held and Used [Line Items]
Long-lived assets held for use impairment	$ 5			$ 5

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance as of January 1	$ 254	$ 254
Incurred liabilities, including acquisitions	14	6
Settled liabilities, including dispositions	(6)	(12)
Accretion expense (included in depreciation, depletion and amortization)	12	12
Revisions of estimates	42	(6)
Ending balance as of December 31	316	254	$ 254
Asset retirement obligation, current	28	13
Impairments	60	144	$ 24
Gulf Of Mexico
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance as of January 1	7
Revisions of estimates	37
Ending balance as of December 31	37	$ 7
Asset retirement obligation, current	14
Impairments	$ 30

Leases - Supplemental Balance S

Leases - Supplemental Balance Sheet Information (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Other noncurrent assets	Other noncurrent assets
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other noncurrent assets	Other noncurrent assets
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Other current liabilities	Other current liabilities
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities	Other current liabilities
Deferred credits and other liabilities	$ 132	$ 194
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Deferred credits and other liabilities	Deferred credits and other liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Deferred credits and other liabilities	Deferred credits and other liabilities
ROU assets:
Operating leases	$ 59	$ 133
Finance leases	28	0
Total ROU assets	87	133
Lease liabilities:
Operating leases	40	70
Finance leases	6	0
Operating leases	23	67
Finance leases	24	0
Total lease liabilities	$ 93	$ 137

Leases - Lease Costs (Details)

Leases - Lease Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Short-term lease costs	$ 121	$ 170
Long-term lease costs	64	75
Variable lease costs	33	23
Amortization of ROU assets	3	0
Total lease costs	221	268
Cash paid for amounts included in the measurement of operating lease liabilities	73	100
ROU assets obtained in exchange for new operating lease liabilities	15	46
ROU assets obtained in exchange for new finance lease liabilities	28	0
Reductions to ROU assets resulting from modifications or cancellations of operating leases	(13)	(68)
Finance leases	$ 28	$ 0

Leases - Lease Maturity (Detail

Leases - Lease Maturity (Details) - USD ($) $ in Millions	Dec. 31, 2021	Sep. 30, 2021	Dec. 31, 2020
Operating Lease Obligations
2022	$ 45
2023	8
2024	5
2025	4
2026	2
Thereafter	0
Total undiscounted lease payments	64
Less: amount representing interest	1
Total lease liabilities	63
Less: current portion of lease liability as of December 31, 2021	40		$ 70
Long-term lease liability as of December 31, 2021	23		67
Finance Lease Obligations
2022	7
2023	7
2024	7
2025	7
2026	4
Thereafter	0
Total undiscounted lease payments	32
Less: amount representing interest	2
Total lease liabilities	30	$ 32
Less: current portion of lease liability as of December 31, 2021	6		0
Long-term lease liability as of December 31, 2021	24		0
Total Lease Obligations
2022	52
2023	15
2024	12
2025	11
2026	6
Thereafter	0
Total undiscounted lease payments	96
Less: amount representing interest	3
Total lease liabilities	93		$ 137
Less: current portion of lease liability as of December 31, 2021	46
Long-term lease liability as of December 31, 2021	$ 47

Leases - Narrative (Details)

Leases - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Sep. 30, 2021
Leases [Abstract]
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]		Liabilities
Total costs incurred under lease	$ 302
Term of contract	5 years
Finance lease, ROU		$ 32
Total lease liabilities	$ 30	$ 32
Finance lease extension term	5 years
Residual value guarantee	100.00%
Weighted average lease term	2 years
Discount rate	3.00%
Finance lease, weighted-average remaining lease term	5 years
Finance lease, discount rate	2.00%
Annual payments to be received	$ 6

Leases - Lease Payments to be R

Leases - Lease Payments to be Received (Details) $ in Millions	Dec. 31, 2021USD ($)
Leases [Abstract]
2022	$ 6
2023	6
2024	6
2025	6
2026	6
Thereafter	49
Total undiscounted cash flows	$ 79

Goodwill - Narrative (Details)

Goodwill - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Goodwill Disclosure [Abstract]
Goodwill impairment	$ 95	$ 0	$ 95	$ 0

Derivatives - Balance Sheet Com

Derivatives - Balance Sheet Components (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Derivatives, Fair Value [Line Items]
Asset	$ 28	$ 39
Liability	13	49
Net Asset (Liability)	15	(10)
Not Designated as Hedges
Derivatives, Fair Value [Line Items]
Asset	28	20
Liability	8	33
Net Asset (Liability)	20	(13)
Not Designated as Hedges | Other current liabilities | Commodity
Derivatives, Fair Value [Line Items]
Asset	1	7
Liability	8	32
Net Asset (Liability)	(7)	(25)
Not Designated as Hedges | Other noncurrent assets | Interest Rate
Derivatives, Fair Value [Line Items]
Asset	27	10
Liability	0	0
Net Asset (Liability)	27	10
Not Designated as Hedges | Other current assets | Commodity
Derivatives, Fair Value [Line Items]
Asset		3
Liability		1
Net Asset (Liability)		2
Cash Flow Hedges
Derivatives, Fair Value [Line Items]
Asset	0	19
Liability	5	16
Net Asset (Liability)	(5)	3
Cash Flow Hedges | Other current liabilities | Interest Rate
Derivatives, Fair Value [Line Items]
Asset	0
Liability	3
Net Asset (Liability)	(3)
Cash Flow Hedges | Other noncurrent assets | Interest Rate
Derivatives, Fair Value [Line Items]
Asset		19
Liability		0
Net Asset (Liability)		19
Cash Flow Hedges | Deferred credits and other liabilities | Interest Rate
Derivatives, Fair Value [Line Items]
Asset	0	0
Liability	2	16
Net Asset (Liability)	$ (2)	$ (16)

Derivatives - Outstanding Deriv

Derivatives - Outstanding Derivative Contracts (Details) - Not Designated as Hedges	Feb. 14, 2022MMBTU_per_dayBbls_per_day$ / bbl	Dec. 31, 2021MMBTU_per_dayBbls_per_day$ / bbl
Three-Way Collars - Crude Oil 2022 Q1
Derivative [Line Items]
Derivative, volume | Bbls_per_day		50,000
Derivative, ceiling		92.26
Derivative, floor		52
Derivative, sold put		42
Three-Way Collars - Crude Oil 2022 Q1 | Subsequent Event
Derivative [Line Items]
Derivative, volume | Bbls_per_day	50,000
Derivative, ceiling	96.54
Derivative, floor	55.93
Derivative, sold put	45.93
Three-Way Collars - Crude Oil 2022 Q2
Derivative [Line Items]
Derivative, volume | Bbls_per_day		50,000
Derivative, ceiling		92.26
Derivative, floor		52
Derivative, sold put		42
Three-Way Collars - Crude Oil 2022 Q2 | Subsequent Event
Derivative [Line Items]
Derivative, volume | Bbls_per_day	50,000
Derivative, ceiling	98.79
Derivative, floor	58
Derivative, sold put	48
Three-Way Collars - Crude Oil 2022 Q3
Derivative [Line Items]
Derivative, volume | Bbls_per_day		20,000
Derivative, ceiling		92.80
Derivative, floor		50
Derivative, sold put		40
Three-Way Collars - Crude Oil 2022 Q3 | Subsequent Event
Derivative [Line Items]
Derivative, volume | Bbls_per_day	50,000
Derivative, ceiling	97.52
Derivative, floor	56.67
Derivative, sold put	46.67
Three-Way Collars - Crude Oil 2022 Q4
Derivative [Line Items]
Derivative, volume | Bbls_per_day		20,000
Derivative, ceiling		92.80
Derivative, floor		50
Derivative, sold put		40
Three-Way Collars - Crude Oil 2022 Q4 | Subsequent Event
Derivative [Line Items]
Derivative, volume | Bbls_per_day	50,000
Derivative, ceiling	97.52
Derivative, floor	56.67
Derivative, sold put	46.67
NYMEX Roll Basis Swaps - Crude Oil 2022 Q1
Derivative [Line Items]
Derivative, volume | Bbls_per_day		45,000
NYMEX Roll Basis Swaps - Crude Oil 2022 Q1 | Subsequent Event
Derivative [Line Items]
Derivative, volume | Bbls_per_day	50,167
NYMEX Roll Basis Swaps - Crude Oil 2022 Q1 | Long
Derivative [Line Items]
Derivative, weighted average price		0.56
NYMEX Roll Basis Swaps - Crude Oil 2022 Q1 | Long | Subsequent Event
Derivative [Line Items]
Derivative, weighted average price	0.60
NYMEX Roll Basis Swaps - Crude Oil 2022 Q2
Derivative [Line Items]
Derivative, volume | Bbls_per_day		45,000
NYMEX Roll Basis Swaps - Crude Oil 2022 Q2 | Subsequent Event
Derivative [Line Items]
Derivative, volume | Bbls_per_day	60,000
NYMEX Roll Basis Swaps - Crude Oil 2022 Q2 | Long
Derivative [Line Items]
Derivative, weighted average price		0.56
NYMEX Roll Basis Swaps - Crude Oil 2022 Q2 | Long | Subsequent Event
Derivative [Line Items]
Derivative, weighted average price	0.67
NYMEX Roll Basis Swaps - Crude Oil 2022 Q3
Derivative [Line Items]
Derivative, volume | Bbls_per_day		45,000
NYMEX Roll Basis Swaps - Crude Oil 2022 Q3 | Subsequent Event
Derivative [Line Items]
Derivative, volume | Bbls_per_day	60,000
NYMEX Roll Basis Swaps - Crude Oil 2022 Q3 | Long
Derivative [Line Items]
Derivative, weighted average price		0.56
NYMEX Roll Basis Swaps - Crude Oil 2022 Q3 | Long | Subsequent Event
Derivative [Line Items]
Derivative, weighted average price	0.67
NYMEX Roll Basis Swaps - Crude Oil 2022 Q4
Derivative [Line Items]
Derivative, volume | Bbls_per_day		45,000
NYMEX Roll Basis Swaps - Crude Oil 2022 Q4 | Subsequent Event
Derivative [Line Items]
Derivative, volume | Bbls_per_day	60,000
NYMEX Roll Basis Swaps - Crude Oil 2022 Q4 | Long
Derivative [Line Items]
Derivative, weighted average price		0.56
NYMEX Roll Basis Swaps - Crude Oil 2022 Q4 | Long | Subsequent Event
Derivative [Line Items]
Derivative, weighted average price	0.67
Three-Way Collars - Natural Gas 2022, First Quarter
Derivative [Line Items]
Derivative, volume | MMBTU_per_day		50,000
Derivative, ceiling		5.14
Derivative, floor		3.60
Derivative, sold put		2.60
Three-Way Collars - Natural Gas 2022, First Quarter | Subsequent Event
Derivative [Line Items]
Derivative, volume | MMBTU_per_day	50,000
Derivative, ceiling	5.14
Derivative, floor	3.60
Derivative, sold put	2.60
Three-Way Collars - Natural Gas 2022, Second Quarter
Derivative [Line Items]
Derivative, volume | MMBTU_per_day		0
Derivative, ceiling		0
Derivative, floor		0
Derivative, sold put		0
Three-Way Collars - Natural Gas 2022, Second Quarter | Subsequent Event
Derivative [Line Items]
Derivative, volume | MMBTU_per_day	50,000
Derivative, ceiling	6.18
Derivative, floor	3.50
Derivative, sold put	2.50
Three-Way Collars - Natural Gas 2022, Third Quarter
Derivative [Line Items]
Derivative, volume | MMBTU_per_day		0
Derivative, ceiling		0
Derivative, floor		0
Derivative, sold put		0
Three-Way Collars - Natural Gas 2022, Third Quarter | Subsequent Event
Derivative [Line Items]
Derivative, volume | MMBTU_per_day	50,000
Derivative, ceiling	6.18
Derivative, floor	3.50
Derivative, sold put	2.50
Three-Way Collars - Natural Gas 2022, Fourth Quarter
Derivative [Line Items]
Derivative, volume | MMBTU_per_day		0
Derivative, ceiling		0
Derivative, floor		0
Derivative, sold put		0
Three-Way Collars - Natural Gas 2022, Fourth Quarter | Subsequent Event
Derivative [Line Items]
Derivative, volume | MMBTU_per_day	50,000
Derivative, ceiling	6.18
Derivative, floor	3.50
Derivative, sold put	2.50

Derivatives - Schedule of mark-

Derivatives - Schedule of mark-to-market impact and commodity derivative settlements (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Realized gain (loss) on derivatives, net	$ 54	$ 12	$ 0
Net settlements of derivative instruments	356	123	65
Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized gain (loss) on derivative instruments, net	16	(27)	(124)
Realized gain (loss) on derivatives, net	$ (399)	$ 143	$ 52

Derivatives - Narrative (Detail

Derivatives - Narrative (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		12 Months Ended
	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Dec. 31, 2021	Aug. 04, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Long-term debt, gross				$ 4,036		$ 5,436
Senior Unsecured Notes, 3.850%, Due 2025
Derivative Instruments, Gain (Loss) [Line Items]
Debt instrument, interest rate					3.85%
Senior Unsecured Notes | Senior Unsecured Notes, 3.850%, Due 2025
Derivative Instruments, Gain (Loss) [Line Items]
Long-term debt, gross				$ 0		900
Debt instrument, interest rate				3.85%
Interest Rate Contract, Maturing June 1, 2025
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount						350
Reclassification from AOCI		$ 31
Mark-to-market losses	$ 4
Interest Rate Contract, Maturing June 1, 2025 | Not Designated as Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Gain on interest rate swap				$ 27
Interest Rate Contract, Maturing September 9, 2026
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount				295		320
Reclassification from AOCI		(1)
Amount expected to be reclassified within 12 months				3
Designated as Hedging Instrument | Interest Rate Contract, Maturing November 1, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount						500
Designated as Hedging Instrument | Interest Rate Contract, Maturing June 1, 2025 | Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount						350
Designated as Hedging Instrument | Interest Rate Contract, Maturing September 9, 2026 | Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount							$ 320
Not Designated as Hedges | Interest Rate Contract, Maturing November 1, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount				0		500
Reclassification of de-designated forward interest rate swaps			$ 2
Gain on interest rate swap				$ 28
Not Designated as Hedges | Interest Rate Contract, Maturing June 1, 2025
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount						$ 350
Not Designated as Hedges | Interest Rate Contract, Maturing September 9, 2026
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount		25
Not Designated as Hedges | Interest Rate Contract, Maturing September 9, 2026 | Scenario, Adjustment
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount		$ 25

Derivatives - Schedule of Termi

Derivatives - Schedule of Terminated Interest Rate Swap Agreement (Details) - USD ($) $ in Millions	Dec. 31, 2021	Jun. 30, 2021	Dec. 31, 2020
Interest Rate Contract, Maturing November 1, 2022 | Not Designated as Hedges
Derivative [Line Items]
Derivative, notional amount	$ 0		$ 500
Weighted average interest rate, LIBOR	0.00%		0.99%
Interest Rate Contract, Maturing June 1, 2025
Derivative [Line Items]
Derivative, notional amount			$ 350
Weighted average interest rate, LIBOR			0.95%
Interest Rate Contract, Maturing June 1, 2025 | Not Designated as Hedges
Derivative [Line Items]
Derivative, notional amount			$ 350
Weighted average interest rate, LIBOR	0.95%
Interest Rate Contract, Maturing September 9, 2026
Derivative [Line Items]
Derivative, notional amount	$ 295		$ 320
Weighted average interest rate, LIBOR	1.52%		1.51%
Interest Rate Contract, Maturing September 9, 2026 | Not Designated as Hedges
Derivative [Line Items]
Derivative, notional amount		$ 25
Weighted average interest rate, LIBOR	1.45%

Derivatives - Schedule of Inter

Derivatives - Schedule of Interest Rate Swap Agreements (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Interest Rate Contract, Maturing June 1, 2025
Derivative [Line Items]
Derivative, notional amount		$ 350
Weighted average interest rate, LIBOR		0.95%
Interest Rate Contract, Maturing September 9, 2026
Derivative [Line Items]
Derivative, notional amount	$ 295	$ 320
Weighted average interest rate, LIBOR	1.52%	1.51%

Fair Value Measurements - Recur

Fair Value Measurements - Recurring (Details) - Recurring - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets	$ 27	$ 29
Derivative instruments, liabilities	(12)	(39)
Total	15	(10)
Interest Rate | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets	27	10
Interest Rate | Designated as Hedging Instrument
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets		19
Derivative instruments, liabilities	(5)	(16)
Commodity
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, liabilities	(7)	(23)
Level 1
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets	0	0
Derivative instruments, liabilities	(2)	0
Total	(2)	0
Level 1 | Interest Rate | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets	0	0
Level 1 | Interest Rate | Designated as Hedging Instrument
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets		0
Derivative instruments, liabilities	0	0
Level 1 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, liabilities	(2)	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets	27	29
Derivative instruments, liabilities	(10)	(39)
Total	17	(10)
Level 2 | Interest Rate | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets	27	10
Level 2 | Interest Rate | Designated as Hedging Instrument
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets		19
Derivative instruments, liabilities	(5)	(16)
Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, liabilities	(5)	(23)
Level 3
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets	0	0
Derivative instruments, liabilities	0	0
Total	0	0
Level 3 | Interest Rate | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets	0	0
Level 3 | Interest Rate | Designated as Hedging Instrument
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, assets		0
Derivative instruments, liabilities	0	0
Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative instruments, liabilities	$ 0	$ 0

Fair Value Measurements - Fair

Fair Value Measurements - Fair Values, Financial Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Fair Value
Financial assets
Current assets	$ 11	$ 4
Other noncurrent assets	12	24
Total financial assets	23	28
Financial liabilities
Other current liabilities	99	72
Long-term debt, including current portion	4,705	6,077
Deferred credits and other liabilities	46	82
Total financial liabilities	4,850	6,231
Carrying Amount
Financial assets
Current assets	10	4
Other noncurrent assets	27	37
Total financial assets	37	41
Financial liabilities
Other current liabilities	136	103
Long-term debt, including current portion	4,033	5,431
Deferred credits and other liabilities	46	76
Total financial liabilities	$ 4,215	$ 5,610

Debt - Narrative (Details)

Debt - Narrative (Details) - USD ($)	Aug. 04, 2021	Mar. 30, 2021	May 28, 2023	Dec. 31, 2021	Jun. 21, 2021	Jun. 20, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Long-term debt				$ 4,014,000,000			$ 5,404,000,000
Senior Unsecured Notes, 2.800%, Due 2022
Debt Instrument [Line Items]
Long-term debt		$ 500,000,000
Debt instrument, interest rate		2.80%
Costs related to make-whole provision premium and write off of unamortized discount and issuance costs		$ 19,000,000
Senior Unsecured Notes, 2.800%, Due 2022 | Senior Unsecured Notes
Debt Instrument [Line Items]
Debt instrument, interest rate				2.80%
Senior Unsecured Notes, 3.850%, Due 2025
Debt Instrument [Line Items]
Long-term debt	$ 900,000,000
Debt instrument, interest rate	3.85%
Costs related to make-whole provision premium and write off of unamortized discount and issuance costs	$ 102,000,000
Senior Unsecured Notes, 3.850%, Due 2025 | Senior Unsecured Notes
Debt Instrument [Line Items]
Debt instrument, interest rate				3.85%
Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit, outstanding balance				$ 0
Line of credit facility, maximum borrowing capacity					$ 3,100,000,000	$ 3,000,000,000
Covenant, ratio of indebtedness to net capital, maximum				65.00%
Ratio of indebtedness to net capital				0.20
Revolving Credit Facility | Forecast
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity			$ 3,000,000,000

Debt - Schedule of Debt (Detail

Debt - Schedule of Debt (Details) - USD ($) $ in Millions	Dec. 31, 2021	Aug. 04, 2021	Mar. 30, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Long-term debt, gross	$ 4,036			$ 5,436
Unamortized discount	(3)			(5)
Unamortized debt issuance cost	(19)			(27)
Total long-term debt	4,014			5,404
Debt immediately due if change in control	$ 236
Senior Unsecured Notes, 2.800%, Due 2022
Debt Instrument [Line Items]
Debt instrument, interest rate			2.80%
Total long-term debt			$ 500
Senior Unsecured Notes, 2.800%, Due 2022 | Senior Unsecured Notes
Debt Instrument [Line Items]
Debt instrument, interest rate	2.80%
Long-term debt, gross	$ 0			500
Senior Unsecured Notes, 9.375%, Due 2022 | Senior Unsecured Notes
Debt Instrument [Line Items]
Debt instrument, interest rate	9.375%
Long-term debt, gross	$ 32			32
Senior Unsecured Notes, Series A, Due 2022 | Senior Unsecured Notes
Debt Instrument [Line Items]
Long-term debt, gross	$ 3			3
Senior Unsecured Notes, 8.500%, Due 2023 | Senior Unsecured Notes
Debt Instrument [Line Items]
Debt instrument, interest rate	8.50%
Long-term debt, gross	$ 70			70
Senior Unsecured Notes, 8.125%, Due 2023 | Senior Unsecured Notes
Debt Instrument [Line Items]
Debt instrument, interest rate	8.125%
Long-term debt, gross	$ 131			131
Senior Unsecured Notes, 3.850%, Due 2025
Debt Instrument [Line Items]
Debt instrument, interest rate		3.85%
Total long-term debt		$ 900
Senior Unsecured Notes, 3.850%, Due 2025 | Senior Unsecured Notes
Debt Instrument [Line Items]
Debt instrument, interest rate	3.85%
Long-term debt, gross	$ 0			900
Senior Unsecured Notes, 4.400%, Due 2027 | Senior Unsecured Notes
Debt Instrument [Line Items]
Debt instrument, interest rate	4.40%
Long-term debt, gross	$ 1,000			1,000
Senior Unsecured Notes, 6.800%, Due 2032 | Senior Unsecured Notes
Debt Instrument [Line Items]
Debt instrument, interest rate	6.80%
Long-term debt, gross	$ 550			550
Senior Unsecured Notes, 6.600%, Due 2037 | Senior Unsecured Notes
Debt Instrument [Line Items]
Debt instrument, interest rate	6.60%
Long-term debt, gross	$ 750			750
Senior Unsecured Notes, 5.200%, Due 2045 | Senior Unsecured Notes
Debt Instrument [Line Items]
Debt instrument, interest rate	5.20%
Long-term debt, gross	$ 500			500
Bonds, 2.00%, Due 2037 | Bonds
Debt Instrument [Line Items]
Debt instrument, interest rate	2.00%
Long-term debt, gross	$ 200			200
Bonds, 2.10%, Due 2037 | Bonds
Debt Instrument [Line Items]
Debt instrument, interest rate	2.10%
Long-term debt, gross	$ 200			200
Bonds, 2.20%, Due 2037 | Bonds
Debt Instrument [Line Items]
Debt instrument, interest rate	2.20%
Long-term debt, gross	$ 200			200
Bonds, 2.125%, Due 2037 | Bonds
Debt Instrument [Line Items]
Debt instrument, interest rate	2.125%
Long-term debt, gross	$ 200			200
Bonds, 2.375%, Due 2037 | Bonds
Debt Instrument [Line Items]
Debt instrument, interest rate	2.375%
Long-term debt, gross	$ 200			$ 200

Debt - Maturity (Details)

Debt - Maturity (Details) $ in Millions	Dec. 31, 2021USD ($)
Long-term Debt, Fiscal Year Maturity [Abstract]
2022	$ 35
2023	401
2024	400
2025	0
2026	400
Thereafter	2,800
Total long-term debt, including current portion	$ 4,036

Incentive Based Compensation -

Incentive Based Compensation - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized (in shares)	27,900,000
Performance shares, payout determination, share price trading day duration	30 days
Performance period	2 years
Dividends paid (in dollars per share)	$ 0.18	$ 0.08	$ 0.20
Allocated stock-based compensation expense	$ 43,000,000	$ 55,000,000	$ 60,000,000
Proceeds from stock options exercised	5,000,000	1,000,000	1,000,000
Tax benefit realized from exercise of stock options	0	0	0
Unrecognized compensation costs	$ 1,000,000
Share-based Payment Arrangement, Tranche One
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting percentage, banking feature lock threshold percentage	50.00%
Share-based Payment Arrangement, Tranche Two
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting percentage, banking feature lock threshold percentage	100.00%
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	3 years
Maximum term	10 years
Stock options exercised, intrinsic value	$ 3,000,000
Stock Appreciation Rights (SARs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards other than options, outstanding (in shares)	0
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants in period (in shares)	2,306,696
Granted (in dollars per share)	$ 11.21
Unrecognized compensation costs	$ 28,000,000
Unrecognized compensation costs, period for recognition	1 year
Vested in period, total fair value	$ 39,000,000	$ 49,000,000	$ 48,000,000
Weighted average grant date fair value (in dollars per share)	$ 10.98	$ 11.72	$ 15.88
Restricted Stock | Officer
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	3 years
Restricted Stock | Non Officer
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	3 years
Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date fair value (in dollars per share)	$ 18.07	$ 10.55	$ 20.66
Performance Shares | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting rights, percentage	0.00%
Performance Shares | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting rights, percentage	200.00%
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	1 year	3 years
Restricted Stock Units (RSUs) | Officer
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	3 years
Restricted Stock Units (RSUs) | Non Officer
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	3 years
Performance Unit
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards other than options, outstanding (in shares)	1,622,994
Allocated stock-based compensation expense	$ 11,000,000	$ 5,000,000	$ 7,000,000
Performance Unit | Officer
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants in period (in shares)	307,473	1,038,676	656,636
Performance Unit - Share Settlement
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants in period (in shares)	307,473
Granted (in dollars per share)	$ 18.07
Performance Unit - Share Settlement | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting rights, percentage	0.00%
Performance Unit - Share Settlement | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting rights, percentage	200.00%
Performance Unit - Cash Settlement
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards other than options, outstanding (in shares)	307,473
Grants in period (in shares)	307,473
Granted (in dollars per share)	$ 15.55

Incentive Based Compensation _2

Incentive Based Compensation - Stock Option Award Assumptions (Details) - Stock Options - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Exercise price per share (in dollars per share)	$ 0	$ 10.47	$ 16.79
Expected annual dividend yield		1.90%	1.20%
Expected life in years		6 years 1 month 20 days	5 years 9 months 25 days
Expected volatility		44.00%	43.00%
Risk-free interest rate		1.50%	2.50%
Weighted average grant date fair value of stock option awards granted (in dollars per share)		$ 3.82	$ 6.62

Incentive Based Compensation _3

Incentive Based Compensation - Stock Option Award Activity (Details) - Stock Options - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Number of Shares
Beginning of year, stock option awards (in shares)	6,014,255
Granted, stock option awards (in shares)	0
Exercised, stock option awards (in shares)	(602,842)
Canceled, stock option awards (in shares)	(1,137,109)
End of year, stock option awards (in shares)	4,274,304	6,014,255
Exercisable at end of year, stock option awards (in shares)	3,541,275
Expected to vest, stock option awards (in shares)	731,889
Weighted Average Exercise Price
Beginning of year, weighted average exercise price (in dollars per share)	$ 21
Granted, weighted average exercise price (in dollars per share)	0	$ 10.47	$ 16.79
Exercises, weighted average exercise price (in dollars per share)	9.10
Canceled, weighted average exercise price (in dollars per share)	23.10
End of year, weighted average exercise price (in dollars per share)	22.13	$ 21
Exercisable at end of year, weighted average exercise price (in dollars per share)	24.26
Expected to vest, weighted average exercise price (in dollars per share)	$ 11.81
Share-based Payment Arrangement [Abstract]
Outstanding at end of year, Weighted Average Remaining Contractual Term	5 years
Exercisable at end of year, Weighted Average Remaining Contractual Term	4 years
Expected to vest, Weighted Average Remaining Contractual Term	8 years
Outstanding at end of year, Average Intrinsic Value	$ 6,256,356	$ 0	$ 0
Exercisable at end of year, Average Intrinsic Value	2,816,507
Expected to vest, Average Intrinsic Value	$ 3,433,157

Incentive Based Compensation _4

Incentive Based Compensation - Restricted Stock Awards and RSUs (Details) - Restricted Stock - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Awards
Unvested at beginning of year (in shares)	7,851,754
Granted (in shares)	2,306,696
Vested (in shares)	(3,086,302)
Canceled (in shares)	(1,183,906)
Unvested at end of year (in shares)	5,888,242	7,851,754
Weighted Average Grant Date Fair Value
Unvested at beginning of year (in dollars per share)	$ 11.72	$ 15.88
Granted (in dollars per share)	11.21
Vested (in dollars per share)	12.78
Canceled (in dollars per share)	11.62
Unvested at end of year (in dollars per share)	$ 10.98	$ 11.72

Incentive Based Compensation _5

Incentive Based Compensation - Performance Unit Awards (Details) - Performance Shares - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Valuation date stock price (in dollars per share)	$ 11.20	$ 10.47	$ 16.79
Expected annual dividend yield	1.10%	1.90%	1.20%
Expected volatility	71.00%	39.00%	43.00%
Risk-free interest rate	0.30%	1.40%	2.50%
Weighted average grant date fair value (in dollars per share)	$ 18.07	$ 10.55	$ 20.66

Defined Benefit Postretiremen_3

Defined Benefit Postretirement Plans and Defined Contribution Plan - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Assumed Health Care Cost Trend Rates [Line Items]
Decrease in other benefit obligations				$ 99
Estimated future employer contributions in next year	$ 17
Employer discretionary contribution amount	$ 13	$ 13	$ 18
Equity Securities
Defined Benefit Plan Assumed Health Care Cost Trend Rates [Line Items]
Target allocation percentage	55.00%
Fixed Income Securities
Defined Benefit Plan Assumed Health Care Cost Trend Rates [Line Items]
Target allocation percentage	45.00%
Pension Benefits
Defined Benefit Plan Assumed Health Care Cost Trend Rates [Line Items]
Reclassification from AOCI			$ 20
Unfunded Plans
Defined Benefit Plan Assumed Health Care Cost Trend Rates [Line Items]
Estimated future employer contributions in next year	$ 3
Other Benefits
Defined Benefit Plan Assumed Health Care Cost Trend Rates [Line Items]
Estimated future employer contributions in next year	$ 10

Defined Benefit Postretiremen_4

Defined Benefit Postretirement Plans and Defined Contribution Plan - Obligations and Funded Status (Details) - U.S. - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Benefits
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Accumulated benefit obligation	$ 260	$ 298
Change in benefit obligations:
Beginning balance	308	354
Service cost	16	19	$ 19
Interest cost	7	9	12
Actuarial (gain) loss	(15)	36
Gain due to curtailment	0	(1)
Settlements paid	(43)	(104)
Benefits paid	(4)	(5)
Ending balance	269	308	354
Change in fair value of plan assets:
Beginning balance	194	236
Actual return on plan assets	13	18
Employer contributions	32	49
Settlements paid	(43)	(104)
Benefits paid	(4)	(5)
Ending balance	192	194	236
Funded status of plans at December 31
Funded status of plans at December 31	(77)	(114)
Amounts recognized in the consolidated balance sheets:
Current liabilities	(3)	(4)
Noncurrent liabilities	(74)	(110)
Accrued benefit cost	(77)	(114)
Pretax amounts in accumulated other comprehensive loss:
Net loss	37	72
Prior service credit	(13)	(19)
Other Benefits
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Accumulated benefit obligation	73	80
Change in benefit obligations:
Beginning balance	80	89
Service cost	0	1
Interest cost	2	2
Actuarial (gain) loss	1	4
Gain due to curtailment	0	0
Settlements paid	0	0
Benefits paid	(10)	(16)
Ending balance	73	80	89
Change in fair value of plan assets:
Beginning balance	0	0
Actual return on plan assets	0	0
Employer contributions	10	16
Settlements paid	0	0
Benefits paid	(10)	(16)
Ending balance	0	0	$ 0
Funded status of plans at December 31
Funded status of plans at December 31	(73)	(80)
Amounts recognized in the consolidated balance sheets:
Current liabilities	(10)	(10)
Noncurrent liabilities	(63)	(70)
Accrued benefit cost	(73)	(80)
Pretax amounts in accumulated other comprehensive loss:
Net loss	23	24
Prior service credit	$ (81)	$ (97)

Defined Benefit Postretiremen_5

Defined Benefit Postretirement Plans and Defined Contribution Plan - Schedule of Net Periodic Benefit Cost and OCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Depreciation, Depletion and Amortization [Abstract]
Net settlement loss	$ (5)	$ 1	$ (3)
Not Allocated to Segments
Depreciation, Depletion and Amortization [Abstract]
Net settlement loss	(5)	1	0
Pension Benefits
Depreciation, Depletion and Amortization [Abstract]
Net curtailment gain		17
Pension Benefits | U.S.
Components of net periodic benefit costs:
Service cost	16	19	19
Interest cost	7	9	12
Expected return on plan assets	(8)	(11)	(10)
Depreciation, Depletion and Amortization [Abstract]
- prior service cost (credit)	(6)	(6)	(7)
- actuarial loss	5	9	7
Net settlement loss	9	30	12
Net curtailment gain	0	(3)	0
Net periodic benefit cost	23	47	33
Other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss (pretax):
Actuarial loss (gain)	(21)	27	14
Settlement loss and amortization of actuarial gain (loss)	(14)	(40)	(19)
Prior service cost (credit)	0	0	0
Curtailment gain and amortization of prior service credit (cost)	6	10	7
Total recognized in other comprehensive (income) loss	(29)	(3)	2
Total recognized in net periodic benefit cost and other comprehensive (income) loss	(6)	44	35
Pension Benefits | U.S. | Not Allocated to Segments
Depreciation, Depletion and Amortization [Abstract]
Net settlement loss			12
Pension Benefits | Int’l
Components of net periodic benefit costs:
Service cost			0
Interest cost			8
Expected return on plan assets			(11)
Depreciation, Depletion and Amortization [Abstract]
- prior service cost (credit)			0
- actuarial loss			0
Net settlement loss			0
Net curtailment gain			0
Net periodic benefit cost			(3)
Other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss (pretax):
Actuarial loss (gain)			(21)
Settlement loss and amortization of actuarial gain (loss)			(41)
Prior service cost (credit)			0
Curtailment gain and amortization of prior service credit (cost)			(6)
Total recognized in other comprehensive (income) loss			(68)
Total recognized in net periodic benefit cost and other comprehensive (income) loss			(71)
Other Benefits | U.S.
Components of net periodic benefit costs:
Service cost	0	1
Interest cost	2	2
Expected return on plan assets	0	0
Depreciation, Depletion and Amortization [Abstract]
- prior service cost (credit)	(16)	(18)
- actuarial loss	2	2
Net settlement loss	0	0
Net curtailment gain	0	(14)
Net periodic benefit cost	(12)	(27)
Other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss (pretax):
Actuarial loss (gain)	1	4
Settlement loss and amortization of actuarial gain (loss)	(2)	(2)
Prior service cost (credit)	0	0
Curtailment gain and amortization of prior service credit (cost)	16	32
Total recognized in other comprehensive (income) loss	15	34
Total recognized in net periodic benefit cost and other comprehensive (income) loss	$ 3	$ 7
Other Benefits | Int’l
Components of net periodic benefit costs:
Service cost			1
Interest cost			3
Expected return on plan assets			0
Depreciation, Depletion and Amortization [Abstract]
- prior service cost (credit)			(19)
- actuarial loss			1
Net settlement loss			0
Net curtailment gain			0
Net periodic benefit cost			(14)
Other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss (pretax):
Actuarial loss (gain)			9
Settlement loss and amortization of actuarial gain (loss)			(1)
Prior service cost (credit)			0
Curtailment gain and amortization of prior service credit (cost)			19
Total recognized in other comprehensive (income) loss			27
Total recognized in net periodic benefit cost and other comprehensive (income) loss			$ 13

Defined Benefit Postretiremen_6

Defined Benefit Postretirement Plans and Defined Contribution Plan - Plan Assumptions (Details) - U.S.	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2023
Pension Benefits
Weighted average assumptions used to determine benefit obligation:
Discount rate		2.83%	2.52%	3.13%
Rate of compensation increase		0.50%	0.50%	4.50%
Cash balance interest crediting		3.00%	3.00%	3.00%
Weighted average assumptions used to determine net periodic benefit cost:
Discount rate		2.77%	2.90%	3.70%
Expected long-term return on plan assets		5.75%	6.00%	6.25%
Rate of compensation increase		0.50%	4.50%	4.00%
Cash balance interest crediting		3.00%	3.00%	3.00%
Pension Benefits | Forecast
Weighted average assumptions used to determine benefit obligation:
Rate of compensation increase	5.00%				4.50%
Weighted average assumptions used to determine net periodic benefit cost:
Rate of compensation increase	4.50%
Other Benefits
Weighted average assumptions used to determine benefit obligation:
Discount rate		2.48%	2.02%	2.91%
Rate of compensation increase		0.50%	0.50%	4.50%
Cash balance interest crediting		0.00%	0.00%	0.00%
Weighted average assumptions used to determine net periodic benefit cost:
Discount rate		2.02%	2.63%	4.09%
Expected long-term return on plan assets		0.00%	0.00%	0.00%
Rate of compensation increase		0.50%	4.50%	4.00%
Cash balance interest crediting		0.00%	0.00%	0.00%

Defined Benefit Postretiremen_7

Defined Benefit Postretirement Plans and Defined Contribution Plan - Fair Value of Defined Benefit Pension Plan Assets (Details) - Recurring - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Plan assets	$ 192	$ 194
Plan assets before comingled funds	50	87
Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Plan assets	(1)
Common stock
Defined Benefit Plan Disclosure [Line Items]
Plan assets	28	61
Private equity
Defined Benefit Plan Disclosure [Line Items]
Plan assets	7	8
Other
Defined Benefit Plan Disclosure [Line Items]
Plan assets	16	18
Commingled funds
Defined Benefit Plan Disclosure [Line Items]
Plan assets	142	107
Level 1
Defined Benefit Plan Disclosure [Line Items]
Plan assets	27	61
Plan assets before comingled funds	27	61
Level 1 | Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Plan assets	(1)
Level 1 | Common stock
Defined Benefit Plan Disclosure [Line Items]
Plan assets	28	61
Level 1 | Private equity
Defined Benefit Plan Disclosure [Line Items]
Plan assets	0	0
Level 1 | Other
Defined Benefit Plan Disclosure [Line Items]
Plan assets	0	0
Level 1 | Commingled funds
Defined Benefit Plan Disclosure [Line Items]
Plan assets	0	0
Level 2
Defined Benefit Plan Disclosure [Line Items]
Plan assets	0	0
Plan assets before comingled funds	0	0
Level 2 | Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Plan assets	0
Level 2 | Common stock
Defined Benefit Plan Disclosure [Line Items]
Plan assets	0	0
Level 2 | Private equity
Defined Benefit Plan Disclosure [Line Items]
Plan assets	0	0
Level 2 | Other
Defined Benefit Plan Disclosure [Line Items]
Plan assets	0	0
Level 2 | Commingled funds
Defined Benefit Plan Disclosure [Line Items]
Plan assets	0	0
Level 3
Defined Benefit Plan Disclosure [Line Items]
Plan assets	23	26
Plan assets before comingled funds	23	26
Level 3 | Cash and cash equivalents
Defined Benefit Plan Disclosure [Line Items]
Plan assets	0
Level 3 | Common stock
Defined Benefit Plan Disclosure [Line Items]
Plan assets	0	0
Level 3 | Private equity
Defined Benefit Plan Disclosure [Line Items]
Plan assets	7	8
Level 3 | Other
Defined Benefit Plan Disclosure [Line Items]
Plan assets	16	18
Level 3 | Commingled funds
Defined Benefit Plan Disclosure [Line Items]
Plan assets	$ 0	$ 0

Defined Benefit Postretiremen_8

Defined Benefit Postretirement Plans and Defined Contribution Plan - Cash Flows (Details) $ in Millions	Dec. 31, 2021USD ($)
Pension Benefits
Defined Benefit Plan Estimated Future Benefit Payments [Line Items]
2022	$ 29
2023	27
2024	25
2025	23
2026	22
2027 through 2031	101
Other Benefits
Defined Benefit Plan Estimated Future Benefit Payments [Line Items]
2022	10
2023	9
2024	8
2025	7
2026	6
2027 through 2031	$ 22

Reclassifications Out of Accu_3

Reclassifications Out of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other net periodic benefit (costs) credits	$ 5	$ (1)	$ 3
Net interest and other	(188)	(256)	(244)
Net income (loss)	946	(1,451)	$ 480
Amortization of prior service credit | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other net periodic benefit (costs) credits	22	24
Amortization of actuarial loss | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other net periodic benefit (costs) credits	(7)	(11)
Net settlement loss | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other net periodic benefit (costs) credits	(9)	(30)
Net curtailment gain | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other net periodic benefit (costs) credits	0	17
Postretirement and postemployment plans | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Other net periodic benefit (costs) credits
Net income (loss)	(22)	0
Reclassification of de-designated forward interest rate swaps | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Net interest and other	$ (28)	$ 0

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating activities:
Interest paid, net of amounts capitalized		$ 231	$ 251	$ 253
Income taxes paid to (received from) taxing authorities, net of refunds		24	(51)	73
Noncash investing activities:
Increase (decrease) in asset retirement costs		56	0	80
Asset retirement obligations assumed by buyer		0	0	1,082
Proceeds from tax refunds	$ 89	2	94	90
Increase in capital expenditure accrual		$ 81	$ 95	$ 288

Other Items (Details)

Other Items (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net Interest and Other Financing [Abstract]
Interest income	$ 1	$ 5	$ 25
Interest expense	(257)	(279)	(280)
Realized gain (loss) on derivatives, net	54	12	0
Total interest	(202)	(262)	(255)
Net foreign currency gain	0	0	4
Other	14	6	7
Total other	14	6	11
Net interest and other	$ (188)	$ (256)	$ (244)

Equity Method Investments - Sum

Equity Method Investments - Summary of Equity Method Investments (Details) - USD ($) $ in Millions	Dec. 31, 2021	Sep. 30, 2021	Dec. 31, 2020
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 450		$ 447
EGHoldings
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	56.00%	60.00%
Equity method investments	$ 148		113
Alba Plant LLC
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	52.00%
Equity method investments	$ 154		168
AMPCO
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	45.00%
Equity method investments	$ 148		$ 166

Equity Method Investments - Nar

Equity Method Investments - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Sep. 30, 2021
Schedule of Equity Method Investments [Line Items]
Loss on equity method investments	$ 12
Impairment	0	$ 171	$ 0
Equity method investment, difference between carrying amount and underlying equity	112	140
Accretion of difference between carrying amount and underlying equity	22
Revenue from related parties	30	38	$ 42
Accounts receivable, related parties	23	24
Accounts payable, related parties	$ 20	$ 13
EGHoldings
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	56.00%			60.00%

Equity Method Investments - S_2

Equity Method Investments - Summary of Financial Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Schedule of Equity Method Investments [Line Items]
Revenues and other income	$ 5,467	$ 3,086	$ 5,190
Income from operations	1,308	(1,180)	636
Net income (loss)	946	(1,451)	480
Current assets	1,821	1,612
Current liabilities	1,637	1,213
Consolidated Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Revenues and other income	1,095	586	832
Income from operations	537	16	250
Net income (loss)	440	(3)	187
Current assets	556	389
Noncurrent assets	822	941
Current liabilities	247	235
Noncurrent liabilities	$ 231	$ 170

Stockholders Equity (Details)

Stockholders Equity (Details) - USD ($) shares in Millions, $ in Millions	2 Months Ended	3 Months Ended	12 Months Ended
	Feb. 16, 2022	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Nov. 03, 2021	Nov. 02, 2021
Class of Stock [Line Items]
Shares repurchased (shares)			0
Shares repurchased, value			$ 734	$ 91	$ 362
Stock repurchased for tax obligations for restricted stock awards			10
Share Repurchase Program
Class of Stock [Line Items]
Shares repurchased (shares)		46		9
Shares repurchased, value		$ 724		$ 85
Share repurchase program authorization						$ 2,500	$ 1,100
Remaining share repurchase program authorized amount		$ 1,900	$ 1,900
Share Repurchase Program | Subsequent Event
Class of Stock [Line Items]
Shares repurchased (shares)	258

Commitments and Contingencies (

Commitments and Contingencies (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Guarantor Obligations [Line Items]
Guarantor obligations, current carrying value	$ 4
Contingent royalty liability	134
Contingent capital and expense receivable, noncurrent	24
Asset retirement obligation	316	$ 254	$ 254
Gulf Of Mexico
Guarantor Obligations [Line Items]
Asset retirement obligation	37	$ 7
Accounts Payable
Guarantor Obligations [Line Items]
Contingent royalty liability	122
Other current liabilities
Guarantor Obligations [Line Items]
Contingent royalty liability	12
Performance of Equatorial Guinea LNG Operations, S.A.
Guarantor Obligations [Line Items]
Guarantor obligations, maximum amount	91
Performance of Alba Plant LLC.
Guarantor Obligations [Line Items]
Guarantor obligations, maximum amount	$ 25

Uncategorized Items - mro-20211

Label	Element	Value
Accounting Standards Update [Extensible Enumeration]	us-gaap_AccountingStandardsUpdateExtensibleList	Accounting Standards Update 2016-02 [Member]