Marathon Oil (MRO) 10-Q 7 Nov 19 2019 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Oct. 31, 2019
Document and Entity Information [Abstract]
Title of 12(b) Security	Common Stock, par value $1.00
Document Type	10-Q
Entity File Number	1-1513
Entity Incorporation, State or Country Code	DE
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2019
Document Fiscal Period Focus	Q3
Document Fiscal Year Focus	2019
Amendment Flag	false
Entity Registrant Name (tagged on cover)	Marathon Oil Corporation
Entity Address, Address Line One	5555 San Felipe Street,
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77056-2723
City Area Code	(713)
Local Phone Number	629-6600
Trading Symbol	MRO
Security Exchange Name	NYSE
Entity Central Index Key	0000101778
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		799,928,541
Document Transition Report	false
Entity Current Reporting Status	Yes
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Small Business	false
Entity Tax Identification Number	25-0996816
Entity Interactive Data Current	Yes

Consolidated Statements of Inco

Consolidated Statements of Income (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenues and other income:
Revenues from contracts with customers	$ 1,249	$ 1,538	$ 3,830	$ 4,522
Net gain (loss) on commodity derivatives	47	(70)	(28)	(324)
Income from equity method investments	21	64	63	161
Net gain on disposal of assets	22	16	56	323
Other income	6	119	54	135
Total revenues and other income	1,345	1,667	3,975	4,817
Costs and expenses:
Production	163	215	543	637
Shipping, handling and other operating	138	152	462	408
Exploration	22	56	107	173
Depreciation, depletion and amortization	622	626	1,781	1,828
Impairments	0	8	24	50
Taxes other than income	81	86	232	215
General and administrative	82	101	263	306
Total costs and expenses	1,108	1,244	3,412	3,617
Income from operations	237	423	563	1,200
Net interest and other	(64)	(58)	(177)	(168)
Other net periodic benefit costs	2	(8)	9	(11)
Income before income taxes	175	357	395	1,021
Provision (benefit) for income taxes	10	103	(105)	315
Net income	$ 165	$ 254	$ 500	$ 706
Net income per share:
Basic	$ 0.21	$ 0.30	$ 0.62	$ 0.83
Per diluted share:
Diluted	$ 0.21	$ 0.30	$ 0.62	$ 0.83
Weighted average common shares outstanding:
Basic	802	848	813	852
Diluted	803	849	813	853

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Statement of Comprehensive Income [Abstract]
Net income	$ 165	$ 254	$ 500	$ 706
Postretirement and postemployment plans:
Change in actuarial gain (loss) in postretirement and postemployment plans	77	20	64	37
Income tax provision	39	0	39	0
Postretirement and postemployment plans, net of tax	38	20	25	37
Foreign currency translation:
Foreign currency translation adjustment related to sale of U.K. business	30	0	30	0
Income tax provision	(7)	0	(7)	0
Foreign currency translation, net of tax	23	0	23	0
Other, net of tax	1	0	1	4
Other comprehensive income	62	20	49	41
Comprehensive income	$ 227	$ 274	$ 549	$ 747

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 1,165	$ 1,462
Receivables, less reserve of $12 and $11	1,148	1,079
Inventories	71	96
Other current assets	136	257
Current assets held for sale	0	27
Total current assets	2,520	2,921
Equity method investments	667	745
Property, plant and equipment, less accumulated depreciation, depletion and amortization of $17,366 and $21,830	16,717	16,804
Goodwill	95	97
Other noncurrent assets	374	723
Noncurrent assets held for sale	0	31
Total assets	20,373	21,321
Current liabilities:
Accounts payable	1,374	1,320
Payroll and benefits payable	92	154
Accrued taxes	86	181
Other current liabilities	227	170
Long-term debt due within one year	600	0
Current liabilities held for sale	0	7
Total current liabilities	2,379	1,832
Long-term debt	4,903	5,499
Deferred tax liabilities	183	199
Defined benefit postretirement plan obligations	174	195
Asset retirement obligations	198	1,081
Deferred credits and other liabilities	265	279
Noncurrent liabilities held for sale	0	108
Total liabilities	8,102	9,193
Commitments and contingencies
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, 2019 and December 31, 2018)	937	937
Held in treasury, at cost – 136 million shares and 118 million shares	(4,028)	(3,816)
Additional paid-in capital	7,197	7,238
Retained earnings	8,053	7,706
Accumulated other comprehensive income	112	63
Total stockholders’ equity	12,271	12,128
Total liabilities and stockholders’ equity	$ 20,373	$ 21,321

Consolidated Balance Sheets (_2

Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Statement of Financial Position [Abstract]
Receivables, less reserve of $12 and $11	$ 12	$ 11
Property, plant and equipment, less accumulated depreciation, depletion and amortization of $17,366 and $21,830	$ (17,366)	$ (21,830)
Preferred stock, no par value	$ 0	$ 0
Preferred stock shares authorized	26,000,000	26,000,000
Preferred stock shares issued	0	0
Preferred stock shares outstanding	0	0
Common stock, par value per share	$ 1	$ 1
Common stock shares authorized	1,925,000,000	1,925,000,000
Common stock, shares issued	937,000,000	937,000,000
Held in treasury, shares	136,000,000	118,000,000

Consolidated Statements of Cash

Consolidated Statements of Cash Flows (Unaudited) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)
Statement of Cash Flows [Abstract]
Net income	$ 500	$ 706
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	1,781	1,828
Impairments	24	50
Exploratory dry well costs and unproved property impairments	85	144
Net gain on disposal of assets	(56)	(323)
Deferred income taxes	(34)	62
Net loss on derivative instruments	28	324
Net settlements of derivative instruments	41	(255)
Pension and other post retirement benefits, net	(51)	(60)
Stock-based compensation	45	44
Equity method investments, net	26	42
Changes in:
Current receivables	(99)	(389)
Inventories	4	(11)
Current accounts payable and accrued liabilities	(164)	334
Other current assets and liabilities	108	0
All other operating, net	(189)	(117)
Net Cash Provided by (Used in) Operating Activities	2,049	2,379
Investing activities:
Additions to property, plant and equipment	(1,934)	(2,069)
Additions to other assets	41	(135)
Acquisitions, net of cash acquired	0	(25)
Disposal of assets, net of cash transferred to the buyer	(84)	1,249
Equity method investments - return of capital	51	48
All other investing, net	2	11
Net cash used in investing activities	(1,924)	(921)
Financing activities:
Purchases of common stock	(296)	(349)
Dividends paid	(122)	(128)
All other financing, net	(4)	22
Net cash used in financing activities	(422)	(455)
Effect of exchange rate on cash and cash equivalents	0	(2)
Net increase (decrease) in cash and cash equivalents	(297)	1,001
Cash and cash equivalents at beginning of period		$ 563
Cash and cash equivalents at end of period	1,165
Cash and cash equivalents	$ 1,165

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 (Loss)
Beginning balance at Dec. 31, 2017	$ 11,708	$ 0	$ 937	$ (3,325)	$ 7,379	$ 6,779	$ (62)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock-based compensation	65			158	(93)
Shares repurchased	(8)			(8)
Stock-based compensation	(49)				(49)
Net income	356					356
Other comprehensive income (loss)	4						4
Dividends paid (per share amount of $0.05)	(42)					(42)
Ending balance at Mar. 31, 2018	12,034	0	937	(3,175)	7,237	7,093	(58)
Beginning balance at Dec. 31, 2017	11,708	0	937	(3,325)	7,379	6,779	(62)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	706
Other comprehensive income (loss)	41
Ending balance at Sep. 30, 2018	12,044	0	937	(3,455)	7,226	7,357	(21)
Beginning balance at Mar. 31, 2018	12,034	0	937	(3,175)	7,237	7,093	(58)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock-based compensation	25			40	(15)
Shares repurchased	(2)			(2)
Stock-based compensation	5				5
Net income	96					96
Other comprehensive income (loss)	17						17
Dividends paid (per share amount of $0.05)	(43)					(43)
Ending balance at Jun. 30, 2018	12,132	0	937	(3,137)	7,227	7,146	(41)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock-based compensation	14			21	(7)
Shares repurchased	(339)			(339)
Stock-based compensation	6				6
Net income	254					254
Other comprehensive income (loss)	20						20
Dividends paid (per share amount of $0.05)	(43)					(43)
Ending balance at Sep. 30, 2018	12,044	0	937	(3,455)	7,226	7,357	(21)
Beginning balance at Dec. 31, 2018	12,128	0	937	(3,816)	7,238	7,706	63
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Cumulative Effect on Retained Earnings, Net of Tax	(31)					(31)
Shares issued - stock-based compensation	62			101	(39)
Shares repurchased	(30)			(30)
Stock-based compensation	(50)				(50)
Net income	174					174
Other comprehensive income (loss)	(4)						(4)
Dividends paid (per share amount of $0.05)	(41)					(41)
Ending balance at Mar. 31, 2019	12,208	0	937	(3,745)	7,149	7,808	59
Beginning balance at Dec. 31, 2018	12,128	0	937	(3,816)	7,238	7,706	63
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	500
Other comprehensive income (loss)	49
Ending balance at Sep. 30, 2019	12,271	0	937	(4,028)	7,197	8,053	112
Beginning balance at Mar. 31, 2019	12,208	0	937	(3,745)	7,149	7,808	59
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock-based compensation	2			(3)	5
Shares repurchased	(236)			(236)
Stock-based compensation	16				16
Net income	161					161
Other comprehensive income (loss)	(9)						(9)
Dividends paid (per share amount of $0.05)	(41)					(41)
Ending balance at Jun. 30, 2019	12,101	0	937	(3,984)	7,170	7,928	50
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock-based compensation	(5)			(14)	9
Shares repurchased	(30)			(30)
Stock-based compensation	18				18
Net income	165					165
Other comprehensive income (loss)	62						62
Dividends paid (per share amount of $0.05)	(40)					(40)
Ending balance at Sep. 30, 2019	$ 12,271	$ 0	$ 937	$ (4,028)	$ 7,197	$ 8,053	$ 112

Consolidated Statements of St_2

Consolidated Statements of Stockholders' Equity (Unaudited) (Parenthetical) - $ / shares	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018
Statement of Stockholders' Equity [Abstract]
Dividends paid (in dollars per share)	$ 0.05	$ 0.05	$ 0.05	$ 0.05	$ 0.05	$ 0.05	$ 0.15	$ 0.15

Basis of Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 2019
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 2018 Annual Report on Form 10-K. The results of operations for the third quarter and first nine months of 2019 are not necessarily indicative of the results to be expected for the full year. Reclassifications

Accounting Standards

Accounting Standards	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
Accounting Standards	Accounting Standards Not Yet Adopted Financial instruments – credit losses In June 2016, the FASB issued a new accounting standards update that changes the impairment model for trade receivables, net investments in leases, debt securities, loans and certain other instruments. The standard requires the use of a forward-looking “expected loss” model as opposed to the current “incurred loss” model. This standard is effective for us in the first quarter of 2020 and will be adopted on a modified retrospective basis through a cumulative-effect adjustment to retained earnings as of the beginning of the adoption period. We continue to evaluate the provisions of this accounting standards update and do not expect a material impact on our consolidated results of operations, financial position and cash flows. Recently Adopted Lease accounting standard In February 2016, the FASB issued a new leasing accounting standard, which modified the definition of a lease and established comprehensive accounting and financial reporting requirements for leasing arrangements. It requires lessees to recognize a lease liability and a right-of-use (“ROU”) asset for all leases, including operating leases, with a term of greater than 12 months on the balance sheet. On January 1, 2019, we adopted the new lease accounting standard using the modified retrospective method and applied to all leases that existed as of that date. It does not apply to leases to explore for or use minerals, oil, natural gas and similar non-regenerative resources, including the intangible right to explore for those natural resources and rights to use the land in which those natural resources are contained. The new lease standard requires certain accounting policy decisions while also providing a number of optional practical expedients for transition accounting. Our accounting policies and the practical expedients utilized are summarized below: • Implemented an accounting policy to not recognize any right-of-use assets and lease liabilities related to short-term leases on the balance sheet. • Implemented an accounting policy to not separate the lease and nonlease components for all asset classes, except for vessels. • Elected the package of practical expedients which allows us to not reassess our prior conclusions regarding the lease identification and lease classification for contracts that commenced or expired prior to the effective date. • Elected the practical expedient pertaining to land easements which allows us to continue accounting for existing agreements under the previous accounting policies as nonlease transactions. Any modifications of existing contracts or new agreements will be assessed under the new lease accounting guidance and may become leases in the future. As a result of the adoption, we recorded a cumulative-effect adjustment to stockholders’ equity on the date of adoption of $31 million . We continue presenting all prior comparative periods without any restatements. Hedge accounting standard In August 2017, the FASB issued a new accounting standards update that amends the hedge accounting model to enable entities to hedge certain financial and nonfinancial risk attributes previously not allowed. The amendment also reduces the overall complexity of documenting, assessing and measuring hedge effectiveness. This standard was effective for us in the first quarter of 2019. Adoption of this standard did not have a significant impact on our consolidated results of operations, financial position or cash flows.

Income (Loss) and Dividends per

Income (Loss) and Dividends per Common Share	9 Months Ended
	Sep. 30, 2019
Earnings Per Share [Abstract]
Income (Loss) 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 6 million and 5 million of stock options for the three and nine months ended September 30, 2019 , and 5 million and 6 million of stock options for the three and nine months ended September 30, 2018 , that were antidilutive. Three Months Ended September 30, Nine Months Ended September 30, (In millions, except per share data) 2019 2018 2019 2018 Net income $ 165 $ 254 $ 500 $ 706 Weighted average common shares outstanding 802 848 813 852 Effect of dilutive securities 1 1 — 1 Weighted average common shares, diluted 803 849 813 853 Net income per share: Basic $ 0.21 $ 0.30 $ 0.62 $ 0.83 Diluted $ 0.21 $ 0.30 $ 0.62 $ 0.83 Dividends per share $ 0.05 $ 0.05 $ 0.15 $ 0.15

Acquisitions (Notes)

Acquisitions (Notes)	9 Months Ended
	Sep. 30, 2019
Acquisitions [Abstract]
Business Combination Disclosure [Text Block]	Acquisitions In the fourth quarter of 2019, we entered into agreements to acquire approximately 40,000 net acres in a Texas Delaware oil play in West Texas for $106 million , subject to closing adjustments. These transactions are expected to close later this year. During the fourth quarter of 2019, we entered into an agreement to purchase approximately 18,000 net acres in the Eagle Ford for $185 million , subject to closing adjustments. This transaction is expected to close early 2020.

Dispositions

Dispositions	9 Months Ended
	Sep. 30, 2019
Discontinued Operations and Disposal Groups [Abstract]
Dispositions	Dispositions United States Segment In the second quarter of 2018, we entered into separate agreements to sell non-core, non-operated conventional properties, primarily in the Gulf of Mexico. These transactions closed during the third quarter of 2018. International Segment On July 1, 2019, we closed on the sale of our U.K. business (Marathon Oil U.K. LLC and Marathon Oil West of Shetlands Limited), for proceeds of $95 million which reflects the assumption by RockRose Energy PLC (“RockRose”) of the U.K. business’ working capital and cash equivalent balances of approximately $345 million on December 31, 2018 . During the third quarter of 2019, we recognized a pre-tax gain of $14 million . As of September 30, 2019, we continue to have surety bonds outstanding that guarantee our decommissioning liabilities related to the Marathon Oil U.K. LLC (“MOUK”) assets and recognized a liability and corresponding expense of approximately $6 million related to the estimated fair value of our exposure to these surety bonds (see Note 23 for further detail). Income before taxes relating to our U.K. business for the three months ended September 30, 2019 and 2018, was nil and $132 million ; and for the nine months ended September 30, 2019 and 2018, was $37 million and $239 million . In the second quarter of 2019, we closed on the sale of our 15% non-operated interest in the Atrush block in Kurdistan for proceeds of $63 million , before closing adjustments. This property was classified as held for sale in the consolidated balance sheet at December 31, 2018 , with total assets of $58 million and total liabilities of $17 million . In the first quarter of 2018, we closed on the sale of our subsidiary, Marathon Oil Libya Limited, which held our 16.33% non-operated interest in the Waha concessions in Libya, to a subsidiary of Total S.A. (Elf Aquitaine SAS) for proceeds of approximately $450 million , excluding closing adjustments, and recognized a pre-tax gain of $255 million

Revenues

Revenues	9 Months Ended
	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
Revenues	Revenues The majority of our revenues are derived from the sale of crude oil and condensate, NGLs and natural gas under spot and term agreements with our customers in the United States and various international locations. The following tables present our revenues from contracts with customers disaggregated by product type and geographic areas. United States Three Months Ended September 30, 2019 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 336 $ 452 $ 116 $ 88 $ 25 $ 1,017 Natural gas liquids 23 6 28 5 2 64 Natural gas 28 8 37 3 5 81 Other 1 — — — 9 10 Revenues from contracts with customers $ 388 $ 466 $ 181 $ 96 $ 41 $ 1,172 Three Months Ended September 30, 2018 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 436 $ 447 $ 114 $ 59 $ 34 $ 1,090 Natural gas liquids 70 19 48 12 3 152 Natural gas 36 9 46 6 5 102 Other — — — — 3 3 Revenues from contracts with customers $ 542 $ 475 $ 208 $ 77 $ 45 $ 1,347 Nine Months Ended September 30, 2019 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,004 $ 1,277 $ 304 $ 229 $ 83 $ 2,897 Natural gas liquids 88 31 81 20 5 225 Natural gas 94 26 118 10 15 263 Other 4 — — — 45 49 Revenues from contracts with customers $ 1,190 $ 1,334 $ 503 $ 259 $ 148 $ 3,434 Nine Months Ended September 30, 2018 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,196 $ 1,182 $ 340 $ 173 $ 131 $ 3,022 Natural gas liquids 157 51 130 24 8 370 Natural gas 102 27 127 13 17 286 Other 3 — — — 12 15 Revenues from contracts with customers $ 1,458 $ 1,260 $ 597 $ 210 $ 168 $ 3,693 International Three Months Ended September 30, 2019 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 67 $ — $ — $ 67 Natural gas liquids 1 — — 1 Natural gas 8 — — 8 Revenues from contracts with customers $ 77 $ — $ — $ 77 Three Months Ended September 30, 2018 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 100 $ 41 $ 20 $ 161 Natural gas liquids 1 1 — 2 Natural gas 9 11 — 20 Other — 8 — 8 Revenues from contracts with customers $ 110 $ 61 $ 20 $ 191 Nine Months Ended September 30, 2019 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 215 $ 107 $ 19 $ 341 Natural gas liquids 3 1 — 4 Natural gas 24 12 — 36 Other 1 14 — 15 Revenues from contracts with customers $ 243 $ 134 $ 19 $ 396 Nine Months Ended September 30, 2018 (In millions) E.G. U.K. Libya Other International Total Crude oil and condensate $ 271 $ 207 $ 187 $ 65 $ 730 Natural gas liquids 3 4 — — 7 Natural gas 28 31 9 — 68 Other — 24 — — 24 Revenues from contracts with customers $ 302 $ 266 $ 196 $ 65 $ 829 Contract receivables and liabilities The following table provides information about receivables and contract assets (liabilities) from contracts with customers. (In millions) September 30, 2019 January 1, 2019 Receivables from contracts with customers, included in receivables, less reserves $ 822 $ 714 Contract asset (liability) $ — $ (1 ) The contract liability balance on January 1, 2019 primarily relates to the advance consideration received from customers for crude oil sales and processing services in the U.K. Subsequent to the sale of our U.K. business, we no longer hold this contract liability. Changes in the contract asset (liability) balance during the period are as follows. (In millions) Nine Months Ended September 30, 2019 Contract asset (liability) balance as of January 1, 2019 $ (1 ) Revenue recognized as performance obligations are satisfied 74 Amounts invoiced to customers (52 ) Contract asset (liability) transferred to buyer (a) (21 ) Contract asset (liability) balance as of September 30, 2019 $ — (a) Refer to Note 5 for further information on the sale of our U.K. business.

Segment Information

Segment Information	9 Months Ended
	Sep. 30, 2019
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”) – explores for, 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.”) Information regarding assets by segment is not presented because it is not reviewed by the chief operating decision maker (“CODM”). Segment income represents income which excludes certain items not allocated to our operating segments, net of income taxes. A portion of our corporate and operations general and administrative support costs are not allocated to the operating segments. These unallocated costs primarily consist of employment costs (including pension effects), professional services, facilities and other costs associated with corporate and operations support activities. Additionally, items which affect comparability such as: gains or losses on dispositions, certain property impairments, unrealized gains or losses on commodity derivative instruments, pension settlement losses or other items (as determined by the CODM) are not allocated to operating segments. Three Months Ended September 30, 2019 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 1,172 $ 77 $ — $ 1,249 Net gain (loss) on commodity derivatives 14 — 33 (b) 47 Income from equity method investments — 21 — 21 Net gain on disposal of assets — — 22 (c) 22 Other income 3 2 1 6 Less costs and expenses: Production 147 16 — 163 Shipping, handling and other operating 137 1 — 138 Exploration 22 — — 22 Depreciation, depletion and amortization 589 25 8 622 Taxes other than income 80 — 1 81 General and administrative 34 5 43 82 Net interest and other — — 64 64 Other net periodic benefit costs — — (2 ) (2 ) Income tax provision — 10 — 10 Segment income (loss) $ 180 $ 43 $ (58 ) $ 165 Capital expenditures (a) $ 667 $ 1 $ 7 $ 675 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 14 ). (c) Primarily related to the sale of our U.K. business (See Note 5 ). Three Months Ended September 30, 2018 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 1,347 $ 191 $ — $ 1,538 Net gain (loss) on commodity derivatives (89 ) — 19 (b) (70 ) Income from equity method investments — 64 — 64 Net gain on disposal of assets — — 16 (c) 16 Other income 2 4 113 (d) 119 Less costs and expenses: Production 172 43 — 215 Shipping, handling and other operating 136 16 — 152 Exploration 55 1 — 56 Depreciation, depletion and amortization 571 49 6 626 Impairments — — 8 (e) 8 Taxes other than income 86 — — 86 General and administrative 37 7 57 101 Net interest and other — — 58 58 Other net periodic benefit costs — (3 ) 11 (f) 8 Income tax provision 2 30 71 103 Segment income (loss) $ 201 $ 116 $ (63 ) $ 254 Capital expenditures (a) $ 691 $ 6 $ 7 $ 704 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 14 ). (c) Sales of certain non-core proved properties in our International and United States segments. (d) Reduction of our asset retirement obligation in our International segment (See Note 12 ). (e) Due to the anticipated sale of non-core property in our International segment (See Note 11 ). (f) Includes pension settlement loss of $10 million (See Note 19 ). Nine Months Ended September 30, 2019 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 3,434 $ 396 $ — $ 3,830 Net gain (loss) on commodity derivatives 41 — (69 ) (b) (28 ) Income from equity method investments — 63 — 63 Net gain on disposal of assets — — 56 (c) 56 Other income 8 7 39 (d) 54 Less costs and expenses: Production 433 112 (2 ) 543 Shipping, handling and other operating 424 24 14 462 Exploration 107 — — 107 Depreciation, depletion and amortization 1,664 97 20 1,781 Impairments — — 24 (e) 24 Taxes other than income 233 — (1 ) 232 General and administrative 94 20 149 263 Net interest and other — — 177 177 Other net periodic benefit costs — (3 ) (6 ) (9 ) Income tax provision (benefit) 1 16 (122 ) (f) (105 ) Segment income (loss) $ 527 $ 200 $ (227 ) $ 500 Capital expenditures (a) $ 1,959 $ 16 $ 15 $ 1,990 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 14 ). (c) Primarily related to the sale of our working interest in the Droshky field (Gulf of Mexico) and the sale of our U.K. business (See Note 5 ). (d) Primarily related to the indemnification of certain tax liabilities in connection with the 2010-2011 Federal Tax Audit (See Note 8 ). (e) Primarily a result of anticipated sales of non-core proved properties in our International and United States segments (See Note 11 ). (f) Primarily relates to the settlement of the 2010-2011 Federal Tax Audit (See Note 8 ). Nine Months Ended September 30, 2018 (In millions) U.S. Int’l Not Allocated to Segments Total Revenue from contracts with customers $ 3,693 $ 829 $ — $ 4,522 Net gain (loss) on commodity derivatives (255 ) — (69 ) (b) (324 ) Income from equity method investments — 161 — 161 Net gain on disposal of assets — — 323 (c) 323 Other income 7 7 121 (d) 135 Less costs and expenses: Production 476 162 (1 ) 637 Shipping, handling and other operating 364 45 (1 ) 408 Exploration 170 3 — 173 Depreciation, depletion and amortization 1,655 153 20 1,828 Impairments — — 50 (e) 50 Taxes other than income 218 — (3 ) 215 General and administrative 108 25 173 306 Net interest and other — — 168 168 Other net periodic benefit costs — (7 ) 18 (f) 11 Income tax provision 5 226 84 315 Segment income (loss) $ 449 $ 390 $ (133 ) $ 706 Capital expenditures (a) $ 1,943 $ 28 $ 17 $ 1,988 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 14 ). (c) Primarily related to the gain on sale of our Libya subsidiary (See Note 5 ). (d) Reduction of our asset retirement obligation in our International segment (See Note 12 ). (e) Due to the anticipated sales of certain non-core proved properties in our International and United States segments (See Note 11 ). (f) Includes pension settlement loss of $16 million (See Note 19 ).

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2019
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 7 . For the three and nine months ended September 30, 2019 and 2018 , our effective income tax rates were as follows: Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 Effective income tax expense (benefit) rate (a) 6 % 29 % (27 )% 31 % (a) In all periods presented, we maintained our valuation allowance on our net federal deferred tax assets in the U.S. The following items caused the effective income tax rates to be different from our U.S. statutory tax rate of 21% for 2019 and 2018 : • Income taxes for the third quarter of 2019 were impacted by the income mix between domestic and international operations. Income taxes for the nine months ended September 30, 2019 were impacted by the settlement of the 2010-2011 U.S. Federal Tax Audit (“IRS Audit”) in the first quarter of 2019, resulting in a tax benefit of $126 million . Additionally, in the first quarter of 2019, we recorded a non-cash deferred tax benefit of $18 million in the U.K. related to an internal restructuring. These two items are discrete to the first nine months of 2019 . Excluding these discrete adjustments, the effective income tax rate for the first nine months of 2019 was an expense of 10% . • Income taxes for the third quarter of 2018 were impacted by deferred tax expense in the U.K. During the nine months ended September 30, 2018 , income taxes were impacted by the tax expense in Libya of $162 million . As a result of the IRS Audit settlement in the first quarter of 2019, the uncertain tax positions previously established are now effectively settled. The release of the accrued uncertain tax positions resulted in a $126 million tax benefit, primarily related to the additional alternative minimum tax (“AMT”) credits, see Note 23 for further detail. Pursuant to the Tax Sharing Agreement we entered into with Marathon Petroleum Corporation (“MPC”) in connection with the 2011 spin-off transaction, MPC agreed to indemnify us for certain liabilities. In addition to the benefit from the settlement of the IRS Audit in the first quarter of 2019, we recorded a current receivable and other income of $42 million for indemnity payments due from MPC for tax expense and interest we had previously recognized. The indemnity relates to tax and interest allocable to MPC as a result of the IRS Audit. During the second quarter of 2019, we paid the IRS and were subsequently reimbursed by MPC for settlement of their indemnity obligation. During the first quarter of 2019, we withdrew our appeal related to the Brae area decommissioning costs in the U.K., thus the uncertain tax positions previously established are now considered effectively settled with no tax expense or benefit impact.

Inventories

Inventories	9 Months Ended
	Sep. 30, 2019
Inventory Disclosure [Abstract]
Inventories	Inventories Crude oil and natural gas are recorded at weighted average cost and carried at the lower of cost or net realizable value. Supplies and other items consist principally of tubular goods and equipment which are valued at weighted average cost and reviewed periodically for obsolescence or impairment when market conditions indicate. (In millions) September 30, 2019 December 31, 2018 Crude oil and natural gas $ 9 $ 11 Supplies and other items 62 85 Inventories $ 71 $ 96

Property, Plant and Equipment,

Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization	9 Months Ended
	Sep. 30, 2019
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization	Property, Plant and Equipment (In millions) September 30, 2019 December 31, 2018 United States $ 16,127 $ 16,011 International 512 710 Corporate 78 83 Net property, plant and equipment $ 16,717 $ 16,804 We had no exploratory well costs capitalized greater than one year as of September 30, 2019 and December 31, 2018 .

Impairments

Impairments	9 Months Ended
	Sep. 30, 2019
Impairment Expense [Abstract]
Impairments	Impairments The following table summarizes impairment charges of proved properties. Additionally, it presents the values of assets, by major category, measured at fair value on a nonrecurring basis in periods subsequent to their initial recognition. Three Months Ended September 30, 2019 2018 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ — $ — $ 39 $ 8 Nine Months Ended September 30, 2019 2018 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 56 $ 24 $ 108 $ 50 • 2019 – During the nine months ended September 30, 2019 , we recorded pre-tax non-cash proved property impairments of $24 million , primarily as a result of anticipated sales for certain non-core proved properties in our United States segment and the sale of our non-operated interest in the Atrush block (Kurdistan) in our International segment. The related fair value was measured using the market approach, based upon anticipated sales proceeds less costs to sell which resulted in a Level 2 classification. See Note 5 for further detail. • 2018 – During the nine months ended September 30, 2018 , we recorded pre-tax non-cash proved property impairments of $50 million , to a fair value of $108 million

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2019
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 for the nine months ended were as follows: September 30, (In millions) 2019 2018 Beginning balance $ 1,145 $ 1,483 Incurred liabilities, including acquisitions 25 10 Settled liabilities, including dispositions (1,106 ) (105 ) Accretion expense (included in depreciation, depletion and amortization) 29 53 Revisions of estimates 15 (130 ) Held for sale 108 (10 ) Ending balance $ 216 $ 1,301 September 30, 2019 • Settled liabilities primarily relates to the sale of our U.K. business, which closed during the third quarter of 2019. • Held for sale reflects a transfer to settled liabilities during 2019. This transfer was primarily related to the Droshky field (Gulf of Mexico), which was considered held for sale at year-end 2018 and closed in the first quarter of 2019. • Ending balance includes $18 million classified as short-term at September 30, 2019 . September 30, 2018 • Settled liabilities primarily relate to the sale of non-core, non-operated conventional properties in the Gulf of Mexico as well as retirements in the U.K. See Note 5 for discussion of these divestitures in further detail. • Revisions of estimates were primarily due to the acceleration of U.K. abandonment activities to capture favorable market conditions and lower estimated abandonment costs. • Ending balance includes $58 million classified as short-term at September 30, 2018 .

Leases

Leases	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Leases	Leases Supplemental balance sheet information related to leases was as follows: (In millions) September 30, 2019 Operating Leases: Balance Sheet Location: ROU asset Other noncurrent assets $ 226 Current portion of long-term lease liability Other current liabilities $ 104 Long-term lease liability Deferred credits and other liabilities $ 127 In determining our ROU assets and long-term lease liabilities, the new lease standard requires certain accounting policy decisions, while also providing a number of optional practical expedients for transition accounting. Our accounting policies and the practical expedients utilized are summarized below: • Implemented an accounting policy to not recognize any right-of-use assets and lease liabilities related to short-term leases on the balance sheet. • Implemented an accounting policy to not separate the lease and nonlease components for all asset classes, except for vessels. • Elected the package of practical expedients which allows us to not reassess our prior conclusions regarding the lease identification and lease classification for contracts that commenced or expired prior to the effective date. • Elected the practical expedient pertaining to land easements which allows us to continue accounting for existing agreements under the previous accounting policies as nonlease transactions. Any modifications of existing contracts or new agreements will be assessed under the new lease accounting guidance and may become leases in the future. We enter into various lease agreements to support our operations including drilling rigs, well fracturing equipment, compressors, buildings, aircraft, vessels, vehicles and miscellaneous field equipment. We primarily act as a lessee in these transactions and all of our existing leases are classified as either short-term or long-term operating leases. The majority of the drilling rig agreements and all of fracturing equipment agreements are classified as short-term leases based on the noncancellable period for which we have the right to use the equipment and assessment of options present in each agreement. We also incur variable lease costs under these agreements primarily related to chemicals and sand used in fracturing operations or various additional on-demand equipment and labor. The lease costs associated with the drilling rigs and fracturing equipment are primarily capitalized as part of the well costs. Our long-term leases are comprised of compressors, buildings, drilling rigs, aircraft, vessels, vehicles and miscellaneous field equipment. Our lease agreements may require both fixed and variable payments; none of the variable payments are rate or index-based, therefore only fixed payments were considered for recognizing lease liabilities and ROU assets related to long-term leases. Also, based on our election not to separate the lease and nonlease components, fixed payments related to equipment, crew and other nonlease components are included in the initial measurement of lease liabilities and ROU assets for all asset classes, except for vessels. For vessels, the contractual consideration was allocated between lease and nonlease components based on estimates provided by service providers. Our leased assets may be used in joint oil and gas operations with other working interest owners. We recognize lease liabilities and ROU assets only when we are the signatory to a contract as an operator of joint properties. Such lease liabilities and ROU assets are determined based on gross contractual obligations. As we use the leased assets for joint operations, we have the contractual right to recover the other working interest owners’ share of lease costs. As a result, our lease costs are presented on a net basis, reduced for any costs recoverable from other working interest owners. The table below presents our net lease costs as of September 30, 2019 with the majority of operating lease costs expensed as incurred, while the majority of the short-term and variable term lease costs are capitalized into property, plant and equipment. (In millions) Three Months Ended September 30, 2019 Nine Months Ended September 30, 2019 Lease costs: Operating lease costs (a) $ 21 $ 61 Short-term lease costs (b) 94 251 Variable lease costs (c) 24 96 Total lease costs $ 139 $ 408 Other information: Cash paid for amounts included in the measurement of operating lease liabilities $ 71 ROU assets obtained in exchange for new operating lease liabilities (d) 296 (a) Represents our net share of the ROU asset amortization and the interest expense. (b) Represents our net share of lease costs arising from leases of less than one year but longer than one month that were not included in the lease liability. (c) Represents our net share of variable lease payments that were not included in the lease liability. (d) Represents the cumulative value of ROU assets recognized at lease inception during the first nine months of 2019 . This amount is then amortized as we utilize the ROU asset, the net effect of which is the ending ROU asset of $226 million (first table above). We use our periodic incremental borrowing rate to discount future contractual payments to their present values. The weighted average lease term and the discount rate relevant to long-term leases were three years and 4% as of September 30, 2019 . The remaining annual undiscounted cash flows associated with long-term leases and the reconciliation of these cash flows to the lease liabilities recognized on the consolidated balance sheet is summarized below. (In millions) Operating Lease Obligations 2019 $ 35 2020 107 2021 62 2022 34 2023 4 Thereafter 1 Total undiscounted lease payments $ 243 Less: amount representing interest 12 Total operating lease liabilities $ 231 Less: current portion of long-term lease liability as of September 30, 2019 104 Long-term lease liability as of September 30, 2019 $ 127 At December 31, 2018 , future minimum commitments under the previous accounting standard, ASC 840, for operating lease obligations having noncancellable lease terms in excess of one year were as follows: (In millions) Operating Lease Obligations 2019 $ 62 2020 54 2021 35 2022 12 2023 5 Thereafter 49 Sublease rentals — Total minimum lease payments $ 217 * Future minimum commitments for capital lease obligations were nil as of December 31, 2018 . Our wholly-owned subsidiary, Marathon E.G. Production Limited, is a lessor for residential housing in Equatorial Guinea, which is occupied by EGHoldings, a related party equity method investee – see Note 22 . 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 2019 $ 2 2020 6 2021 6 2022 6 2023 6 Thereafter 67 Total undiscounted cash flows $ 93 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 new Houston office location is expected to be completed in 2021. The lessor and other participants are providing financing for up to $380 million , to fund the estimated project costs. As of September 30, 2019 , project costs incurred totaled approximately $54 million , primarily for land acquisition and initial design costs. The initial lease term is five years and will commence once construction is substantially complete and the new Houston office is ready for occupancy. 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 approximately 89%
Leases	Leases Supplemental balance sheet information related to leases was as follows: (In millions) September 30, 2019 Operating Leases: Balance Sheet Location: ROU asset Other noncurrent assets $ 226 Current portion of long-term lease liability Other current liabilities $ 104 Long-term lease liability Deferred credits and other liabilities $ 127 In determining our ROU assets and long-term lease liabilities, the new lease standard requires certain accounting policy decisions, while also providing a number of optional practical expedients for transition accounting. Our accounting policies and the practical expedients utilized are summarized below: • Implemented an accounting policy to not recognize any right-of-use assets and lease liabilities related to short-term leases on the balance sheet. • Implemented an accounting policy to not separate the lease and nonlease components for all asset classes, except for vessels. • Elected the package of practical expedients which allows us to not reassess our prior conclusions regarding the lease identification and lease classification for contracts that commenced or expired prior to the effective date. • Elected the practical expedient pertaining to land easements which allows us to continue accounting for existing agreements under the previous accounting policies as nonlease transactions. Any modifications of existing contracts or new agreements will be assessed under the new lease accounting guidance and may become leases in the future. We enter into various lease agreements to support our operations including drilling rigs, well fracturing equipment, compressors, buildings, aircraft, vessels, vehicles and miscellaneous field equipment. We primarily act as a lessee in these transactions and all of our existing leases are classified as either short-term or long-term operating leases. The majority of the drilling rig agreements and all of fracturing equipment agreements are classified as short-term leases based on the noncancellable period for which we have the right to use the equipment and assessment of options present in each agreement. We also incur variable lease costs under these agreements primarily related to chemicals and sand used in fracturing operations or various additional on-demand equipment and labor. The lease costs associated with the drilling rigs and fracturing equipment are primarily capitalized as part of the well costs. Our long-term leases are comprised of compressors, buildings, drilling rigs, aircraft, vessels, vehicles and miscellaneous field equipment. Our lease agreements may require both fixed and variable payments; none of the variable payments are rate or index-based, therefore only fixed payments were considered for recognizing lease liabilities and ROU assets related to long-term leases. Also, based on our election not to separate the lease and nonlease components, fixed payments related to equipment, crew and other nonlease components are included in the initial measurement of lease liabilities and ROU assets for all asset classes, except for vessels. For vessels, the contractual consideration was allocated between lease and nonlease components based on estimates provided by service providers. Our leased assets may be used in joint oil and gas operations with other working interest owners. We recognize lease liabilities and ROU assets only when we are the signatory to a contract as an operator of joint properties. Such lease liabilities and ROU assets are determined based on gross contractual obligations. As we use the leased assets for joint operations, we have the contractual right to recover the other working interest owners’ share of lease costs. As a result, our lease costs are presented on a net basis, reduced for any costs recoverable from other working interest owners. The table below presents our net lease costs as of September 30, 2019 with the majority of operating lease costs expensed as incurred, while the majority of the short-term and variable term lease costs are capitalized into property, plant and equipment. (In millions) Three Months Ended September 30, 2019 Nine Months Ended September 30, 2019 Lease costs: Operating lease costs (a) $ 21 $ 61 Short-term lease costs (b) 94 251 Variable lease costs (c) 24 96 Total lease costs $ 139 $ 408 Other information: Cash paid for amounts included in the measurement of operating lease liabilities $ 71 ROU assets obtained in exchange for new operating lease liabilities (d) 296 (a) Represents our net share of the ROU asset amortization and the interest expense. (b) Represents our net share of lease costs arising from leases of less than one year but longer than one month that were not included in the lease liability. (c) Represents our net share of variable lease payments that were not included in the lease liability. (d) Represents the cumulative value of ROU assets recognized at lease inception during the first nine months of 2019 . This amount is then amortized as we utilize the ROU asset, the net effect of which is the ending ROU asset of $226 million (first table above). We use our periodic incremental borrowing rate to discount future contractual payments to their present values. The weighted average lease term and the discount rate relevant to long-term leases were three years and 4% as of September 30, 2019 . The remaining annual undiscounted cash flows associated with long-term leases and the reconciliation of these cash flows to the lease liabilities recognized on the consolidated balance sheet is summarized below. (In millions) Operating Lease Obligations 2019 $ 35 2020 107 2021 62 2022 34 2023 4 Thereafter 1 Total undiscounted lease payments $ 243 Less: amount representing interest 12 Total operating lease liabilities $ 231 Less: current portion of long-term lease liability as of September 30, 2019 104 Long-term lease liability as of September 30, 2019 $ 127 At December 31, 2018 , future minimum commitments under the previous accounting standard, ASC 840, for operating lease obligations having noncancellable lease terms in excess of one year were as follows: (In millions) Operating Lease Obligations 2019 $ 62 2020 54 2021 35 2022 12 2023 5 Thereafter 49 Sublease rentals — Total minimum lease payments $ 217 * Future minimum commitments for capital lease obligations were nil as of December 31, 2018 . Our wholly-owned subsidiary, Marathon E.G. Production Limited, is a lessor for residential housing in Equatorial Guinea, which is occupied by EGHoldings, a related party equity method investee – see Note 22 . 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 2019 $ 2 2020 6 2021 6 2022 6 2023 6 Thereafter 67 Total undiscounted cash flows $ 93 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 new Houston office location is expected to be completed in 2021. The lessor and other participants are providing financing for up to $380 million , to fund the estimated project costs. As of September 30, 2019 , project costs incurred totaled approximately $54 million , primarily for land acquisition and initial design costs. The initial lease term is five years and will commence once construction is substantially complete and the new Houston office is ready for occupancy. 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 approximately 89%

Derivatives

Derivatives	9 Months Ended
	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives For further information regarding the fair value measurement of derivative instruments, see Note 15 . 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, 2019 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ 58 $ 5 $ 53 Other current assets Commodity 6 — 6 Other noncurrent assets Commodity — 1 (1 ) Deferred credits and other liabilities Total Not Designated as Hedges $ 64 $ 6 $ 58 Cash Flow Hedges Interest Rate $ — $ 1 $ (1 ) Deferred credits and other liabilities Total Designated Hedges $ — $ 1 $ (1 ) Total $ 64 $ 7 $ 57 December 31, 2018 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ 131 $ — $ 131 Other current assets Commodity — 4 (4 ) Deferred credits and other liabilities Total Not Designated as Hedges $ 131 $ 4 $ 127 Derivatives Not Designated as Hedges We have entered into multiple crude oil derivatives indexed to the respective indices as noted in the table below, related to a portion of our forecasted United States sales through 2021 . These derivatives consist of three-way collars, basis swaps 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. These crude oil derivatives were not designated as hedges. The following table sets forth outstanding derivative contracts as of September 30, 2019 , and the weighted average prices for those contracts: 2019 2020 2021 Crude Oil Fourth Quarter Full Year Full Year NYMEX WTI Three-Way Collars Volume (Bbls/day) 80,000 42,945 — Weighted average price per Bbl: Ceiling $ 74.19 $ 65.58 $ — Floor $ 56.75 $ 55.00 $ — Sold put $ 49.50 $ 47.77 $ — Basis Swaps - Argus WTI Midland (a) Volume (Bbls/day) 15,000 15,000 — Weighted average price per Bbl $ (1.40 ) $ (0.94 ) $ — Basis Swaps - Net Energy Clearbrook (b) Volume (Bbls/day) 2,000 — — Weighted average price per Bbl $ (3.33 ) $ — $ — Basis Swaps - NYMEX WTI / ICE Brent (c) Volume (Bbls/day) 5,000 5,000 808 Weighted average price per Bbl $ (7.24 ) $ (7.24 ) $ (7.24 ) Basis Swaps - Argus WTI Houston (d) Volume (Bbls/day) 10,000 — — Weighted average price per Bbl $ 5.51 $ — $ — NYMEX Roll Basis Swaps Volume (Bbls/day) 60,000 — — Weighted average price per Bbl $ 0.38 $ — $ — (a) The basis differential price is indexed against Argus WTI Midland. (b) The basis differential price is indexed against Net Energy Canada Bakken SW at Clearbrook (“UHC”). (c) The basis differential price is indexed against International Commodity Exchange (“ICE”) Brent and NYMEX WTI. (d) The basis differential price is indexed against Argus WTI Houston. Between October 1, 2019 and November 5, 2019 , we entered into 100,000 MMBtu/day of three-way collars for January - March 2020 with a ceiling price of $3.32 , a floor price of $2.75 and a sold put price of $2.25 . The mark-to-market impact and settlement of the commodity derivative instruments as of September 30, 2019 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) 2019 2018 2019 2018 Mark-to-market gain (loss) $ 33 $ 19 $ (69 ) $ (69 ) Net settlements of commodity derivative instruments $ 14 $ (89 ) $ 41 $ (255 ) Derivatives Designated as Cash Flow Hedges In September 2019 , we entered into forward starting interest rate swaps with a total notional amount of $160 million to hedge variations in cash flows related to the 1-month London Interbank Offered Rate (“LIBOR”) component of future lease payments of our future Houston office. These swaps will settle monthly on the same day the lease payment is made with the first swap settlement occurring in January 2022. We expect the first lease payment to commence sometime in the period from December 2021 to May 2022. The last swap will mature on September 9, 2026. See Note 13 for further details regarding the lease of the new Houston office. The following table presents information about our interest rate swap agreements, including the weighted average LIBOR-based, fixed rate. September 30, 2019 December 31, 2018 (In millions, except fixed rates) Aggregate Notional Amount Weighted Average, LIBOR Aggregate Notional Amount Weighted Average, LIBOR Interest rate swaps $ 160 1.50 % $ — — % At September 30, 2019, accumulated other comprehensive income included deferred losses of $1 million related to forward starting interest rate swaps. No amounts related to these swaps are expected to impact the consolidated statements of income in the next 12 months.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2019
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, 2019 and December 31, 2018 by hierarchy level. September 30, 2019 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ — $ 61 $ — $ 61 Derivative instruments, assets $ — $ 61 $ — $ 61 Derivative instruments, liabilities Commodity (a) $ (3 ) $ — $ — $ (3 ) Interest rate $ — $ (1 ) $ — $ (1 ) Derivative instruments, liabilities $ (3 ) $ (1 ) $ — $ (4 ) (a) Derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 14 . December 31, 2018 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ 21 $ 106 $ — $ 127 Derivative instruments, assets $ 21 $ 106 $ — $ 127 Derivative instruments, liabilities Derivative instruments, liabilities $ — $ — $ — $ — (a) Derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 14 . Commodity derivatives include three-way collars, basis swaps and NYMEX roll basis swaps. These instruments are measured at fair value using either a Black-Scholes or a modified Black-Scholes Model. For basis swaps and NYMEX roll basis 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, 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 14 for detail on the forward starting interest rate swaps. Fair Value Estimates - Goodwill As of September 30, 2019 , our consolidated balance sheet included goodwill of $95 million . Goodwill is tested for impairment on an annual basis, or between annual tests when events or changes in circumstances indicate the fair value may have been reduced below its carrying value. Goodwill is tested for impairment at the reporting unit level. Our reporting units are the same as our reporting segments, of which only the International reporting unit includes goodwill. Our policy is to first assess the qualitative factors in order to determine whether the fair value of our International reporting unit is more likely than not less than its carrying amount. Certain qualitative factors used in our evaluation include, among other things, the results of the most recent quantitative assessment of goodwill (second quarter of 2017 ); macroeconomic conditions; industry and market conditions (including commodity prices and cost factors); overall financial performance; and other relevant entity-specific events. If, after considering these events and circumstances we determine that it is more likely than not the fair value of the International reporting unit is less than its carrying amount, the quantitative goodwill test is performed. During the second quarter of 2019 , we performed our annual impairment test of goodwill using the qualitative assessment. Our qualitative assessment considered the significant excess fair value over carrying value in our most recent step one test and noted there are more positive/neutral indicators than negative. After assessing the totality of these qualitative factors, our assessment did not indicate that it is more likely than not that the fair value is less than its carrying value. As a result, we concluded that no impairment to goodwill was required for our International reporting unit. Fair Values – Nonrecurring For detail on our fair values for nonrecurring items see Note 5 , for detail related to an outstanding guarantee related to our U.K. disposition and Note 11 for detail 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, 2019 and December 31, 2018 . September 30, 2019 December 31, 2018 (In millions) Fair Value Carrying Amount Fair Value Carrying Amount Financial assets Current assets $ 4 $ 4 $ 3 $ 3 Other noncurrent assets 29 35 76 81 Total financial assets $ 33 $ 39 $ 79 $ 84 Financial liabilities Other current liabilities $ 75 $ 103 $ 37 $ 58 Long-term debt, including current portion (a) 6,018 5,529 5,469 5,528 Deferred credits and other liabilities 108 96 93 88 Total financial liabilities $ 6,201 $ 5,728 $ 5,599 $ 5,674 (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, 2019
Debt Disclosure [Abstract]
Debt	Debt Revolving Credit Facility In September 2019, we entered into a fourth amendment to our unsecured revolving credit facility (the “Credit Facility”) to reduce the maximum borrowing from $3.4 billion to $3.0 billion and extended the maturity date by one year to May 28, 2023. As of September 30, 2019 , we had no borrowings against our $3.0 billion Credit Facility, as described below or under our U.S. commercial paper program that is backed by the Credit Facility. The Credit Facility includes a covenant requiring our debt-to-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, 2019 , we were in compliance with this covenant with a debt-to-capitalization ratio of 31% . Long-term debt At September 30, 2019 , we had $5.5 billion of total debt outstanding, of which $600 million was due June 2020. On October 3, 2019, we redeemed our $600 million 2.7% senior unsecured notes due June 2020. After considering this debt redemption, our next debt maturity is the $1.0 billion 2.8% senior unsecured notes due 2022. Debt Issuance On October 1, 2019, we closed a $600 million remarketing to investors of sub-series A bonds which are part of the $1.0 billion St. John the Baptist, State of Louisiana revenue refunding bonds originally issued and purchased in December 2017. The $600 million in proceeds from the conversion and remarketing were used to pay the purchase price of our converted 2017 bonds on the closing date. We continue to own the remaining $400 million of the revenue refunding bonds and have the right to convert and remarket them to investors at any time up to the 2037 maturity date. The following table further summarizes this transaction. Sub-Series A Bonds Par Amount Interest Rate Mandatory Purchase Date Maturity Date Sub-series A-1 Bonds $200 million 2.00% April 1, 2023 June 1, 2037 Sub-series A-2 Bonds $200 million 2.10% July 1, 2024 June 1, 2037 Sub-series A-3 Bonds $200 million 2.20% July 1, 2026 June 1, 2037

Stockholders' Equity

Stockholders' Equity	9 Months Ended
	Sep. 30, 2019
Equity [Abstract]
Stockholders' Equity	Stockholders’ Equity On July 31, 2019, the Board of Directors authorized an extension of the share repurchase program, which increased the remaining share repurchase authorization to $1.5 billion . In the nine months ended September 30, 2019 , we acquired approximately 19 million common shares at a cost of $280 million , which were held as treasury stock. Including these repurchases, the total remaining share repurchase authorization was $1.5 billion at September 30, 2019

Incentive Based Compensation

Incentive Based Compensation	9 Months Ended
	Sep. 30, 2019
Share-based Payment Arrangement [Abstract]
Incentive Based Compensation	Incentive Based Compensation Stock options, restricted stock awards and restricted stock units The following table presents a summary of activity for the first nine months of 2019 : Stock Options Restricted Stock Awards & Units Number of Shares Weighted Average Exercise Price Awards Weighted Average Grant Date Fair Value Outstanding at December 31, 2018 6,180,007 $ 24.39 8,504,946 $ 14.04 Granted 648,526 (a) $ 16.79 3,910,971 $ 16.90 Exercised/Vested (11,470 ) $ 14.25 (3,608,790 ) $ 12.45 Canceled (925,010 ) $ 25.33 (1,504,665 ) $ 15.76 Outstanding at September 30, 2019 5,892,053 $ 23.42 7,302,462 $ 16.00 (a) The weighted average grant date fair value of stock option awards granted was $6.62 per share. Stock-based performance unit awards During the first nine months of 2019 , we granted 656,636 stock-based performance units to certain officers to be settled in shares. The grant date fair value per unit was $20.66 , as calculated using a Monte Carlo valuation model. At the grant date, each unit represents the value of one share of our common stock. These units are settled in shares, and the number of shares of our common stock to be paid is based on the vesting percentage, which can be from zero to 200%

Defined Benefit Postretirement

Defined Benefit Postretirement Plans	9 Months Ended
	Sep. 30, 2019
Retirement Benefits [Abstract]
Defined Benefit Postretirement Plans	Defined Benefit Postretirement Plans The following summarizes the components of net periodic benefit cost: Three Months Ended September 30, Pension Benefits Other Benefits (In millions) 2019 2018 2019 2018 Service cost $ 5 $ 4 $ — $ — Interest cost 3 7 1 2 Expected return on plan assets (3 ) (9 ) — — Amortization: – prior service cost (credit) (1 ) (2 ) (5 ) (2 ) – actuarial loss 2 3 1 — Net settlement loss (a) — 10 — — Net periodic benefit cost (b) $ 6 $ 13 $ (3 ) $ — Nine Months Ended September 30, Pension Benefits Other Benefits (In millions) 2019 2018 2019 2018 Service cost $ 14 $ 13 $ — $ 1 Interest cost 17 20 3 6 Expected return on plan assets (19 ) (26 ) — — Amortization: – prior service credit (5 ) (7 ) (14 ) (6 ) – actuarial loss 6 9 1 1 Net settlement loss (a) 2 16 — — Net periodic benefit cost (b) $ 15 $ 25 $ (10 ) $ 2 (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 cost reflects a calculated market-related value of plan assets which recognizes changes in fair value over three years. During the first nine months of 2019 , we made contributions of $35 million to our funded pension plans and we expect to make additional contributions up to an estimated $6 million over the remainder of 2019 . During the first nine months of 2019 , we made payments of $4 million and $17 million related to unfunded pension plans and other postretirement benefit plans. In connection with the sale of our U.K. business, the noncontributory defined benefit pension plan covering U.K. employees was transferred to the buyer. See Note 5 for further information on this disposition. During the three and nine months ended September 30, 2019, we reclassified $20 million from accumulated other comprehensive income to pension assets upon remeasurement of the plan. See table below for summary of the obligations and funded status related to the U.K. pension plan for nine months ended September 30, 2019 and year-ended December 31, 2018. Pension Benefits (In millions) September 30, 2019 December 31, 2018 Accumulated benefit obligation $ — $ 511 Change in benefit obligations: Beginning balance $ 511 $ 599 Interest cost 8 14 Plan amendment — 3 Divestiture (a) (549 ) — Actuarial loss (gain) 36 (38 ) Foreign currency exchange rate changes 6 (29 ) Settlements paid — (23 ) Benefits paid (12 ) (15 ) Ending balance $ — $ 511 Change in fair value of plan assets: Beginning balance $ 594 $ 670 Actual return on plan assets 68 (21 ) Employer contributions 8 17 Foreign currency exchange rate changes 8 (34 ) Divestiture (666 ) — Settlements paid — (23 ) Benefits paid (12 ) (15 ) Ending balance $ — $ 594 Funded status of plans at September 30, 2019 and December 31, 2018 $ — $ 83 Amounts recognized in the consolidated balance sheets: Noncurrent assets $ — $ 83 Accrued benefit cost $ — $ 83 Pretax amounts in accumulated other comprehensive loss: Net loss (gain) $ — $ 59 Prior service cost (credit) — 5 (a) Refer to Note 5 for further information on the sale of our U.K. business.

Reclassifications Out of Accumu

Reclassifications Out of Accumulated Other Comprehensive Income (Loss)	9 Months Ended
	Sep. 30, 2019
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) 2019 2018 2019 2018 Income Statement Line Postretirement and postemployment plans Amortization of prior service credit $ 6 $ 4 $ 19 $ 13 Other net periodic benefit costs Amortization of actuarial loss (3 ) (3 ) (7 ) (10 ) Other net periodic benefit costs Net settlement loss — (10 ) (2 ) (16 ) Other net periodic benefit costs 3 (9 ) 10 (13 ) Income before income taxes Other insignificant — (4 ) — (4 ) Net interest and other U.K. pension plan transferred to buyer (a)(b) 83 — 83 — Net gain (loss) on disposal of assets Foreign currency translation adjustment related to sale of U.K. business (b) 30 — 30 — Net gain (loss) on disposal of assets Income tax provision (c) (46 ) — (46 ) — Provision for income taxes Total reclassifications to expense, net of tax $ 70 $ (13 ) $ 77 $ (17 ) Net income (a) See Note 19 for detail on the U.K. pension plan. (b) See Note 5 for detail on the U.K. disposition. (c) During 2019 and 2018 we had a full valuation allowance on net federal deferred tax assets in the U.S. therefore, the income tax provision in this table relates to our former U.K. business.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2019
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Nine Months Ended September 30, (In millions) 2019 2018 Included in operating activities: Interest paid, net of amounts capitalized $ 190 $ 187 Income taxes paid to taxing authorities 151 298 Noncash investing activities: Increase in asset retirement costs $ 40 $ 12 Asset retirement obligations assumed by buyer (a) 1,082 82 (a) In 2019, our dispositions include the sale of the Droshky field (Gulf of Mexico), the sale of our non-operated interest in the Atrush block in Kurdistan and the sale of our U.K. business. See Note 5 for further detail on dispositions. Other noncash investing activities include accrued capital expenditures for the nine months ended September 30, 2019 and 2018 of $302 million and $238 million .

Equity Method Investments

Equity Method Investments	9 Months Ended
	Sep. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Equity Method Investments During the periods ended September 30, 2019 and December 31, 2018 our equity method investees were considered related parties and included: • EGHoldings, in which we have a 60% noncontrolling interest. EGHoldings is engaged in LNG production activity. • Alba Plant LLC, in which we have a 52% noncontrolling interest. Alba Plant LLC processes LPG. • AMPCO, in which we have a 45% interest. AMPCO is engaged in methanol production activity. Our equity method investments are summarized in the following table: (In millions) Ownership as of September 30, 2019 September 30, 2019 December 31, 2018 EGHoldings 60% $ 324 $ 402 Alba Plant LLC 52% 158 167 AMPCO 45% 185 176 Total $ 667 $ 745 Summarized financial information for equity method investees is as follows: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2019 2018 2019 2018 Income data: Revenues and other income $ 184 $ 238 $ 637 $ 664 Income from operations 61 151 192 391 Net income 45 129 140 331

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Following the sale of our U.K. business to RockRose, we continue to have surety bonds outstanding that guarantee our decommissioning liabilities related to the MOUK assets. We issued these surety bonds in November 2018 with a notional value of approximately £92 million and an expiration date of December 31, 2019. RockRose is contractually required to post a replacement security to cover 2020 by no later than December 1, 2019. If RockRose is unable to post a replacement security by December 1, 2019, the counterparties of our existing surety bonds have the right to submit a demand notice against our surety bonds. In order to mitigate this exposure, we have secured surety bonds from RockRose issued in favor of Marathon for the full amount of £92 million . As of September 30, 2019, RockRose had not posted a replacement security and we recognized a liability and corresponding expense of approximately $6 million related to the estimated fair value of our exposure to these surety bonds. Should RockRose post a replacement security, we will derecognize our $6 million other current liability and record income of a corresponding amount. See Note 5 for discussion of the U.K. sale in further detail. 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. MEGPL is a signatory to the agreements related to our equity method investee, Alba Plant LLC. These agreements contain clauses that cause MEGPL to indemnify the owners of the Alen Unit against actions or inaction by Alba Plant LLC. Pursuant to these agreements, MEGPL agreed to indemnify third party property or events, including environmental assessments, injury to Alba Plant LLC’s personnel, and damage to or loss of Alba Plant LLC’s automobiles. At this time, we cannot reasonably estimate this obligation as we do not have any history of prior indemnification claims, as completion of the plant modifications is not expected to finish until 2021, and as such, we do not have any history of environmental discharge or contamination. Therefore, we have not recorded a liability with respect to these indemnification clauses since the amount of potential future payments under such guarantees is not determinable. In the fourth quarter of 2017, the U.K. tax authorities challenged the deductibility for certain Brae area decommissioning costs, which we claimed for U.K. corporation tax purposes. The dispute related to the timing of the deduction and did not dispute the general deductibility of decommissioning costs. In accordance with U.K. regulations, we paid the amount of tax and interest in question, approximately $108 million , and filed our appeal. In the first quarter of 2019, we withdrew our appeal on this matter, and the corresponding revisions to current and deferred tax liabilities have no cumulative adverse earnings impact on our consolidated results of operations. We are continuously undergoing examination of our U.S. federal income tax returns by the IRS. With the closure of the 2010-2011 IRS Audit referenced in Note 8 , these audits have been completed through the 2016 tax year with the exception of the following item. During the third quarter of 2017, we received a partnership adjustment notification related to the 2010 and 2011 tax years, for which we filed a Tax Court Petition in the fourth quarter of 2017. During the third quarter of 2019, we received the court decision which ruled in our favor for all material items. The IRS is in the process of preparing the final reports for the 2010 and 2011 tax years. 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. 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.

Basis of Presentation (Policies

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2019
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 2018 Annual Report on Form 10-K. The results of operations for the third quarter and first nine months of 2019 are not necessarily indicative of the results to be expected for the full year. Reclassifications

Income (Loss) and Dividends p_2

Income (Loss) and Dividends per Common Share (Tables)	9 Months Ended
	Sep. 30, 2019
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The per share calculations below exclude 6 million and 5 million of stock options for the three and nine months ended September 30, 2019 , and 5 million and 6 million of stock options for the three and nine months ended September 30, 2018 , that were antidilutive. Three Months Ended September 30, Nine Months Ended September 30, (In millions, except per share data) 2019 2018 2019 2018 Net income $ 165 $ 254 $ 500 $ 706 Weighted average common shares outstanding 802 848 813 852 Effect of dilutive securities 1 1 — 1 Weighted average common shares, diluted 803 849 813 853 Net income per share: Basic $ 0.21 $ 0.30 $ 0.62 $ 0.83 Diluted $ 0.21 $ 0.30 $ 0.62 $ 0.83 Dividends per share $ 0.05 $ 0.05 $ 0.15 $ 0.15

Revenues (Tables)

Revenues (Tables)	9 Months Ended
	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following tables present our revenues from contracts with customers disaggregated by product type and geographic areas. United States Three Months Ended September 30, 2019 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 336 $ 452 $ 116 $ 88 $ 25 $ 1,017 Natural gas liquids 23 6 28 5 2 64 Natural gas 28 8 37 3 5 81 Other 1 — — — 9 10 Revenues from contracts with customers $ 388 $ 466 $ 181 $ 96 $ 41 $ 1,172 Three Months Ended September 30, 2018 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 436 $ 447 $ 114 $ 59 $ 34 $ 1,090 Natural gas liquids 70 19 48 12 3 152 Natural gas 36 9 46 6 5 102 Other — — — — 3 3 Revenues from contracts with customers $ 542 $ 475 $ 208 $ 77 $ 45 $ 1,347 Nine Months Ended September 30, 2019 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,004 $ 1,277 $ 304 $ 229 $ 83 $ 2,897 Natural gas liquids 88 31 81 20 5 225 Natural gas 94 26 118 10 15 263 Other 4 — — — 45 49 Revenues from contracts with customers $ 1,190 $ 1,334 $ 503 $ 259 $ 148 $ 3,434 Nine Months Ended September 30, 2018 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 1,196 $ 1,182 $ 340 $ 173 $ 131 $ 3,022 Natural gas liquids 157 51 130 24 8 370 Natural gas 102 27 127 13 17 286 Other 3 — — — 12 15 Revenues from contracts with customers $ 1,458 $ 1,260 $ 597 $ 210 $ 168 $ 3,693 International Three Months Ended September 30, 2019 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 67 $ — $ — $ 67 Natural gas liquids 1 — — 1 Natural gas 8 — — 8 Revenues from contracts with customers $ 77 $ — $ — $ 77 Three Months Ended September 30, 2018 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 100 $ 41 $ 20 $ 161 Natural gas liquids 1 1 — 2 Natural gas 9 11 — 20 Other — 8 — 8 Revenues from contracts with customers $ 110 $ 61 $ 20 $ 191 Nine Months Ended September 30, 2019 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 215 $ 107 $ 19 $ 341 Natural gas liquids 3 1 — 4 Natural gas 24 12 — 36 Other 1 14 — 15 Revenues from contracts with customers $ 243 $ 134 $ 19 $ 396 Nine Months Ended September 30, 2018 (In millions) E.G. U.K. Libya Other International Total Crude oil and condensate $ 271 $ 207 $ 187 $ 65 $ 730 Natural gas liquids 3 4 — — 7 Natural gas 28 31 9 — 68 Other — 24 — — 24 Revenues from contracts with customers $ 302 $ 266 $ 196 $ 65 $ 829
Contract with Customer, Liability	The following table provides information about receivables and contract assets (liabilities) from contracts with customers. (In millions) September 30, 2019 January 1, 2019 Receivables from contracts with customers, included in receivables, less reserves $ 822 $ 714 Contract asset (liability) $ — $ (1 ) Changes in the contract asset (liability) balance during the period are as follows. (In millions) Nine Months Ended September 30, 2019 Contract asset (liability) balance as of January 1, 2019 $ (1 ) Revenue recognized as performance obligations are satisfied 74 Amounts invoiced to customers (52 ) Contract asset (liability) transferred to buyer (a) (21 ) Contract asset (liability) balance as of September 30, 2019 $ —

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Three Months Ended September 30, 2019 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 1,172 $ 77 $ — $ 1,249 Net gain (loss) on commodity derivatives 14 — 33 (b) 47 Income from equity method investments — 21 — 21 Net gain on disposal of assets — — 22 (c) 22 Other income 3 2 1 6 Less costs and expenses: Production 147 16 — 163 Shipping, handling and other operating 137 1 — 138 Exploration 22 — — 22 Depreciation, depletion and amortization 589 25 8 622 Taxes other than income 80 — 1 81 General and administrative 34 5 43 82 Net interest and other — — 64 64 Other net periodic benefit costs — — (2 ) (2 ) Income tax provision — 10 — 10 Segment income (loss) $ 180 $ 43 $ (58 ) $ 165 Capital expenditures (a) $ 667 $ 1 $ 7 $ 675 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 14 ). (c) Primarily related to the sale of our U.K. business (See Note 5 ). Three Months Ended September 30, 2018 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 1,347 $ 191 $ — $ 1,538 Net gain (loss) on commodity derivatives (89 ) — 19 (b) (70 ) Income from equity method investments — 64 — 64 Net gain on disposal of assets — — 16 (c) 16 Other income 2 4 113 (d) 119 Less costs and expenses: Production 172 43 — 215 Shipping, handling and other operating 136 16 — 152 Exploration 55 1 — 56 Depreciation, depletion and amortization 571 49 6 626 Impairments — — 8 (e) 8 Taxes other than income 86 — — 86 General and administrative 37 7 57 101 Net interest and other — — 58 58 Other net periodic benefit costs — (3 ) 11 (f) 8 Income tax provision 2 30 71 103 Segment income (loss) $ 201 $ 116 $ (63 ) $ 254 Capital expenditures (a) $ 691 $ 6 $ 7 $ 704 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 14 ). (c) Sales of certain non-core proved properties in our International and United States segments. (d) Reduction of our asset retirement obligation in our International segment (See Note 12 ). (e) Due to the anticipated sale of non-core property in our International segment (See Note 11 ). (f) Includes pension settlement loss of $10 million (See Note 19 ). Nine Months Ended September 30, 2019 (In millions) U.S. Int’l Not Allocated to Segments Total Revenues from contracts with customers $ 3,434 $ 396 $ — $ 3,830 Net gain (loss) on commodity derivatives 41 — (69 ) (b) (28 ) Income from equity method investments — 63 — 63 Net gain on disposal of assets — — 56 (c) 56 Other income 8 7 39 (d) 54 Less costs and expenses: Production 433 112 (2 ) 543 Shipping, handling and other operating 424 24 14 462 Exploration 107 — — 107 Depreciation, depletion and amortization 1,664 97 20 1,781 Impairments — — 24 (e) 24 Taxes other than income 233 — (1 ) 232 General and administrative 94 20 149 263 Net interest and other — — 177 177 Other net periodic benefit costs — (3 ) (6 ) (9 ) Income tax provision (benefit) 1 16 (122 ) (f) (105 ) Segment income (loss) $ 527 $ 200 $ (227 ) $ 500 Capital expenditures (a) $ 1,959 $ 16 $ 15 $ 1,990 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 14 ). (c) Primarily related to the sale of our working interest in the Droshky field (Gulf of Mexico) and the sale of our U.K. business (See Note 5 ). (d) Primarily related to the indemnification of certain tax liabilities in connection with the 2010-2011 Federal Tax Audit (See Note 8 ). (e) Primarily a result of anticipated sales of non-core proved properties in our International and United States segments (See Note 11 ). (f) Primarily relates to the settlement of the 2010-2011 Federal Tax Audit (See Note 8 ). Nine Months Ended September 30, 2018 (In millions) U.S. Int’l Not Allocated to Segments Total Revenue from contracts with customers $ 3,693 $ 829 $ — $ 4,522 Net gain (loss) on commodity derivatives (255 ) — (69 ) (b) (324 ) Income from equity method investments — 161 — 161 Net gain on disposal of assets — — 323 (c) 323 Other income 7 7 121 (d) 135 Less costs and expenses: Production 476 162 (1 ) 637 Shipping, handling and other operating 364 45 (1 ) 408 Exploration 170 3 — 173 Depreciation, depletion and amortization 1,655 153 20 1,828 Impairments — — 50 (e) 50 Taxes other than income 218 — (3 ) 215 General and administrative 108 25 173 306 Net interest and other — — 168 168 Other net periodic benefit costs — (7 ) 18 (f) 11 Income tax provision 5 226 84 315 Segment income (loss) $ 449 $ 390 $ (133 ) $ 706 Capital expenditures (a) $ 1,943 $ 28 $ 17 $ 1,988 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 14 ). (c) Primarily related to the gain on sale of our Libya subsidiary (See Note 5 ). (d) Reduction of our asset retirement obligation in our International segment (See Note 12 ). (e) Due to the anticipated sales of certain non-core proved properties in our International and United States segments (See Note 11 ). (f) Includes pension settlement loss of $16 million (See Note 19 ).

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2019
Income Tax Disclosure [Abstract]
Effective Income Tax Rate	For the three and nine months ended September 30, 2019 and 2018 , our effective income tax rates were as follows: Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 Effective income tax expense (benefit) rate (a) 6 % 29 % (27 )% 31 % (a) In all periods presented, we maintained our valuation allowance on our net federal deferred tax assets in the U.S.

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Sep. 30, 2019
Inventory Disclosure [Abstract]
Schedule of Inventory, Current	(In millions) September 30, 2019 December 31, 2018 Crude oil and natural gas $ 9 $ 11 Supplies and other items 62 85 Inventories $ 71 $ 96

Property, Plant and Equipment_2

Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization (Tables)	9 Months Ended
	Sep. 30, 2019
Property, Plant and Equipment [Abstract]
Schedule of Property, Plant and Equipment	(In millions) September 30, 2019 December 31, 2018 United States $ 16,127 $ 16,011 International 512 710 Corporate 78 83 Net property, plant and equipment $ 16,717 $ 16,804

Impairments (Tables)

Impairments (Tables)	9 Months Ended
	Sep. 30, 2019
Impairment Expense [Abstract]
Fair Value Measurements, Nonrecurring	The following table summarizes impairment charges of proved properties. Additionally, it presents the values of assets, by major category, measured at fair value on a nonrecurring basis in periods subsequent to their initial recognition. Three Months Ended September 30, 2019 2018 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ — $ — $ 39 $ 8 Nine Months Ended September 30, 2019 2018 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 56 $ 24 $ 108 $ 50

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2019
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 for the nine months ended were as follows: September 30, (In millions) 2019 2018 Beginning balance $ 1,145 $ 1,483 Incurred liabilities, including acquisitions 25 10 Settled liabilities, including dispositions (1,106 ) (105 ) Accretion expense (included in depreciation, depletion and amortization) 29 53 Revisions of estimates 15 (130 ) Held for sale 108 (10 ) Ending balance $ 216 $ 1,301

Leases (Tables)

Leases (Tables)	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Supplemental Balance Sheet Information	Supplemental balance sheet information related to leases was as follows: (In millions) September 30, 2019 Operating Leases: Balance Sheet Location: ROU asset Other noncurrent assets $ 226 Current portion of long-term lease liability Other current liabilities $ 104 Long-term lease liability Deferred credits and other liabilities $ 127
Lease Costs	The table below presents our net lease costs as of September 30, 2019 with the majority of operating lease costs expensed as incurred, while the majority of the short-term and variable term lease costs are capitalized into property, plant and equipment. (In millions) Three Months Ended September 30, 2019 Nine Months Ended September 30, 2019 Lease costs: Operating lease costs (a) $ 21 $ 61 Short-term lease costs (b) 94 251 Variable lease costs (c) 24 96 Total lease costs $ 139 $ 408 Other information: Cash paid for amounts included in the measurement of operating lease liabilities $ 71 ROU assets obtained in exchange for new operating lease liabilities (d) 296 (a) Represents our net share of the ROU asset amortization and the interest expense. (b) Represents our net share of lease costs arising from leases of less than one year but longer than one month that were not included in the lease liability. (c) Represents our net share of variable lease payments that were not included in the lease liability. (d) Represents the cumulative value of ROU assets recognized at lease inception during the first nine months of 2019 . This amount is then amortized as we utilize the ROU asset, the net effect of which is the ending ROU asset of $226 million (first table above).
Operating Lease, Maturity	The remaining annual undiscounted cash flows associated with long-term leases and the reconciliation of these cash flows to the lease liabilities recognized on the consolidated balance sheet is summarized below. (In millions) Operating Lease Obligations 2019 $ 35 2020 107 2021 62 2022 34 2023 4 Thereafter 1 Total undiscounted lease payments $ 243 Less: amount representing interest 12 Total operating lease liabilities $ 231 Less: current portion of long-term lease liability as of September 30, 2019 104 Long-term lease liability as of September 30, 2019 $ 127
Operating Lease, Maturity	At December 31, 2018 , future minimum commitments under the previous accounting standard, ASC 840, for operating lease obligations having noncancellable lease terms in excess of one year were as follows: (In millions) Operating Lease Obligations 2019 $ 62 2020 54 2021 35 2022 12 2023 5 Thereafter 49 Sublease rentals — Total minimum lease payments $ 217
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 2019 $ 2 2020 6 2021 6 2022 6 2023 6 Thereafter 67 Total undiscounted cash flows $ 93

Derivatives (Tables)

Derivatives (Tables)	9 Months Ended
	Sep. 30, 2019
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, 2019 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ 58 $ 5 $ 53 Other current assets Commodity 6 — 6 Other noncurrent assets Commodity — 1 (1 ) Deferred credits and other liabilities Total Not Designated as Hedges $ 64 $ 6 $ 58 Cash Flow Hedges Interest Rate $ — $ 1 $ (1 ) Deferred credits and other liabilities Total Designated Hedges $ — $ 1 $ (1 ) Total $ 64 $ 7 $ 57 December 31, 2018 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ 131 $ — $ 131 Other current assets Commodity — 4 (4 ) Deferred credits and other liabilities Total Not Designated as Hedges $ 131 $ 4 $ 127
Schedule of Notional Amounts of Outstanding Derivative Positions	The following table sets forth outstanding derivative contracts as of September 30, 2019 , and the weighted average prices for those contracts: 2019 2020 2021 Crude Oil Fourth Quarter Full Year Full Year NYMEX WTI Three-Way Collars Volume (Bbls/day) 80,000 42,945 — Weighted average price per Bbl: Ceiling $ 74.19 $ 65.58 $ — Floor $ 56.75 $ 55.00 $ — Sold put $ 49.50 $ 47.77 $ — Basis Swaps - Argus WTI Midland (a) Volume (Bbls/day) 15,000 15,000 — Weighted average price per Bbl $ (1.40 ) $ (0.94 ) $ — Basis Swaps - Net Energy Clearbrook (b) Volume (Bbls/day) 2,000 — — Weighted average price per Bbl $ (3.33 ) $ — $ — Basis Swaps - NYMEX WTI / ICE Brent (c) Volume (Bbls/day) 5,000 5,000 808 Weighted average price per Bbl $ (7.24 ) $ (7.24 ) $ (7.24 ) Basis Swaps - Argus WTI Houston (d) Volume (Bbls/day) 10,000 — — Weighted average price per Bbl $ 5.51 $ — $ — NYMEX Roll Basis Swaps Volume (Bbls/day) 60,000 — — Weighted average price per Bbl $ 0.38 $ — $ — (a) The basis differential price is indexed against Argus WTI Midland. (b) The basis differential price is indexed against Net Energy Canada Bakken SW at Clearbrook (“UHC”). (c) The basis differential price is indexed against International Commodity Exchange (“ICE”) Brent and NYMEX WTI. (d) The basis differential price is indexed against Argus WTI Houston.
Schedule of Interest Rate Swap Agreement	The following table presents information about our interest rate swap agreements, including the weighted average LIBOR-based, fixed rate. September 30, 2019 December 31, 2018 (In millions, except fixed rates) Aggregate Notional Amount Weighted Average, LIBOR Aggregate Notional Amount Weighted Average, LIBOR Interest rate swaps $ 160 1.50 % $ — — %

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2019
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, 2019 and December 31, 2018 by hierarchy level. September 30, 2019 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ — $ 61 $ — $ 61 Derivative instruments, assets $ — $ 61 $ — $ 61 Derivative instruments, liabilities Commodity (a) $ (3 ) $ — $ — $ (3 ) Interest rate $ — $ (1 ) $ — $ (1 ) Derivative instruments, liabilities $ (3 ) $ (1 ) $ — $ (4 ) (a) Derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 14 . December 31, 2018 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ 21 $ 106 $ — $ 127 Derivative instruments, assets $ 21 $ 106 $ — $ 127 Derivative instruments, liabilities Derivative instruments, liabilities $ — $ — $ — $ — (a) Derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 14 .
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, 2019 and December 31, 2018 . September 30, 2019 December 31, 2018 (In millions) Fair Value Carrying Amount Fair Value Carrying Amount Financial assets Current assets $ 4 $ 4 $ 3 $ 3 Other noncurrent assets 29 35 76 81 Total financial assets $ 33 $ 39 $ 79 $ 84 Financial liabilities Other current liabilities $ 75 $ 103 $ 37 $ 58 Long-term debt, including current portion (a) 6,018 5,529 5,469 5,528 Deferred credits and other liabilities 108 96 93 88 Total financial liabilities $ 6,201 $ 5,728 $ 5,599 $ 5,674 (a) Excludes debt issuance costs.

Incentive Based Compensation (T

Incentive Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2019
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 2019 : Stock Options Restricted Stock Awards & Units Number of Shares Weighted Average Exercise Price Awards Weighted Average Grant Date Fair Value Outstanding at December 31, 2018 6,180,007 $ 24.39 8,504,946 $ 14.04 Granted 648,526 (a) $ 16.79 3,910,971 $ 16.90 Exercised/Vested (11,470 ) $ 14.25 (3,608,790 ) $ 12.45 Canceled (925,010 ) $ 25.33 (1,504,665 ) $ 15.76 Outstanding at September 30, 2019 5,892,053 $ 23.42 7,302,462 $ 16.00 (a) The weighted average grant date fair value of stock option awards granted was $6.62 per share.

Defined Benefit Postretiremen_2

Defined Benefit Postretirement Plans (Tables)	9 Months Ended
	Sep. 30, 2019
Retirement Benefits [Abstract]
Changes in Projected Benefit Obligations, Fair Value of Plan Assets, and Funded Status of Plan [Table Text Block]	(a) Refer to Note 5 for further information on the sale of our U.K. business.
Schedule of Net Periodic Benefit Cost	The following summarizes the components of net periodic benefit cost: Three Months Ended September 30, Pension Benefits Other Benefits (In millions) 2019 2018 2019 2018 Service cost $ 5 $ 4 $ — $ — Interest cost 3 7 1 2 Expected return on plan assets (3 ) (9 ) — — Amortization: – prior service cost (credit) (1 ) (2 ) (5 ) (2 ) – actuarial loss 2 3 1 — Net settlement loss (a) — 10 — — Net periodic benefit cost (b) $ 6 $ 13 $ (3 ) $ — Nine Months Ended September 30, Pension Benefits Other Benefits (In millions) 2019 2018 2019 2018 Service cost $ 14 $ 13 $ — $ 1 Interest cost 17 20 3 6 Expected return on plan assets (19 ) (26 ) — — Amortization: – prior service credit (5 ) (7 ) (14 ) (6 ) – actuarial loss 6 9 1 1 Net settlement loss (a) 2 16 — — Net periodic benefit cost (b) $ 15 $ 25 $ (10 ) $ 2 (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 cost 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, 2019
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) 2019 2018 2019 2018 Income Statement Line Postretirement and postemployment plans Amortization of prior service credit $ 6 $ 4 $ 19 $ 13 Other net periodic benefit costs Amortization of actuarial loss (3 ) (3 ) (7 ) (10 ) Other net periodic benefit costs Net settlement loss — (10 ) (2 ) (16 ) Other net periodic benefit costs 3 (9 ) 10 (13 ) Income before income taxes Other insignificant — (4 ) — (4 ) Net interest and other U.K. pension plan transferred to buyer (a)(b) 83 — 83 — Net gain (loss) on disposal of assets Foreign currency translation adjustment related to sale of U.K. business (b) 30 — 30 — Net gain (loss) on disposal of assets Income tax provision (c) (46 ) — (46 ) — Provision for income taxes Total reclassifications to expense, net of tax $ 70 $ (13 ) $ 77 $ (17 ) Net income (a) See Note 19 for detail on the U.K. pension plan. (b) See Note 5 for detail on the U.K. disposition. (c) During 2019 and 2018 we had a full valuation allowance on net federal deferred tax assets in the U.S. therefore, the income tax provision in this table relates to our former U.K. business.

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2019
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Nine Months Ended September 30, (In millions) 2019 2018 Included in operating activities: Interest paid, net of amounts capitalized $ 190 $ 187 Income taxes paid to taxing authorities 151 298 Noncash investing activities: Increase in asset retirement costs $ 40 $ 12 Asset retirement obligations assumed by buyer (a) 1,082 82 (a) In 2019, our dispositions include the sale of the Droshky field (Gulf of Mexico), the sale of our non-operated interest in the Atrush block in Kurdistan and the sale of our U.K. business. See Note 5 for further detail on dispositions.

Equity Method Investments (Tabl

Equity Method Investments (Tables)	9 Months Ended
	Sep. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Equity Method Investments	Our equity method investments are summarized in the following table: (In millions) Ownership as of September 30, 2019 September 30, 2019 December 31, 2018 EGHoldings 60% $ 324 $ 402 Alba Plant LLC 52% 158 167 AMPCO 45% 185 176 Total $ 667 $ 745 Summarized financial information for equity method investees is as follows: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2019 2018 2019 2018 Income data: Revenues and other income $ 184 $ 238 $ 637 $ 664 Income from operations 61 151 192 391 Net income 45 129 140 331

Accounting Standards Lease acco

Accounting Standards Lease accounting standard (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Sep. 30, 2019
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Total operating lease liabilities		$ 231
ROU asset		$ 226
Cumulative Effect on Retained Earnings, Net of Tax	$ (31)
Retained Earnings
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative Effect on Retained Earnings, Net of Tax	$ (31)

Income (Loss) and Dividends p_3

Income (Loss) and Dividends per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018
Earnings Per Share [Abstract]
Antidilutive securities excluded from computation of earnings per share (in shares)	6			5			5	6
Net income	$ 165	$ 161	$ 174	$ 254	$ 96	$ 356	$ 500	$ 706
Weighted average common shares outstanding (in shares)	802			848			813	852
Effect of dilutive securities (in shares)	1			1			0	1
Weighted average common shares, diluted (in shares)	803			849			813	853
Net income per share:
Basic	$ 0.21			$ 0.30			$ 0.62	$ 0.83
Per diluted share:
Diluted	0.21			0.30			0.62	0.83
Dividends per share (in dollars per share)	$ 0.05	$ 0.05	$ 0.05	$ 0.05	$ 0.05	$ 0.05	$ 0.15	$ 0.15

Acquisitions (Details)

Acquisitions (Details) a in Thousands, $ in Millions	1 Months Ended	9 Months Ended
	Nov. 07, 2019USD ($)a	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)
Subsequent Event [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired		$ 0	$ 25
TexasDelaware | Subsequent Event
Subsequent Event [Line Items]
Oil and Gas Acres Undeveloped and Developed, Net | a	40
Payments to Acquire Businesses, Net of Cash Acquired	$ 106
Eagle Ford | Subsequent Event
Subsequent Event [Line Items]
Oil and Gas Acres Undeveloped and Developed, Net | a	18
Payments to Acquire Businesses, Net of Cash Acquired	$ 185

Dispositions - International Se

Dispositions - International Segment (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended				9 Months Ended
	Jul. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Sep. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and gas property and equipment						$ (84)	$ 1,249
Surety bond exposure, liability		$ 6				6
Surety bond exposure, expense		6
Income before income taxes		175		$ 357		395	1,021
International E&P | U.K. Business | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and gas property and equipment	$ 95
Cash, cash equivalents and working capital								$ 345
Net gain (loss) on disposal of assets		14
Income before income taxes		$ 0		$ 132		$ 37	$ 239
International E&P | Atrush Block in Kurdistan | Disposal Group, Held-for-sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal group, assets								58
Disposal group, liabilities								$ 17
International E&P | Atrush Block in Kurdistan | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and gas property and equipment			$ 63
Percentage of oil and gas property disposed		15.00%
International E&P | Marathon Oil Libya Limited | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of oil and gas property and equipment					$ 450
Net gain (loss) on disposal of assets					$ 255
Percentage of oil and gas property disposed					16.33%

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, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 1,249	$ 1,538	$ 3,830	$ 4,522
United States E&P
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,172	1,347	3,434	3,693
United States E&P | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	388	542	1,190	1,458
United States E&P | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	466	475	1,334	1,260
United States E&P | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	181	208	503	597
United States E&P | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	96	77	259	210
United States E&P | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	41	45	148	168
United States E&P | Crude oil and condensate
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,017	1,090	2,897	3,022
United States E&P | Crude oil and condensate | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	336	436	1,004	1,196
United States E&P | Crude oil and condensate | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	452	447	1,277	1,182
United States E&P | Crude oil and condensate | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	116	114	304	340
United States E&P | Crude oil and condensate | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	88	59	229	173
United States E&P | Crude oil and condensate | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	25	34	83	131
United States E&P | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	64	152	225	370
United States E&P | Natural gas liquids | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	23	70	88	157
United States E&P | Natural gas liquids | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6	19	31	51
United States E&P | Natural gas liquids | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	28	48	81	130
United States E&P | Natural gas liquids | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5	12	20	24
United States E&P | Natural gas liquids | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2	3	5	8
United States E&P | Natural gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	81	102	263	286
United States E&P | Natural gas | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	28	36	94	102
United States E&P | Natural gas | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8	9	26	27
United States E&P | Natural gas | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	37	46	118	127
United States E&P | Natural gas | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3	6	10	13
United States E&P | Natural gas | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5	5	15	17
United States E&P | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	10	3	49	15
United States E&P | Other | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	0	4	3
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	9	3	45	12
International E&P
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		191	396	829
International E&P | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	77	110	243	302
International E&P | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	61	134	266
International E&P | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0			196
International E&P | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	77	20	19	65
International E&P | Crude oil and condensate
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		161	341	730
International E&P | Crude oil and condensate | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	67	100	215	271
International E&P | Crude oil and condensate | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	41	107	207
International E&P | Crude oil and condensate | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0			187
International E&P | Crude oil and condensate | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	67	20	19	65
International E&P | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		2	4	7
International E&P | Natural gas liquids | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	1	3	3
International E&P | Natural gas liquids | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	1	1	4
International E&P | Natural gas liquids | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0			0
International E&P | Natural gas liquids | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	0	0	0
International E&P | Natural gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		20	36	68
International E&P | Natural gas | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8	9	24	28
International E&P | Natural gas | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	11	12	31
International E&P | Natural gas | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0			9
International E&P | Natural gas | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8	0	0	0
International E&P | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		8	15	24
International E&P | Other | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		0	1	0
International E&P | Other | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		8	14	24
International E&P | Other | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers				0
International E&P | Other | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		0	0	0
Operating Segments | United States E&P
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,172	1,347	3,434	3,693
Operating Segments | International E&P
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	77	191	396	829
Not Allocated to Segments
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 0	$ 0	$ 0	$ 0

Revenues - Contract Receivables

Revenues - Contract Receivables and Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Receivables from contracts with customers, included in receivables, less reserves	$ 822	$ 714
Contract with Customer, Asset, Net, Current	0
Contract asset (liability)	$ 0	$ (1)

Revenues - Significant Changes

Revenues - Significant Changes in the Contract Liability Balance (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
Change In Contract With Customer, Liability [Roll Forward]
Contract asset (liability) balance as of January 1, 2019	$ 1
Revenue recognized as performance obligations are satisfied	74
Amounts invoiced to customers	(52)
Contract asset (liability) transferred to buyer(a)	(21)
Contract asset (liability) balance as of September 30, 2019	$ 0

Segment Information (Details)

Segment Information (Details) $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Sep. 30, 2019USD ($)segment	Sep. 30, 2018USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segment							2
Revenues from contracts with customers	$ 1,249			$ 1,538			$ 3,830	$ 4,522
Net gain (loss) on commodity derivatives	47			(70)			(28)	(324)
Income from equity method investments	21			64			63	161
Net gain on disposal of assets	22			16			56	323
Other income	6			119			54	135
Less costs and expenses:
Production	163			215			543	637
Shipping, handling and other operating	138			152			462	408
Exploration	22			56			107	173
Depreciation, depletion and amortization	622			626			1,781	1,828
Impairments	0			8			24	50
Taxes other than income	81			86			232	215
General and administrative	82			101			263	306
Net interest and other	64			58			177	168
Other net periodic benefit costs	(2)			8			(9)	11
Income tax provision (benefit)	10			103			(105)	315
Net income	165	$ 161	$ 174	254	$ 96	$ 356	500	706
Capital expenditures	675			704			1,990	1,988
Pension Plan
Less costs and expenses:
Other net periodic benefit costs	0						2	16
Not Allocated to Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	0			0			0	0
Net gain (loss) on commodity derivatives	33			19			(69)	(69)
Income from equity method investments	0			0			0	0
Net gain on disposal of assets	22			16			56	323
Other income	1			113			39	121
Less costs and expenses:
Production	0			0			(2)	(1)
Shipping, handling and other operating	0			0			14	(1)
Exploration	0			0			0	0
Depreciation, depletion and amortization	8			6			20	20
Impairments				8			24	50
Taxes other than income	1			0			(1)	(3)
General and administrative	43			57			149	173
Net interest and other	64			58			177	168
Other net periodic benefit costs	(2)			11			(6)	18
Income tax provision (benefit)	0			71			(122)	84
Net income	(58)			(63)			(227)	(133)
Capital expenditures	7			7			15	17
United States E&P
Segment Reporting Information [Line Items]
Revenues from contracts with customers	1,172			1,347			3,434	3,693
United States E&P | Operating Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	1,172			1,347			3,434	3,693
Net gain (loss) on commodity derivatives	14			(89)			41	(255)
Income from equity method investments	0			0			0	0
Net gain on disposal of assets	0			0			0	0
Other income	3			2			8	7
Less costs and expenses:
Production	147			172			433	476
Shipping, handling and other operating	137			136			424	364
Exploration	22			55			107	170
Depreciation, depletion and amortization	589			571			1,664	1,655
Impairments				0			0	0
Taxes other than income	80			86			233	218
General and administrative	34			37			94	108
Net interest and other	0			0			0	0
Other net periodic benefit costs	0			0			0	0
Income tax provision (benefit)	0			2			1	5
Net income	180			201			527	449
Capital expenditures	667			691			1,959	1,943
Int'l E&P
Segment Reporting Information [Line Items]
Revenues from contracts with customers				191			396	829
Int'l E&P | Operating Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	77			191			396	829
Net gain (loss) on commodity derivatives	0			0			0	0
Income from equity method investments	21			64			63	161
Net gain on disposal of assets	0			0			0	0
Other income	2			4			7	7
Less costs and expenses:
Production	16			43			112	162
Shipping, handling and other operating	1			16			24	45
Exploration	0			1			0	3
Depreciation, depletion and amortization	25			49			97	153
Impairments				0			0	0
Taxes other than income	0			0			0	0
General and administrative	5			7			20	25
Net interest and other	0			0			0	0
Other net periodic benefit costs	0			(3)			(3)	(7)
Income tax provision (benefit)	10			30			16	226
Net income	43			116			200	390
Capital expenditures	1			6			16	28
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plan Adjustment, Net Gain (Loss) Due To Settlement, Attributable To Parent [Member]
Less costs and expenses:
Other net periodic benefit costs	$ 0			$ 10			$ 2	$ 16

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Income Tax Disclosure [Abstract]
Effective income tax expense (benefit) rate	6.00%	29.00%	(27.00%)	31.00%
Tax benefit from settlement			$ 126
Tax benefit from internal restructuring			$ 18
Effective income tax expense (benefit) rate, excluding discrete items			10.00%
Tax expense from foreign currency revaluation				$ 162
Income tax receivable, current	$ 42		$ 42

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Inventory Disclosure [Abstract]
Crude oil and natural gas	$ 9	$ 11
Supplies and other items	62	85
Inventories	$ 71	$ 96

Property, Plant and Equipment_3

Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 16,717	$ 16,804
Exploratory well costs capitalized greater than one year after completion of drilling	0	0
Operating Segments | United States E&P
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	16,127	16,011
Operating Segments | International E&P
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	512	710
Not Allocated to Segments
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 78	$ 83

Impairments - Fair Value Measur

Impairments - Fair Value Measurements, Nonrecurring (Details) - Nonrecurring - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets Held-for-sale, Long Lived, Fair Value Disclosure	$ 0		$ 0
Long-lived assets, Fair Value	56	$ 108	56	$ 108	$ 39
Long-lived assets, Impairment	$ 0	$ 8	$ 24	$ 50

Impairments - Narrative (Detail

Impairments - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairments	$ 0	$ 8	$ 24	$ 50
Nonrecurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Adjustment	0	8	24	50
Property, Plant, and Equipment, Fair Value Disclosure	$ 56	$ 108	$ 56	$ 108	$ 39

Impairments - Exploration Expen

Impairments - Exploration Expenses (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Exploration Expenses [Line Items]
Total exploration expenses	$ 22	$ 56	$ 107	$ 173

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2018
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation, beginning balance	$ 1,145	$ 1,483
Incurred liabilities, including acquisitions	25	10
Settled liabilities, including dispositions	(1,106)	(105)
Accretion expense (included in depreciation, depletion and amortization)	29	53
Revisions of estimates	15	(130)
Held for sale	108	(10)
Asset retirement obligation, ending balance	216	$ 1,301
Asset retirement obligation, current	$ 18		$ 58

Leases - Supplemental Balance S

Leases - Supplemental Balance Sheet Information (Details) $ in Millions	Sep. 30, 2019USD ($)
Leases [Abstract]
ROU asset	$ 226
Current portion of long-term lease liability	104
Long-term lease liability	$ 127

Leases - Lease Costs (Details)

Leases - Lease Costs (Details) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2019USD ($)
Leases [Abstract]
Operating lease costs	$ 21	$ 61
Short-term lease costs	94	251
Variable lease costs	24	96
Total lease costs	139	408
Cash paid for amounts included in the measurement of operating lease liabilities		71
ROU assets obtained in exchange for new operating lease liabilities(d)		296
ROU asset	$ 226	$ 226

Leases - Narrative (Details)

Leases - Narrative (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Leases [Abstract]
Weighted average lease term	3 years
Discount rate	4.00%
Annual payments to be received	$ 6
Maximum financing available		$ 380
Total costs incurred under lease	$ 54
Term of contract	5 years
Finance lease extension term	5 years
Residual value guarantee		89.00%

Leases - Lease Maturity (Detai

Leases - Lease Maturity (Details) - USD ($)	Sep. 30, 2019	Dec. 31, 2018
Lease Maturity [Abstract]
2019	$ 35,000,000
2019		$ 62,000,000
2020	107,000,000
2020		54,000,000
2021	62,000,000
2021		35,000,000
2022	34,000,000
2022		12,000,000
2023	4,000,000
2023		5,000,000
Thereafter	1,000,000
Thereafter		49,000,000
Total undiscounted lease payments	243,000,000
Less: amount representing interest	12,000,000
Total operating lease liabilities	231,000,000
Less: current portion of long-term lease liability as of September 30, 2019	104,000,000
Long-term lease liability as of September 30, 2019	$ 127,000,000
Sublease rentals		0
Total minimum lease payments		217,000,000
Future minimum commitments for capital lease obligations		$ 0

Leases - Lease Payments to be

Leases - Lease Payments to be Received (Details) $ in Millions	Sep. 30, 2019USD ($)
Leases [Abstract]
2019	$ 2
2020	6
2021	6
2022	6
2023	6
Thereafter	67
Total undiscounted cash flows	93
Thereafter	$ 1

Derivatives - Schedule of Deriv

Derivatives - Schedule of Derivative Instruments in the Consolidated Balance Sheets (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Asset	$ 64
Liability	7
Net Asset (Liability)	57
Not Designated as Hedges
Derivatives, Fair Value [Line Items]
Asset	64	$ 131
Liability	6	4
Net Asset (Liability)	58	127
Commodity | Other current assets | Not Designated as Hedges
Derivatives, Fair Value [Line Items]
Asset	58	131
Liability	5
Net Asset (Liability)	53	131
Commodity | Noncurrent assets | Not Designated as Hedges
Derivatives, Fair Value [Line Items]
Asset	6
Net Asset (Liability)	6
Commodity | Deferred credits and other liabilities | Not Designated as Hedges
Derivatives, Fair Value [Line Items]
Liability	1	4
Net Asset (Liability)	(1)	$ (4)
Cash Flow Hedging
Derivatives, Fair Value [Line Items]
Asset	0
Liability	1
Net Asset (Liability)	(1)
Cash Flow Hedging | Interest Rate | Deferred credits and other liabilities
Derivatives, Fair Value [Line Items]
Liability	1
Net Asset (Liability)	$ (1)

Derivatives - Narrative (Detail

Derivatives - Narrative (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on commodity derivatives	$ 47,000,000	$ (70,000,000)	$ (28,000,000)	$ (324,000,000)
Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on commodity derivatives	33,000,000	19,000,000	(69,000,000)	(69,000,000)
Net gain (loss) on settlements, net	14,000,000	(89,000,000)	41,000,000	(255,000,000)
Interest Rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount					$ 0
Deferred loss related to interest rate swaps	1,000,000
Operating Segments | United States E&P
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on commodity derivatives	14,000,000	$ (89,000,000)	41,000,000	$ (255,000,000)
Cash Flow Hedging | Interest Rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, notional amount	$ 160,000,000		$ 160,000,000

Derivatives - Outstanding Deriv

Derivatives - Outstanding Derivative Contracts (Details) - Not Designated as Hedges	1 Months Ended	9 Months Ended
	Nov. 05, 2019Bbls_per_day$ / bbl	Sep. 30, 2019Bbls_per_day$ / bbl
Three-Way Collars - Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		80,000
Three-Way Collars - Crude Oil 2020 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		42,945
Three-Way Collars - Crude Oil 2021 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		0
Three-Way Collars - Crude Oil 2019 Q4, Ceiling [Member]
Derivative [Line Items]
Underlying, Derivative Volume		74.19
Three-Way Collars - Crude Oil 2020, Ceiling [Member]
Derivative [Line Items]
Underlying, Derivative Volume		65.58
Three-Way Collars - Crude Oil 2021, Ceiling [Member]
Derivative [Line Items]
Underlying, Derivative Volume		0
Three-Way Collars - Crude Oil 2019 Q4, Floor [Member]
Derivative [Line Items]
Underlying, Derivative Volume		56.75
Three-Way Collars - Crude Oil 2020, Floor [Member]
Derivative [Line Items]
Underlying, Derivative Volume		55
Three-Way Collars - Crude Oil 2021 Q1, Floor [Member]
Derivative [Line Items]
Underlying, Derivative Volume		0
Three-Way Collars - Crude Oil 2019 Q4, Sold Put [Member]
Derivative [Line Items]
Underlying, Derivative Volume		49.50
Three-Way Collars - Crude Oil 2020, Sold Put [Member]
Derivative [Line Items]
Underlying, Derivative Volume		47.77
Three-Way Collars - Crude Oil 2021, Sold Put [Member]
Derivative [Line Items]
Underlying, Derivative Volume		0
Midland Basis Swaps - Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		15,000
Underlying, Derivative Volume		(1.40)
Midland Basis Swaps - Crude Oil 2020 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		15,000
Underlying, Derivative Volume		(0.94)
Midland Basis Swaps - Crude Oil 2021 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		0
Underlying, Derivative Volume		0
Brent Basis Swaps - Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		5,000
Underlying, Derivative Volume		(7.24)
Brent Basis Swaps - Crude Oil 2020 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		5,000
Underlying, Derivative Volume		(7.24)
Brent Basis Swaps - Crude Oil 2021 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		808
Underlying, Derivative Volume		(7.24)
Clearbrook Basis Swaps Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		2,000
Underlying, Derivative Volume		(3.33)
Clearbrook Basis Swaps Crude Oil 2020 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		0
Underlying, Derivative Volume		0
Clearbrook Basis Swaps Crude Oil 2021 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		0
Underlying, Derivative Volume		0
ArgusWTIHouston Basis Swaps - Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		10,000
Underlying, Derivative Volume		5.51
ArgusWTIHouston Basis Swaps - Crude Oil 2020 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		0
Underlying, Derivative Volume		0
ArgusWTIHouston Basis Swaps - Crude Oil 2021 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		0
Underlying, Derivative Volume		0
NYMEX Roll Basis Swaps - Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		60,000
Underlying, Derivative Volume		0.38
NYMEX Roll Basis Swaps - Crude Oil 2020 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		0
Underlying, Derivative Volume		0
NYMEX Roll Basis Swaps - Crude Oil 2021 [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day		0
Underlying, Derivative Volume		0
Subsequent Event | Three-Way Collars - Natural Gas Q1 2020 [Domain]
Derivative [Line Items]
Derivative, nonmonetary notional amount | Bbls_per_day	100,000
Subsequent Event | Three-Way Collars - Natural Gas Q1 2020, Ceiling [Member]
Derivative [Line Items]
Underlying, Derivative Volume	3.32
Subsequent Event | Three-Way Collars - Natural Gas Q1 2020, Floor [Member]
Derivative [Line Items]
Underlying, Derivative Volume	2.75
Subsequent Event | Three-Way Collars - Natural Gas Q1 2020, Sold Put [Member]
Derivative [Line Items]
Underlying, Derivative Volume	2.25

Derivatives Derivatives - Sched

Derivatives Derivatives - Schedule of Interest Rate Swap Agreements (Details) - Interest Rate - USD ($)	Sep. 30, 2019	Dec. 31, 2018
Derivative [Line Items]
Derivative, notional amount		$ 0
Weighted average interest rate, LIBOR	1.50%	0.00%
Cash Flow Hedging
Derivative [Line Items]
Derivative, notional amount	$ 160,000,000

Derivatives Derivatives - Sch_2

Derivatives Derivatives - Schedule of mark-to-market impact and commodity derivative settlements (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ 47	$ (70)	$ (28)	$ (324)
Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	33	19	(69)	(69)
Derivative Instrument Not Designated As Hedging Instruments, Gain (Loss) On Settlements, Net	$ 14	$ (89)	$ 41	$ (255)

Fair Value Measurements - Fair

Fair Value Measurements - Fair Values - Recurring (Details) - Recurring - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	$ 61	$ 127
Derivative instruments, liabilities	(4)	0
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	61	127
Derivative instruments, liabilities	(3)
Interest Rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, liabilities	(1)
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	0	21
Derivative instruments, liabilities	(3)	0
Level 1 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	0	21
Derivative instruments, liabilities	(3)
Level 1 | Interest Rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, liabilities	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	61	106
Derivative instruments, liabilities	(1)	0
Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	61	106
Derivative instruments, liabilities	0
Level 2 | Interest Rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, liabilities	(1)
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
Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	0	$ 0
Derivative instruments, liabilities	0
Level 3 | Interest Rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, liabilities	$ 0

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Fair Value Disclosures [Abstract]
Goodwill	$ 95	$ 97

Fair Value Measurements - Fai_2

Fair Value Measurements - Fair Values - Financial Instruments (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Fair Value
Financial assets
Current assets	$ 4	$ 3
Other noncurrent assets	29	76
Total financial assets	33	79
Financial liabilities
Other current liabilities	75	37
Long-term debt, including current portion	6,018	5,469
Deferred credits and other liabilities	108	93
Total financial liabilities	6,201	5,599
Carrying Amount
Financial assets
Current assets	4	3
Other noncurrent assets	35	81
Total financial assets	39	84
Financial liabilities
Other current liabilities	103	58
Long-term debt, including current portion	5,529	5,528
Deferred credits and other liabilities	96	88
Total financial liabilities	$ 5,728	$ 5,674

Debt - Revolving Credit Facilit

Debt - Revolving Credit Facility (Details)	Sep. 30, 2019USD ($)	Aug. 31, 2019USD ($)
Revolving Credit Facility
Line of Credit Facility [Line Items]
Line of credit, outstanding amount	$ 0
Covenant, ratio of indebtedness to net capital, maximum	0.65
Ratio of indebtedness to net capital	0.31
Revolving Credit Facility
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 3,000,000,000	$ 3,400,000,000

Debt - Long-Term Debt (Details)

Debt - Long-Term Debt (Details) - USD ($) $ in Millions	Oct. 03, 2019	Sep. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Outstanding debt		$ 5,500
Long-term debt due within one year		600	$ 0
Long-term debt		$ 4,903	$ 5,499
Senior Unsecured Note Due 2022
Debt Instrument [Line Items]
Interest rate		2.80%
Long-term debt		$ 1,000
Subsequent Event
Debt Instrument [Line Items]
Repayments of Debt	$ 600
Subsequent Event | Senior Unsecured Notes Due 2020
Debt Instrument [Line Items]
Interest rate	2.70%

Debt - Debt Issuance (Details)

Debt - Debt Issuance (Details) - USD ($) $ in Millions	Oct. 01, 2019	Sep. 30, 2019	Dec. 31, 2017
St. John the Baptist Parish, State of Louisiana Revenue Bonds Due 2037
Debt Instrument [Line Items]
Revenue refunding bond		$ 400	$ 1,000
Subsequent Event
Debt Instrument [Line Items]
Proceeds from issuance of debt	$ 600

Debt - Schedule of Debt Issuanc

Debt - Schedule of Debt Issuance (Details) - Subsequent Event	Oct. 01, 2019USD ($)
Sub-series A-1 Bonds
Debt Instrument [Line Items]
Par amount	$ 200,000,000
Interest rate	2.00%
Sub-series A-2 Bonds
Debt Instrument [Line Items]
Par amount	$ 200,000,000
Interest rate	2.10%
Sub-series A-3 Bonds
Debt Instrument [Line Items]
Par amount	$ 200,000,000
Interest rate	2.20%

Stockholders' Equity (Details)

Stockholders' Equity (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Jul. 31, 2019
Equity, Class of Treasury Stock [Line Items]
Shares repurchased	$ 30	$ 236	$ 30	$ 339	$ 2	$ 8
Share Repurchase Program
Equity, Class of Treasury Stock [Line Items]
Shares repurchased (in shares)							19
Shares repurchased							$ 280
Stock repurchase program, remaining authorized repurchase amount	$ 1,500						$ 1,500	$ 1,500

Incentive Based Compensation -

Incentive Based Compensation - Stock Options, Restricted Stock Awards and Restricted Stock Units (Details)	9 Months Ended
	Sep. 30, 2019$ / sharesshares
Number of Shares
Outstanding, beginning (in shares) | shares	6,180,007
Granted (in shares) | shares	648,526
Options Exercised (in shares) | shares	(11,470)
Canceled (in shares) | shares	(925,010)
Outstanding, ending (in shares) | shares	5,892,053
Weighted Average Exercise Price
Outstanding, beginning (in dollars per share)	$ 24.39
Granted (in dollars per share)	16.79
Options Exercised (in dollars per share)	14.25
Canceled (in dollars per share)	25.33
Outstanding, ending (in dollars per share)	23.42
Weighted Average Grant Date Fair Value
Weighted average grant date fair value (in dollars per share)	$ 6.62
Restricted Stock Awards & Units
Awards
Outstanding, beginning (in shares) | shares	8,504,946
Granted (in shares) | shares	3,910,971
Stock Vested (in shares) | shares	(3,608,790)
Canceled (in shares) | shares	(1,504,665)
Outstanding, ending (in shares) | shares	7,302,462
Weighted Average Grant Date Fair Value
Outstanding, beginning (in dollars per share)	$ 14.04
Granted (in dollars per share)	16.90
Stock Vested (in dollars per share)	12.45
Canceled (in dollars per share)	15.76
Outstanding, ending (in dollars per share)	$ 16

Incentive Based Compensation _2

Incentive Based Compensation - Stock-based Performance Unit Awards (Details) - Performance Unit Awards	9 Months Ended
	Sep. 30, 2019$ / sharesshares
Granted Officer
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares) | shares	656,636
Grant date fair value (in dollars per share) | $ / shares	$ 20.66
Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting percentage	200.00%
Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting percentage	0.00%

Defined Benefit Postretiremen_3

Defined Benefit Postretirement Plans (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Amortization:
Net settlement loss	$ (2)	$ 8	$ (9)	$ 11
Estimated future contributions over the remainder of the current year	6		6
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	5	4	14	13
Interest cost	3	7	17	20
Expected return on plan assets	(3)	(9)	(19)	(26)
Amortization:
– prior service credit	(1)	(2)	(5)	(7)
– actuarial loss	2	3	6	9
Net settlement loss	0		2	16
Net periodic benefit cost	6	13	15	25
Payment for other postretirement benefit plans	20		20
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	0	0	1
Interest cost	1	2	3	6
Expected return on plan assets	0	0	0	0
Amortization:
– prior service credit	(5)	(2)	(14)	(6)
– actuarial loss	1	0	1	1
Net settlement loss	0	0	0	0
Net periodic benefit cost	$ (3)	$ 0	(10)	$ 2
Payment for other postretirement benefits			17
Funded Plan
Amortization:
Payment for pension benefits			35
Unfunded Plan
Amortization:
Payment for pension benefits			$ 4

Defined Benefit Postretiremen_4

Defined Benefit Postretirement Plans Defined Benefit Postretirement Plan - Obligations and Funded Status (Details) - Foreign Plan [Member] $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2019USD ($)	Dec. 31, 2018USD ($)
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Accumulated Benefit Obligation	$ 0	$ 511
Benefit obligations, beginning balance	511	599
Interest cost	8	14
Defined Benefit Plan, Accumulated Benefit Obligation, Increase (Decrease) for Plan Amendment	0	3
Defined Benefit Plan, Benefit Obligation, Divestiture	(549)	0
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	36	(38)
Defined Benefit Plan, Benefit Obligation, Foreign Currency Translation Gain (Loss)	6	(29)
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Settlement	0	(23)
Defined Benefit Plan, Benefit Obligation, Benefits Paid	(12)	(15)
Benefit obligations, ending balance	0	511
Fair value of plan assets, beginning balance	594	670
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss)	68	(21)
Defined Benefit Plan, Plan Assets, Contributions by Employer	8	17
Defined Benefit Plan, Plan Assets, Foreign Currency Translation Gain (Loss)	8	(34)
Defined Benefit Plan, Plan Assets, Divestiture	(666)	0
Defined Benefit Plan, Plan Assets, Payment for Settlement	0	(23)
Defined Benefit Plan, Plan Assets, Benefits Paid	(12)	(15)
Fair value of plan assets, ending balance	0	594
Defined Benefit Plan, Funded (Unfunded) Status of Plan	0	83
Defined Benefit Plan, Accumulated Other Comprehensive Income (Loss), Gain (Loss), before Tax	0	59
Defined Benefit Plan, Accumulated Other Comprehensive (Income) Loss, Prior Service Cost (Credit), before Tax	0	5
Noncurrent assets
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position	0	83
Accrued benefit cost
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position	$ 0	$ 83

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, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other net periodic benefit costs	$ 2			$ (8)			$ 9	$ (11)
Income before income taxes	175			357			395	1,021
Net interest and other	(64)			(58)			(177)	(168)
Foreign currency translation adjustment related to sale of U.K pension plan	30			0			30	0
Income tax impact	(7)			0			(7)	0
Net income	165	$ 161	$ 174	254	$ 96	$ 356	500	706
Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Divestiture of U.K. pension plan	83			0			83	0
Amortization of prior service credit | Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other net periodic benefit costs	6			4			19	13
Amortization of actuarial loss | Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other net periodic benefit costs	(3)			(3)			(7)	(10)
Net settlement loss | Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other net periodic benefit costs	0			(10)			(2)	(16)
Postretirement and postemployment plans | Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes	3			(9)			10	(13)
Net interest and other	0			(4)			0	(4)
Income tax impact	46			0			46	0
Net income	$ 70			$ (13)			$ 77	$ (17)

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Included in operating activities:
Interest paid, net of amounts capitalized		$ 190	$ 187
Income taxes paid to taxing authorities		151	298
Noncash investing activities:
Increase in asset retirement costs		40	12
Asset retirement obligations assumed by buyer(a)		1,082	$ 82
Capital expenditures incurred but not yet paid	$ 238	$ 302

Equity Method Investments (Deta

Equity Method Investments (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 667		$ 667		$ 745
Income data:
Revenues and other income	184	$ 238	637	$ 664
Income from operations	61	151	192	391
Net income	$ 45	$ 129	$ 140	$ 331
EGHoldings
Schedule of Equity Method Investments [Line Items]
Ownership percentage	60.00%		60.00%
Equity method investments	$ 324		$ 324		402
Alba Plant LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage	52.00%		52.00%
Equity method investments	$ 158		$ 158		167
AMPCO
Schedule of Equity Method Investments [Line Items]
Ownership percentage	45.00%		45.00%
Equity method investments	$ 185		$ 185		$ 176

Commitments and Contingencies (

Commitments and Contingencies (Details) £ in Millions, $ in Millions	Sep. 30, 2019USD ($)	Nov. 30, 2018GBP (£)	Dec. 31, 2017USD ($)
Loss Contingencies [Line Items]
Surety bond, notional amount | £		£ 92
Surety bond exposure, liability	$ 6
Foreign Tax Authority | UK Government
Loss Contingencies [Line Items]
Income taxes paid from settlement with taxing authority			$ 108

Uncategorized Items - mro-20190

Label	Element	Value
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Including Disposal Group and Discontinued Operations	us-gaap_CashCashEquivalentsRestrictedCashAndRestrictedCashEquivalentsIncludingDisposalGroupAndDiscontinuedOperations	$ 1,564,000,000