Marathon Oil (MRO) 10-Q 8 Aug 19 2019 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2019	Jul. 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	Jun. 30, 2019
Document Fiscal Period Focus	Q2
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		804,042,151
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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Revenues and other income:
Revenues from contracts with customers	$ 1,381	$ 1,447	$ 2,581	$ 2,984
Net gain (loss) on commodity derivatives	16	(152)	(75)	(254)
Income from equity method investments	31	60	42	97
Net gain (loss) on disposal of assets	(8)	50	34	307
Other income	13	12	48	16
Total revenues and other income	1,433	1,417	2,630	3,150
Costs and expenses:
Production	193	205	380	422
Shipping, handling and other operating	170	126	324	256
Exploration	26	65	85	117
Depreciation, depletion and amortization	605	612	1,159	1,202
Impairments	18	34	24	42
Taxes other than income	79	65	151	129
General and administrative	87	105	181	205
Total costs and expenses	1,178	1,212	2,304	2,373
Income from operations	255	205	326	777
Net interest and other	(64)	(65)	(113)	(110)
Other net periodic benefit costs	2	0	7	(3)
Income before income taxes	193	140	220	664
Provision (benefit) for income taxes	32	44	(115)	212
Net income	$ 161	$ 96	$ 335	$ 452
Net income per share:
Basic	$ 0.20	$ 0.11	$ 0.41	$ 0.53
Per diluted share:
Diluted	$ 0.20	$ 0.11	$ 0.41	$ 0.53
Weighted average common shares outstanding:
Basic	813	854	817	853
Diluted	814	855	817	854

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Statement of Comprehensive Income [Abstract]
Net income	$ 161	$ 96	$ 335	$ 452
Postretirement and postemployment plans:
Change in actuarial loss in postretirement and postemployment plans	(9)	13	(13)	17
Postretirement and postemployment plans, net of tax	(9)	13	(13)	17
Other Comprehensive Income (Loss), Securities, Available-for-sale, Adjustment, after Tax	0	4	0	4
Other comprehensive income (loss)	(9)	17	(13)	21
Comprehensive income	$ 152	$ 113	$ 322	$ 473

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 961
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Including Disposal Group and Discontinued Operations	1,296	$ 1,462
Receivables, less reserve of $12 and $11	1,144	1,079
Inventories	72	96
Other current assets	101	257
Current assets held for sale	410	27
Total current assets	2,688	2,921
Equity method investments	684	745
Property, plant and equipment, less accumulated depreciation, depletion and amortization of $17,260 and $21,830	16,730	16,804
Goodwill	95	97
Other noncurrent assets	420	723
Noncurrent assets held for sale	665	31
Total assets	21,282	21,321
Current liabilities:
Accounts payable	1,401	1,320
Payroll and benefits payable	88	154
Accrued taxes	77	181
Other current liabilities	216	170
Long-term debt due within one year	600	0
Current liabilities held for sale	89	7
Total current liabilities	2,471	1,832
Long-term debt	4,902	5,499
Deferred tax liabilities	184	199
Defined benefit postretirement plan obligations	179	195
Asset retirement obligations	189	1,081
Deferred credits and other liabilities	292	279
Noncurrent liabilities held for sale	964	108
Total liabilities	9,181	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 June 30, 2019 and December 31, 2018)	937	937
Held in treasury, at cost – 133 million shares and 118 million shares	(3,984)	(3,816)
Additional paid-in capital	7,170	7,238
Retained earnings	7,928	7,706
Accumulated other comprehensive income	50	63
Total stockholders’ equity	12,101	12,128
Total liabilities and stockholders’ equity	$ 21,282	$ 21,321

Consolidated Balance Sheets (_2

Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Millions	Jun. 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 $17,260 and $21,830	$ (17,260)	$ (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	133,000,000	118,000,000

Consolidated Statements of Cash

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Operating activities:
Net income	$ 335	$ 452
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	1,159	1,202
Impairments	24	42
Exploratory dry well costs and unproved property impairments	69	93
Net gain on disposal of assets	(34)	(307)
Deferred income taxes	(33)	(6)
Net loss on derivative instruments	75	254
Net settlements of derivative instruments	27	(166)
Pension and other post retirement benefits, net	(41)	(51)
Stock-based compensation	32	28
Equity method investments, net	12	27
Changes in:
Current receivables	(95)	(256)
Inventories	3	(17)
Current accounts payable and accrued liabilities	(158)	133
Other current assets and liabilities	119	(8)
All other operating, net	(182)	(4)
Net cash provided by operating activities	1,312	1,416
Investing activities:
Additions to property, plant and equipment	(1,262)	(1,300)
Additions to other assets	42	(129)
Acquisitions, net of cash acquired	0	(25)
Disposal of assets, net of cash transferred to the buyer	69	1,183
Equity method investments - return of capital	49	32
All other investing, net	(27)	7
Net cash used in investing activities	(1,129)	(232)
Financing activities:
Purchases of common stock	(266)	(11)
Dividends paid	(82)	(85)
All other financing, net	(2)	18
Net cash used in financing activities	(350)	(78)
Effect of exchange rate on cash and cash equivalents	1	(2)
Net increase (decrease) in cash and cash equivalents	(166)	1,104
Cash and cash equivalents at beginning of period	1,462	563
Cash and cash equivalents at end of period	1,296	1,667
Cash and cash equivalents	961	1,667
Cash and cash equivalents included in current assets held for sale	$ 335	$ 0

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	452
Other comprehensive income (loss)	21
Ending balance at Jun. 30, 2018	12,132	0	937	(3,137)	7,227	7,146	(41)
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)
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	335
Other comprehensive income (loss)	(13)
Ending balance at Jun. 30, 2019	12,101	0	937	(3,984)	7,170	7,928	50
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

Consolidated Statements of St_2

Consolidated Statements of Stockholders' Equity (Unaudited) (Parenthetical) - $ / shares	3 Months Ended				6 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2019	Jun. 30, 2018
Statement of Stockholders' Equity [Abstract]
Dividends paid (in dollars per share)	$ 0.05	$ 0.05	$ 0.05	$ 0.05	$ 0.10	$ 0.10

Basis of Presentation

Basis of Presentation	6 Months Ended
	Jun. 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 second quarter and first six months of 2019 are not necessarily indicative of the results to be expected for the full year. As a result of the announcement to sell our U.K. business in the first quarter of 2019 , we have reflected these assets and liabilities as held for sale at June 30, 2019 in the consolidated balance sheet and the consolidated statement of cash flows. The related disclosures in this report exclude these held for sale amounts, unless otherwise noted. This divestiture is discussed in further detail in Note 4 . Reclassifications

Accounting Standards

Accounting Standards	6 Months Ended
	Jun. 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. Early adoption is permitted starting January 2019. We are evaluating the provisions of this accounting standards update and assessing the impact, if any, it may have on our consolidated results of operations, financial position or 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	6 Months Ended
	Jun. 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 of stock options for each of the three and six months ended June 30, 2019 and 6 million and 8 million of stock options for the three and six months ended June 30, 2018 , respectively, that were antidilutive. Three Months Ended June 30, Six Months Ended June 30, (In millions, except per share data) 2019 2018 2019 2018 Net income $ 161 $ 96 $ 335 $ 452 Weighted average common shares outstanding 813 854 817 853 Effect of dilutive securities 1 1 — 1 Weighted average common shares, diluted 814 855 817 854 Net income per share: Basic $ 0.20 $ 0.11 $ 0.41 $ 0.53 Diluted $ 0.20 $ 0.11 $ 0.41 $ 0.53 Dividends per share $ 0.05 $ 0.05 $ 0.10 $ 0.10

Dispositions

Dispositions	6 Months Ended
	Jun. 30, 2019
Discontinued Operations and Disposal Groups [Abstract]
Dispositions	Dispositions United States Segment In the second quarter of 2019, we entered into agreements to sell non-core, proved properties and classified these transactions as held for sale in the consolidated balance sheet at June 30, 2019 , with total assets of $26 million and total liabilities of $7 million . 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 In July 2019, we closed on the sale of our U.K. business (Marathon Oil U.K. LLC and Marathon Oil West of Shetlands Limited), which resulted in proceeds of approximately $95 million and reflects the assumption by RockRose Energy PLC (the buyer) of the U.K. business’ working capital and cash equivalent balances of approximately $345 million on December 31, 2018 . The transaction has an effective date of January 1, 2019. Our U.K. business was classified as held for sale in the consolidated balance sheets at June 30, 2019 , with total assets of $1,049 million (including $125 million in cash restricted by escrow agreement terms with the balance transferring to buyer upon close) and total liabilities of $1,046 million , including asset retirement obligations of $966 million . For the second quarter of 2019 and 2018 , we had approximately $22 million and $48 million , in income before income taxes relating to our U.K business. For the six months ended June 30, 2019 and 2018 , we had approximately $37 million and $107 million , in income before income taxes relating to our U.K business. 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	6 Months Ended
	Jun. 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 June 30, 2019 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 350 $ 453 $ 111 $ 77 $ 30 $ 1,021 Natural gas liquids 30 15 31 7 1 84 Natural gas 32 6 36 1 4 79 Other 1 — — — 15 16 Revenues from contracts with customers $ 413 $ 474 $ 178 $ 85 $ 50 $ 1,200 Three Months Ended June 30, 2018 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 394 $ 405 $ 111 $ 59 $ 44 $ 1,013 Natural gas liquids 45 17 45 6 2 115 Natural gas 33 8 38 2 5 86 Other 1 — — — 6 7 Revenues from contracts with customers $ 473 $ 430 $ 194 $ 67 $ 57 $ 1,221 Six Months Ended June 30, 2019 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 668 $ 825 $ 188 $ 141 $ 58 $ 1,880 Natural gas liquids 65 25 53 15 3 161 Natural gas 66 18 81 7 10 182 Other 3 — — — 36 39 Revenues from contracts with customers $ 802 $ 868 $ 322 $ 163 $ 107 $ 2,262 Six Months Ended June 30, 2018 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 760 $ 735 $ 226 $ 114 $ 97 $ 1,932 Natural gas liquids 87 32 82 12 5 218 Natural gas 66 18 81 7 12 184 Other 3 — — — 9 12 Revenues from contracts with customers $ 916 $ 785 $ 389 $ 133 $ 123 $ 2,346 International Three Months Ended June 30, 2019 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 101 $ 51 $ 9 $ 161 Natural gas liquids 1 — — 1 Natural gas 9 4 — 13 Other — 6 — 6 Revenues from contracts with customers $ 111 $ 61 $ 9 $ 181 Three Months Ended June 30, 2018 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 100 $ 71 $ 22 $ 193 Natural gas liquids 1 3 — 4 Natural gas 10 12 — 22 Other — 7 — 7 Revenues from contracts with customers $ 111 $ 93 $ 22 $ 226 Six Months Ended June 30, 2019 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 148 $ 107 $ 19 $ 274 Natural gas liquids 2 1 — 3 Natural gas 16 12 — 28 Other — 14 — 14 Revenues from contracts with customers $ 166 $ 134 $ 19 $ 319 Six Months Ended June 30, 2018 (In millions) E.G. U.K. Libya Other International Total Crude oil and condensate $ 171 $ 166 $ 187 $ 45 $ 569 Natural gas liquids 2 3 — — 5 Natural gas 19 20 9 — 48 Other — 16 — — 16 Revenues from contracts with customers $ 192 $ 205 $ 196 $ 45 $ 638 Contract receivables and liabilities The following table provides information about receivables and contract assets (liabilities) from contracts with customers. (In millions) June 30, 2019 January 1, 2019 Receivables from contracts with customers, included in receivables, less reserves $ 797 $ 714 Contract asset (liability) $ 21 $ (1 ) The contract liability primarily relates to the advance consideration received from customers for crude oil sales and processing services in the U.K. A contract asset would represent crude oil delivered in the U.K. to a customer for which payment will be collected over time as it becomes due under the pricing terms stipulated in the sales agreement. As a practical expedient, when the balance of this U.K. customer is a contract asset, we do not adjust revenue for the effects of a significant financing element as the period between when crude oil is delivered to the customer and when payment is expected to be received is one year or less at contract inception. Changes in the contract asset (liability) balance during the period are as follows. Six Months Ended (In millions) June 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) balance as of June 30, 2019 $ 21

Segment Information

Segment Information	6 Months Ended
	Jun. 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 and 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, proved 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 June 30, 2019 Not Allocated (In millions) U.S. Int’l to Segments Total Revenues from contracts with customers $ 1,200 $ 181 $ — $ 1,381 Net gain on commodity derivatives 5 — 11 (b) 16 Income from equity method investments — 31 — 31 Net loss on disposal of assets — — (8 ) (c) (8 ) Other income 4 2 7 13 Less costs and expenses: Production 147 46 — 193 Shipping, handling and other operating 147 10 13 170 Exploration 26 — — 26 Depreciation, depletion and amortization 561 38 6 605 Impairments — — 18 (d) 18 Taxes other than income 79 — — 79 General and administrative 31 8 48 87 Net interest and other — — 64 64 Other net periodic benefit costs — (1 ) (1 ) (2 ) Income tax provision (benefit) 3 17 12 32 Segment income $ 215 $ 96 $ (150 ) $ 161 Capital expenditures (a) $ 686 $ 10 $ 5 $ 701 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 13 ). (c) Primarily related to the sale of our certain non-core proved properties in our International segment (See Note 4 ). (d) Primarily a result of the anticipated sale of non-core proved properties in the United States segment (See Note 10 ). Three Months Ended June 30, 2018 Not Allocated (In millions) U.S. Int’l to Segments Total Revenues from contracts with customers $ 1,221 $ 226 $ — $ 1,447 Net loss on commodity derivatives (107 ) — (45 ) (b) (152 ) Income from equity method investments — 60 — 60 Net gain on disposal of assets — — 50 50 Other income 2 2 8 12 Less costs and expenses: Production 153 52 — 205 Shipping, handling and other operating 117 10 (1 ) 126 Exploration 64 1 — 65 Depreciation, depletion and amortization 556 50 6 612 Impairments — — 34 (c) 34 Taxes other than income 68 — (3 ) 65 General and administrative 35 9 61 105 Net interest and other — — 65 65 Other net periodic benefit costs — (2 ) 2 — Income tax provision (benefit) — 26 18 44 Segment income (loss) $ 123 $ 142 $ (169 ) $ 96 Capital expenditures (a) $ 641 $ 16 $ 5 $ 662 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 13 ). (c) Primarily a result of anticipated sales of certain non-core proved properties in our International and United States segments (See Note 10 ). Six Months Ended June 30, 2019 Not Allocated (In millions) U.S. Int’l to Segments Total Revenues from contracts with customers $ 2,262 $ 319 $ — $ 2,581 Net gain (loss) on commodity derivatives 27 — (102 ) (b) (75 ) Income from equity method investments — 42 — 42 Net gain on disposal of assets — — 34 (c) 34 Other income 5 5 38 (d) 48 Less costs and expenses: Production 286 96 (2 ) 380 Shipping, handling and other operating 287 23 14 324 Exploration 85 — — 85 Depreciation, depletion and amortization 1,075 72 12 1,159 Impairments — — 24 (e) 24 Taxes other than income 153 — (2 ) 151 General and administrative 60 15 106 181 Net interest and other — — 113 113 Other net periodic benefit costs — (3 ) (4 ) (7 ) Income tax provision (benefit) 1 6 (122 ) (f) (115 ) Segment income $ 347 $ 157 $ (169 ) $ 335 Capital expenditures (a) $ 1,292 $ 15 $ 8 $ 1,315 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 13 ). (c) Primarily related to the sale of our working interest in the Droshky field (Gulf of Mexico) (See Note 4 ). (d) Primarily related to the indemnification of certain tax liabilities in connection with the 2010-2011 Federal Tax Audit (See Note 7 ). (e) Primarily a result of anticipated sales of our certain non-core proved properties in our International and United States segments (See Note 10 ). (f) Primarily relates to the settlement of the 2010-2011 Federal Tax Audit (See Note 7 ). Six Months Ended June 30, 2018 Not Allocated (In millions) U.S. Int’l to Segments Total Revenue from contracts with customers $ 2,346 $ 638 $ — $ 2,984 Net loss on commodity derivatives (166 ) — (88 ) (b) (254 ) Income from equity method investments — 97 — 97 Net gain on disposal of assets — — 307 (c) 307 Other income 5 3 8 16 Less costs and expenses: Production 304 119 (1 ) 422 Shipping, handling and other operating 228 29 (1 ) 256 Exploration 115 2 — 117 Depreciation, depletion and amortization 1,084 104 14 1,202 Impairments — — 42 (d) 42 Taxes other than income 132 — (3 ) 129 General and administrative 71 18 116 205 Net interest and other — — 110 110 Other net periodic benefit costs — (4 ) 7 3 Income tax provision (benefit) 3 196 13 212 Segment income (loss) $ 248 $ 274 $ (70 ) $ 452 Capital expenditures (a) $ 1,252 $ 22 $ 10 $ 1,284 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 13 ). (c) Primarily related to the gain on sale of our Libya subsidiary (See Note 4 ). (d) Primarily a result of anticipated sales of certain non-core proved properties in our International and United States segments (See Note 4 ).

Income Taxes

Income Taxes	6 Months Ended
	Jun. 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 6 . For the three and six months ended June 30, 2019 and 2018 , our effective income tax rates were as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Effective income tax expense (benefit) rate (a) 17 % 31 % (52 )% 32 % (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 second quarter of 2019 were impacted by pre-tax income and foreign currency revaluation. Income taxes for the six months ended June 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 six months of 2019 . Excluding these discrete adjustments, the effective income tax rate for the first six months of 2019 was an expense of 13% . • Income taxes for the second quarter of 2018 were impacted by foreign currency revaluation. During the six months ended June 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 22 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	6 Months Ended
	Jun. 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) June 30, 2019 December 31, 2018 Crude oil and natural gas $ 9 $ 11 Supplies and other items 63 85 Inventories $ 72 $ 96

Property, Plant and Equipment,

Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization	6 Months Ended
	Jun. 30, 2019
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization	Property, Plant and Equipment (In millions) June 30, 2019 December 31, 2018 United States $ 16,112 $ 16,011 International 540 710 Corporate 78 83 Net property, plant and equipment $ 16,730 $ 16,804 We had no exploratory well costs capitalized greater than one year as of June 30, 2019 and December 31, 2018 .

Impairments

Impairments	6 Months Ended
	Jun. 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 June 30, 2019 2018 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 19 $ 18 $ 69 $ 34 Six Months Ended June 30, 2019 2018 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 56 $ 24 $ 69 $ 42 • 2019 – During the six months ended June 30, 2019 , we recorded pre-tax non-cash proved property impairments of $24 million , primarily as a result of anticipated sales proceeds 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 4 for discussion of the divestiture in further detail. • 2018 – During the six months ended June 30, 2018 , we recorded pre-tax non-cash proved property impairments of $42 million , to a fair value of $69 million , primarily as a result of anticipated sales proceeds for certain non-core proved properties in our International and United States segments. The related fair value measurement utilized the market approach, based upon anticipated sales proceeds less costs to sell which resulted in a Level 2 classification. See Note 4 for discussion of the divestiture in further detail.

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 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 six months ended were as follows: June 30, (In millions) 2019 2018 Beginning balance $ 1,145 $ 1,483 Incurred liabilities, including acquisitions 18 8 Settled liabilities, including dispositions (129 ) (14 ) Accretion expense (included in depreciation, depletion and amortization) 26 36 Revisions of estimates 11 (9 ) Held for sale (864 ) (89 ) Ending balance $ 207 $ 1,415 June 30, 2019 • Settled liabilities are primarily related to the sale of our working interest in the Droshky field (Gulf of Mexico), which closed during the first quarter of 2019. • Held for sale includes the asset retirement obligations of $966 million associated with the sale of our U.K. business, which was partially offset by settled liabilities for dispositions primarily related to the Droshky field in the first quarter of 2019. See Note 4 for discussion of the divestitures in further detail. • Ending balance includes $18 million classified as short-term at June 30, 2019 . June 30, 2018 • Held for sale includes the asset retirement obligations associated with the sale of non-core, non-operated conventional properties, primarily in the Gulf of Mexico. See Note 4 for discussion of the divestitures in further detail. • Ending balance includes $51 million classified as short-term at June 30, 2018 .

Leases

Leases	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Leases	Leases Supplemental balance sheet information related to leases was as follows: (In millions) June 30, 2019 Operating Leases: Balance Sheet Location: ROU asset Other noncurrent assets $ 248 Current portion of long-term lease liability Other current liabilities $ 104 Long-term lease liability Deferred credits and other liabilities $ 151 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 June 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 June 30, 2019 Six Months Ended June 30, 2019 Lease costs: Operating lease costs (a) $ 19 $ 40 Short-term lease costs (b) 76 157 Variable lease costs (c) 12 72 Total lease costs $ 107 $ 269 Other information: Cash paid for amounts included in the measurement of operating lease liabilities $ 27 ROU assets obtained in exchange for new operating lease liabilities (d) $ 293 (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 six 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 $248 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 June 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 $ 61 2020 106 2021 62 2022 35 2023 5 Thereafter 1 Total undiscounted lease payments $ 270 Less: amount representing interest 15 Total operating lease liabilities $ 255 Less: current portion of long-term lease liability as of June 30, 2019 104 Long-term lease liability as of June 30, 2019 $ 151 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 21 . The lease was classified as an operating lease and expires in 2024, with a lessee option to extend through 2034. Lease payments are fixed for the entire duration of the agreement at approximately $6 million per year. Our lease income is reported in other income in our consolidated statements of income for all periods presented. The undiscounted cash flows to be received under this lease agreement are summarized below. (In millions) Operating Lease Future Cash Receipts 2019 $ 4 2020 6 2021 6 2022 6 2023 6 Thereafter 66 Total undiscounted cash flows $ 94 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 June 30, 2019 , project costs incurred totaled approximately $50 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) June 30, 2019 Operating Leases: Balance Sheet Location: ROU asset Other noncurrent assets $ 248 Current portion of long-term lease liability Other current liabilities $ 104 Long-term lease liability Deferred credits and other liabilities $ 151 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 June 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 June 30, 2019 Six Months Ended June 30, 2019 Lease costs: Operating lease costs (a) $ 19 $ 40 Short-term lease costs (b) 76 157 Variable lease costs (c) 12 72 Total lease costs $ 107 $ 269 Other information: Cash paid for amounts included in the measurement of operating lease liabilities $ 27 ROU assets obtained in exchange for new operating lease liabilities (d) $ 293 (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 six 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 $248 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 June 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 $ 61 2020 106 2021 62 2022 35 2023 5 Thereafter 1 Total undiscounted lease payments $ 270 Less: amount representing interest 15 Total operating lease liabilities $ 255 Less: current portion of long-term lease liability as of June 30, 2019 104 Long-term lease liability as of June 30, 2019 $ 151 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 21 . The lease was classified as an operating lease and expires in 2024, with a lessee option to extend through 2034. Lease payments are fixed for the entire duration of the agreement at approximately $6 million per year. Our lease income is reported in other income in our consolidated statements of income for all periods presented. The undiscounted cash flows to be received under this lease agreement are summarized below. (In millions) Operating Lease Future Cash Receipts 2019 $ 4 2020 6 2021 6 2022 6 2023 6 Thereafter 66 Total undiscounted cash flows $ 94 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 June 30, 2019 , project costs incurred totaled approximately $50 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	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	Derivatives For further information regarding the fair value measurement of derivative instruments see Note 14 . All of our commodity derivatives are subject to enforceable master netting arrangements or similar agreements under which we report net amounts. The following tables present the gross fair values of derivative instruments and the reported net amounts along with where they appear on the consolidated balance sheets. June 30, 2019 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ 33 $ 4 $ 29 Other current assets Commodity — 4 (4 ) Deferred credits and other liabilities Total Not Designated as Hedges $ 33 $ 8 $ 25 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 Commodity Derivatives 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 commodity derivatives were not designated as hedges. The following table sets forth outstanding derivative contracts as of June 30, 2019 , and the weighted average prices for those contracts: 2019 2020 2021 Crude Oil Third Quarter Fourth Quarter Full Year Full Year NYMEX WTI Three-Way Collars (a) Volume (Bbls/day) 80,000 80,000 9,945 — Weighted average price per Bbl: Ceiling $ 74.19 $ 74.19 $ 70.00 $ — Floor $ 56.75 $ 56.75 $ 55.00 $ — Sold put $ 49.50 $ 49.50 $ 47.00 $ — Basis Swaps - Argus WTI Midland (b) Volume (Bbls/day) 15,000 15,000 15,000 — Weighted average price per Bbl $ (1.40 ) $ (1.40 ) $ (0.94 ) $ — Basis Swaps - Net Energy Clearbrook (c) Volume (Bbls/day) 1,000 1,000 — — Weighted average price per Bbl $ (3.50 ) $ (3.50 ) $ — $ — Basis Swaps - NYMEX WTI / ICE Brent (d) Volume (Bbls/day) 5,000 5,000 5,000 808 Weighted average price per Bbl $ (7.24 ) $ (7.24 ) $ (7.24 ) $ (7.24 ) Basis Swaps - Argus WTI Houston (e) Volume (Bbls/day) 10,000 10,000 — — Weighted average price per Bbl $ 5.51 $ 5.51 $ — $ — NYMEX Roll Basis Swaps Volume (Bbls/day) 60,000 60,000 — — Weighted average price per Bbl $ 0.38 $ 0.38 $ — $ — (a) Between July 1, 2019 and August 5, 2019 , we entered into 10,000 Bbls/day of three-way collars for January - December 2020, with a ceiling of $65.12 , a sold put of $48.00 , and a floor of $55.00 . (b) The basis differential price is indexed against Argus WTI Midland. (c) The basis differential price is indexed against Net Energy Canada Bakken SW at Clearbrook (“UHC”). (d) The basis differential price is indexed against International Commodity Exchange (“ICE”) Brent and NYMEX WTI. (e) The basis differential price is indexed against Argus WTI Houston. The mark-to-market impact and settlement of these commodity derivative instruments appears in net gain (loss) on commodity derivatives in our consolidated statements of income. The mark-to-market impact for the three and six months ended June 30, 2019 was a gain of $11 million and a loss of $102 million compared to a loss of $45 million and a loss of $88 million for the same respective periods in 2018 . Net settlements of commodity derivative instruments for the three and six months ended June 30, 2019 was a gain of $5 million and a gain of $27 million compared to a loss of $107 million and a loss of $166 million for the same respective periods in 2018 .

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 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 June 30, 2019 and December 31, 2018 by hierarchy level. June 30, 2019 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ — $ 30 $ — $ 30 Derivative instruments, assets $ — $ 30 $ — $ 30 Derivative instruments, liabilities Commodity (a) $ (5 ) $ — $ — $ (5 ) Derivative instruments, liabilities $ (5 ) $ — $ — $ (5 ) (a) Derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 13 . 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 13 . 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. Fair Value Estimates - Goodwill As of June 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 See Note 4 and Note 10 for detail on our fair values for nonrecurring items, such as 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 June 30, 2019 and December 31, 2018. June 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 25 31 76 81 Total financial assets $ 29 $ 35 $ 79 $ 84 Financial liabilities Other current liabilities $ 76 $ 101 $ 37 $ 58 Long-term debt, including current portion (a) 6,048 5,528 5,469 5,528 Deferred credits and other liabilities 109 98 93 88 Total financial liabilities $ 6,233 $ 5,727 $ 5,599 $ 5,674 (a) Excludes capital leases and 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	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Debt	Debt Revolving Credit Facility As of June 30, 2019 , we had no borrowings against our $3.4 billion revolving credit facility (the “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 that our ratio of total debt to total capitalization not exceed 65% as of the last day of each fiscal quarter. If an event of default occurs, 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 June 30, 2019 , we were in compliance with this covenant with a debt-to-capitalization ratio of 31% . Long-term debt At June 30, 2019 , we had $5.5 billion of total debt outstanding, of which $600 million is due June 2020.

Stockholders' Equity

Stockholders' Equity	6 Months Ended
	Jun. 30, 2019
Equity [Abstract]
Stockholders' Equity	Stockholders’ Equity In the six months ended June 30, 2019 , we acquired approximately 16 million common shares at a cost of $250 million , which were held as treasury stock. Including these repurchases, the total remaining share repurchase authorization was $550 million at June 30, 2019 . 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 .

Incentive Based Compensation

Incentive Based Compensation	6 Months Ended
	Jun. 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 six 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 3,846,526 $ 16.96 Exercised/Vested (10,470 ) $ 14.92 (3,562,277 ) $ 12.41 Canceled (590,624 ) $ 24.01 (377,692 ) $ 15.35 Outstanding at June 30, 2019 6,227,439 $ 23.65 8,411,503 $ 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 six 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% based on performance achieved and as determined by the Compensation Committee of the Board of Directors. The performance goals are tied to our total shareholder return (“TSR”) as compared to TSR for a group of peer companies determined by the Compensation Committee of our Board of Directors. Dividend equivalents may accrue during the performance period and would be paid in cash at the end of the performance period based on the amount of dividends credited generally over the performance period on shares of our common stock that represent the number of the units granted multiplied by the vesting percentage.

Defined Benefit Postretirement

Defined Benefit Postretirement Plans	6 Months Ended
	Jun. 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 June 30, Pension Benefits Other Benefits (In millions) 2019 2018 2019 2018 Service cost $ 5 $ 5 $ — $ — Interest cost 7 6 1 2 Expected return on plan assets (8 ) (8 ) — — Amortization: – prior service cost (credit) (2 ) (3 ) (4 ) (2 ) – actuarial loss 2 3 — 1 Net settlement loss (a) 2 2 — — Net periodic benefit cost (b) $ 6 $ 5 $ (3 ) $ 1 Six Months Ended June 30, Pension Benefits Other Benefits (In millions) 2019 2018 2019 2018 Service cost $ 9 $ 9 $ — $ 1 Interest cost 14 13 2 4 Expected return on plan assets (16 ) (17 ) — — Amortization: – prior service credit (4 ) (5 ) (8 ) (4 ) – actuarial loss 4 6 — 1 Net settlement loss (a) 2 6 — — Net periodic benefit cost (b) $ 9 $ 12 $ (6 ) $ 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 six months of 2019 , we made contributions of $29 million to our funded pension plans and we expect to make additional contributions up to an estimated $12 million over the remainder of 2019 . During the first six months of 2019 , we made payments of $3 million and $11 million related to unfunded pension plans and other postretirement benefit plans. The net U.K. pension assets are classified as held for sale in the consolidated balance sheet as of June 30, 2019 . See Note 4

Reclassifications Out of Accumu

Reclassifications Out of Accumulated Other Comprehensive Income (Loss)	6 Months Ended
	Jun. 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 June 30, Six Months Ended June 30, (In millions) 2019 2018 2019 2018 Income Statement Line Postretirement and postemployment plans Amortization of prior service credit $ 6 $ 5 $ 12 $ 9 Other net periodic benefit costs Amortization of actuarial loss (2 ) (4 ) (4 ) (7 ) Other net periodic benefit costs Net settlement loss (2 ) (2 ) (2 ) (6 ) Other net periodic benefit costs 2 (1 ) 6 (4 ) Income (loss) before income taxes Other insignificant, net of tax — (4 ) — (4 ) Net interest and other — — — — (Provision) benefit for income taxes (a) Total reclassifications to expense, net of tax $ 2 $ (5 ) $ 6 $ (8 ) Net income (loss) (a)

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	6 Months Ended
	Jun. 30, 2019
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Six Months Ended June 30, (In millions) 2019 2018 Included in operating activities: Interest paid, net of amounts capitalized $ 70 $ 134 Income taxes paid to taxing authorities 149 282 Noncash investing activities: Increase (decrease) in asset retirement costs $ 29 $ (1 ) Asset retirement obligations assumed by buyer (a) 109 3 (a) In 2019, we closed the sale of the Droshky field (Gulf of Mexico) and the sale of our non-operated interest in the Atrush block in Kurdistan. Other noncash investing activities include accrued capital expenditures for the six months ended June 30, 2019 and 2018 of $300 million and $303 million .

Equity Method Investments

Equity Method Investments	6 Months Ended
	Jun. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Equity Method Investments During the periods ended June 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: Ownership as of June 30, December 31, (In millions) June 30, 2019 2019 2018 EGHoldings 60% $ 331 $ 402 Alba Plant LLC 52% 173 167 AMPCO 45% 180 176 Total $ 684 $ 745 Summarized financial information for equity method investees is as follows: Three Months Ended June 30, Six Months Ended June 30, (In millions) 2019 2018 2019 2018 Income data: Revenues and other income $ 233 $ 228 $ 453 $ 426 Income from operations $ 82 $ 143 $ 131 $ 240 Net income $ 63 $ 123 $ 95 $ 202

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies In the second quarter of 2019, Marathon E.G. Production Limited (“MEGPL”), a consolidated and wholly-owned subsidiary, signed a series of agreements to process third-party Alen Unit gas through existing infrastructure located in Punta Europa, E.G. 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 7 , these audits have been completed through the 2014 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 have filed a Tax Court Petition in the fourth quarter of 2017. We believe that it is more likely than not that we will prevail. 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)	6 Months Ended
	Jun. 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 second quarter and first six months of 2019 are not necessarily indicative of the results to be expected for the full year. As a result of the announcement to sell our U.K. business in the first quarter of 2019 , we have reflected these assets and liabilities as held for sale at June 30, 2019 in the consolidated balance sheet and the consolidated statement of cash flows. The related disclosures in this report exclude these held for sale amounts, unless otherwise noted. This divestiture is discussed in further detail in Note 4 . Reclassifications

Income (Loss) and Dividends p_2

Income (Loss) and Dividends per Common Share (Tables)	6 Months Ended
	Jun. 30, 2019
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The per share calculations below exclude 6 million of stock options for each of the three and six months ended June 30, 2019 and 6 million and 8 million of stock options for the three and six months ended June 30, 2018 , respectively, that were antidilutive. Three Months Ended June 30, Six Months Ended June 30, (In millions, except per share data) 2019 2018 2019 2018 Net income $ 161 $ 96 $ 335 $ 452 Weighted average common shares outstanding 813 854 817 853 Effect of dilutive securities 1 1 — 1 Weighted average common shares, diluted 814 855 817 854 Net income per share: Basic $ 0.20 $ 0.11 $ 0.41 $ 0.53 Diluted $ 0.20 $ 0.11 $ 0.41 $ 0.53 Dividends per share $ 0.05 $ 0.05 $ 0.10 $ 0.10

Revenues (Tables)

Revenues (Tables)	6 Months Ended
	Jun. 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 June 30, 2019 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 350 $ 453 $ 111 $ 77 $ 30 $ 1,021 Natural gas liquids 30 15 31 7 1 84 Natural gas 32 6 36 1 4 79 Other 1 — — — 15 16 Revenues from contracts with customers $ 413 $ 474 $ 178 $ 85 $ 50 $ 1,200 Three Months Ended June 30, 2018 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 394 $ 405 $ 111 $ 59 $ 44 $ 1,013 Natural gas liquids 45 17 45 6 2 115 Natural gas 33 8 38 2 5 86 Other 1 — — — 6 7 Revenues from contracts with customers $ 473 $ 430 $ 194 $ 67 $ 57 $ 1,221 Six Months Ended June 30, 2019 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 668 $ 825 $ 188 $ 141 $ 58 $ 1,880 Natural gas liquids 65 25 53 15 3 161 Natural gas 66 18 81 7 10 182 Other 3 — — — 36 39 Revenues from contracts with customers $ 802 $ 868 $ 322 $ 163 $ 107 $ 2,262 Six Months Ended June 30, 2018 (In millions) Eagle Ford Bakken Oklahoma Northern Delaware Other U.S. Total Crude oil and condensate $ 760 $ 735 $ 226 $ 114 $ 97 $ 1,932 Natural gas liquids 87 32 82 12 5 218 Natural gas 66 18 81 7 12 184 Other 3 — — — 9 12 Revenues from contracts with customers $ 916 $ 785 $ 389 $ 133 $ 123 $ 2,346 International Three Months Ended June 30, 2019 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 101 $ 51 $ 9 $ 161 Natural gas liquids 1 — — 1 Natural gas 9 4 — 13 Other — 6 — 6 Revenues from contracts with customers $ 111 $ 61 $ 9 $ 181 Three Months Ended June 30, 2018 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 100 $ 71 $ 22 $ 193 Natural gas liquids 1 3 — 4 Natural gas 10 12 — 22 Other — 7 — 7 Revenues from contracts with customers $ 111 $ 93 $ 22 $ 226 Six Months Ended June 30, 2019 (In millions) E.G. U.K. Other International Total Crude oil and condensate $ 148 $ 107 $ 19 $ 274 Natural gas liquids 2 1 — 3 Natural gas 16 12 — 28 Other — 14 — 14 Revenues from contracts with customers $ 166 $ 134 $ 19 $ 319 Six Months Ended June 30, 2018 (In millions) E.G. U.K. Libya Other International Total Crude oil and condensate $ 171 $ 166 $ 187 $ 45 $ 569 Natural gas liquids 2 3 — — 5 Natural gas 19 20 9 — 48 Other — 16 — — 16 Revenues from contracts with customers $ 192 $ 205 $ 196 $ 45 $ 638
Contract with Customer, Liability	The following table provides information about receivables and contract assets (liabilities) from contracts with customers. (In millions) June 30, 2019 January 1, 2019 Receivables from contracts with customers, included in receivables, less reserves $ 797 $ 714 Contract asset (liability) $ 21 $ (1 ) Changes in the contract asset (liability) balance during the period are as follows. Six Months Ended (In millions) June 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) balance as of June 30, 2019 $ 21

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2019
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Three Months Ended June 30, 2019 Not Allocated (In millions) U.S. Int’l to Segments Total Revenues from contracts with customers $ 1,200 $ 181 $ — $ 1,381 Net gain on commodity derivatives 5 — 11 (b) 16 Income from equity method investments — 31 — 31 Net loss on disposal of assets — — (8 ) (c) (8 ) Other income 4 2 7 13 Less costs and expenses: Production 147 46 — 193 Shipping, handling and other operating 147 10 13 170 Exploration 26 — — 26 Depreciation, depletion and amortization 561 38 6 605 Impairments — — 18 (d) 18 Taxes other than income 79 — — 79 General and administrative 31 8 48 87 Net interest and other — — 64 64 Other net periodic benefit costs — (1 ) (1 ) (2 ) Income tax provision (benefit) 3 17 12 32 Segment income $ 215 $ 96 $ (150 ) $ 161 Capital expenditures (a) $ 686 $ 10 $ 5 $ 701 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 13 ). (c) Primarily related to the sale of our certain non-core proved properties in our International segment (See Note 4 ). (d) Primarily a result of the anticipated sale of non-core proved properties in the United States segment (See Note 10 ). Three Months Ended June 30, 2018 Not Allocated (In millions) U.S. Int’l to Segments Total Revenues from contracts with customers $ 1,221 $ 226 $ — $ 1,447 Net loss on commodity derivatives (107 ) — (45 ) (b) (152 ) Income from equity method investments — 60 — 60 Net gain on disposal of assets — — 50 50 Other income 2 2 8 12 Less costs and expenses: Production 153 52 — 205 Shipping, handling and other operating 117 10 (1 ) 126 Exploration 64 1 — 65 Depreciation, depletion and amortization 556 50 6 612 Impairments — — 34 (c) 34 Taxes other than income 68 — (3 ) 65 General and administrative 35 9 61 105 Net interest and other — — 65 65 Other net periodic benefit costs — (2 ) 2 — Income tax provision (benefit) — 26 18 44 Segment income (loss) $ 123 $ 142 $ (169 ) $ 96 Capital expenditures (a) $ 641 $ 16 $ 5 $ 662 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 13 ). (c) Primarily a result of anticipated sales of certain non-core proved properties in our International and United States segments (See Note 10 ). Six Months Ended June 30, 2019 Not Allocated (In millions) U.S. Int’l to Segments Total Revenues from contracts with customers $ 2,262 $ 319 $ — $ 2,581 Net gain (loss) on commodity derivatives 27 — (102 ) (b) (75 ) Income from equity method investments — 42 — 42 Net gain on disposal of assets — — 34 (c) 34 Other income 5 5 38 (d) 48 Less costs and expenses: Production 286 96 (2 ) 380 Shipping, handling and other operating 287 23 14 324 Exploration 85 — — 85 Depreciation, depletion and amortization 1,075 72 12 1,159 Impairments — — 24 (e) 24 Taxes other than income 153 — (2 ) 151 General and administrative 60 15 106 181 Net interest and other — — 113 113 Other net periodic benefit costs — (3 ) (4 ) (7 ) Income tax provision (benefit) 1 6 (122 ) (f) (115 ) Segment income $ 347 $ 157 $ (169 ) $ 335 Capital expenditures (a) $ 1,292 $ 15 $ 8 $ 1,315 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 13 ). (c) Primarily related to the sale of our working interest in the Droshky field (Gulf of Mexico) (See Note 4 ). (d) Primarily related to the indemnification of certain tax liabilities in connection with the 2010-2011 Federal Tax Audit (See Note 7 ). (e) Primarily a result of anticipated sales of our certain non-core proved properties in our International and United States segments (See Note 10 ). (f) Primarily relates to the settlement of the 2010-2011 Federal Tax Audit (See Note 7 ). Six Months Ended June 30, 2018 Not Allocated (In millions) U.S. Int’l to Segments Total Revenue from contracts with customers $ 2,346 $ 638 $ — $ 2,984 Net loss on commodity derivatives (166 ) — (88 ) (b) (254 ) Income from equity method investments — 97 — 97 Net gain on disposal of assets — — 307 (c) 307 Other income 5 3 8 16 Less costs and expenses: Production 304 119 (1 ) 422 Shipping, handling and other operating 228 29 (1 ) 256 Exploration 115 2 — 117 Depreciation, depletion and amortization 1,084 104 14 1,202 Impairments — — 42 (d) 42 Taxes other than income 132 — (3 ) 129 General and administrative 71 18 116 205 Net interest and other — — 110 110 Other net periodic benefit costs — (4 ) 7 3 Income tax provision (benefit) 3 196 13 212 Segment income (loss) $ 248 $ 274 $ (70 ) $ 452 Capital expenditures (a) $ 1,252 $ 22 $ 10 $ 1,284 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 13 ). (c) Primarily related to the gain on sale of our Libya subsidiary (See Note 4 ). (d) Primarily a result of anticipated sales of certain non-core proved properties in our International and United States segments (See Note 4 ).

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Effective Income Tax Rate	For the three and six months ended June 30, 2019 and 2018 , our effective income tax rates were as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Effective income tax expense (benefit) rate (a) 17 % 31 % (52 )% 32 % (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)	6 Months Ended
	Jun. 30, 2019
Inventory Disclosure [Abstract]
Schedule of Inventory, Current	(In millions) June 30, 2019 December 31, 2018 Crude oil and natural gas $ 9 $ 11 Supplies and other items 63 85 Inventories $ 72 $ 96

Property, Plant and Equipment_2

Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization (Tables)	6 Months Ended
	Jun. 30, 2019
Property, Plant and Equipment [Abstract]
Schedule of Property, Plant and Equipment	(In millions) June 30, 2019 December 31, 2018 United States $ 16,112 $ 16,011 International 540 710 Corporate 78 83 Net property, plant and equipment $ 16,730 $ 16,804

Impairments (Tables)

Impairments (Tables)	6 Months Ended
	Jun. 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 June 30, 2019 2018 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 19 $ 18 $ 69 $ 34 Six Months Ended June 30, 2019 2018 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 56 $ 24 $ 69 $ 42

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 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 six months ended were as follows: June 30, (In millions) 2019 2018 Beginning balance $ 1,145 $ 1,483 Incurred liabilities, including acquisitions 18 8 Settled liabilities, including dispositions (129 ) (14 ) Accretion expense (included in depreciation, depletion and amortization) 26 36 Revisions of estimates 11 (9 ) Held for sale (864 ) (89 ) Ending balance $ 207 $ 1,415

Leases (Tables)

Leases (Tables)	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Supplemental Balance Sheet Information	Supplemental balance sheet information related to leases was as follows: (In millions) June 30, 2019 Operating Leases: Balance Sheet Location: ROU asset Other noncurrent assets $ 248 Current portion of long-term lease liability Other current liabilities $ 104 Long-term lease liability Deferred credits and other liabilities $ 151
Lease Costs	The table below presents our net lease costs as of June 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 June 30, 2019 Six Months Ended June 30, 2019 Lease costs: Operating lease costs (a) $ 19 $ 40 Short-term lease costs (b) 76 157 Variable lease costs (c) 12 72 Total lease costs $ 107 $ 269 Other information: Cash paid for amounts included in the measurement of operating lease liabilities $ 27 ROU assets obtained in exchange for new operating lease liabilities (d) $ 293 (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 six 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 $248 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 $ 61 2020 106 2021 62 2022 35 2023 5 Thereafter 1 Total undiscounted lease payments $ 270 Less: amount representing interest 15 Total operating lease liabilities $ 255 Less: current portion of long-term lease liability as of June 30, 2019 104 Long-term lease liability as of June 30, 2019 $ 151
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 $ 4 2020 6 2021 6 2022 6 2023 6 Thereafter 66 Total undiscounted cash flows $ 94

Derivatives (Tables)

Derivatives (Tables)	6 Months Ended
	Jun. 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. June 30, 2019 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ 33 $ 4 $ 29 Other current assets Commodity — 4 (4 ) Deferred credits and other liabilities Total Not Designated as Hedges $ 33 $ 8 $ 25 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 June 30, 2019 , and the weighted average prices for those contracts: 2019 2020 2021 Crude Oil Third Quarter Fourth Quarter Full Year Full Year NYMEX WTI Three-Way Collars (a) Volume (Bbls/day) 80,000 80,000 9,945 — Weighted average price per Bbl: Ceiling $ 74.19 $ 74.19 $ 70.00 $ — Floor $ 56.75 $ 56.75 $ 55.00 $ — Sold put $ 49.50 $ 49.50 $ 47.00 $ — Basis Swaps - Argus WTI Midland (b) Volume (Bbls/day) 15,000 15,000 15,000 — Weighted average price per Bbl $ (1.40 ) $ (1.40 ) $ (0.94 ) $ — Basis Swaps - Net Energy Clearbrook (c) Volume (Bbls/day) 1,000 1,000 — — Weighted average price per Bbl $ (3.50 ) $ (3.50 ) $ — $ — Basis Swaps - NYMEX WTI / ICE Brent (d) Volume (Bbls/day) 5,000 5,000 5,000 808 Weighted average price per Bbl $ (7.24 ) $ (7.24 ) $ (7.24 ) $ (7.24 ) Basis Swaps - Argus WTI Houston (e) Volume (Bbls/day) 10,000 10,000 — — Weighted average price per Bbl $ 5.51 $ 5.51 $ — $ — NYMEX Roll Basis Swaps Volume (Bbls/day) 60,000 60,000 — — Weighted average price per Bbl $ 0.38 $ 0.38 $ — $ — (a) Between July 1, 2019 and August 5, 2019 , we entered into 10,000 Bbls/day of three-way collars for January - December 2020, with a ceiling of $65.12 , a sold put of $48.00 , and a floor of $55.00 . (b) The basis differential price is indexed against Argus WTI Midland. (c) The basis differential price is indexed against Net Energy Canada Bakken SW at Clearbrook (“UHC”). (d) The basis differential price is indexed against International Commodity Exchange (“ICE”) Brent and NYMEX WTI.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 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 June 30, 2019 and December 31, 2018 by hierarchy level. June 30, 2019 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ — $ 30 $ — $ 30 Derivative instruments, assets $ — $ 30 $ — $ 30 Derivative instruments, liabilities Commodity (a) $ (5 ) $ — $ — $ (5 ) Derivative instruments, liabilities $ (5 ) $ — $ — $ (5 ) (a) Derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 13 . 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 13 .
Fair Value, by Balance Sheet Grouping	The following table summarizes financial instruments, excluding receivables, payables and derivative financial instruments, and their reported fair values by individual balance sheet line item at June 30, 2019 and December 31, 2018. June 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 25 31 76 81 Total financial assets $ 29 $ 35 $ 79 $ 84 Financial liabilities Other current liabilities $ 76 $ 101 $ 37 $ 58 Long-term debt, including current portion (a) 6,048 5,528 5,469 5,528 Deferred credits and other liabilities 109 98 93 88 Total financial liabilities $ 6,233 $ 5,727 $ 5,599 $ 5,674 (a) Excludes capital leases and debt issuance costs.

Incentive Based Compensation (T

Incentive Based Compensation (Tables)	6 Months Ended
	Jun. 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 six 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 3,846,526 $ 16.96 Exercised/Vested (10,470 ) $ 14.92 (3,562,277 ) $ 12.41 Canceled (590,624 ) $ 24.01 (377,692 ) $ 15.35 Outstanding at June 30, 2019 6,227,439 $ 23.65 8,411,503 $ 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)	6 Months Ended
	Jun. 30, 2019
Retirement Benefits [Abstract]
Schedule of Net Periodic Benefit Cost	The following summarizes the components of net periodic benefit cost: Three Months Ended June 30, Pension Benefits Other Benefits (In millions) 2019 2018 2019 2018 Service cost $ 5 $ 5 $ — $ — Interest cost 7 6 1 2 Expected return on plan assets (8 ) (8 ) — — Amortization: – prior service cost (credit) (2 ) (3 ) (4 ) (2 ) – actuarial loss 2 3 — 1 Net settlement loss (a) 2 2 — — Net periodic benefit cost (b) $ 6 $ 5 $ (3 ) $ 1 Six Months Ended June 30, Pension Benefits Other Benefits (In millions) 2019 2018 2019 2018 Service cost $ 9 $ 9 $ — $ 1 Interest cost 14 13 2 4 Expected return on plan assets (16 ) (17 ) — — Amortization: – prior service credit (4 ) (5 ) (8 ) (4 ) – actuarial loss 4 6 — 1 Net settlement loss (a) 2 6 — — Net periodic benefit cost (b) $ 9 $ 12 $ (6 ) $ 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)	6 Months Ended
	Jun. 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 June 30, Six Months Ended June 30, (In millions) 2019 2018 2019 2018 Income Statement Line Postretirement and postemployment plans Amortization of prior service credit $ 6 $ 5 $ 12 $ 9 Other net periodic benefit costs Amortization of actuarial loss (2 ) (4 ) (4 ) (7 ) Other net periodic benefit costs Net settlement loss (2 ) (2 ) (2 ) (6 ) Other net periodic benefit costs 2 (1 ) 6 (4 ) Income (loss) before income taxes Other insignificant, net of tax — (4 ) — (4 ) Net interest and other — — — — (Provision) benefit for income taxes (a) Total reclassifications to expense, net of tax $ 2 $ (5 ) $ 6 $ (8 ) Net income (loss) (a)

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2019
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Six Months Ended June 30, (In millions) 2019 2018 Included in operating activities: Interest paid, net of amounts capitalized $ 70 $ 134 Income taxes paid to taxing authorities 149 282 Noncash investing activities: Increase (decrease) in asset retirement costs $ 29 $ (1 ) Asset retirement obligations assumed by buyer (a) 109 3 (a) In 2019, we closed the sale of the Droshky field (Gulf of Mexico) and the sale of our non-operated interest in the Atrush block in Kurdistan.

Equity Method Investments (Tabl

Equity Method Investments (Tables)	6 Months Ended
	Jun. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Equity Method Investments	Our equity method investments are summarized in the following table: Ownership as of June 30, December 31, (In millions) June 30, 2019 2019 2018 EGHoldings 60% $ 331 $ 402 Alba Plant LLC 52% 173 167 AMPCO 45% 180 176 Total $ 684 $ 745 Summarized financial information for equity method investees is as follows: Three Months Ended June 30, Six Months Ended June 30, (In millions) 2019 2018 2019 2018 Income data: Revenues and other income $ 233 $ 228 $ 453 $ 426 Income from operations $ 82 $ 143 $ 131 $ 240 Net income $ 63 $ 123 $ 95 $ 202

Accounting Standards Lease acco

Accounting Standards Lease accounting standard (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Jun. 30, 2019
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Total operating lease liabilities		$ 255
ROU asset		$ 248
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				6 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2019	Jun. 30, 2018
Earnings Per Share [Abstract]
Antidilutive securities excluded from computation of earnings per share (in shares)	6		6		6	8
Net income	$ 161	$ 174	$ 96	$ 356	$ 335	$ 452
Weighted average common shares outstanding (in shares)	813		854		817	853
Effect of dilutive securities (in shares)	1		1		0	1
Weighted average common shares, diluted (in shares)	814		855		817	854
Net income per share:
Basic	$ 0.20		$ 0.11		$ 0.41	$ 0.53
Per diluted share:
Diluted	0.20		0.11		0.41	0.53
Dividends per share (in dollars per share)	$ 0.05	$ 0.05	$ 0.05	$ 0.05	$ 0.10	$ 0.10

Dispositions - United States Se

Dispositions - United States Segment (Details) - United States E&P - Non-Core Proved Properties - Disposal Group, Held-for-sale, Not Discontinued Operations $ in Millions	Jun. 30, 2019USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal group, assets	$ 26
Disposal group, liabilities	$ 7

Dispositions - International Se

Dispositions - International Segment (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended			6 Months Ended
	Jul. 31, 2019	Jun. 30, 2019	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018	Dec. 31, 2017
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					$ 69	$ 1,183
Cash, cash equivalents and working capital		$ 335	$ 0		335	0
Asset retirement obligation		207	1,415		207	1,415	$ 1,145	$ 1,483
Income before income taxes		193	140		220	664
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]
Cash, cash equivalents and working capital		125			125		345
Disposal group, assets		1,049			1,049
Disposal group, liabilities		1,046			1,046
Asset retirement obligation		966			966
Income before income taxes		22	$ 48		$ 37	$ 107
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
Percentage of oil and gas property disposed				16.33%
Net gain (loss) on disposal of assets				$ 255
Subsequent Event | 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

Revenues - Revenues from Contra

Revenues - Revenues from Contracts with Customers by Product Type and Geographic Areas (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 1,381	$ 1,447	$ 2,581	$ 2,984
United States E&P
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,200	1,221	2,262	2,346
United States E&P | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	413	473	802	916
United States E&P | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	474	430	868	785
United States E&P | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	178	194	322	389
United States E&P | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	85	67	163	133
United States E&P | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	50	57	107	123
United States E&P | Crude oil and condensate
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,021	1,013	1,880	1,932
United States E&P | Crude oil and condensate | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	350	394	668	760
United States E&P | Crude oil and condensate | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	453	405	825	735
United States E&P | Crude oil and condensate | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	111	111	188	226
United States E&P | Crude oil and condensate | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	77	59	141	114
United States E&P | Crude oil and condensate | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	30	44	58	97
United States E&P | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	84	115	161	218
United States E&P | Natural gas liquids | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	30	45	65	87
United States E&P | Natural gas liquids | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	15	17	25	32
United States E&P | Natural gas liquids | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	31	45	53	82
United States E&P | Natural gas liquids | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	7	6	15	12
United States E&P | Natural gas liquids | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	2	3	5
United States E&P | Natural gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	79	86	182	184
United States E&P | Natural gas | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	32	33	66	66
United States E&P | Natural gas | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6	8	18	18
United States E&P | Natural gas | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	36	38	81	81
United States E&P | Natural gas | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	2	7	7
United States E&P | Natural gas | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4	5	10	12
United States E&P | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	16	7	39	12
United States E&P | Other | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	1	3	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	15	6	36	9
International E&P
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		226	319	638
International E&P | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	111	111	166	192
International E&P | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	61	93	134	205
International E&P | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	9			196
International E&P | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	181	22	19	45
International E&P | Crude oil and condensate
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		193	274	569
International E&P | Crude oil and condensate | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	101	100	148	171
International E&P | Crude oil and condensate | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	51	71	107	166
International E&P | Crude oil and condensate | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	9			187
International E&P | Crude oil and condensate | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	161	22	19	45
International E&P | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		4	3	5
International E&P | Natural gas liquids | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	1	2	2
International E&P | Natural gas liquids | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	3	1	3
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		22	28	48
International E&P | Natural gas | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	9	10	16	19
International E&P | Natural gas | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4	12	12	20
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	13	0	0	0
International E&P | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers		7	14	16
International E&P | Other | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
International E&P | Other | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6	7	14	16
International E&P | Other | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0			0
International E&P | Other | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6	0	0	0
Operating Segments | United States E&P
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,200	1,221	2,262	2,346
Operating Segments | International E&P
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	181	226	319	638
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	Jun. 30, 2019	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Receivables from contracts with customers, included in receivables, less reserves	$ 797	$ 714
Contract with Customer, Asset, Net, Current	21
Contract asset (liability)	$ (21)	$ (1)

Revenues - Significant Changes

Revenues - Significant Changes in the Contract Liability Balance (Details) $ in Millions	6 Months Ended
	Jun. 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) balance as of June 30, 2019	$ 21

Segment Information (Details)

Segment Information (Details) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Jun. 30, 2019USD ($)segment	Jun. 30, 2018USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segment					2
Revenues from contracts with customers	$ 1,381		$ 1,447		$ 2,581	$ 2,984
Net gain (loss) on commodity derivatives	16		(152)		(75)	(254)
Income from equity method investments	31		60		42	97
Net gain (loss) on disposal of assets	(8)		50		34	307
Other income	13		12		48	16
Less costs and expenses:
Production	193		205		380	422
Shipping, handling and other operating	170		126		324	256
Exploration	26		65		85	117
Depreciation, depletion and amortization	605		612		1,159	1,202
Impairments	18		34		24	42
Taxes other than income	79		65		151	129
General and administrative	87		105		181	205
Net interest and other	64		65		113	110
Other net periodic benefit costs	(2)		0		(7)	3
Income tax provision (benefit)	32		44		(115)	212
Net income	161	$ 174	96	$ 356	335	452
Capital expenditures	701		662		1,315	1,284
Pension Plan
Less costs and expenses:
Other net periodic benefit costs	2		2		2	6
Not Allocated to Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	0		0		0	0
Net gain (loss) on commodity derivatives	11		(45)		(102)	(88)
Income from equity method investments	0		0		0	0
Net gain (loss) on disposal of assets	(8)		50		34	307
Other income	7		8		38	8
Less costs and expenses:
Production	0		0		(2)	(1)
Shipping, handling and other operating	13		(1)		14	(1)
Exploration	0		0		0	0
Depreciation, depletion and amortization	6		6		12	14
Impairments	18		34		24	42
Taxes other than income	0		(3)		(2)	(3)
General and administrative	48		61		106	116
Net interest and other	64		65		113	110
Other net periodic benefit costs	(1)		2		(4)	7
Income tax provision (benefit)	12		18		(122)	13
Net income	(150)		(169)		(169)	(70)
Capital expenditures	5		5		8	10
United States E&P
Segment Reporting Information [Line Items]
Revenues from contracts with customers	1,200		1,221		2,262	2,346
United States E&P | Operating Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	1,200		1,221		2,262	2,346
Net gain (loss) on commodity derivatives	5		(107)		27	(166)
Income from equity method investments	0		0		0	0
Net gain (loss) on disposal of assets	0		0		0	0
Other income	4		2		5	5
Less costs and expenses:
Production	147		153		286	304
Shipping, handling and other operating	147		117		287	228
Exploration	26		64		85	115
Depreciation, depletion and amortization	561		556		1,075	1,084
Impairments	0		0		0	0
Taxes other than income	79		68		153	132
General and administrative	31		35		60	71
Net interest and other	0		0		0	0
Other net periodic benefit costs	0		0		0	0
Income tax provision (benefit)	3		0		1	3
Net income	215		123		347	248
Capital expenditures	686		641		1,292	1,252
Int'l E&P
Segment Reporting Information [Line Items]
Revenues from contracts with customers			226		319	638
Int'l E&P | Operating Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	181		226		319	638
Net gain (loss) on commodity derivatives	0		0		0	0
Income from equity method investments	31		60		42	97
Net gain (loss) on disposal of assets	0		0		0	0
Other income	2		2		5	3
Less costs and expenses:
Production	46		52		96	119
Shipping, handling and other operating	10		10		23	29
Exploration	0		1		0	2
Depreciation, depletion and amortization	38		50		72	104
Impairments	0		0		0	0
Taxes other than income	0		0		0	0
General and administrative	8		9		15	18
Net interest and other	0		0		0	0
Other net periodic benefit costs	(1)		(2)		(3)	(4)
Income tax provision (benefit)	17		26		6	196
Net income	96		142		157	274
Capital expenditures	10		16		15	22
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	$ 2		$ 2		$ 2	$ 6

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Income Tax Disclosure [Abstract]
Effective income tax expense (benefit) rate	17.00%	31.00%	(52.00%)	32.00%
Tax benefit from settlement			$ 126
Tax benefit from internal restructuring			$ 18
Effective income tax expense (benefit) rate, excluding discrete items			13.00%
Tax expense from foreign currency revaluation				$ 162
Income tax receivable, current	$ 42		$ 42

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Inventory Disclosure [Abstract]
Crude oil and natural gas	$ 9	$ 11
Supplies and other items	63	85
Inventories	$ 72	$ 96

Property, Plant and Equipment_3

Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 16,730	$ 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	16,112	16,011
Operating Segments | International E&P
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	540	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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	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	$ 19		$ 19
Long-lived assets, Fair Value	56	$ 69	56	$ 69
Long-lived assets, Impairment	$ 18	$ 34	$ 24	$ 42

Impairments - Narrative (Detail

Impairments - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairments	$ 18	$ 34	$ 24	$ 42
Nonrecurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Adjustment	18	34	24	42
Property, Plant, and Equipment, Fair Value Disclosure	$ 56	$ 69	$ 56	$ 69

Impairments - Exploration Expen

Impairments - Exploration Expenses (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Exploration Expenses [Line Items]
Total exploration expenses	$ 26	$ 65	$ 85	$ 117

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation, beginning balance	$ 1,145	$ 1,483
Incurred liabilities, including acquisitions	18	8
Settled liabilities, including dispositions	(129)	(14)
Accretion expense (included in depreciation, depletion and amortization)	26	36
Revisions of estimates	11	(9)
Held for sale	(864)	(89)
Asset retirement obligation, ending balance	207	1,415
Asset retirement obligation, current	$ 18	$ 51

Leases - Supplemental Balance S

Leases - Supplemental Balance Sheet Information (Details) $ in Millions	Jun. 30, 2019USD ($)
Leases [Abstract]
ROU asset	$ 248
Current portion of long-term lease liability	104
Long-term lease liability	$ 151

Leases - Lease Costs (Details)

Leases - Lease Costs (Details) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2019USD ($)	Jun. 30, 2019USD ($)
Leases [Abstract]
Operating lease costs	$ 19	$ 40
Short-term lease costs	76	157
Variable lease costs	12	72
Total lease costs	107	269
Cash paid for amounts included in the measurement of operating lease liabilities		27
ROU assets obtained in exchange for new operating lease liabilities(d)		293
ROU asset	$ 248	$ 248

Leases - Narrative (Details)

Leases - Narrative (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 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	$ 50
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 ($)	Jun. 30, 2019	Dec. 31, 2018
Lease Maturity [Abstract]
2019	$ 61,000,000
2019		$ 62,000,000
2020	106,000,000
2020		54,000,000
2021	62,000,000
2021		35,000,000
2022	35,000,000
2022		12,000,000
2023	5,000,000
2023		5,000,000
Thereafter	1,000,000
Thereafter		49,000,000
Total undiscounted lease payments	270,000,000
Less: amount representing interest	15,000,000
Total operating lease liabilities	255,000,000
Less: current portion of long-term lease liability as of June 30, 2019	104,000,000
Long-term lease liability as of June 30, 2019	$ 151,000,000
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	Jun. 30, 2019USD ($)
Leases [Abstract]
2019	$ 4
2020	6
2021	6
2022	6
2023	6
Thereafter	66
Total undiscounted cash flows	94
Thereafter	$ 1

Derivatives - Schedule of Deriv

Derivatives - Schedule of Derivative Instruments in the Consolidated Balance Sheets (Details) - Not Designated as Hedges - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Asset	$ 33	$ 131
Liability	8	4
Net Asset (Liability)	25	127
Commodity | Other current assets
Derivatives, Fair Value [Line Items]
Asset	33	131
Liability	4
Net Asset (Liability)	29	131
Commodity | Deferred credits and other liabilities
Derivatives, Fair Value [Line Items]
Liability	4	4
Net Asset (Liability)	$ 4	$ 4

Derivatives - Narrative (Detail

Derivatives - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on commodity derivatives	$ 16	$ (152)	$ (75)	$ (254)
Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on commodity derivatives	11	(45)	(102)	(88)
Net gain (loss) on settlements, net	5	(107)	27	(166)
Operating Segments | United States E&P
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on commodity derivatives	$ 5	$ (107)	$ 27	$ (166)

Derivatives - Outstanding Deriv

Derivatives - Outstanding Derivative Contracts (Details) - Not Designated as Hedges	1 Months Ended	6 Months Ended
	Aug. 05, 2019Bbls_per_day$ / bbl	Jun. 30, 2019Bbls_per_day$ / bbl
Three-Way Collars - Crude Oil 2019 Q3 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		80,000
Three-Way Collars - Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		80,000
Three-Way Collars - Crude Oil 2020 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		9,945
Three-Way Collars - Crude Oil 2021 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		0
Three-Way Collars - Crude Oil 2019 Q3, Ceiling [Member]
Derivative [Line Items]
Underlying, Derivative Volume		74.19
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		70
Three-Way Collars - Crude Oil 2021, Ceiling [Member]
Derivative [Line Items]
Underlying, Derivative Volume		0
Three-Way Collars - Crude Oil 2019 Q3, Floor [Member]
Derivative [Line Items]
Underlying, Derivative Volume		56.75
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 Q3, Sold Put [Member]
Derivative [Line Items]
Underlying, Derivative Volume		49.50
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
Three-Way Collars - Crude Oil 2021, Sold Put [Member]
Derivative [Line Items]
Underlying, Derivative Volume		0
Midland Basis Swaps - Crude Oil 2019 Q3 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		15,000
Underlying, Derivative Volume		(1.40)
Midland Basis Swaps - Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		15,000
Underlying, Derivative Volume		(1.40)
Midland Basis Swaps - Crude Oil 2020 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		15,000
Underlying, Derivative Volume		(0.94)
Midland Basis Swaps - Crude Oil 2021 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		0
Underlying, Derivative Volume		0
Brent Basis Swaps - Crude Oil 2019 Q3 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		5,000
Underlying, Derivative Volume		(7.24)
Brent Basis Swaps - Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		5,000
Underlying, Derivative Volume		(7.24)
Brent Basis Swaps - Crude Oil 2020 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		5,000
Underlying, Derivative Volume		(7.24)
Brent Basis Swaps - Crude Oil 2021 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		808
Underlying, Derivative Volume		(7.24)
Clearbrook Basis Swaps Crude Oil Clearbrook Basis Swaps Crude Oil 2019 Q3 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		1,000
Underlying, Derivative Volume		(3.50)
Clearbrook Basis Swaps Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		1,000
Underlying, Derivative Volume		(3.50)
Clearbrook Basis Swaps Crude Oil 2020 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		0
Underlying, Derivative Volume		0
Clearbrook Basis Swaps Crude Oil 2021 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		0
Underlying, Derivative Volume		0
ArgusWTIHouston Basis Swaps - Crude Oil 2019 Q3 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		10,000
Underlying, Derivative Volume		5.51
ArgusWTIHouston Basis Swaps - Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		10,000
Underlying, Derivative Volume		5.51
ArgusWTIHouston Basis Swaps - Crude Oil 2020 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		0
Underlying, Derivative Volume		0
ArgusWTIHouston Basis Swaps - Crude Oil 2021 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		0
Underlying, Derivative Volume		0
NYMEX Roll Basis Swaps - Crude Oil 2019 Q3 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		60,000
Underlying, Derivative Volume		0.38
NYMEX Roll Basis Swaps - Crude Oil 2019 Q4 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		60,000
Underlying, Derivative Volume		0.38
NYMEX Roll Basis Swaps - Crude Oil 2020 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		0
Underlying, Derivative Volume		0
NYMEX Roll Basis Swaps - Crude Oil 2021 [Member]
Derivative [Line Items]
Volume | Bbls_per_day		0
Underlying, Derivative Volume		0
Subsequent Event | Three-Way Collars - Crude Oil January-December 2020 [Member]
Derivative [Line Items]
Volume | Bbls_per_day	10,000
Subsequent Event | Three-Way Collars - Crude Oil January-December 2020, Ceiling [Member]
Derivative [Line Items]
Underlying, Derivative Volume	65.12
Subsequent Event | Three-Way Collars - Crude Oil January-December 2020, Sold Put [Member]
Derivative [Line Items]
Underlying, Derivative Volume	48
Subsequent Event | Three-Way Collars - Crude Oil January-December 2020, Floor [Member]
Derivative [Line Items]
Underlying, Derivative Volume	55

Fair Value Measurements - Fair

Fair Value Measurements - Fair Values - Recurring (Details) - Recurring - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	$ 30	$ 127
Derivative instruments, liabilities	5	0
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	30	127
Derivative instruments, liabilities	(5)
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	0	21
Derivative instruments, liabilities	5	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	(5)
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	30	106
Derivative instruments, liabilities	0	0
Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	30	106
Derivative instruments, liabilities	0
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

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($) $ in Millions	Jun. 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	Jun. 30, 2019	Dec. 31, 2018
Fair Value
Financial assets
Current assets	$ 4	$ 3
Other noncurrent assets	25	76
Total financial assets	29	79
Financial liabilities
Other current liabilities	76	37
Long-term debt, including current portion	6,048	5,469
Deferred credits and other liabilities	109	93
Total financial liabilities	6,233	5,599
Carrying Amount
Financial assets
Current assets	4	3
Other noncurrent assets	31	81
Total financial assets	35	84
Financial liabilities
Other current liabilities	101	58
Long-term debt, including current portion	5,528	5,528
Deferred credits and other liabilities	98	88
Total financial liabilities	$ 5,727	$ 5,674

Debt - Revolving Credit Facilit

Debt - Revolving Credit Facility (Details)	Jun. 30, 2019USD ($)	Dec. 31, 2018USD ($)
Line of Credit Facility [Line Items]
Long-term debt	$ 4,902,000,000	$ 5,499,000,000
Revolving Credit Facility
Line of Credit Facility [Line Items]
Line of credit	$ 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	$ 3,400,000,000

Debt - Long-Term Debt (Details)

Debt - Long-Term Debt (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Debt, Long-term and Short-term, Combined Amount	$ 5,500
Long-term debt due within one year	600	$ 0
Long-term debt	$ 4,902	$ 5,499

Stockholders' Equity (Details)

Stockholders' Equity (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2019	Jul. 31, 2019
Equity, Class of Treasury Stock [Line Items]
Shares repurchased	$ 236	$ 30	$ 2	$ 8
Share Repurchase Program
Equity, Class of Treasury Stock [Line Items]
Shares repurchased (in shares)					16
Shares repurchased					$ 250
Stock repurchase program, remaining authorized repurchase amount	$ 550				$ 550
Subsequent Event | Share Repurchase Program
Equity, Class of Treasury Stock [Line Items]
Stock repurchase program, remaining authorized repurchase amount						$ 1,500

Incentive Based Compensation -

Incentive Based Compensation - Stock Options, Restricted Stock Awards and Restricted Stock Units (Details)	6 Months Ended
	Jun. 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	(10,470)
Canceled (in shares) | shares	(590,624)
Outstanding, ending (in shares) | shares	6,227,439
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)	14.92
Canceled (in dollars per share)	24.01
Outstanding, ending (in dollars per share)	23.65
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	3,846,526
Stock Vested (in shares) | shares	(3,562,277)
Canceled (in shares) | shares	(377,692)
Outstanding, ending (in shares) | shares	8,411,503
Weighted Average Grant Date Fair Value
Outstanding, beginning (in dollars per share)	$ 14.04
Granted (in dollars per share)	16.96
Stock Vested (in dollars per share)	12.41
Canceled (in dollars per share)	15.35
Outstanding, ending (in dollars per share)	$ 16

Incentive Based Compensation _2

Incentive Based Compensation - Stock-based Performance Unit Awards (Details) - Performance Unit Awards	6 Months Ended
	Jun. 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		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Amortization:
Net settlement loss	$ (2)	$ 0	$ (7)	$ 3
Estimated future contributions over the remainder of the current year	12		12
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	5	5	9	9
Interest cost	7	6	14	13
Expected return on plan assets	(8)	(8)	(16)	(17)
Amortization:
– prior service credit	(2)	(3)	(4)	(5)
– actuarial loss	2	3	4	6
Net settlement loss	2	2	2	6
Net periodic benefit cost	6	5	9	12
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	0	0	1
Interest cost	1	2	2	4
Expected return on plan assets	0	0	0	0
Amortization:
– prior service credit	(4)	(2)	(8)	(4)
– actuarial loss	0	1	0	1
Net settlement loss	0	0	0	0
Net periodic benefit cost	$ (3)	$ 1	(6)	$ 2
Payment for other postretirement benefit plans			11
Funded Plan
Amortization:
Payment for pension benefits			29
Unfunded Plan
Amortization:
Payment for pension benefits			$ 3

Reclassifications Out of Accu_3

Reclassifications Out of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2019	Jun. 30, 2018
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other net periodic benefit costs	$ 2		$ 0		$ 7	$ (3)
Income (loss) before income taxes	193		140		220	664
Net interest and other	(64)		(65)		(113)	(110)
(Provision) benefit for income taxes	(32)		(44)		115	(212)
Net income	161	$ 174	96	$ 356	335	452
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		5		12	9
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	(2)		(4)		(4)	(7)
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	(2)		(2)		(2)	(6)
Postretirement and postemployment plans | Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income (loss) before income taxes	2		(1)		6	(4)
Net interest and other	0		(4)		0	(4)
(Provision) benefit for income taxes	0		0		0	0
Net income	$ 2		$ (5)		$ 6	$ (8)

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Included in operating activities:
Interest paid, net of amounts capitalized		$ 70	$ 134
Income taxes paid to taxing authorities		149	282
Noncash investing activities:
Increase (decrease) in asset retirement costs		29	(1)
Asset retirement obligations assumed by buyer(a)		109	$ 3
Capital expenditures incurred but not yet paid	$ 303	$ 300

Equity Method Investments (Deta

Equity Method Investments (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 684		$ 684		$ 745
Income data:
Revenues and other income	233	$ 228	453	$ 426
Income from operations	82	143	131	240
Net income	$ 63	$ 123	$ 95	$ 202
EGHoldings
Schedule of Equity Method Investments [Line Items]
Ownership percentage	60.00%		60.00%
Equity method investments	$ 331		$ 331		402
Alba Plant LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage	52.00%		52.00%
Equity method investments	$ 173		$ 173		167
AMPCO
Schedule of Equity Method Investments [Line Items]
Ownership percentage	45.00%		45.00%
Equity method investments	$ 180		$ 180		$ 176

Commitments and Contingencies (

Commitments and Contingencies (Details) $ in Millions	Dec. 31, 2017USD ($)
Foreign Tax Authority | UK Government
Loss Contingencies [Line Items]
Income taxes paid from settlement with taxing authority	$ 108