Marathon Oil (MRO) 10-Q 3 Nov 22 2022 Q3 Quarterly report Financial data

Cover

Cover - shares	9 Months Ended
	Sep. 30, 2022	Oct. 31, 2022
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2022
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 Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		635,067,840
Document Fiscal Period Focus	Q3
Document Fiscal Year Focus	2022
Amendment Flag	false
Entity Central Index Key	0000101778
Current Fiscal Year End Date	--12-31

Consolidated Statements of Inco

Consolidated Statements of Income (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Revenues and other income:
Revenues from contracts with customers	$ 2,008	$ 1,438	$ 5,937	$ 3,869
Net gain (loss) on commodity derivatives	41	(79)	(129)	(398)
Income from equity method investments	190	86	469	179
Net gain on disposal of assets	2	7	1	8
Other income	6	1	25	9
Total revenues and other income	2,247	1,453	6,303	3,667
Costs and expenses:
Production	193	131	509	378
Shipping, handling and other operating	199	219	575	538
Exploration	73	63	92	109
Depreciation, depletion and amortization	460	522	1,319	1,550
Impairments	2	13	4	60
Taxes other than income	137	88	381	236
General and administrative	79	70	220	227
Total costs and expenses	1,143	1,106	3,100	3,098
Income from operations	1,104	347	3,203	569
Net interest and other	(52)	(57)	(128)	(129)
Other net periodic benefit credits	5	0	14	2
Loss on early extinguishment of debt	0	(102)	0	(121)
Income before income taxes	1,057	188	3,089	321
Provision for income taxes	240	4	2	24
Net income	$ 817	$ 184	$ 3,087	$ 297
Net income per share:
Basic (in dollars per share)	$ 1.22	$ 0.23	$ 4.40	$ 0.38
Diluted (in dollars per share)	$ 1.22	$ 0.23	$ 4.39	$ 0.38
Weighted average common shares outstanding:
Basic (in shares)	670	789	701	791
Diluted (in shares)	672	789	703	791

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Statement of Comprehensive Income [Abstract]
Net income	$ 817	$ 184	$ 3,087	$ 297
Other comprehensive income, net of tax
Change in actuarial gain (loss) and other for postretirement and postemployment plans	(3)	4	(6)	17
Change in derivative hedges unrecognized gain	7	1	23	20
Reclassification of de-designated forward interest rate swaps	0	0	0	(28)
Other	0	0	(1)	0
Other comprehensive income	4	5	16	9
Comprehensive income	$ 821	$ 189	$ 3,103	$ 306

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 1,109	$ 580
Receivables, net	1,358	1,142
Inventories	103	77
Other current assets	66	22
Total current assets	2,636	1,821
Equity method investments	568	450
Property, plant and equipment, net of accumulated depreciation, depletion and amortization of $23,458 and $22,412	14,245	14,499
Deferred tax assets	155	0
Other noncurrent assets	254	224
Total assets	17,858	16,994
Current liabilities:
Accounts payable	1,480	1,110
Payroll and benefits payable	76	74
Accrued taxes	168	157
Other current liabilities	305	260
Long-term debt due within one year	402	36
Total current liabilities	2,431	1,637
Long-term debt	3,579	3,978
Deferred tax liabilities	159	136
Defined benefit postretirement plan obligations	117	137
Asset retirement obligations	283	288
Deferred credits and other liabilities	102	132
Total liabilities	6,671	6,308
Commitments and contingencies (Note 22)
Stockholders’ Equity
Preferred stock – no shares issued or outstanding (no par value, 26 million shares authorized)	0	0
Common stock:
Issued – 937 million shares (par value $1 per share, 1.925 billion shares authorized at September 30, 2022 and December 31, 2021)	937	937
Held in treasury, at cost – 294 million shares and 194 million shares	(7,240)	(4,825)
Additional paid-in capital	7,196	7,221
Retained earnings	10,196	7,271
Accumulated other comprehensive income	98	82
Total stockholders’ equity	11,187	10,686
Total liabilities and stockholders’ equity	$ 17,858	$ 16,994

Consolidated Balance Sheets (_2

Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Property, plant and equipment, accumulated depreciation	$ 23,458	$ 22,412
Preferred stock, shares issued (in shares)	0	0
Preferred stock, shares outstanding (in shares)	0	0
Preferred stock, no par value (in dollars per share)	$ 0	$ 0
Preferred stock, shares authorized (in shares)	26,000,000	26,000,000
Common stock, shares issued (in shares)	937,000,000	937,000,000
Common stock, par value (in dollars per share)	$ 1	$ 1
Common stock, shares authorized (in shares)	1,925,000,000	1,925,000,000
Held in treasury, shares (in shares)	294,000,000	194,000,000

Consolidated Statements of Cash

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Operating activities:
Net income	$ 3,087	$ 297
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	1,319	1,550
Impairments	4	60
Exploratory dry well costs and unproved property impairments	85	101
Net gain on disposal of assets	(1)	(8)
Loss on early extinguishment of debt	0	121
Deferred income taxes	(137)	(32)
Unrealized loss on derivative instruments, net	4	130
Pension and other post retirement benefits, net	(28)	(25)
Stock-based compensation	28	29
Equity method investments, net	(130)	(57)
Changes in:
Current receivables	(221)	(313)
Inventories	(27)	(1)
Current accounts payable and accrued liabilities	300	228
Other current assets and liabilities	(57)	66
All other operating, net	75	(53)
Net cash provided by operating activities	4,301	2,093
Investing activities:
Additions to property, plant and equipment	(1,117)	(772)
Acquisitions, net of cash acquired	2	0
Disposal of assets, net of cash transferred to the buyer	8	29
Equity method investments - return of capital	12	15
All other investing, net	0	0
Net cash used in investing activities	(1,095)	(728)
Financing activities:
Debt repayment	(35)	(1,400)
Debt extinguishment costs	0	(117)
Shares repurchased under buyback programs	(2,474)	0
Dividends paid	(162)	(94)
Purchases of shares for tax withholding obligations	(21)	(10)
All other financing, net	15	(1)
Net cash used in financing activities	(2,677)	(1,622)
Net increase (decrease) in cash and cash equivalents	529	(257)
Cash and cash equivalents at beginning of period	580	742
Cash and cash equivalents at end of period	$ 1,109	$ 485

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity (Unaudited) - USD ($) $ in Millions	Total	Preferred Stock	Common Stock	Treasury Stock	Additional Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Income
Beginning balance at Dec. 31, 2020	$ 10,561	$ 0	$ 937	$ (4,089)	$ 7,174	$ 6,466	$ 73
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation	(3)			(24)	21
Net income	97					97
Other comprehensive income (loss)	39						39
Dividends paid	(23)					(23)
Ending balance at Mar. 31, 2021	10,671	0	937	(4,113)	7,195	6,540	112
Beginning balance at Dec. 31, 2020	10,561	0	937	(4,089)	7,174	6,466	73
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	297
Other comprehensive income (loss)	9
Ending balance at Sep. 30, 2021	10,796	0	937	(4,105)	7,213	6,669	82
Beginning balance at Mar. 31, 2021	10,671	0	937	(4,113)	7,195	6,540	112
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation	14			8	6
Net income	16					16
Other comprehensive income (loss)	(35)						(35)
Dividends paid	(32)					(32)
Ending balance at Jun. 30, 2021	10,634	0	937	(4,105)	7,201	6,524	77
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation	12				12
Net income	184					184
Other comprehensive income (loss)	5						5
Dividends paid	(39)					(39)
Ending balance at Sep. 30, 2021	10,796	0	937	(4,105)	7,213	6,669	82
Beginning balance at Dec. 31, 2021	10,686	0	937	(4,825)	7,221	7,271	82
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares repurchased under buyback programs	(592)			(592)
Stock-based compensation	12			55	(43)
Net income	1,304					1,304
Other comprehensive income (loss)	8						8
Dividends paid	(52)					(52)
Ending balance at Mar. 31, 2022	11,366	0	937	(5,362)	7,178	8,523	90
Beginning balance at Dec. 31, 2021	10,686	0	937	(4,825)	7,221	7,271	82
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	3,087
Other comprehensive income (loss)	16
Ending balance at Sep. 30, 2022	11,187	0	937	(7,240)	7,196	10,196	98
Beginning balance at Mar. 31, 2022	11,366	0	937	(5,362)	7,178	8,523	90
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares repurchased under buyback programs	(760)			(760)
Stock-based compensation	12			4	8
Net income	966					966
Other comprehensive income (loss)	4						4
Dividends paid	(56)					(56)
Ending balance at Jun. 30, 2022	11,532	0	937	(6,118)	7,186	9,433	94
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares repurchased under buyback programs	(1,122)			(1,122)
Stock-based compensation	10				10
Net income	817					817
Other comprehensive income (loss)	4						4
Dividends paid	(54)					(54)
Ending balance at Sep. 30, 2022	$ 11,187	$ 0	$ 937	$ (7,240)	$ 7,196	$ 10,196	$ 98

Consolidated Statements of St_2

Consolidated Statements of Stockholders' Equity (Unaudited) (Parenthetical) - $ / shares	3 Months Ended						9 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Statement of Stockholders' Equity [Abstract]
Dividends paid (in dollars per share)	$ 0.08	$ 0.08	$ 0.07	$ 0.05	$ 0.04	$ 0.03	$ 0.23	$ 0.12

Basis of Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	Basis of Presentation These consolidated financial statements are unaudited; however, in the opinion of management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal recurring nature unless disclosed otherwise. These consolidated financial statements, including notes, have been prepared in accordance with the applicable rules of the SEC and do not include all of the information and disclosures required by U.S. GAAP for complete financial statements. These interim financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our 2021 Annual Report on Form 10-K. The results of operations for the third quarter and first nine months of 2022 are not necessarily indicative of the results to be expected for the full year.

Accounting Standards

Accounting Standards	9 Months Ended
	Sep. 30, 2022
Accounting Policies [Abstract]
Accounting Standards	Accounting Standards Accounting Standards Updates Adopted No accounting standards were adopted in the third quarter or first nine months of 2022 that had a material impact on our consolidated financial statements. Accounting Standards Updates Not Yet Adopted In March 2020, the FASB issued ASU 2020-04, which provides optional expedients and exceptions for applying U.S. GAAP to contracts, hedging relationships and other transactions that reference London Interbank Offered Rate (LIBOR) or another reference rate expected to be discontinued. The guidance is effective March 12, 2020 and can be applied prospectively through December 31, 2022. Upon adoption, we do not believe it will have a material impact on our consolidated results of operations, financial position and cash flows.

Income and Dividends per Common

Income and Dividends per Common Share	9 Months Ended
	Sep. 30, 2022
Earnings Per Share [Abstract]
Income and Dividends per Common Share	Income and Dividends per Common Share Basic income per share is based on the weighted average number of common shares outstanding. Diluted income per share assumes exercise of stock options in all periods, provided the effect is not antidilutive. The per share calculations below exclude 1 million and 2 million of stock options for the three and nine months ended September 30, 2022, respectively, and 4 million of stock options for each of the three and nine months ended September 30, 2021, that were antidilutive. Three Months Ended September 30, Nine Months Ended September 30, (In millions, except per share data) 2022 2021 2022 2021 Net income $ 817 $ 184 $ 3,087 $ 297 Weighted average common shares outstanding 670 789 701 791 Effect of dilutive securities 2 — 2 — Weighted average common shares, diluted 672 789 703 791 Net income per share: Basic $ 1.22 $ 0.23 $ 4.40 $ 0.38 Diluted $ 1.22 $ 0.23 $ 4.39 $ 0.38 Dividends per share $ 0.08 $ 0.05 $ 0.23 $ 0.12

Revenues

Revenues	9 Months Ended
	Sep. 30, 2022
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 Equatorial Guinea. As of September 30, 2022 and December 31, 2021, receivables from contracts with customers, included in receivables, net were $1.1 billion and $961 million, respectively. The following tables present our revenues from contracts with customers disaggregated by product type and geographic areas for the three and nine months ended September 30: United States Three Months Ended September 30, 2022 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 523 $ 648 $ 104 $ 114 $ 39 $ 1,428 Natural gas liquids 49 82 63 16 6 216 Natural gas 56 67 105 22 11 261 Other 3 — — — 19 22 Revenues from contracts with customers $ 631 $ 797 $ 272 $ 152 $ 75 $ 1,927 Three Months Ended September 30, 2021 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 391 $ 425 $ 74 $ 75 $ 19 $ 984 Natural gas liquids 50 63 53 12 5 183 Natural gas 38 29 62 12 3 144 Other 2 — — — 62 64 Revenues from contracts with customers $ 481 $ 517 $ 189 $ 99 $ 89 $ 1,375 Nine Months Ended September 30, 2022 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,526 $ 2,049 $ 341 $ 302 $ 124 $ 4,342 Natural gas liquids 148 263 191 46 23 671 Natural gas 145 156 256 55 28 640 Other 6 — — — 71 77 Revenues from contracts with customers $ 1,825 $ 2,468 $ 788 $ 403 $ 246 $ 5,730 Nine Months Ended September 30, 2021 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,003 $ 1,208 $ 206 $ 229 $ 65 $ 2,711 Natural gas liquids 109 152 127 32 10 430 Natural gas 114 71 212 42 11 450 Other 6 — — — 99 105 Revenues from contracts with customers $ 1,232 $ 1,431 $ 545 $ 303 $ 185 $ 3,696 International (E.G.) Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2022 2021 2022 2021 Crude oil and condensate $ 75 $ 56 $ 186 $ 151 Natural gas liquids 1 — 2 2 Natural gas 5 6 17 18 Other — 1 2 2 Revenues from contracts with customers $ 81 $ 63 $ 207 $ 173

Segment Information

Segment Information	9 Months Ended
	Sep. 30, 2022
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 Equatorial Guinea (“E.G.”) Segment income represents income that 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, changes in our valuation allowance, unrealized gains or losses on commodity and 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. Three Months Ended September 30, 2022 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 1,927 $ 81 $ — $ 2,008 Net gain (loss) on commodity derivatives (26) — 67 (b) 41 Income from equity method investments — 190 — 190 Net gain on disposal of assets — — 2 2 Other income 4 1 1 6 Less costs and expenses: Production 173 20 — 193 Shipping, handling and other operating 171 5 23 199 Exploration 11 — 62 (c) 73 Depreciation, depletion and amortization 441 14 5 460 Impairments — — 2 2 Taxes other than income 136 — 1 137 General and administrative 37 4 38 79 Net interest and other — — 52 52 Other net periodic benefit costs — — (5) (5) Income tax provision (benefit) 213 48 (21) 240 Segment income (loss) $ 723 $ 181 $ (87) $ 817 Total assets $ 15,487 $ 1,294 $ 1,077 $ 17,858 Capital expenditures (a) $ 406 $ 1 $ 6 $ 413 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 13 ). (c) Includes dry well costs and unproved property impairments of $48 million for Louisiana exploration leases and $14 million for Permian exploration leases (See Note 9 and Note 10 ). Three Months Ended September 30, 2021 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 1,375 $ 63 $ — $ 1,438 Net gain (loss) on commodity derivatives (106) — 27 (b) (79) Income from equity method investments — 86 — 86 Net gain on disposal of assets — — 7 7 Other income — — 1 1 Less costs and expenses: Production 119 12 — 131 Shipping, handling and other operating 209 7 3 219 Exploration 15 — 48 (c) 63 Depreciation, depletion and amortization 499 17 6 522 Impairments — — 13 (d) 13 Taxes other than income 88 — — 88 General and administrative 29 3 38 70 Net interest and other — — 57 (e) 57 Other net periodic benefit costs — — — — Loss on early extinguishment of debt — — 102 (f) 102 Income tax provision (benefit) 5 17 (18) 4 Segment income (loss) $ 305 $ 93 $ (214) $ 184 Total assets $ 15,528 $ 1,071 $ 562 $ 17,161 Capital expenditures (a) $ 303 $ 2 $ 3 $ 308 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 13 ). (c) Includes unproved property impairments of $20 million for Louisiana exploration leases and$16 million related to the disposition of a Permian lease. Also includes $12 million of dry well costs associated with drilled and uncompleted wells, primarily in Permian. (d) Includes impairments of $5 million for proved properties in Permian (See Note 10 ) and $8 million associated with decommissioning costs for non-producing long-lived assets in GOM (See Note 1 0 and Note 11 ). (e) Includes a $5 million gain on 2022 interest rate swaps and a $3 million gain on 2025 interest rate swaps (See Note 13 ). (f) Represents costs related to a make-whole provision premium and the write off of issuance costs related to the redemption of the 2025 Notes in September 2021 (See Note 15 ). Nine Months Ended September 30, 2022 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 5,730 $ 207 $ — $ 5,937 Net loss on commodity derivatives (125) — (4) (b) (129) Income from equity method investments — 469 — 469 Net gain on disposal of assets — — 1 1 Other income 10 5 10 25 Less costs and expenses: Production 464 45 — 509 Shipping, handling and other operating 508 15 52 575 Exploration 30 — 62 (c) 92 Depreciation, depletion and amortization 1,260 45 14 1,319 Impairments — — 4 4 Taxes other than income 374 — 7 381 General and administrative 94 10 116 220 Net interest and other — — 128 (d) 128 Other net periodic benefit costs — — (14) (14) Income tax provision (benefit) 655 110 (763) (e) 2 Segment income $ 2,230 $ 456 $ 401 $ 3,087 Total assets $ 15,487 $ 1,294 $ 1,077 $ 17,858 Capital expenditures (a) $ 1,124 $ 1 $ 11 $ 1,136 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 1 3 ). (c) Includes dry well costs and unproved property impairments of $48 million for Louisiana exploration leases and $14 million for Permian exploration leases (See Note 9 and Note 10 ). (d) Includes a $17 million gain on 2025 interest rate swaps (See Note 13 ). (e) Includes a $685 million benefit related to the partial release of our valuation allowance (See Note 6 ). Nine Months Ended September 30, 2021 (In millions) U.S. Int’l Not Allocated to Segments Total Revenue from contracts with customers $ 3,696 $ 173 $ — $ 3,869 Net loss on commodity derivatives (268) — (130) (b) (398) Income from equity method investments — 179 — 179 Net gain on disposal of assets — — 8 8 Other income 4 3 2 9 Less costs and expenses: Production 343 35 — 378 Shipping, handling and other operating 506 13 19 538 Exploration 54 — 55 (c) 109 Depreciation, depletion and amortization 1,477 54 19 1,550 Impairments — — 60 (d) 60 Taxes other than income 238 — (2) 236 General and administrative 79 9 139 (e) 227 Net interest and other — — 129 (f) 129 Other net periodic benefit credit — — (2) (2) Loss on early extinguishment of debt — — 121 (g) 121 Income tax provision (benefit) 11 33 (20) 24 Segment income (loss) $ 724 $ 211 $ (638) $ 297 Total assets $ 15,528 $ 1,071 $ 562 $ 17,161 Capital expenditures (a) $ 770 $ 4 $ 7 $ 781 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 1 3 ). (c) 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 $12 million of dry well costs associated with drilled and uncompleted wells, primarily in Permian. (d) Includes impairments of $24 million for central facilities in Eagle Ford (See Note 10 ), $5 million for proved properties in Permian (See Note 10 ), and $30 million associated with decommissioning costs for non-producing long-lived assets in GOM (See Note 10 and Note 11 ). (e) Includes $13 million associated with the termination of an aircraft lease agreement and $12 million arising from severance expenses associated with a workforce reduction. (f) Includes a $24 million gain on 2022 interest rate swaps and a $34 million gain on 2025 interest rate swaps (See Note 13 ). (g) 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 15

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes Effective Tax Rate 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 . For the three and nine months ended September 30, 2022 and 2021, our effective income tax rates were as follows: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Effective income tax rate 23 % 2 % — % 7 % • 2022 — Our effective income tax rate was different from our U.S. statutory tax rate of 21% for the nine months ended September 30, 2022, due to the first quarter 2022 release of the valuation allowance on certain U.S. and state deferred tax assets resulting in a non-cash deferred tax benefit of $685 million. As we previously disclosed in our 2021 Form 10-K, we maintained a full valuation allowance on our net federal deferred tax assets and would continue to do so until there exists sufficient positive evidence to support a reversal of the allowance. In the first quarter, as a result of significant increases in commodity prices, corresponding increases in projections of our future taxable income, and the absence of objective negative evidence such as a cumulative loss in recent years, we determined we have sufficient positive evidence to release a majority of the federal valuation allowance. We retained a partial valuation allowance on certain U.S. deferred tax assets primarily as a result of volatility in commodity prices impacting assessed likelihood of future realizability. • 2021 — Our effective income tax rate was different from our U.S. statutory tax rate of 21% for the three and nine months ended September 30, 2021, as a result of the valuation allowance on net federal deferred tax assets in the U.S. which was in place at the time. In addition, the income mix of our U.S. and E.G. operations, including the income mix within E.G. between equity method investees and subsidiaries, contributed to the difference.

Credit Losses

Credit Losses	9 Months Ended
	Sep. 30, 2022
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, reasonable and supportable forecasts of future economic conditions and other data as deemed appropriate. Changes in the allowance for credit losses were as follows: (In millions) September 30, 2022 December 31, 2021 Beginning balance as of January 1 $ 15 $ 22 Current period provision (2) 3 Current period write offs (1) (5) Recoveries of amounts previously reserved — (5) Ending balance $ 12 $ 15

Inventories

Inventories	9 Months Ended
	Sep. 30, 2022
Inventory Disclosure [Abstract]
Inventories	InventoriesCrude oil and natural gas liquids 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 obsolescence or impairment when market conditions indicate. (In millions) September 30, 2022 December 31, 2021 Crude oil and natural gas liquids $ 14 $ 8 Supplies and other items 89 69 Inventories $ 103 $ 77

Property, Plant and Equipment

Property, Plant and Equipment	9 Months Ended
	Sep. 30, 2022
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment (In millions) September 30, 2022 December 31, 2021 United States $ 13,889 $ 14,097 International 302 347 Corporate 54 55 Net property, plant and equipment $ 14,245 $ 14,499 As of September 30, 2022 and December 31, 2021, we had $20 million and $80 million , respectively, of e xploratory 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 majority of the suspended wells require completion activities and installation of infrastructure in order to classify the reserves as proved. The decrease during the nine months ended September 30, 2022 included a $46 million reduction in suspended well costs as we resumed drilling or completion activities and brought previously suspended wells to sales. During the third quarter of 2022, we also recorded $14 million of dry well costs associated with drilled and uncompleted exploratory wells, primarily in Louisiana Austin Chalk. See Note 10

Impairments

Impairments	9 Months Ended
	Sep. 30, 2022
Impairment Expense [Abstract]
Impairments	Impairments The following table summarizes impairment charges of proved properties and their corresponding fair values. Three Months Ended September 30, 2022 2021 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ — $ — $ — $ 5 Asset retirement costs of long-lived assets $ — $ 2 $ — $ 8 Nine Months Ended September 30, 2022 2021 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ — $ — $ — $ 30 Asset retirement costs of long-lived assets $ — $ 4 $ — $ 30 • 2022 — There were no significant impairments of proved property in 2022. During the third quarter of 2022, we recognized impairments totaling $48 million of unproved property leases and dry well costs in Louisiana Austin Chalk. The impairments resulted from a combination of factors including timing of lease expiration dates, our assessment of risk and resource, and the decision not to develop the acreage. We also recognized impairments of $14 million for unproved property leases in Permian as a result of an acreage exchange. The combined effects of these impairments were recorded as exploration expense. • 2021 — During the third quarter of 2021, we recognized unproved property impairments of $20 million for Louisiana exploration leases and $16 million related to the disposition of a Permian lease. In addition, we also recognized $12 million of dry well costs associated with drilled and uncompleted wells, primarily in Permian. The combined effects of these impairments were recorded as exploration expense. For proved property, 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. In the second quarter of 2021, we recorded an impairment expense of $24 million associated with the decommissioning of two central facilities located in Eagle Ford. During the nine months ended September 30, 2021, we 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. See Note 11

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2022
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: September 30, (In millions) 2022 2021 Beginning balance as of January 1 $ 316 $ 254 Incurred liabilities, including acquisitions 10 9 Settled liabilities, including dispositions (8) (3) Accretion expense (included in depreciation, depletion and amortization) 11 9 Revisions of estimates (1) 40 Ending balance as of September 30, total $ 328 $ 309 Ending balance as of September 30, short-term $ 45 $ 23 • 2021 — In the first nine months of 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 September 30, 2021, $14 million of these Gulf of Mexico related revisions of estimates were classified as short-term. See Note 22 for further information. Of the $37 million, approximately $30 million was recognized as impairment expense during the nine months ended September 30, 2021. See Note 10

Leases

Leases	9 Months Ended
	Sep. 30, 2022
Leases [Abstract]
Leases	Leases Lessee Balance sheet information related to right-of-use (“ROU”) assets and lease liabilities was as follows: (In millions) Balance Sheet Location: September 30, 2022 December 31, 2021 ROU assets: Operating leases Other noncurrent assets $ 95 $ 59 Finance leases Other noncurrent assets 26 28 Total ROU assets $ 121 $ 87 Lease liabilities: Current liabilities Operating leases Other current liabilities $ 65 $ 40 Finance leases Other current liabilities 6 6 Noncurrent liabilities Operating leases Deferred credits and other liabilities 35 23 Finance leases Deferred credits and other liabilities 19 24 Total lease liabilities $ 125 $ 93 Operating Leases We enter into various lease agreements to support our operations including drilling rigs, well fracturing equipment, compressors, buildings, 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. 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. The initial lease term is five years and commenced in late September 2021 after the new Houston office was ready for occupancy. In March 2022, we made our first cash lease payment. For the nine months ended September 30, 2022, our cash lease payments were approximately $6 million. At the end of the initial lease term, we can negotiate to extend the lease term for an additional five years, subject to the approval of the participants; purchase the property subject to certain terms and conditions; or remarket the property to an unrelated third party. The lease contains a residual value guarantee of 100% of the total acquisition and construction costs. Lessor Our wholly owned subsidiary, Marathon E.G. Production Limited, is a lessor for residential housing in E.G., which is occupied by EGHoldings, a related party equity method investee – see Note 21 . 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 $ 2 2023 6 2024 6 2025 6 2026 6 Thereafter 48 Total undiscounted cash flows $ 74
Leases	Leases Lessee Balance sheet information related to right-of-use (“ROU”) assets and lease liabilities was as follows: (In millions) Balance Sheet Location: September 30, 2022 December 31, 2021 ROU assets: Operating leases Other noncurrent assets $ 95 $ 59 Finance leases Other noncurrent assets 26 28 Total ROU assets $ 121 $ 87 Lease liabilities: Current liabilities Operating leases Other current liabilities $ 65 $ 40 Finance leases Other current liabilities 6 6 Noncurrent liabilities Operating leases Deferred credits and other liabilities 35 23 Finance leases Deferred credits and other liabilities 19 24 Total lease liabilities $ 125 $ 93 Operating Leases We enter into various lease agreements to support our operations including drilling rigs, well fracturing equipment, compressors, buildings, 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. 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. The initial lease term is five years and commenced in late September 2021 after the new Houston office was ready for occupancy. In March 2022, we made our first cash lease payment. For the nine months ended September 30, 2022, our cash lease payments were approximately $6 million. At the end of the initial lease term, we can negotiate to extend the lease term for an additional five years, subject to the approval of the participants; purchase the property subject to certain terms and conditions; or remarket the property to an unrelated third party. The lease contains a residual value guarantee of 100% of the total acquisition and construction costs. Lessor Our wholly owned subsidiary, Marathon E.G. Production Limited, is a lessor for residential housing in E.G., which is occupied by EGHoldings, a related party equity method investee – see Note 21 . 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 $ 2 2023 6 2024 6 2025 6 2026 6 Thereafter 48 Total undiscounted cash flows $ 74
Leases	Leases Lessee Balance sheet information related to right-of-use (“ROU”) assets and lease liabilities was as follows: (In millions) Balance Sheet Location: September 30, 2022 December 31, 2021 ROU assets: Operating leases Other noncurrent assets $ 95 $ 59 Finance leases Other noncurrent assets 26 28 Total ROU assets $ 121 $ 87 Lease liabilities: Current liabilities Operating leases Other current liabilities $ 65 $ 40 Finance leases Other current liabilities 6 6 Noncurrent liabilities Operating leases Deferred credits and other liabilities 35 23 Finance leases Deferred credits and other liabilities 19 24 Total lease liabilities $ 125 $ 93 Operating Leases We enter into various lease agreements to support our operations including drilling rigs, well fracturing equipment, compressors, buildings, 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. 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. The initial lease term is five years and commenced in late September 2021 after the new Houston office was ready for occupancy. In March 2022, we made our first cash lease payment. For the nine months ended September 30, 2022, our cash lease payments were approximately $6 million. At the end of the initial lease term, we can negotiate to extend the lease term for an additional five years, subject to the approval of the participants; purchase the property subject to certain terms and conditions; or remarket the property to an unrelated third party. The lease contains a residual value guarantee of 100% of the total acquisition and construction costs. Lessor Our wholly owned subsidiary, Marathon E.G. Production Limited, is a lessor for residential housing in E.G., which is occupied by EGHoldings, a related party equity method investee – see Note 21 . 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 $ 2 2023 6 2024 6 2025 6 2026 6 Thereafter 48 Total undiscounted cash flows $ 74

Derivatives

Derivatives	9 Months Ended
	Sep. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives For further information regarding the fair value measurement of derivative instruments, see Note 14 . All of our commodity derivatives are subject to enforceable master netting arrangements or similar agreements under which we report net amounts. The following tables present the gross fair values of derivative instruments and the reported net amounts along with where they appear on the consolidated balance sheets. September 30, 2022 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ — $ — $ — Other current assets Commodity 1 12 (11) Other current liabilities Total Not Designated as Hedges $ 1 $ 12 $ (11) Cash Flow Hedges Interest Rate $ 8 $ — $ 8 Other current assets Interest Rate 18 — 18 Other noncurrent assets Total Designated Hedges $ 26 $ — $ 26 Total $ 27 $ 12 $ 15 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 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 U.S. sales through the first quarter of 2023. These derivatives consist of three-way collars, two-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. The following table sets forth outstanding derivative contracts as of September 30, 2022, and the weighted average prices for those contracts: 2022 2023 Fourth Quarter First Quarter Crude Oil NYMEX WTI Three-Way Collars Volume (Bbls/day) 30,000 — Weighted average price per Bbl: Ceiling $ 97.52 $ — Floor $ 56.67 $ — Sold put $ 46.67 $ — NYMEX Roll Basis Swaps Volume (Bbls/day) 60,000 — Weighted average price per Bbl $ 0.67 $ — Natural Gas Henry Hub (“HH”) Two-Way Collars Volume (MMBtu/day) 50,000 50,000 Weighted average price per MMBtu: Ceiling $ 19.28 $ 19.28 Floor $ 5.00 $ 5.00 Henry Hub Three-Way Collars Volume (MMBtu/day) 100,000 — Weighted average price per MMBtu: Ceiling $ 7.13 $ — Floor $ 3.88 $ — Sold Put $ 2.88 $ — 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. Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2022 2021 2022 2021 Unrealized gain (loss) on derivative instruments, net $ 67 $ 27 $ (4) $ (130) Realized gain (loss) on derivative instruments, net (a) $ (26) $ (106) $ (125) $ (268) (a) During the third quarter and first nine months of 2022, net cash paid for settled derivative positions was $56 million and $145 million, respectively. During the third quarter and first nine months of 2021, net cash paid for settled derivative positions was $108 million and $203 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 related to 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 can be tied to 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 de-designated forward starting interest rate swaps 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. We recorded a $5 million mark-to-market gain and a $24 million mark-to-market gain within net interest to reflect the change in value of these interest rate swaps during the three and nine months ended September 30, 2021, respectively. 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”). In September 2021, we fully redeemed these 2025 Notes. We recorded a $3 million mark-to-market gain and a $34 million mark-to-market gain within net interest to reflect the change in value of these interest rate swaps during the three and nine months ended September 30, 2021. In March 2022, we closed these positions and settled the interest rate swaps for proceeds of $44 million. During the nine months ended September 30, 2022, we recorded a cumulative $17 million gain within net interest for these swaps. 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. These interest rate swap contracts began to settle in January 2022. On June 10, 2022, we closed the $25 million de-designated hedges, which resulted in cash proceeds of approximately $2 million. As of September 30, 2022, the remaining open interest rate swaps for the Houston office (with a notional amount of $295 million) are still classified as cash flow hedges. The following table presents, by maturity date, information about our de-designated forward starting interest rate swap agreements. These positions were fully liquidated as of September 30, 2022. September 30, 2022 December 31, 2021 Maturity Date Aggregate Notional Amount (in millions) Weighted Average, LIBOR Aggregate Notional Amount (in millions) Weighted Average, LIBOR June 1, 2025 $ — — % $ 350 0.95 % September 9, 2026 $ — — % $ 25 1.45 % 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 Houston office. 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 (see discussion in preceding section). The notional amount of open interest rate swaps for the Houston office is $295 million. The Houston office lease commenced in September 2021, however our first cash lease payment for February 2022 rent was paid in March. The first settlement date for the interest rate swaps was in January 2022. The last swap will mature in September 2026. During the third quarter and first nine months of 2022, net cash received/paid for the settled interest rate swap positions was immaterial. As of September 30, 2022, we expect to reclassify $8 million from accumulated other comprehensive income into the income statement over the next twelve months. See Note 12 for further details regarding the lease of the Houston office. The following table presents, by maturity date, information about our interest rate swap agreements, including the fixed weighted average LIBOR. September 30, 2022 December 31, 2021 Maturity Date Aggregate Notional Amount (in millions) Weighted Average, LIBOR Aggregate Notional Amount (in millions) Weighted Average, LIBOR September 9, 2026 $ 295 1.52 % $ 295 1.52 %

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2022
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 September 30, 2022 and December 31, 2021 by hierarchy level. September 30, 2022 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Interest rate - designated as cash flow hedges $ — $ 26 $ — $ 26 Derivative instruments, assets $ — $ 26 $ — $ 26 Derivative instruments, liabilities Commodity (a) $ (2) $ (9) $ — $ (11) Derivative instruments, liabilities $ (2) $ (9) $ — $ (11) Total $ (2) $ 17 $ — $ 15 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 (a) Commodity derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 13 . Commodity derivatives include three-way collars, two-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 commodity 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 13 for detail on the forward starting interest rate swaps. Fair Values – Nonrecurring See Note 10 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 insignificant 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 September 30, 2022 and December 31, 2021. September 30, 2022 December 31, 2021 (In millions) Fair Value Carrying Amount Fair Value Carrying Amount Financial assets Current assets $ — $ — $ 11 $ 10 Other noncurrent assets 10 28 12 27 Total financial assets $ 10 $ 28 $ 23 $ 37 Financial liabilities Current liabilities $ 107 $ 171 $ 99 $ 136 Long-term debt, including current portion (a) 3,793 3,997 4,705 4,033 Deferred credits and other liabilities 16 15 46 46 Total financial liabilities $ 3,916 $ 4,183 $ 4,850 $ 4,215 (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	9 Months Ended
	Sep. 30, 2022
Debt Disclosure [Abstract]
Debt	Debt Revolving Credit Facility As of September 30, 2022, we had no borrowings against our $2.5 billion unsecured revolving credit facility (“Credit Facility”). On July 28, 2022, we executed the seventh amendment to our Credit Facility. The primary changes to the Credit Facility effected by this amendment were to (i) extend the maturity date of the Credit Facility by three years to July 28, 2027, (ii) decrease the size of the Credit Facility from $3.1 billion to $2.5 billion, (iii) replace the LIBOR interest rate benchmark with the secured overnight financing rate (“SOFR”) and (iv) implement certain revisions to the Pricing Schedule. 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 September 30, 2022, we were in compliance with this covenant with a ratio of 20%. Debt Redemption In May 2022, we redeemed the $32 million 9.375% Senior Notes on the maturity date. In September 2021, we redeemed our outstanding $900 million 3.85% Senior Notes due 2025 (“2025 Notes”). We incurred $102 million in costs related to the make-whole provision premium and the write off of unamortized discount and issuance costs. In April 2021, we redeemed our outstanding $500 million 2.8% Senior Notes due 2022 (“2022 Notes”). We incurred $19 million in costs related to a make-whole provision premium and the write off of unamortized discount and issuance costs. Long-term debt At September 30, 2022, we had $4.0 billion of total long-term debt outstanding, which includes $402 million of long-term debt due within one year. Included in long-term debt due within one year is $200 million in 2.0% Bonds which feature a mandatory put on April 1, 2023. Refer to our 2021 Annual Report on Form 10-K for a listing of our long-term debt maturities.

Stockholders' Equity

Stockholders' Equity	9 Months Ended
	Sep. 30, 2022
Equity [Abstract]
Stockholders' Equity	Stockholders’ Equity During the first nine months of 2022, we repurchased approximately $2.5 billion of shares of our common stock pursuant to the share repurchase program. The total remaining share repurchase authorization was approximately $926 million at September 30, 2022. Purchases under the program are made at our discretion and may be in either open market transactions, including block purchases, or in privately negotiated transactions using cash on hand, cash generated from operations or proceeds from potential asset sales. This program may be changed based upon our financial condition or changes in market conditions and is subject to termination prior to completion. Additionally, during the first nine months of 2022 we repurchased $21 million of shares related to our tax withholding obligation associated with the vesting of employee restricted stock awards and restricted stock units; these repurchases do not impact our share repurchase program authorization. Subsequent to the quarter, we repurchased approximately $230 million of shares of our common stock through November 2, 2022. Effective November 2, 2022, our Board of Directors increased our remaining share repurchase program authorization to $2.5 billion.

Incentive Based Compensation

Incentive Based Compensation	9 Months Ended
	Sep. 30, 2022
Share-Based Payment Arrangement [Abstract]
Incentive Based Compensation	Incentive Based Compensation Stock options, restricted stock and restricted stock units The following table presents a summary of activity for the first nine months of 2022: Stock Options Restricted Stock & Units Number of Shares Weighted Average Exercise Price Number of Shares & Units Weighted Average Grant Date Fair Value Outstanding at December 31, 2021 4,274,304 $ 22.13 5,888,242 $ 10.98 Granted — $ — 1,719,757 $ 22.83 Exercised/Vested (1,842,093) $ 14.41 (2,796,967) $ 12.05 Canceled (414,952) $ 33.55 (187,859) $ 14.14 Outstanding at September 30, 2022 2,017,259 $ 26.82 4,623,173 $ 14.62 Stock-based performance unit awards During the first nine months of 2022, we granted 167,043 stock-based performance units to eligible officers, which are settled in shares. The grant date fair value per unit was $34.07. During the first nine months of 2022, we also granted 167,043 stock-based performance units to eligible officers, which are settled in cash. At the grant date for these performance units, each unit represents the value of one share of our common stock. The fair value of each cash-settled performance unit was $23.37 as of September 30, 2022.

Defined Benefit Postretirement

Defined Benefit Postretirement Plans	9 Months Ended
	Sep. 30, 2022
Retirement Benefits [Abstract]
Defined Benefit Postretirement Plans	Defined Benefit Postretirement Plans The following summarizes the components of net periodic benefit costs (credits): Three Months Ended September 30, Pension Benefits Other Benefits (In millions) 2022 2021 2022 2021 Service cost $ 4 $ 4 $ — $ — Interest cost 1 2 1 — Expected return on plan assets (2) (2) — — Amortization: – prior service credit (1) (1) (4) (4) – actuarial loss — 1 — 1 Net settlement loss (a) — 3 — — Net periodic benefit costs (credits) (b) $ 2 $ 7 $ (3) $ (3) Nine Months Ended September 30, Pension Benefits Other Benefits (In millions) 2022 2021 2022 2021 Service cost $ 11 $ 12 $ — $ — Interest cost 5 6 2 1 Expected return on plan assets (7) (6) — — Amortization: – prior service credit (4) (4) (12) (12) – actuarial loss 1 4 1 2 Net settlement loss (a) — 8 — — Net periodic benefit costs (credits) (b) $ 6 $ 20 $ (9) $ (9) (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 cost for that year. (b) Net periodic benefit costs (credits) reflects a calculated market-related value of plan assets which recognizes changes in fair value over three years. During the first nine months of 2022, we made contributions of $17 million to our funded pension plan. We also made a payment of $7 million related to our other postretirement benefit plans. We expect to contribute an additional $4 million in contributions to our funded pension plan this year.

Reclassifications Out of Accumu

Reclassifications Out of Accumulated Other Comprehensive Income (Loss)	9 Months Ended
	Sep. 30, 2022
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): Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2022 2021 2022 2021 Income Statement Line Postretirement and postemployment plans Amortization of prior service credit $ 5 $ 5 $ 16 $ 16 Other net periodic benefit costs Amortization of actuarial loss — (2) (2) (6) Other net periodic benefit costs Net settlement loss — (3) — (8) Other net periodic benefit costs Interest rate swaps Reclassification of de-designated forward interest rate swaps — — — (28) Net interest and other (1) — (3) — Provision for income taxes Total reclassifications of (income) expense, net of tax (a) $ 4 $ — $ 11 $ (26) Net income (loss)

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2022
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Nine Months Ended September 30, (In millions) 2022 2021 Included in operating activities: Interest paid $ 153 $ 185 Income taxes paid, net of refunds (a) $ 128 $ 8 Noncash investing activities: Increase in asset retirement costs $ 9 $ 49 (a) The nine months ended September 30, 2021 includes $1 million related to tax refunds.

Equity Method Investments

Equity Method Investments	9 Months Ended
	Sep. 30, 2022
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Equity Method Investments During the periods ended September 30, 2022 and December 31, 2021 our equity method investees were considered related parties. Our investment in our equity method investees are summarized in the following table: (In millions) Ownership as of September 30, 2022 September 30, 2022 December 31, 2021 EGHoldings (a) 56% $ 293 $ 148 Alba Plant LLC (b) 52% 142 154 AMPCO (c) 45% 133 148 Total $ 568 $ 450 (a) EGHoldings is engaged in LNG production activity. (b) Alba Plant LLC processes LPG. (c) AMPCO is engaged in methanol production activity. Summarized, 100% combined financial information for equity method investees is as follows: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2022 2021 2022 2021 Income data: Revenues and other income $ 499 $ 325 $ 1,332 $ 806 Income from operations 358 188 893 395 Net income $ 335 $ 155 $ 811 $ 312 Revenues from related parties were $7 million and $22 million for the three and nine months ended September 30, 2022, respectively, $8 million and $24 million for the three and nine months ended September 30, 2021, respectively, with the majority related to EGHoldings in all periods. Cash received from equity investees is classified as dividends or return of capital on the Consolidated Statements of Cash Flows. Dividends from equity method investees are reflected in the Operating activities section in Equity Method Investments, net while return of capital is reflected in the Investing activities section. Dividends and return of capital received by us totaled $150 million and $350 million for the three and nine months ended September 30, 2022, respectively, and $56 million and $137 million for the three and nine months ended September 30, 2021, respectively.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2022
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies 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 September 30, 2022, we have a $153 million current liability in suspended royalty and working interest revenue, including interest, of which $138 million was included within accounts payable and $15 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 $26 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. 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, we are exposed to the risk that owners and/or operators of assets purchased from us become unable 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. Marathon Oil has been named in various lawsuits alleging royalty underpayments in our domestic operations. We intend to vigorously defend ourselves against such claims. For instance, Marathon Oil was named in a lawsuit alleging improper royalty deductions in certain of our Oklahoma operations, and after plaintiffs lost their attempt to certify a class action, a settlement in principle was reached, subject to court approval. We have accrued for potential liabilities associated with these lawsuits based on currently available information; however, actual losses may exceed our accruals or we could be required to accrue additional amounts in the future. In January 2020, we received a Notice of Violation (“NOV”) from the EPA related to allegations of violations of the Clean Air Act relating to our operations on the Fort Berthold Indian Reservation between 2015 and 2019. We are actively negotiating a draft consent decree with the EPA and Department of Justice containing certain proposed injunctive terms relating to this enforcement action. The enforcement action will likely include monetary sanctions and implementation of both environmental mitigation projects and injunctive terms, which would increase both our development costs and operating costs. We maintain an accrual for estimated future costs related to this matter regarding actions required to retrofit or replace existing equipment, which we expect to incur over multiple years. Our accrual does not include possible monetary sanctions or costs associated with mitigation projects as we are unable to estimate those amounts. Through the date of this filing, there exists substantial uncertainty as to the ultimate result of this matter and it is reasonably possible the result could be materially different from our accrual. In July 2022, the Company received an NOV from the EPA relating to alleged Clean Air Act violations following flyovers conducted in 2020 over certain of the Company’s oil and gas facilities in New Mexico. The notice involves alleged emission and permitting violations. The Company has initiated discussions with the EPA to resolve these matters. As we are still investigating these allegations, we are unable to estimate the potential loss associated with this matter, however, it is reasonably possible that the resolution may result in a fine or penalty in excess of $300,000. 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 September 30, 2022, accrued liabilities for remediation relating to environmental laws and regulations were not material. It is not presently possible to estimate the ultimate amount of all remediation cost that might be incurred or the penalties that may be imposed. 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.

Subsequent Event (Notes)

Subsequent Event (Notes)	9 Months Ended
	Sep. 30, 2022
Subsequent Events [Abstract]
Subsequent Event	Subsequent EventOn November 2, 2022, we executed a definitive purchase agreement to acquire the assets and certain related liabilities of Ensign Natural Resources in the Eagle Ford resource play in Texas for total cash consideration of $3.0 billion. The assets primarily consist of approximately 130,000 net proved and unproved acres, with an average 97% working interest, approximately 700 existing wells, and estimated current production of approximately 67,000 net boepd (including 22,000 net bopd of oil). We expect to fund the acquisition using a combination of cash on hand, borrowings on the company’s Credit Facility, and new prepayable debt. The transaction is subject to customary terms and conditions, including closing adjustments, and is expected to close by year-end 2022.

Basis of Presentation (Policies

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	These consolidated financial statements are unaudited; however, in the opinion of management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal recurring nature unless disclosed otherwise. These consolidated financial statements, including notes, have been prepared in accordance with the applicable rules of the SEC and do not include all of the information and disclosures required by U.S. GAAP for complete financial statements. These interim financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our 2021 Annual Report on Form 10-K. The results of operations for the third quarter and first nine months of 2022 are not necessarily indicative of the results to be expected for the full year.
Accounting Standards Updates Adopted and Not Yet Adopted	Accounting Standards Updates Adopted No accounting standards were adopted in the third quarter or first nine months of 2022 that had a material impact on our consolidated financial statements. Accounting Standards Updates Not Yet Adopted In March 2020, the FASB issued ASU 2020-04, which provides optional expedients and exceptions for applying U.S. GAAP to contracts, hedging relationships and other transactions that reference London Interbank Offered Rate (LIBOR) or another reference rate expected to be discontinued. The guidance is effective March 12, 2020 and can be applied prospectively through December 31, 2022. Upon adoption, we do not believe it will have a material impact on our consolidated results of operations, financial position and cash flows.

Income and Dividends per Comm_2

Income and Dividends per Common Share (Tables)	9 Months Ended
	Sep. 30, 2022
Earnings Per Share [Abstract]
Schedule of Income (Loss) Per Share, Basic and Diluted	The per share calculations below exclude 1 million and 2 million of stock options for the three and nine months ended September 30, 2022, respectively, and 4 million of stock options for each of the three and nine months ended September 30, 2021, that were antidilutive. Three Months Ended September 30, Nine Months Ended September 30, (In millions, except per share data) 2022 2021 2022 2021 Net income $ 817 $ 184 $ 3,087 $ 297 Weighted average common shares outstanding 670 789 701 791 Effect of dilutive securities 2 — 2 — Weighted average common shares, diluted 672 789 703 791 Net income per share: Basic $ 1.22 $ 0.23 $ 4.40 $ 0.38 Diluted $ 1.22 $ 0.23 $ 4.39 $ 0.38 Dividends per share $ 0.08 $ 0.05 $ 0.23 $ 0.12

Revenues (Tables)

Revenues (Tables)	9 Months Ended
	Sep. 30, 2022
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 for the three and nine months ended September 30: United States Three Months Ended September 30, 2022 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 523 $ 648 $ 104 $ 114 $ 39 $ 1,428 Natural gas liquids 49 82 63 16 6 216 Natural gas 56 67 105 22 11 261 Other 3 — — — 19 22 Revenues from contracts with customers $ 631 $ 797 $ 272 $ 152 $ 75 $ 1,927 Three Months Ended September 30, 2021 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 391 $ 425 $ 74 $ 75 $ 19 $ 984 Natural gas liquids 50 63 53 12 5 183 Natural gas 38 29 62 12 3 144 Other 2 — — — 62 64 Revenues from contracts with customers $ 481 $ 517 $ 189 $ 99 $ 89 $ 1,375 Nine Months Ended September 30, 2022 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,526 $ 2,049 $ 341 $ 302 $ 124 $ 4,342 Natural gas liquids 148 263 191 46 23 671 Natural gas 145 156 256 55 28 640 Other 6 — — — 71 77 Revenues from contracts with customers $ 1,825 $ 2,468 $ 788 $ 403 $ 246 $ 5,730 Nine Months Ended September 30, 2021 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,003 $ 1,208 $ 206 $ 229 $ 65 $ 2,711 Natural gas liquids 109 152 127 32 10 430 Natural gas 114 71 212 42 11 450 Other 6 — — — 99 105 Revenues from contracts with customers $ 1,232 $ 1,431 $ 545 $ 303 $ 185 $ 3,696 International (E.G.) Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2022 2021 2022 2021 Crude oil and condensate $ 75 $ 56 $ 186 $ 151 Natural gas liquids 1 — 2 2 Natural gas 5 6 17 18 Other — 1 2 2 Revenues from contracts with customers $ 81 $ 63 $ 207 $ 173

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2022
Segment Reporting [Abstract]
Schedule of Segment Reporting Information	Three Months Ended September 30, 2022 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 1,927 $ 81 $ — $ 2,008 Net gain (loss) on commodity derivatives (26) — 67 (b) 41 Income from equity method investments — 190 — 190 Net gain on disposal of assets — — 2 2 Other income 4 1 1 6 Less costs and expenses: Production 173 20 — 193 Shipping, handling and other operating 171 5 23 199 Exploration 11 — 62 (c) 73 Depreciation, depletion and amortization 441 14 5 460 Impairments — — 2 2 Taxes other than income 136 — 1 137 General and administrative 37 4 38 79 Net interest and other — — 52 52 Other net periodic benefit costs — — (5) (5) Income tax provision (benefit) 213 48 (21) 240 Segment income (loss) $ 723 $ 181 $ (87) $ 817 Total assets $ 15,487 $ 1,294 $ 1,077 $ 17,858 Capital expenditures (a) $ 406 $ 1 $ 6 $ 413 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 13 ). (c) Includes dry well costs and unproved property impairments of $48 million for Louisiana exploration leases and $14 million for Permian exploration leases (See Note 9 and Note 10 ). Three Months Ended September 30, 2021 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 1,375 $ 63 $ — $ 1,438 Net gain (loss) on commodity derivatives (106) — 27 (b) (79) Income from equity method investments — 86 — 86 Net gain on disposal of assets — — 7 7 Other income — — 1 1 Less costs and expenses: Production 119 12 — 131 Shipping, handling and other operating 209 7 3 219 Exploration 15 — 48 (c) 63 Depreciation, depletion and amortization 499 17 6 522 Impairments — — 13 (d) 13 Taxes other than income 88 — — 88 General and administrative 29 3 38 70 Net interest and other — — 57 (e) 57 Other net periodic benefit costs — — — — Loss on early extinguishment of debt — — 102 (f) 102 Income tax provision (benefit) 5 17 (18) 4 Segment income (loss) $ 305 $ 93 $ (214) $ 184 Total assets $ 15,528 $ 1,071 $ 562 $ 17,161 Capital expenditures (a) $ 303 $ 2 $ 3 $ 308 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 13 ). (c) Includes unproved property impairments of $20 million for Louisiana exploration leases and$16 million related to the disposition of a Permian lease. Also includes $12 million of dry well costs associated with drilled and uncompleted wells, primarily in Permian. (d) Includes impairments of $5 million for proved properties in Permian (See Note 10 ) and $8 million associated with decommissioning costs for non-producing long-lived assets in GOM (See Note 1 0 and Note 11 ). (e) Includes a $5 million gain on 2022 interest rate swaps and a $3 million gain on 2025 interest rate swaps (See Note 13 ). (f) Represents costs related to a make-whole provision premium and the write off of issuance costs related to the redemption of the 2025 Notes in September 2021 (See Note 15 ). Nine Months Ended September 30, 2022 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 5,730 $ 207 $ — $ 5,937 Net loss on commodity derivatives (125) — (4) (b) (129) Income from equity method investments — 469 — 469 Net gain on disposal of assets — — 1 1 Other income 10 5 10 25 Less costs and expenses: Production 464 45 — 509 Shipping, handling and other operating 508 15 52 575 Exploration 30 — 62 (c) 92 Depreciation, depletion and amortization 1,260 45 14 1,319 Impairments — — 4 4 Taxes other than income 374 — 7 381 General and administrative 94 10 116 220 Net interest and other — — 128 (d) 128 Other net periodic benefit costs — — (14) (14) Income tax provision (benefit) 655 110 (763) (e) 2 Segment income $ 2,230 $ 456 $ 401 $ 3,087 Total assets $ 15,487 $ 1,294 $ 1,077 $ 17,858 Capital expenditures (a) $ 1,124 $ 1 $ 11 $ 1,136 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 1 3 ). (c) Includes dry well costs and unproved property impairments of $48 million for Louisiana exploration leases and $14 million for Permian exploration leases (See Note 9 and Note 10 ). (d) Includes a $17 million gain on 2025 interest rate swaps (See Note 13 ). (e) Includes a $685 million benefit related to the partial release of our valuation allowance (See Note 6 ). Nine Months Ended September 30, 2021 (In millions) U.S. Int’l Not Allocated to Segments Total Revenue from contracts with customers $ 3,696 $ 173 $ — $ 3,869 Net loss on commodity derivatives (268) — (130) (b) (398) Income from equity method investments — 179 — 179 Net gain on disposal of assets — — 8 8 Other income 4 3 2 9 Less costs and expenses: Production 343 35 — 378 Shipping, handling and other operating 506 13 19 538 Exploration 54 — 55 (c) 109 Depreciation, depletion and amortization 1,477 54 19 1,550 Impairments — — 60 (d) 60 Taxes other than income 238 — (2) 236 General and administrative 79 9 139 (e) 227 Net interest and other — — 129 (f) 129 Other net periodic benefit credit — — (2) (2) Loss on early extinguishment of debt — — 121 (g) 121 Income tax provision (benefit) 11 33 (20) 24 Segment income (loss) $ 724 $ 211 $ (638) $ 297 Total assets $ 15,528 $ 1,071 $ 562 $ 17,161 Capital expenditures (a) $ 770 $ 4 $ 7 $ 781 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 1 3 ). (c) 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 $12 million of dry well costs associated with drilled and uncompleted wells, primarily in Permian. (d) Includes impairments of $24 million for central facilities in Eagle Ford (See Note 10 ), $5 million for proved properties in Permian (See Note 10 ), and $30 million associated with decommissioning costs for non-producing long-lived assets in GOM (See Note 10 and Note 11 ). (e) Includes $13 million associated with the termination of an aircraft lease agreement and $12 million arising from severance expenses associated with a workforce reduction. (f) Includes a $24 million gain on 2022 interest rate swaps and a $34 million gain on 2025 interest rate swaps (See Note 13 ). (g) 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 15

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation	For the three and nine months ended September 30, 2022 and 2021, our effective income tax rates were as follows: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 Effective income tax rate 23 % 2 % — % 7 %

Credit Losses (Tables)

Credit Losses (Tables)	9 Months Ended
	Sep. 30, 2022
Credit Loss [Abstract]
Summary of Allowance for Doubtful Accounts Balance	Changes in the allowance for credit losses were as follows: (In millions) September 30, 2022 December 31, 2021 Beginning balance as of January 1 $ 15 $ 22 Current period provision (2) 3 Current period write offs (1) (5) Recoveries of amounts previously reserved — (5) Ending balance $ 12 $ 15

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Sep. 30, 2022
Inventory Disclosure [Abstract]
Schedule of Inventory, Current	(In millions) September 30, 2022 December 31, 2021 Crude oil and natural gas liquids $ 14 $ 8 Supplies and other items 89 69 Inventories $ 103 $ 77

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	9 Months Ended
	Sep. 30, 2022
Property, Plant and Equipment [Abstract]
Schedule of Property, Plant and Equipment	(In millions) September 30, 2022 December 31, 2021 United States $ 13,889 $ 14,097 International 302 347 Corporate 54 55 Net property, plant and equipment $ 14,245 $ 14,499

Impairments (Tables)

Impairments (Tables)	9 Months Ended
	Sep. 30, 2022
Impairment Expense [Abstract]
Summary of Impaired Assets	The following table summarizes impairment charges of proved properties and their corresponding fair values. Three Months Ended September 30, 2022 2021 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ — $ — $ — $ 5 Asset retirement costs of long-lived assets $ — $ 2 $ — $ 8 Nine Months Ended September 30, 2022 2021 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ — $ — $ — $ 30 Asset retirement costs of long-lived assets $ — $ 4 $ — $ 30

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2022
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Changes in 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: September 30, (In millions) 2022 2021 Beginning balance as of January 1 $ 316 $ 254 Incurred liabilities, including acquisitions 10 9 Settled liabilities, including dispositions (8) (3) Accretion expense (included in depreciation, depletion and amortization) 11 9 Revisions of estimates (1) 40 Ending balance as of September 30, total $ 328 $ 309 Ending balance as of September 30, short-term $ 45 $ 23

Leases (Tables)

Leases (Tables)	9 Months Ended
	Sep. 30, 2022
Leases [Abstract]
Supplemental Balance Sheet Information	Balance sheet information related to right-of-use (“ROU”) assets and lease liabilities was as follows: (In millions) Balance Sheet Location: September 30, 2022 December 31, 2021 ROU assets: Operating leases Other noncurrent assets $ 95 $ 59 Finance leases Other noncurrent assets 26 28 Total ROU assets $ 121 $ 87 Lease liabilities: Current liabilities Operating leases Other current liabilities $ 65 $ 40 Finance leases Other current liabilities 6 6 Noncurrent liabilities Operating leases Deferred credits and other liabilities 35 23 Finance leases Deferred credits and other liabilities 19 24 Total lease liabilities $ 125 $ 93
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 $ 2 2023 6 2024 6 2025 6 2026 6 Thereafter 48 Total undiscounted cash flows $ 74

Derivatives (Tables)

Derivatives (Tables)	9 Months Ended
	Sep. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments in the Consolidated Balance Sheets	The following tables present the gross fair values of derivative instruments and the reported net amounts along with where they appear on the consolidated balance sheets. September 30, 2022 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ — $ — $ — Other current assets Commodity 1 12 (11) Other current liabilities Total Not Designated as Hedges $ 1 $ 12 $ (11) Cash Flow Hedges Interest Rate $ 8 $ — $ 8 Other current assets Interest Rate 18 — 18 Other noncurrent assets Total Designated Hedges $ 26 $ — $ 26 Total $ 27 $ 12 $ 15 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 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. Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2022 2021 2022 2021 Unrealized gain (loss) on derivative instruments, net $ 67 $ 27 $ (4) $ (130) Realized gain (loss) on derivative instruments, net (a) $ (26) $ (106) $ (125) $ (268) (a) During the third quarter and first nine months of 2022, net cash paid for settled derivative positions was $56 million and $145 million, respectively. During the third quarter and first nine months of 2021, net cash paid for settled derivative positions was $108 million and $203 million, respectively.
Schedule of Notional Amounts of Outstanding Derivative Positions	The following table sets forth outstanding derivative contracts as of September 30, 2022, and the weighted average prices for those contracts: 2022 2023 Fourth Quarter First Quarter Crude Oil NYMEX WTI Three-Way Collars Volume (Bbls/day) 30,000 — Weighted average price per Bbl: Ceiling $ 97.52 $ — Floor $ 56.67 $ — Sold put $ 46.67 $ — NYMEX Roll Basis Swaps Volume (Bbls/day) 60,000 — Weighted average price per Bbl $ 0.67 $ — Natural Gas Henry Hub (“HH”) Two-Way Collars Volume (MMBtu/day) 50,000 50,000 Weighted average price per MMBtu: Ceiling $ 19.28 $ 19.28 Floor $ 5.00 $ 5.00 Henry Hub Three-Way Collars Volume (MMBtu/day) 100,000 — Weighted average price per MMBtu: Ceiling $ 7.13 $ — Floor $ 3.88 $ — Sold Put $ 2.88 $ —
Schedule of Interest Rate Swap Agreement	The following table presents, by maturity date, information about our de-designated forward starting interest rate swap agreements. These positions were fully liquidated as of September 30, 2022. September 30, 2022 December 31, 2021 Maturity Date Aggregate Notional Amount (in millions) Weighted Average, LIBOR Aggregate Notional Amount (in millions) Weighted Average, LIBOR June 1, 2025 $ — — % $ 350 0.95 % September 9, 2026 $ — — % $ 25 1.45 % The following table presents, by maturity date, information about our interest rate swap agreements, including the fixed weighted average LIBOR. September 30, 2022 December 31, 2021 Maturity Date Aggregate Notional Amount (in millions) Weighted Average, LIBOR Aggregate Notional Amount (in millions) Weighted Average, LIBOR September 9, 2026 $ 295 1.52 % $ 295 1.52 %

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2022
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 September 30, 2022 and December 31, 2021 by hierarchy level. September 30, 2022 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Interest rate - designated as cash flow hedges $ — $ 26 $ — $ 26 Derivative instruments, assets $ — $ 26 $ — $ 26 Derivative instruments, liabilities Commodity (a) $ (2) $ (9) $ — $ (11) Derivative instruments, liabilities $ (2) $ (9) $ — $ (11) Total $ (2) $ 17 $ — $ 15 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 (a) Commodity derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 13
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 September 30, 2022 and December 31, 2021. September 30, 2022 December 31, 2021 (In millions) Fair Value Carrying Amount Fair Value Carrying Amount Financial assets Current assets $ — $ — $ 11 $ 10 Other noncurrent assets 10 28 12 27 Total financial assets $ 10 $ 28 $ 23 $ 37 Financial liabilities Current liabilities $ 107 $ 171 $ 99 $ 136 Long-term debt, including current portion (a) 3,793 3,997 4,705 4,033 Deferred credits and other liabilities 16 15 46 46 Total financial liabilities $ 3,916 $ 4,183 $ 4,850 $ 4,215

Incentive Based Compensation (T

Incentive Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2022
Share-Based Payment Arrangement [Abstract]
Schedule of Stock Options, Restricted Stock Awards and Restricted Stock Units Activity	The following table presents a summary of activity for the first nine months of 2022: Stock Options Restricted Stock & Units Number of Shares Weighted Average Exercise Price Number of Shares & Units Weighted Average Grant Date Fair Value Outstanding at December 31, 2021 4,274,304 $ 22.13 5,888,242 $ 10.98 Granted — $ — 1,719,757 $ 22.83 Exercised/Vested (1,842,093) $ 14.41 (2,796,967) $ 12.05 Canceled (414,952) $ 33.55 (187,859) $ 14.14 Outstanding at September 30, 2022 2,017,259 $ 26.82 4,623,173 $ 14.62

Defined Benefit Postretiremen_2

Defined Benefit Postretirement Plans (Tables)	9 Months Ended
	Sep. 30, 2022
Retirement Benefits [Abstract]
Schedule of Net Periodic Benefit Cost	The following summarizes the components of net periodic benefit costs (credits): Three Months Ended September 30, Pension Benefits Other Benefits (In millions) 2022 2021 2022 2021 Service cost $ 4 $ 4 $ — $ — Interest cost 1 2 1 — Expected return on plan assets (2) (2) — — Amortization: – prior service credit (1) (1) (4) (4) – actuarial loss — 1 — 1 Net settlement loss (a) — 3 — — Net periodic benefit costs (credits) (b) $ 2 $ 7 $ (3) $ (3) Nine Months Ended September 30, Pension Benefits Other Benefits (In millions) 2022 2021 2022 2021 Service cost $ 11 $ 12 $ — $ — Interest cost 5 6 2 1 Expected return on plan assets (7) (6) — — Amortization: – prior service credit (4) (4) (12) (12) – actuarial loss 1 4 1 2 Net settlement loss (a) — 8 — — Net periodic benefit costs (credits) (b) $ 6 $ 20 $ (9) $ (9) (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 cost for that year. (b) Net periodic benefit costs (credits) reflects a calculated market-related value of plan assets which recognizes changes in fair value over three years.

Reclassifications Out of Accu_2

Reclassifications Out of Accumulated Other Comprehensive Income (Loss) (Tables)	9 Months Ended
	Sep. 30, 2022
Equity [Abstract]
Schedule of Amounts Reclassified out of Accumulated Other Comprehensive Income (Loss)	The following table presents a summary of amounts reclassified from accumulated other comprehensive income (loss): Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2022 2021 2022 2021 Income Statement Line Postretirement and postemployment plans Amortization of prior service credit $ 5 $ 5 $ 16 $ 16 Other net periodic benefit costs Amortization of actuarial loss — (2) (2) (6) Other net periodic benefit costs Net settlement loss — (3) — (8) Other net periodic benefit costs Interest rate swaps Reclassification of de-designated forward interest rate swaps — — — (28) Net interest and other (1) — (3) — Provision for income taxes Total reclassifications of (income) expense, net of tax (a) $ 4 $ — $ 11 $ (26) Net income (loss)

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2022
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Nine Months Ended September 30, (In millions) 2022 2021 Included in operating activities: Interest paid $ 153 $ 185 Income taxes paid, net of refunds (a) $ 128 $ 8 Noncash investing activities: Increase in asset retirement costs $ 9 $ 49 (a) The nine months ended September 30, 2021 includes $1 million related to tax refunds.

Equity Method Investments (Tabl

Equity Method Investments (Tables)	9 Months Ended
	Sep. 30, 2022
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Equity Method Investments	During the periods ended September 30, 2022 and December 31, 2021 our equity method investees were considered related parties. Our investment in our equity method investees are summarized in the following table: (In millions) Ownership as of September 30, 2022 September 30, 2022 December 31, 2021 EGHoldings (a) 56% $ 293 $ 148 Alba Plant LLC (b) 52% 142 154 AMPCO (c) 45% 133 148 Total $ 568 $ 450 (a) EGHoldings is engaged in LNG production activity. (b) Alba Plant LLC processes LPG. (c) AMPCO is engaged in methanol production activity. Summarized, 100% combined financial information for equity method investees is as follows: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2022 2021 2022 2021 Income data: Revenues and other income $ 499 $ 325 $ 1,332 $ 806 Income from operations 358 188 893 395 Net income $ 335 $ 155 $ 811 $ 312

Income and Dividends per Comm_3

Income and Dividends per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Earnings Per Share [Abstract]
Antidilutive securities excluded from computation of earnings per share (in shares)	1			4			2	4
Net income	$ 817	$ 966	$ 1,304	$ 184	$ 16	$ 97	$ 3,087	$ 297
Weighted average common shares outstanding (in shares)	670			789			701	791
Effect of dilutive securities (in shares)	2			0			2	0
Weighted average common shares, diluted (in shares)	672			789			703	791
Net income per share:
Basic (in dollars per share)	$ 1.22			$ 0.23			$ 4.40	$ 0.38
Diluted (in dollars per share)	1.22			0.23			4.39	0.38
Dividends per share (in dollars per share)	$ 0.08	$ 0.08	$ 0.07	$ 0.05	$ 0.04	$ 0.03	$ 0.23	$ 0.12

Revenues - Narrative (Details)

Revenues - Narrative (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Receivables from contract with customer	$ 1,100	$ 961

Revenues - Revenues from Contra

Revenues - Revenues from Contracts with Customers by Product Type and Geographic Areas (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 2,008	$ 1,438	$ 5,937	$ 3,869
United States E&P
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,927	1,375	5,730	3,696
United States E&P | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	631	481	1,825	1,232
United States E&P | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	797	517	2,468	1,431
United States E&P | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	272	189	788	545
United States E&P | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	152	99	403	303
United States E&P | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	75	89	246	185
United States E&P | Crude oil and condensate
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,428	984	4,342	2,711
United States E&P | Crude oil and condensate | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	523	391	1,526	1,003
United States E&P | Crude oil and condensate | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	648	425	2,049	1,208
United States E&P | Crude oil and condensate | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	104	74	341	206
United States E&P | Crude oil and condensate | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	114	75	302	229
United States E&P | Crude oil and condensate | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	39	19	124	65
United States E&P | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	216	183	671	430
United States E&P | Natural gas liquids | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	49	50	148	109
United States E&P | Natural gas liquids | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	82	63	263	152
United States E&P | Natural gas liquids | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	63	53	191	127
United States E&P | Natural gas liquids | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	16	12	46	32
United States E&P | Natural gas liquids | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6	5	23	10
United States E&P | Natural gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	261	144	640	450
United States E&P | Natural gas | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	56	38	145	114
United States E&P | Natural gas | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	67	29	156	71
United States E&P | Natural gas | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	105	62	256	212
United States E&P | Natural gas | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	22	12	55	42
United States E&P | Natural gas | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11	3	28	11
United States E&P | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	22	64	77	105
United States E&P | Other | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3	2	6	6
United States E&P | Other | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
United States E&P | Other | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
United States E&P | Other | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
United States E&P | Other | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	19	62	71	99
International E&P | International, Equatorial Guinea (E.G.)
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	81	63	207	173
International E&P | Crude oil and condensate | International, Equatorial Guinea (E.G.)
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	75	56	186	151
International E&P | Natural gas liquids | International, Equatorial Guinea (E.G.)
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	0	2	2
International E&P | Natural gas | International, Equatorial Guinea (E.G.)
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5	6	17	18
International E&P | Other | International, Equatorial Guinea (E.G.)
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 0	$ 1	$ 2	$ 2

Segment Information (Details)

Segment Information (Details) $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Sep. 30, 2021 USD ($)	Jun. 30, 2021 USD ($)	Mar. 31, 2021 USD ($)	Sep. 30, 2022 USD ($) segment	Sep. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)
Segment Reporting [Abstract]
Number of reportable segments | segment							2
Number of operating segments | segment							2
Segment Reporting Information [Line Items]
Revenues from contracts with customers	$ 2,008			$ 1,438			$ 5,937	$ 3,869
Net gain (loss) on commodity derivatives	41			(79)			(129)	(398)
Income from equity method investments	190			86			469	179
Net gain on disposal of assets	2			7			1	8
Other income	6			1			25	9
Less costs and expenses:
Production	193			131			509	378
Shipping, handling and other operating	199			219			575	538
Exploration	73			63			92	109
Depreciation, depletion and amortization	460			522			1,319	1,550
Impairments	2			13			4	60
Taxes other than income	137			88			381	236
General and administrative	79			70			220	227
Net interest and other	52			57			128	129
Other net periodic benefit costs	(5)			0			(14)	(2)
Loss on early extinguishment of debt	0			102			0	121
Income tax provision (benefit)	240			4			2	24
Net income	817	$ 966	$ 1,304	184	$ 16	$ 97	3,087	297
Total assets	17,858			17,161			17,858	17,161	$ 16,994
Capital expenditures	413			308			1,136	781
Long-lived assets held for use impairment	0			5			0	30
Impairments	2			8			4	30
Valuation allowance released							685
Loss on lease termination								13
Severance costs								12
Interest Rate Contract, Maturing November 1, 2022 | Not Designated as Hedges
Less costs and expenses:
Gain on interest rate swap				5				24
Interest Rate Contract, Maturing June 1, 2025 | Not Designated as Hedges
Less costs and expenses:
Gain on interest rate swap				3				34
Interest Rate Contract, Maturing June 1, 2025 | Cash Flow Hedges
Less costs and expenses:
Gain on interest rate swap							17
Permian Basin
Less costs and expenses:
Exploration	14			12			14	12
Long-lived assets held for use impairment				5				5
Gulf of Mexico
Less costs and expenses:
Impairments								30
Unproved property impairments
Less costs and expenses:
Exploration				20				20
Unproved property impairments | LOUISIANA
Less costs and expenses:
Exploration	48						48
Lease | Permian Basin
Less costs and expenses:
Exploration				16				16
Non Producing Property | Gulf of Mexico
Less costs and expenses:
Impairments				8				30
Central Facilities | Eagle Ford
Less costs and expenses:
Long-lived assets held for use impairment					$ 24			24
Not Allocated to Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	0			0			0	0
Net gain (loss) on commodity derivatives	67			27			(4)	(130)
Income from equity method investments	0			0			0	0
Net gain on disposal of assets	2			7			1	8
Other income	1			1			10	2
Less costs and expenses:
Production	0			0			0	0
Shipping, handling and other operating	23			3			52	19
Exploration	62			48			62	55
Depreciation, depletion and amortization	5			6			14	19
Impairments	2			13			4	60
Taxes other than income	1			0			7	(2)
General and administrative	38			38			116	139
Net interest and other	52			57			128	129
Other net periodic benefit costs	(5)			0			(14)	(2)
Loss on early extinguishment of debt				102				121
Income tax provision (benefit)	(21)			(18)			(763)	(20)
Net income	(87)			(214)			401	(638)
Total assets	1,077			562			1,077	562
Capital expenditures	6			3			11	7
U.S.
Segment Reporting Information [Line Items]
Revenues from contracts with customers	1,927			1,375			5,730	3,696
U.S. | Eagle Ford
Segment Reporting Information [Line Items]
Revenues from contracts with customers	631			481			1,825	1,232
U.S. | Operating Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	1,927			1,375			5,730	3,696
Net gain (loss) on commodity derivatives	(26)			(106)			(125)	(268)
Income from equity method investments	0			0			0	0
Net gain on disposal of assets	0			0			0	0
Other income	4			0			10	4
Less costs and expenses:
Production	173			119			464	343
Shipping, handling and other operating	171			209			508	506
Exploration	11			15			30	54
Depreciation, depletion and amortization	441			499			1,260	1,477
Impairments	0			0			0	0
Taxes other than income	136			88			374	238
General and administrative	37			29			94	79
Net interest and other	0			0			0	0
Other net periodic benefit costs	0			0			0	0
Loss on early extinguishment of debt				0				0
Income tax provision (benefit)	213			5			655	11
Net income	723			305			2,230	724
Total assets	15,487			15,528			15,487	15,528
Capital expenditures	406			303			1,124	770
Int'l E&P | Operating Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	81			63			207	173
Net gain (loss) on commodity derivatives	0			0			0	0
Income from equity method investments	190			86			469	179
Net gain on disposal of assets	0			0			0	0
Other income	1			0			5	3
Less costs and expenses:
Production	20			12			45	35
Shipping, handling and other operating	5			7			15	13
Exploration	0			0			0	0
Depreciation, depletion and amortization	14			17			45	54
Impairments	0			0			0	0
Taxes other than income	0			0			0	0
General and administrative	4			3			10	9
Net interest and other	0			0			0	0
Other net periodic benefit costs	0			0			0	0
Loss on early extinguishment of debt				0				0
Income tax provision (benefit)	48			17			110	33
Net income	181			93			456	211
Total assets	1,294			1,071			1,294	1,071
Capital expenditures	$ 1			$ 2			$ 1	$ 4

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Income Tax Disclosure [Abstract]
Effective income tax rate	23%	2%	0%	7%
Valuation allowance released			$ 685

Credit Losses (Details)

Credit Losses (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning balance as of January 1	$ 15	$ 22
Current period provision	(2)	3
Current period write offs	(1)	(5)
Recoveries of amounts previously reserved	0	(5)
Ending balance	$ 12	$ 15

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Inventory Disclosure [Abstract]
Crude oil and natural gas liquids	$ 14	$ 8
Supplies and other items	89	69
Inventories	$ 103	$ 77

Property, Plant and Equipment_2

Property, Plant and Equipment (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 14,245		$ 14,499
Exploratory well costs capitalized greater than one year after completion of drilling	20		80
Reduction in suspended well costs		$ 46
Louisiana Austin Chalk
Property, Plant and Equipment [Line Items]
Dry well cost	14
Operating Segments | United States
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	13,889		14,097
Operating Segments | International
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	302		347
Corporate
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 54		$ 55

Impairments - Summary of Impair

Impairments - Summary of Impaired Assets (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Impaired Long-Lived Assets Held and Used [Line Items]
Long-lived assets held for use impairment	$ 0	$ 5	$ 0	$ 30
Asset retirement costs of long-lived assets, impairment	2	8	4	30
Fair Value
Impaired Long-Lived Assets Held and Used [Line Items]
Long-lived assets held for use	0	0	0	0
Asset retirement costs of long-lived assets	$ 0	$ 0	$ 0	$ 0

Impairments - Narrative (Detail

Impairments - Narrative (Details) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Jun. 30, 2021 USD ($) facility	Sep. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)
Impaired Long-Lived Assets Held and Used [Line Items]
Exploration	$ 73	$ 63		$ 92	$ 109
Long-lived assets held for use impairment	0	5		0	30
Number of impaired assets | facility			2
Asset retirement costs of long-lived assets, impairment	2	8		4	30
Unproved property impairments
Impaired Long-Lived Assets Held and Used [Line Items]
Exploration		20			20
LOUISIANA | Unproved property impairments
Impaired Long-Lived Assets Held and Used [Line Items]
Exploration	48			48
Permian Basin
Impaired Long-Lived Assets Held and Used [Line Items]
Exploration	$ 14	12		$ 14	12
Long-lived assets held for use impairment		5			5
Permian Basin | Lease
Impaired Long-Lived Assets Held and Used [Line Items]
Exploration		$ 16			16
Eagle Ford | Central Facilities
Impaired Long-Lived Assets Held and Used [Line Items]
Long-lived assets held for use impairment			$ 24		$ 24

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance as of January 1			$ 316	$ 254
Incurred liabilities, including acquisitions			10	9
Settled liabilities, including dispositions			(8)	(3)
Accretion expense (included in depreciation, depletion and amortization)			11	9
Revisions of estimates			(1)	40
Ending balance as of September 30, total	$ 328	$ 309	328	309
Asset retirement obligation, current	45	23	45	23
Impairments	$ 2	8	$ 4	30
Gulf of Mexico
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Revisions of estimates				37
Asset retirement obligation, current		$ 14		14
Impairments				$ 30

Leases - Supplemental Balance S

Leases - Supplemental Balance Sheet Information (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
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
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	$ 95	$ 59
Finance leases	26	28
Total ROU assets	121	87
Current liabilities:
Operating leases	65	40
Finance leases	6	6
Noncurrent liabilities
Operating leases	35	23
Finance leases	19	24
Total lease liabilities	$ 125	$ 93

Leases - Narrative (Details)

Leases - Narrative (Details) $ in Millions	9 Months Ended
	Sep. 30, 2022 USD ($)
Leases [Abstract]
Term of contract	5 years
Cash lease payments	$ 6
Finance lease extension term	5 years
Residual value guarantee	100%
Annual payments to be received	$ 6

Leases - Lease Payments to be R

Leases - Lease Payments to be Received (Details) $ in Millions	Sep. 30, 2022 USD ($)
Leases [Abstract]
2022	$ 2
2023	6
2024	6
2025	6
2026	6
Thereafter	48
Total undiscounted cash flows	$ 74

Derivatives - Balance Sheet Com

Derivatives - Balance Sheet Components (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Asset	$ 27	$ 28
Liability	12	13
Net Asset (Liability)	15	15
Not Designated as Hedges
Derivatives, Fair Value [Line Items]
Asset	1	28
Liability	12	8
Net Asset (Liability)	(11)	20
Cash Flow Hedges
Derivatives, Fair Value [Line Items]
Asset	26	0
Liability	0	5
Net Asset (Liability)	26	(5)
Commodity | Other current assets | Not Designated as Hedges
Derivatives, Fair Value [Line Items]
Asset	0
Liability	0
Net Asset (Liability)	0
Commodity | Other current liabilities | Not Designated as Hedges
Derivatives, Fair Value [Line Items]
Asset	1	1
Liability	12	8
Net Asset (Liability)	(11)	(7)
Interest Rate | Other current assets | Cash Flow Hedges
Derivatives, Fair Value [Line Items]
Asset	8
Liability	0
Net Asset (Liability)	8
Interest Rate | Other current liabilities | Cash Flow Hedges
Derivatives, Fair Value [Line Items]
Asset		0
Liability		3
Net Asset (Liability)		(3)
Interest Rate | Other noncurrent assets | Not Designated as Hedges
Derivatives, Fair Value [Line Items]
Asset		27
Liability		0
Net Asset (Liability)		27
Interest Rate | Other noncurrent assets | Cash Flow Hedges
Derivatives, Fair Value [Line Items]
Asset	18
Liability	0
Net Asset (Liability)	$ 18
Interest Rate | Deferred credits and other liabilities | Cash Flow Hedges
Derivatives, Fair Value [Line Items]
Asset		0
Liability		2
Net Asset (Liability)		$ (2)

Derivatives - Outstanding Deriv

Derivatives - Outstanding Derivative Contracts (Details) - Not Designated as Hedges	Sep. 30, 2022 bbl / h MMBbls / d $ / MMBTU $ / bbl
Three-Way Collars - Crude Oil 2022, Fourth Quarter
Derivative [Line Items]
Derivative, volume | bbl / h	30,000
Derivative, ceiling | $ / bbl	97.52
Derivative, floor | $ / bbl	56.67
Derivative, sold put | $ / bbl	46.67
Three-Way Collars - Crude Oil 2023, First Quarter
Derivative [Line Items]
Derivative, volume | bbl / h	0
Derivative, ceiling | $ / bbl	0
Derivative, floor | $ / bbl	0
Derivative, sold put | $ / bbl	0
NYMEX Roll Basis Swaps - Crude Oil 2022, Fourth Quarter
Derivative [Line Items]
Derivative, volume | bbl / h	60,000
NYMEX Roll Basis Swaps - Crude Oil 2022, Fourth Quarter | Short
Derivative [Line Items]
Derivative, weighted average price | $ / bbl	0.67
NYMEX Roll Basis Swaps - Crude Oil 2023, First Quarter
Derivative [Line Items]
Derivative, volume | bbl / h	0
NYMEX Roll Basis Swaps - Crude Oil 2023, First Quarter | Short
Derivative [Line Items]
Derivative, weighted average price | $ / bbl	0
Two-Way Collars - Natural Gas 2022, Fourth Quarter
Derivative [Line Items]
Derivative, volume | MMBbls / d	50,000
Derivative, ceiling	19.28
Derivative, floor	5
Two-Way Collars - Natural Gas 2023, First Quarter
Derivative [Line Items]
Derivative, volume | MMBbls / d	50,000
Derivative, ceiling	19.28
Derivative, floor	5
Three-Way Collars - Natural Gas 2022, Fourth Quarter
Derivative [Line Items]
Derivative, volume | MMBbls / d	100,000
Derivative, ceiling	7.13
Derivative, floor	3.88
Derivative, sold put	2.88
Three-Way Collars - Natural Gas 2023, First Quarter
Derivative [Line Items]
Derivative, volume | MMBbls / d	0
Derivative, ceiling	0
Derivative, floor	0
Derivative, sold put	0

Derivatives - Schedule of mark-

Derivatives - Schedule of mark-to-market impact and commodity derivative settlements (Details) - Commodity - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized gain (loss) on derivative instruments, net	$ 67	$ 27	$ (4)	$ (130)
Realized gain (loss) on derivative instruments, net	(26)	(106)	(125)	(268)
Net settlements of derivative instruments	$ 56	$ 108	$ 145	$ 203

Derivatives - Narrative (Detail

Derivatives - Narrative (Details) - USD ($)		1 Months Ended	3 Months Ended		9 Months Ended
	Jun. 10, 2022	Mar. 31, 2022	Mar. 31, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021	Jun. 30, 2021	Dec. 31, 2020	Dec. 31, 2019
Senior Unsecured Note Due 2025
Derivative Instruments, Gain (Loss) [Line Items]
Long-term debt				$ 900,000,000		$ 900,000,000
Interest rate				3.85%		3.85%
Interest Rate
Derivative Instruments, Gain (Loss) [Line Items]
Amount expected to be reclassified within 12 months					$ 8,000,000
Interest Rate Contract, Maturing June 1, 2025 | Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Gain on interest rate swap					17,000,000
Proceeds for settlement of interest rate swaps		$ 44,000,000
Designated as Hedging Instrument | Interest Rate Contract, Maturing November 1, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount									$ 500,000,000
Designated as Hedging Instrument | Interest Rate Contract, Maturing June 1, 2025 | Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount									$ 350,000,000
Designated as Hedging Instrument | Interest Rate Contract, Maturing September 9, 2026
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount					295,000,000		$ 295,000,000
Designated as Hedging Instrument | Interest Rate Contract, Maturing September 9, 2026 | Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount								$ 320,000,000		$ 320,000,000
Not Designated as Hedges | Interest Rate Contract, Maturing November 1, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Net deferred loss of de-designated forward starting interest rate swaps			$ 2,000,000
Gain on interest rate swap				$ 5,000,000		$ 24,000,000
Not Designated as Hedges | Interest Rate Contract, Maturing June 1, 2025
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount					0		350,000,000
Gain on interest rate swap				$ 3,000,000		$ 34,000,000
Not Designated as Hedges | Interest Rate Contract, Maturing September 9, 2026
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount					$ 0		$ 25,000,000
Proceeds for settlement of interest rate swaps	$ 2,000,000
Not Designated as Hedges | Interest Rate Contract, Maturing September 9, 2026 | De-designated as cash flow hedge
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount	$ 25,000,000							$ 25,000,000

Derivatives - Schedule of Termi

Derivatives - Schedule of Terminated Interest Rate Swap Agreements (Details) - Not Designated as Hedges - USD ($)	Sep. 30, 2022	Dec. 31, 2021
Interest Rate Contract, Maturing June 1, 2025
Derivative [Line Items]
Derivative, notional amount	$ 0	$ 350,000,000
Weighted average interest rate, LIBOR	0%	0.95%
Interest Rate Contract, Maturing September 9, 2026
Derivative [Line Items]
Derivative, notional amount	$ 0	$ 25,000,000
Weighted average interest rate, LIBOR	0%	1.45%

Derivatives - Schedule of Inter

Derivatives - Schedule of Interest Rate Swap Agreements (Details) - Interest Rate Contract, Maturing September 9, 2026 - Designated as Hedging Instrument - USD ($)	Sep. 30, 2022	Dec. 31, 2021
Derivative [Line Items]
Derivative, notional amount	$ 295,000,000	$ 295,000,000
Weighted average interest rate, LIBOR	1.52%	1.52%

Fair Value Measurements - Fair

Fair Value Measurements - Fair Value Recurring (Details) - Recurring - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	$ 26	$ 27
Derivative instruments, liabilities	(11)	(12)
Total	15	15
Interest Rate | Designated as Hedging Instrument
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	26
Derivative instruments, liabilities		(5)
Interest Rate | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets		27
Commodity | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, liabilities	(11)	(7)
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	0	0
Derivative instruments, liabilities	(2)	(2)
Total	(2)	(2)
Level 1 | Interest Rate | Designated as Hedging Instrument
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	0
Derivative instruments, liabilities		0
Level 1 | Interest Rate | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets		0
Level 1 | Commodity | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, liabilities	(2)	(2)
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	26	27
Derivative instruments, liabilities	(9)	(10)
Total	17	17
Level 2 | Interest Rate | Designated as Hedging Instrument
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	26
Derivative instruments, liabilities		(5)
Level 2 | Interest Rate | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets		27
Level 2 | Commodity | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, liabilities	(9)	(5)
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	0	0
Derivative instruments, liabilities	0	0
Total	0	0
Level 3 | Interest Rate | Designated as Hedging Instrument
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	0
Derivative instruments, liabilities		0
Level 3 | Interest Rate | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets		0
Level 3 | Commodity | Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, liabilities	$ 0	$ 0

Fair Value Measurements - Fai_2

Fair Value Measurements - Fair Value Financial Instruments (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Fair Value
Financial assets
Current assets	$ 0	$ 11
Other noncurrent assets	10	12
Total financial assets	10	23
Financial liabilities
Current liabilities	107	99
Long-term debt, including current portion	3,793	4,705
Deferred credits and other liabilities	16	46
Total financial liabilities	3,916	4,850
Carrying Amount
Financial assets
Current assets	0	10
Other noncurrent assets	28	27
Total financial assets	28	37
Financial liabilities
Current liabilities	171	136
Long-term debt, including current portion	3,997	4,033
Deferred credits and other liabilities	15	46
Total financial liabilities	$ 4,183	$ 4,215

Debt - Revolving Credit Facilit

Debt - Revolving Credit Facility (Details) - Revolving Credit Facility	Jul. 28, 2022 USD ($)	Sep. 30, 2022 USD ($)	Jul. 27, 2022 USD ($)
Line of Credit Facility [Line Items]
Line of credit, outstanding amount		$ 0
Maximum borrowing capacity	$ 2,500,000,000	$ 2,500,000,000	$ 3,100,000,000
Extended maturity	3 years
Covenant, ratio of indebtedness to net capital, maximum		0.65
Ratio of indebtedness to net capital		0.20

Debt - Debt Redemption (Details

Debt - Debt Redemption (Details) - Unsecured Debt - USD ($) $ in Millions	1 Months Ended
	Sep. 30, 2021	Apr. 30, 2021	May 31, 2022
Senior Unsecured Notes, 9.375%, Due 2022
Debt Instrument [Line Items]
Long-term debt, gross			$ 32
Interest rate			9.375%
Senior Unsecured Notes, 3.850%, Due 2025
Debt Instrument [Line Items]
Long-term debt, gross	$ 900
Interest rate	3.85%
Costs related to make-whole provision premium and write off of unamortized discount and issuance costs	$ 102
Senior Unsecured Notes, 2.800%, Due 2022
Debt Instrument [Line Items]
Long-term debt, gross		$ 500
Interest rate		2.80%
Costs related to make-whole provision premium and write off of unamortized discount and issuance costs		$ 19

Debt - Long-Term Debt (Details)

Debt - Long-Term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Outstanding debt	$ 4,000
Long-term debt due within one year	402	$ 36
Purchase On April 1, 2023
Debt Instrument [Line Items]
Long-term debt due within one year	$ 200
Interest rate	2%

Stockholders' Equity (Details)

Stockholders' Equity (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended			9 Months Ended
	Nov. 02, 2022	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2022
Equity, Class of Treasury Stock [Line Items]
Shares repurchased, value		$ 1,122	$ 760	$ 592
Value of stock repurchased for restricted stock award tax obligation					$ 21
Share Repurchase Program
Equity, Class of Treasury Stock [Line Items]
Shares repurchased, value					2,500
Stock repurchase program, remaining authorized repurchase amount		$ 926			$ 926
Share Repurchase Program | Subsequent Event
Equity, Class of Treasury Stock [Line Items]
Shares repurchased, value	$ 230
Stock repurchase program, remaining authorized repurchase amount	$ 2,500

Incentive Based Compensation -

Incentive Based Compensation - Stock Options, Restricted Stock Awards and Restricted Stock Units (Details)	9 Months Ended
	Sep. 30, 2022 $ / shares shares
Number of Shares
Outstanding, beginning (in shares) | shares	4,274,304
Granted (in shares) | shares	0
Exercised/Vested (in shares) | shares	(1,842,093)
Canceled (in shares) | shares	(414,952)
Outstanding, ending (in shares) | shares	2,017,259
Weighted Average Exercise Price
Outstanding, beginning (in dollars per share) | $ / shares	$ 22.13
Granted (in dollars per share) | $ / shares	0
Exercised/Vested (in dollars per share) | $ / shares	14.41
Canceled (in dollars per share) | $ / shares	33.55
Outstanding, ending (in dollars per share) | $ / shares	$ 26.82
Restricted Stock & Units
Number of Shares & Units
Outstanding, beginning (in shares) | shares	5,888,242
Granted (in shares) | shares	1,719,757
Exercised/Vested (in shares) | shares	(2,796,967)
Canceled (in shares) | shares	(187,859)
Outstanding, ending (in shares) | shares	4,623,173
Weighted Average Grant Date Fair Value
Outstanding, beginning (in dollars per share) | $ / shares	$ 10.98
Granted (in dollars per share) | $ / shares	22.83
Exercised/Vested (in dollars per share) | $ / shares	12.05
Canceled (in dollars per share) | $ / shares	14.14
Outstanding, ending (in dollars per share) | $ / shares	$ 14.62

Incentive Based Compensation _2

Incentive Based Compensation - Narrative (Details)	9 Months Ended
	Sep. 30, 2022 $ / shares shares
Performance Unit - Share Settlement
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)	167,043
Grant date fair value (in dollars per share) | $ / shares	$ 34.07
Performance Unit - Cash Settlement
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)	167,043
Unit conversion ratio (in shares)	1
Fair value as of period end (in dollars per share) | $ / shares	$ 23.37

Defined Benefit Postretiremen_3

Defined Benefit Postretirement Plans (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Amortization:
Net settlement loss	$ (5)	$ 0	$ (14)	$ (2)
Estimated future contributions over the remainder of the current year	4		4
Funded Plan
Amortization:
Payment for pension benefits			17
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	4	11	12
Interest cost	1	2	5	6
Expected return on plan assets	(2)	(2)	(7)	(6)
Amortization:
– prior service credit	(1)	(1)	(4)	(4)
– actuarial loss	0	1	1	4
Net settlement loss	0	3	0	8
Net periodic benefit costs (credits)	2	7	6	20
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	0	0	0
Interest cost	1	0	2	1
Expected return on plan assets	0	0	0	0
Amortization:
– prior service credit	(4)	(4)	(12)	(12)
– actuarial loss	0	1	1	2
Net settlement loss	0	0	0	0
Net periodic benefit costs (credits)	$ (3)	$ (3)	(9)	$ (9)
Payment for other postretirement benefits			$ 7

Reclassifications Out of Accu_3

Reclassifications Out of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other net periodic benefit credits	$ 5			$ 0			$ 14	$ 2
Net interest and other	(52)			(57)			(128)	(129)
Provision for income taxes	240			4			2	24
Net income (loss)	817	$ 966	$ 1,304	184	$ 16	$ 97	3,087	297
Reclassification out of Accumulated Other Comprehensive Income (Loss) | Total reclassifications of (income) expense, net of tax
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net income (loss)	4			0			11	(26)
Reclassification out of Accumulated Other Comprehensive Income (Loss) | Amortization of prior service credit
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other net periodic benefit credits	5			5			16	16
Reclassification out of Accumulated Other Comprehensive Income (Loss) | Amortization of actuarial loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other net periodic benefit credits	0			(2)			(2)	(6)
Reclassification out of Accumulated Other Comprehensive Income (Loss) | Net settlement loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other net periodic benefit credits	0			(3)			0	(8)
Reclassification out of Accumulated Other Comprehensive Income (Loss) | Reclassification of de-designated forward interest rate swaps
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net interest and other	0			0			0	(28)
Provision for income taxes	$ (1)			$ 0			$ (3)	$ 0

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
Included in operating activities:
Interest paid	$ 153	$ 185
Income taxes paid, net of refunds	128	8
Noncash investing activities:
Increase in asset retirement costs	9	49
Proceeds from income tax refunds		1
Capital expenditures incurred but not yet paid	$ 99	$ 104

Equity Method Investments - Sch

Equity Method Investments - Schedule of Equity Method Investments (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 568	$ 450
EG Holdings
Schedule of Equity Method Investments [Line Items]
Ownership percentage	56%
Equity method investments	$ 293	148
Alba Plant LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage	52%
Equity method investments	$ 142	154
AMPCO
Schedule of Equity Method Investments [Line Items]
Ownership percentage	45%
Equity method investments	$ 133	$ 148

Equity Method Investments - Sum

Equity Method Investments - Summarized Financial Information (Details) - USD ($) $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Schedule of Equity Method Investments [Line Items]
Revenues and other income	$ 2,247			$ 1,453			$ 6,303	$ 3,667
Income from operations	1,104			347			3,203	569
Net income	817	$ 966	$ 1,304	184	$ 16	$ 97	3,087	297
Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Revenues and other income	499			325			1,332	806
Income from operations	358			188			893	395
Net income	$ 335			$ 155			$ 811	$ 312

Equity Method Investments - Nar

Equity Method Investments - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Revenue from related parties	$ 7	$ 8	$ 22	$ 24
Proceeds from equity method investment	150	$ 56	350	$ 137
Due from related parties	43		43		$ 23
Due to related parties	$ 6		$ 6		$ 20

Commitments and Contingencies (

Commitments and Contingencies (Details) $ in Thousands	3 Months Ended
	Jun. 30, 2020 guarantee	Sep. 30, 2022 USD ($) tribe	Jul. 31, 2022 USD ($)
Loss Contingencies [Line Items]
Number of affiliated tribes | tribe		3
Contingent royalty liability		$ 153,000
Contingent capital and expense receivable, noncurrent		26,000
Expected penalty or fine (in excess of)			$ 300
Number of guarantees executed | guarantee	2
Guarantees recorded		4,000
Performance of Equatorial Guinea LNG Operations, S.A.
Loss Contingencies [Line Items]
Guarantor obligations, maximum exposure		91,000
Performance of Alba Plant LLC.
Loss Contingencies [Line Items]
Guarantor obligations, maximum exposure		25,000
Accounts payable
Loss Contingencies [Line Items]
Contingent royalty liability		138,000
Other current liabilities
Loss Contingencies [Line Items]
Contingent royalty liability		$ 15,000

Subsequent Event (Details)

Subsequent Event (Details) - Nov. 02, 2022 - Ensign Natural Resources - Subsequent Event $ in Billions	USD ($) a	Total	well	bbl / d	bbl / h
Subsequent Event [Line Items]
Expected price of acquisition | $	$ 3
Assets acquired, net proved and unproved acres | a	130,000
Assets acquired, average working interest, percent		97%
Asset acquisition, number of wells acquired | well			700
Asset acquisition, estimated current production				67,000	22,000