Marathon Oil (MRO) 10-Q 8 Nov 18 2018 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2018	Oct. 31, 2018
Document and Entity Information [Abstract]
Document Type	10-Q
Document Period End Date	Sep. 30, 2018
Document Fiscal Period Focus	Q3
Document Fiscal Year Focus	2,018
Amendment Flag	false
Entity Registrant Name	Marathon Oil Corp
Entity Central Index Key	101,778
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock Shares Outstanding		831,275,876

Consolidated Statements of Inco

Consolidated Statements of Income (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenues and other income:
Revenues from contracts with customers	$ 1,538	$ 1,136	$ 4,522	$ 2,911
Net gain (loss) on commodity derivatives	(70)	(22)	(324)	115
Marketing revenues		48		117
Income from equity method investments	64	63	161	183
Net gain (loss) on disposal of assets	16	19	323	26
Other income	119	8	135	31
Total revenues and other income	1,667	1,252	4,817	3,383
Costs and expenses:
Production	215	197	637	528
Marketing, including purchases from related parties		49		121
Shipping, handling and other operating	152	109	408	309
Exploration	56	294	173	352
Depreciation, depletion and amortization	626	641	1,828	1,789
Impairments	8	201	50	205
Taxes other than income	86	44	215	128
General and administrative	101	89	306	276
Total costs and expenses	1,244	1,624	3,617	3,708
Income (loss) from operations	423	(372)	1,200	(325)
Net interest and other	(58)	(35)	(168)	(199)
Other net periodic benefit costs	(8)	(5)	(11)	(16)
Loss on early extinguishment of debt	0	(46)	0	(46)
Income (loss) from continuing operations before income taxes	357	(458)	1,021	(586)
Provision (benefit) for income taxes	103	141	315	216
Income (loss) from continuing operations	254	(599)	706	(802)
Income (loss) from discontinued operations	0	0	0	(4,893)
Net income (loss)	$ 254	$ (599)	$ 706	$ (5,695)
Per basic share:
Income (loss) from continuing operations (in dollars per share)	$ 0.30	$ (0.70)	$ 0.83	$ (0.94)
Income (loss) from discontinued operations (in dollars per share)	0	0	0	(5.76)
Net income (loss) (in dollars per share)	0.30	(0.70)	0.83	(6.70)
Per diluted share:
Income (loss) from continuing operations (in dollars per share)	0.30	(0.70)	0.83	(0.94)
Income (loss) from discontinued operations (in dollars per share)	0	0	0	(5.76)
Net income (loss) (in dollars per share)	$ 0.30	$ (0.70)	$ 0.83	$ (6.70)
Weighted average common shares outstanding:
Basic (in shares)	848	850	852	850
Diluted (in shares)	849	850	853	850

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 254	$ (599)	$ 706	$ (5,695)
Postretirement and postemployment plans
Change in actuarial loss and other	20	5	37	17
Income tax provision (benefit)	0	19	0	19
Postretirement and postemployment plans, net of tax	20	24	37	36
Derivative hedges
Net unrecognized gain (loss)	0	0	0	(13)
Reclassification of gains on terminated derivative hedges	0	(46)	0	(47)
Income tax provision (benefit)	0	21	0	21
Derivative hedges, net of tax	0	(25)	0	(39)
Foreign currency hedges
Net recognized loss reclassified to discontinued operations	0	0	0	34
Income tax provision (benefit)	0	0	0	(4)
Foreign currency hedges, net of tax	0	0	0	30
Other, net of tax	0	1	4	2
Other comprehensive income (loss)	20	0	41	29
Comprehensive income (loss)	$ 274	$ (599)	$ 747	$ (5,666)

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 1,564	$ 563
Receivables, less reserve of $8 and $12	1,335	1,082
Notes receivable	0	748
Inventories	110	126
Other current assets	31	36
Current assets held for sale	25	11
Total current assets	3,065	2,566
Equity method investments	757	847
Property, plant and equipment, less accumulated depreciation, depletion and amortization of $22,358 and $21,564	16,899	17,665
Goodwill	97	115
Other noncurrent assets	912	764
Noncurrent assets held for sale	48	55
Total assets	21,778	22,012
Current liabilities:
Accounts payable	1,479	1,395
Payroll and benefits payable	127	108
Accrued taxes	128	177
Other current liabilities	405	288
Current liabilities held for sale	3	0
Total current liabilities	2,142	1,968
Long-term debt	5,498	5,494
Deferred tax liabilities	215	833
Defined benefit postretirement plan obligations	286	362
Asset retirement obligations	1,243	1,428
Deferred credits and other liabilities	340	217
Noncurrent liabilities held for sale	10	2
Total liabilities	9,734	10,304
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 and 937 million shares (par value $1 per share, 1.925 billion shares authorized at September 30, 2018 and 1.1 billion shares authorized at December 31, 2017)	937	937
Held in treasury, at cost – 99 million and 87 million shares	(3,455)	(3,325)
Additional paid-in capital	7,226	7,379
Retained earnings	7,357	6,779
Accumulated other comprehensive loss	(21)	(62)
Total stockholders' equity	12,044	11,708
Total liabilities and stockholders' equity	$ 21,778	$ 22,012

Consolidated Balance Sheets (_2

Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Receivables reserve	$ 8	$ 12
Property, plant and equipment accumulated depreciation, depletion and amortization	$ (22,358)	$ (21,564)
Preferred stock, par value (in dollars per share)	$ 0	$ 0
Preferred stock shares authorized (in shares)	26,000,000	26,000,000
Preferred stock, shares issued (in shares)	0	0
Preferred stock, shares outstanding (in shares)	0	0
Common stock, par value (in dollars per share)	$ 1	$ 1
Common stock, shares authorized (in shares)	1,925,000,000	1,100,000,000
Common stock, shares issued (in shares)	937,000,000	937,000,000
Common stock, held in treasury (in shares)	99,000,000	87,000,000

Consolidated Statements of Cash

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Operating activities:
Net income (loss)	$ 706	$ (5,695)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Discontinued operations	0	4,893
Depreciation, depletion and amortization	1,828	1,789
Impairments	50	205
Exploratory dry well costs and unproved property impairments	144	294
Net (gain) loss on disposal of assets	(323)	(26)
Deferred income taxes	62	44
Net (gain) loss on derivative instruments	324	(162)
Net settlements of derivative instruments	(255)	88
Pension and other postretirement benefits, net	(60)	(38)
Stock-based compensation	44	38
Equity method investments, net	42	46
Changes in:
Current receivables	(389)	(192)
Inventories	(11)	4
Current accounts payable and accrued liabilities	334	189
All other operating, net	(117)	10
Net cash provided by operating activities from continuing operations	2,379	1,487
Investing activities:
Additions to property, plant and equipment	(2,069)	(1,305)
Additions to other assets	(135)	(23)
Acquisitions, net of cash acquired	(25)	(1,828)
Disposal of assets, net of cash transferred to buyer	1,249	1,757
Equity method investments - return of capital	48	49
All other investing, net	11	(3)
Net cash provided by (used in) investing activities from continuing operations	(921)	(1,353)
Financing activities:
Borrowings	0	988
Debt repayments	0	(1,764)
Debt extinguishment costs	0	(46)
Purchases of common stock	(349)	(10)
Dividends paid	(128)	(128)
All other financing, net	22	0
Net cash provided by (used in) financing activities	(455)	(960)
Net increase in cash and cash equivalents of discontinued operations (Note 5)	0	130
Effect of exchange rate on cash and cash equivalents	(2)	3
Net increase (decrease) in cash and cash equivalents	1,001	(693)
Cash and cash equivalents at beginning of period	563	2,488
Cash and cash equivalents at end of period	$ 1,564	$ 1,795

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 Loss
Beginning balance at Dec. 31, 2016	$ 17,541	$ 0	$ 937	$ (3,431)	$ 7,446	$ 12,672	$ (83)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares issued - stock-based compensation	65			116	(51)
Shares repurchased	(9)			(9)
Stock-based compensation	(28)				(28)
Net income (loss)	(5,695)					(5,695)
Other comprehensive income	29						29
Dividends paid (per share amount of $0.15)	(128)					(128)
Ending balance at Sep. 30, 2017	11,775	0	937	(3,324)	7,367	6,849	(54)
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	104			219	(115)
Shares repurchased	(349)			(349)
Stock-based compensation	(38)				(38)
Net income (loss)	706					706
Other comprehensive income	41						41
Dividends paid (per share amount of $0.15)	(128)					(128)
Ending balance at Sep. 30, 2018	$ 12,044	$ 0	$ 937	$ (3,455)	$ 7,226	$ 7,357	$ (21)

Consolidated Statements of St_2

Consolidated Statements of Stockholders' Equity (Unaudited) (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Statement of Stockholders' Equity [Abstract]
Dividends paid (in dollars per share)	$ 0.05	$ 0.05	$ 0.15	$ 0.15

Basis of Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 2018
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 2017 Annual Report on Form 10-K. The results of operations for the third quarter and first nine months of 2018 are not necessarily indicative of the results to be expected for the full year. As a result of the sale of our Canadian business in 2017, we reflected this business as discontinued operations in all historical periods presented. Disclosures in this report related to results of operations and cash flows are presented on the basis of continuing operations unless otherwise stated. See Note 5 for discussion of this divestiture in further detail. Reclassifications In the first quarter of 2018 we adopted the new Accounting Standards Codification ("ASC") Topic 606, Revenue from Contracts with Customers using the modified retrospective method. To conform the historical presentation to our current presentation, we reclassified gains/losses arising from our commodity derivatives out of the revenues from contracts with customers line into a separate line, net gain (loss) on commodity derivatives, on the consolidated statements of income. Additionally, in the first quarter of 2018 we adopted the new pension accounting standards update on a retrospective basis, and reclassified the required cost elements from general and administrative expense into production expense, exploration expense, and other net periodic benefit costs. See Note 2 for further discussion of the adoption of these accounting standards.

Accounting Standards

Accounting Standards	9 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Accounting Standards	Accounting Standards Not Yet Adopted Lease accounting standard In February 2016, the FASB issued a new lease accounting standard, which requires lessees to recognize most leases, including operating leases, on the balance sheet as a right of use asset and lease liability. Short-term leases can continue being accounted for off balance sheet based on a policy election. This standard 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. This standard is effective for us in the first quarter of 2019 and shall be applied using a modified retrospective approach at the beginning of the earliest period presented in the financial statements. Early adoption is permitted. In July 2018, the FASB issued a new transition option that allows entities to adopt the new lease accounting standard using the modified retrospective transition method by recognizing a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption rather than in the earliest period presented. We plan to elect this new transition option and continue to apply the legacy guidance in ASC 840, Leases, including its disclosure requirements, in the comparative periods presented in the year of adoption. We will adopt the new standard in the first quarter of 2019 using a modified retrospective approach and will recognize a right of use asset and lease liability on the adoption date. We plan to apply practical expedients provided in the standard that allow, amongst others, not to reassess contracts that commenced prior to the adoption. We also anticipate to elect a policy not to recognize right of use assets and lease liabilities related to short-term leases. We continue to evaluate our contracts and are gathering the necessary data to determine the financial impact of this standard on our consolidated financial statements and related disclosures. We installed and are in the process of configuring software that we believe will facilitate the adoption of the standard. We are also evaluating our processes and internal control environment concurrent with the adoption of this standard. While we have yet to finalize the estimated impact this standard will have on our consolidated financial statements, the adoption is anticipated to result in an increase in both assets and liabilities related to our leases. 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 is effective for us in the first quarter of 2019. Early adoption is permitted in any interim or annual period. The amendment mandates modified retrospective adoption when accounting for hedge relationships in effect as of the adoption date. None of our derivative instruments are currently designated as hedges; as a result we do not expect the adoption of this standard to have a significant impact on our consolidated results of operations, financial position or cash flows. Goodwill standard In January 2017, the FASB issued a new accounting standards update that eliminates the requirement to calculate the implied fair value of the goodwill (Step 2 of goodwill impairment test under the current guidance) to measure a goodwill impairment charge. We anticipate the standard to require entities to record an impairment charge based on the excess of a reporting unit’s carrying amount over its fair value (measure the charge based on Step 1 under the current guidance). This standard is effective for us in the first quarter of 2020 and shall be applied on a prospective basis. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. We plan to adopt the standard on a prospective basis, and do not expect a material impact on our consolidated results of operations, financial position or cash flows for prior periods. 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 Revenue recognition standard On January 1, 2018, we adopted the new ASC Topic 606, Revenue from Contracts with Customers and all the related amendments ("new revenue standard") using the modified retrospective method. We evaluated the effect of transition by applying the provisions of the new revenue standard to contracts with remaining obligations as of January 1, 2018. No cumulative adjustment to retained earnings was necessary as a result of adopting this standard. Results for reporting periods beginning after January 1, 2018 are presented under the new revenue standard, while prior period amounts are not adjusted and continue to be reported in accordance with our historic accounting policies. The primary change relates to the presentation of marketing revenues and marketing expenses from the historical gross presentation to the current net presentation, included within revenues from contracts with customers, for a portion of our international contracts. We concluded that the adoption of the new revenue standard did not result in any significant changes to our consolidated balance sheet or statement of cash flows. The following tables summarize the impacts of adopting the new revenue standard on our consolidated income statement for the three and nine month periods ended September 30, 2018. Three Months Ended September 30, 2018 (In millions) As reported Adjustments Presentation without adoption of ASC Topic 606 Revenues and other income: Revenues from contracts with customers $ 1,538 $ (2 ) $ 1,536 Marketing revenues — 47 47 Other income 119 (1 ) 118 Costs and expenses: Marketing, including purchases from related parties $ — $ 46 $ 46 Shipping, handling and other operating 152 (2 ) 150 Nine Months Ended September 30, 2018 (In millions) As reported Adjustments Presentation without adoption of ASC Topic 606 Revenues and other income: Revenues from contracts with customers $ 4,522 $ (4 ) $ 4,518 Marketing revenues — 122 122 Other income 135 (3 ) 132 Costs and expenses: Marketing, including purchases from related parties $ — $ 122 $ 122 Shipping, handling and other operating 408 (7 ) 401 Pension accounting standard In the first quarter of 2018, we adopted the new accounting standards update that changes how employers that sponsor defined pension and/or other postretirement benefit plans present the net periodic benefit cost in the income statement. As a result, employers are required to present the service cost component of net periodic benefit cost in the same income statement line item(s) as other employee compensation costs arising from services rendered during the period. We adopted this standard on a retrospective basis, and reclassified the required cost elements from general and administrative expense into production expense, exploration expense, and other net periodic benefit costs. The adoption of this standard did not have a significant impact on our consolidated balance sheet or statement of cash flows. The following tables summarize the impacts of adopting this standard on our historical consolidated income statement for the three and nine month periods ended September 30, 2017. Three Months Ended September 30, 2017 (In millions) Previously Reported As reclassified Effect of Change Higher/(Lower) Production $ 194 $ 197 $ 3 Exploration 294 294 — General and administrative 97 89 (8 ) Income (loss) from operations (377 ) (372 ) 5 Other net periodic benefit costs (a) — 5 5 Nine Months Ended September 30, 2017 (In millions) Previously Reported As reclassified Effect of Change Higher/(Lower) Production $ 521 $ 528 $ 7 Exploration 352 352 — General and administrative 299 276 (23 ) Income from operations (341 ) (325 ) 16 Other net periodic benefit costs (a) — 16 16 (a) Includes net settlement loss and other net periodic benefit costs, excluding service costs (See Note 18 ). Classification in the statement of cash flows In August 2016, the FASB issued a new accounting standards update which seeks to reduce the existing diversity in practice in how certain transactions are classified in the statement of cash flows. This standard was effective for us in the first quarter of 2018, and was applied retrospectively. Adoption of this standard did not have a significant impact on our consolidated statements of cash flows. Presentation of restricted cash in the statement of cash flows In November 2016, the FASB issued a new accounting standards update that requires entities to show the changes in the total of cash, cash equivalents and restricted cash in the statement of cash flows. As a result, we no longer present transfers between cash and cash equivalents and restricted cash in the statement of cash flows. When cash, cash equivalents, and restricted cash are presented in more than one line item on the balance sheet, the standard requires a reconciliation of the totals in the statement of cash flows to the related captions in the balance sheet. This reconciliation can be presented either on the face of the statement of cash flows or in the notes to the financial statements. This standard was effective for us in the first quarter of 2018, and was applied retrospectively. Adoption of this standard did not have a significant impact on our consolidated statements of cash flows. Accounting for sale or transfer of nonfinancial assets In February 2017, the FASB issued a new accounting standards update that clarifies the accounting for the sale or transfer of nonfinancial assets and in substance nonfinancial assets to noncustomers, including partial sales. The standard also clarifies that the derecognition of all businesses (except those related to conveyances of oil and gas mineral rights or contracts with customers) should be accounted for in accordance with the derecognition and deconsolidation guidance in Subtopic 810-10. This standard was effective for us in the first quarter of 2018, and was applied using the modified retrospective approach. Adoption of this standard did not have a significant impact on our consolidated results of operations, financial position or cash flows. Definition of a business In January 2017, the FASB issued a new accounting standards update that changes the definition of a business to assist entities with evaluating when a set of transferred assets and activities constitutes a business. The guidance requires us to evaluate if substantially all of the fair value of the gross assets acquired is concentrated in a single identifiable asset or a group of similar identifiable assets; if so, the set of transferred assets and activities would not represent a business. The guidance also requires a business to include at least one substantive process and narrows the definition of outputs by more closely aligning it with how outputs are described in the new revenue guidance. This standard was effective for us in the first quarter of 2018, and was applied prospectively. Adoption of this standard did not have a significant impact on our consolidated results of operations, financial position or cash flows. Financial instruments updates In January 2016, the FASB issued an accounting standards update that addresses certain aspects of recognition, measurement, presentation, and disclosure of financial instruments. We adopted this standard in the first quarter of 2018. Adoption of this standard did not have a significant impact on our consolidated results of operations, financial position or cash flows.

Income (Loss) and Dividends per

Income (Loss) and Dividends per Common Share	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Income (Loss) and Dividends per Common Share	Income (Loss) and Dividends per Common Share Basic income (loss) per share is based on the weighted average number of common shares outstanding. Diluted income per share assumes exercise of stock options in all periods, provided the effect is not antidilutive. The per share calculations below exclude 5 million and 6 million of stock options for the three and nine months period ended September 30, 2018 and 10 million and 11 million stock options for the three and nine months period ended September 30, 2017 that were antidilutive. Three Months Ended September 30, Nine Months Ended September 30, (In millions, except per share data) 2018 2017 2018 2017 Income (loss) from continuing operations $ 254 $ (599 ) $ 706 $ (802 ) Income (loss) from discontinued operations — — — (4,893 ) Net income (loss) $ 254 $ (599 ) $ 706 $ (5,695 ) Weighted average common shares outstanding 848 850 852 850 Effect of dilutive securities 1 — 1 — Weighted average common shares, diluted 849 850 853 850 Per basic share: Income (loss) from continuing operations $ 0.30 $ (0.70 ) $ 0.83 $ (0.94 ) Income (loss) from discontinued operations $ — $ — $ — $ (5.76 ) Net income (loss) $ 0.30 $ (0.70 ) $ 0.83 $ (6.70 ) Per diluted share: Income (loss) from continuing operations $ 0.30 $ (0.70 ) $ 0.83 $ (0.94 ) Income (loss) from discontinued operations $ — $ — $ — $ (5.76 ) Net income (loss) $ 0.30 $ (0.70 ) $ 0.83 $ (6.70 ) Dividends per share $ 0.05 $ 0.05 $ 0.15 $ 0.15

Acquisitions

Acquisitions	9 Months Ended
	Sep. 30, 2018
Business Combinations [Abstract]
Acquisitions	Acquisitions In the second quarter of 2017, we closed on two acquisitions which included approximately 91,000 net acres in the Permian basin of New Mexico. The first acquisition with BC Operating, Inc. and other entities closed for approximately $1.1 billion in cash and the second acquisition with Black Mountain Oil & Gas and other private sellers closed for approximately $700 million in cash. These acquisitions were paid with cash on hand and accounted for as asset acquisitions, with substantially all of the purchase price allocated to unproved property within property, plant and equipment.

Dispositions

Dispositions	9 Months Ended
	Sep. 30, 2018
Discontinued Operations and Disposal Groups [Abstract]
Dispositions	Dispositions United States E&P Segment In the third quarter of 2018, we closed on the sale of non-core, non-operated conventional properties, primarily in the Gulf of Mexico, for combined net proceeds of $16 million , before closing adjustments. A pre-tax gain of $32 million was recognized in the third quarter of 2018. In the third quarter of 2017, we closed on the sale of certain conventional assets in Oklahoma for proceeds of $25 million , subject to closing adjustments, and recognized a pre-tax gain of $21 million . International E&P Segment In the second quarter of 2018, we entered into an agreement to sell a non-core property for proceeds of $56 million , before closing adjustments. This property is classified as held for sale in the consolidated balance sheet at September 30, 2018, with total assets of $73 million , total liabilities of $13 million and is expected to close before year-end. 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 . In the third quarter of 2017, we entered into separate agreements to sell certain non-core properties for combined proceeds of $53 million , before closing adjustments. We closed on one of the asset sales in the fourth quarter of 2017 and recognized no pre-tax gain or loss on sale. We closed on the remaining asset sale during the third quarter of 2018 for a pre-tax loss of $18 million . Canadian Business - Discontinued Operations On May 31, 2017 we closed on the sale of our Canadian business, which included our 20% non-operated interest in the AOSP to Shell and Canadian Natural Resources Limited for $2.5 billion , excluding closing adjustments. Under the terms of the agreement, $1.8 billion was paid to us upon closing. At closing we received two notes receivable for a combined $750 million for the remaining proceeds, which was received in the first quarter of 2018. In the first quarter of 2017, we recorded a non-cash impairment charge of $6.6 billion (after-tax of $4.96 billion ) primarily related to the property, plant and equipment of our Canadian business. This impairment was recorded for excess net book value over anticipated sales proceeds less costs to sell. Fair values of assets held for sale were determined based upon the anticipated sales proceeds less costs to sell, which resulted in a Level 2 classification. As the effective date of the transaction was January 1, 2017, we recorded a loss on sale of $43 million during the second quarter of 2017 due to results of operations from our Canadian business that were transferred to the buyer upon closing. Our Canadian business is reflected as discontinued operations in the consolidated statements of income and the consolidated statements of cash flows for all periods presented. The following table contains select amounts reported in our historical consolidated statements of income and consolidated statements of cash flows as discontinued operations: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2018 2017 2018 2017 Total revenue and other income $ — $ — $ — $ 431 Net gain (loss) on disposal of assets — — — (43 ) Total revenues and other income — — — 388 Costs and expenses: Production — — — 254 Depreciation, depletion and amortization — — — 40 Impairments — — — 6,636 Other — — — 25 Total costs and expenses — — — 6,955 Pretax income (loss) from discontinued operations — — — (6,567 ) Provision (benefit) for income taxes — — — (1,674 ) Income (loss) from discontinued operations $ — $ — $ — $ (4,893 ) Nine Months Ended September 30, (In millions) 2018 2017 Cash flow from discontinued operations: Operating activities $ — $ 141 Investing activities — (13 ) Changes in cash included in current assets held for sale — 2 Net increase in cash and cash equivalents of discontinued operations $ — $ 130

Revenues

Revenues	9 Months Ended
	Sep. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenues	Revenues The majority of our revenues are derived from the sale of crude oil and condensate, natural gas liquids ("NGLs") and natural gas under spot and term agreements with our customers in the U.S. and various international locations. The following tables present our revenues from contracts with customers disaggregated by product type and geographic areas. Three Months Ended September 30, 2018 United States E&P Northern (In millions) Eagle Ford Bakken Oklahoma Delaware Other U.S. Total Crude oil and condensate $ 436 $ 447 $ 114 $ 59 $ 34 $ 1,090 Natural gas liquids 70 19 48 12 3 152 Natural gas 36 9 46 6 5 102 Other — — — — 3 3 Revenues from contracts with customers $ 542 $ 475 $ 208 $ 77 $ 45 $ 1,347 Three Months Ended September 30, 2018 International E&P Other (In millions) E.G. U.K. Libya International Total Crude oil and condensate $ 100 $ 41 $ — $ 20 $ 161 Natural gas liquids 1 1 — — 2 Natural gas 9 11 — — 20 Other — 8 — — 8 Revenues from contracts with customers $ 110 $ 61 $ — $ 20 $ 191 Nine Months Ended September 30, 2018 United States E&P Northern (In millions) Eagle Ford Bakken Oklahoma Delaware Other U.S. Total Crude oil and condensate $ 1,196 $ 1,182 $ 340 $ 173 $ 131 $ 3,022 Natural gas liquids 157 51 130 24 8 370 Natural gas 102 27 127 13 17 286 Other 3 — — — 12 15 Revenues from contracts with customers $ 1,458 $ 1,260 $ 597 $ 210 $ 168 $ 3,693 Nine Months Ended September 30, 2018 International E&P Other (In millions) E.G. U.K. Libya International Total Crude oil and condensate $ 271 $ 207 $ 187 $ 65 $ 730 Natural gas liquids 3 4 — — 7 Natural gas 28 31 9 — 68 Other — 24 — — 24 Revenues from contracts with customers $ 302 $ 266 $ 196 $ 65 $ 829 The pricing in our hydrocarbon sales agreements are variable, determined using various published benchmarks which are adjusted for negotiated quality and location differentials. As a result, revenue collected under our agreements with customers is highly dependent on the market conditions and may fluctuate considerably as the hydrocarbon market prices rise or fall. Typically, our customers pay us monthly, within a short period of time after we deliver the hydrocarbon products. As such, we do not have any financing element associated with our contracts. We do not have any issues related to returns or refunds, as product specifications are standardized for the industry and are typically measured when transferred to a common carrier or midstream entity, and other contractual mechanisms (e.g., price adjustments) are used when products do not meet those specifications. In limited cases, we may also collect advance payments from customers as stipulated in our agreements; payments in excess of recognized revenue are recorded as contract liabilities on our consolidated balance sheet. Under our hydrocarbon sales agreements, the entire consideration amount is variable either due to pricing and/or volumes. We recognize revenue in the amount of variable consideration allocated to distinct units of hydrocarbons transferred to a customer. Such allocation reflects the amount of total consideration we expect to collect for completed deliveries of hydrocarbons and the terms of variable payment relate specifically to our efforts to satisfy the performance obligations under these contracts. Our performance obligations under our hydrocarbon sales agreements are to deliver either the entire production from the dedicated wells or specified contractual volumes of hydrocarbons. We often serve as the operator for jointly owned oil and gas properties. As part of this role, we perform activities to explore, develop and produce oil and gas properties in accordance with the joint operating arrangement and collective decisions of the joint parties. Other working interest owners reimburse us for costs incurred based on our agreements. We determined that these activities are not performed as part of customer relationships, in accordance with the new revenue standard, and such reimbursements will continue to not be recorded as revenues within the scope of the new revenue standard. In addition, we commonly market the share of production belonging to other working interest owners as the operator of jointly owned oil and gas properties. We concluded that those marketing activities are carried out as part of the collaborative arrangement, and we do not purchase or otherwise obtain control of other working interest owners’ share of production. Therefore, we act as a principal only in regards to the sale of our share of production and recognize revenue for the volumes associated with our net production. Crude oil and condensate For the crude sales agreements, we satisfy our performance obligations and recognize revenue once customers take control of the crude at the designated delivery points, which include pipelines, trucks or vessels. Natural gas and NGLs When selling natural gas and NGLs, we engage midstream entities to process our production stream by separating natural gas from the NGLs. Frequently, these midstream entities also purchase our natural gas and NGLs under the same agreements. In these situations, we determined the performance obligation is complete and satisfied at the tailgate of the processing plant when the natural gas and NGLs become identifiable and measurable products. We determined the plant tailgate is the point in time where control, as defined in the new revenue standard, is transferred to midstream entities and they are entitled to significant risks and rewards of ownership of the natural gas and NGLs. The amounts due to midstream entities for gathering and processing services are recognized as shipping and handling cost, since we make those payments in exchange for distinct services. Under some of our natural gas processing agreements, we have an option to take the processed natural gas and NGLs in-kind and sell to customers other than the processing company. In those circumstances, our performance obligations are complete after delivering the processed hydrocarbons to the customer at the designated delivery points, which may be the tailgate of the processing plant or an alternative delivery point requested by the customer. We have “percentage-of-proceeds” arrangements with some midstream entities where they retain a percentage of the proceeds collected for selling our processed natural gas and NGLs as compensation for their processing and marketing services. We recognize revenue for the gross sales volumes and recognize the proceeds retained by midstream companies as shipping and handling cost. Contract receivables and liabilities The following table provides information about receivables and contract assets (liabilities) from contracts with customers. (In millions) September 30, 2018 January 1, 2018 Receivables from contracts with customers, which are included in receivables, less reserves $ 937 $ 811 Contract asset (liability) $ (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. Significant changes in the contract asset (liability) balance during the period are as follows. Nine Months Ended (In millions) September 30, 2018 Contract asset balance as of January 1, 2018 $ — Revenue recognized as performance obligations are satisfied 85 Amounts invoiced to customers (86 ) Contract asset (liability) balance as of September 30, 2018 $ (1 )

Segment Information

Segment Information	9 Months Ended
	Sep. 30, 2018
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 it offers. • United States E&P (" U.S. E&P ") – explores for, produces and markets crude oil and condensate, NGLs and natural gas in the United States • International E&P ("Int’l E&P") – 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 (loss) represents income (loss) which excludes certain items not allocated to our operating segments, net of income taxes. A portion of our corporate and operations general and administrative support costs are not allocated to the operating segments. These unallocated costs primarily consist of employment costs (including pension effects), professional services, facilities and other costs associated with corporate and operations support activities. Additionally, items which affect comparability such as: gains or losses on dispositions, certain impairments, unrealized gains or losses on commodity derivative instruments, pension settlement losses or other items (as determined by the CODM) are not allocated to operating segments. Three Months Ended September 30, 2018 Not Allocated (In millions) U.S. E&P Int'l E&P to Segments Total Revenues from contracts with customers $ 1,347 $ 191 $ — $ 1,538 Net gain (loss) on commodity derivatives (89 ) — 19 (b) (70 ) Income from equity method investments — 64 — 64 Net gain (loss) on disposal of assets — — 16 (c) 16 Other income 2 4 113 (d) 119 Less costs and expenses: Production 172 43 — 215 Shipping, handling and other operating 136 16 — 152 Exploration 55 1 — 56 Depreciation, depletion and amortization 571 49 6 626 Impairments — — 8 (e) 8 Taxes other than income 86 — — 86 General and administrative 37 7 57 101 Net interest and other — — 58 58 Other net periodic benefit costs — (3 ) 11 (f) 8 Income tax provision (benefit) 2 30 71 103 Segment income (loss) / Income (loss) from continuing operations $ 201 $ 116 $ (63 ) $ 254 Capital expenditures (a) $ 691 $ 6 $ 7 $ 704 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 13 ). (c) Sales of certain non-core proved properties in our International and United States E&P segments (See Note 5 ). (d) Reduction of our asset retirement obligation in our International E&P segment (See Note 12 ). (e) Due to the anticipated sale of non-core property in our International E&P segment (See Note 11 ). (f) Includes pension settlement loss of $10 million (See Note 18 ). Three Months Ended September 30, 2017 Not Allocated (In millions) U.S. E&P Int'l E&P to Segments Total Revenues from contracts with customers $ 772 $ 364 $ — $ 1,136 Net gain (loss) on commodity derivatives 34 — (56 ) (b) (22 ) Marketing revenues 12 36 — 48 Income from equity method investments — 63 — 63 Net gain on disposal of assets 1 — 18 (c) 19 Other income 3 — 5 8 Less costs and expenses: Production 121 76 — 197 Marketing costs 14 35 — 49 Shipping, handling and other operating 80 31 (2 ) 109 Exploration 41 3 250 (d) 294 Depreciation, depletion and amortization 531 102 8 641 Impairments — — 201 (e) 201 Taxes other than income 44 — — 44 General and administrative 29 6 54 89 Net interest and other — — 35 (f) 35 Other net periodic benefit costs — — 5 (g) 5 Loss on early extinguishment of debt — — 46 (h) 46 Income tax provision (benefit) — 106 35 141 Segment income (loss) / Income (loss) from continuing operations $ (38 ) $ 104 $ (665 ) $ (599 ) Capital expenditures (a) $ 541 $ 4 $ 9 $ 554 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 13 ). (c) Primarily related to the sale of certain conventional assets in Oklahoma (See Note 5 ). (d) Primarily related to unproved property impairments associated with certain non-core properties within our International E&P segment (See Note 11 ). (e) Primarily related to proved property impairments associated with certain non-core properties within our International E&P segment (See Note 11 ). (f) Includes a gain of $46 million resulting from the termination of our forward starting interest rate swaps (See Note 13 ). (g) Includes pension settlement loss of $8 million (See Note 18 .) (h) Primarily related to the make-whole call provisions paid upon redemption of our senior unsecured notes (See Note 15 ). Nine Months Ended September 30, 2018 Not Allocated (In millions) U.S. E&P Int'l E&P to Segments Total Revenues from contracts with customers $ 3,693 $ 829 $ — $ 4,522 Net gain (loss) on commodity derivatives (255 ) — (69 ) (b) (324 ) Income from equity method investments — 161 — 161 Net gain (loss) on disposal of assets — — 323 (c) 323 Other income 7 7 121 (d) 135 Less costs and expenses: Production 476 162 (1 ) 637 Shipping, handling and other operating 364 45 (1 ) 408 Exploration 170 3 — 173 Depreciation, depletion and amortization 1,655 153 20 1,828 Impairments — — 50 (e) 50 Taxes other than income 218 — (3 ) 215 General and administrative 108 25 173 306 Net interest and other — — 168 168 Other net periodic benefit costs — (7 ) 18 (f) 11 Income tax provision (benefit) 5 226 84 315 Segment income (loss) / Income (loss) from continuing operations $ 449 $ 390 $ (133 ) $ 706 Capital expenditures (a) $ 1,943 $ 28 $ 17 $ 1,988 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 13 ). (c) Primarily related to the gain on sale of our Libya subsidiary (See Note 5 ). (d) Reduction of our asset retirement obligation in our International E&P segment (See Note 12 ). (e) Due to the anticipated sales of certain non-core proved properties in our International and United States E&P segments (See Note 11 ). (f) Includes pension settlement loss of $16 million (See Note 18 ). Nine Months Ended September 30, 2017 Not Allocated (In millions) U.S. E&P Int'l E&P to Segments Total Revenue from contracts with customers $ 2,124 $ 787 $ — $ 2,911 Net gain (loss) on commodity derivatives 51 — 64 (b) 115 Marketing revenues 25 92 — 117 Income from equity method investments — 183 — 183 Net gain (loss) on disposal of assets 2 — 24 (c) 26 Other income 9 14 8 31 Less costs and expenses: Production 348 180 — 528 Marketing costs 30 91 — 121 Shipping, handling and other operating 250 59 — 309 Exploration 97 5 250 (d) 352 Depreciation, depletion and amortization 1,498 266 25 1,789 Impairments 4 — 201 (e) 205 Taxes other than income 116 — 12 128 General and administrative 92 21 163 276 Net interest and other — — 199 (f) 199 Other net periodic benefit costs — (4 ) 20 (g) 16 Loss on early extinguishment of debt — — 46 (h) 46 Income tax provision (benefit) — 202 14 216 Segment income (loss) / Income (loss) from continuing operations $ (224 ) $ 256 $ (834 ) $ (802 ) Capital expenditures (a) $ 1,465 $ 27 $ 20 $ 1,512 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 13 ). (c) Primarily related to the sale of certain conventional assets in Oklahoma (See Note 5 ). (d) Primarily related to unproved property impairments associated with certain non-core properties within our International E&P segment (See Note 11 ). (e) Primarily related to proved property impairments associated with certain non-core properties within our International E&P segment (See Note 11 ). (f) Includes a gain of $46 million resulting from the termination of our forward starting interest rate swaps (See Note 13 ). (g) Includes pension settlement loss of $25 million (See Note 18 ). (h) Primarily related to the make-whole call provisions paid upon redemption of our senior unsecured notes (See Note 15 ).

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2018
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes Effective Tax Rate The effective income tax rate is influenced by a variety of factors including the geographic and functional sources of income and the relative magnitude of these sources of income. The difference between the total provision and the sum of the amounts allocated to segments is reported in the “Not Allocated to Segments” column of the tables in Note 7 . For the three and nine months ended September 30, 2018 and 2017 , our effective income tax rates from continuing operations were as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Effective income tax expense (benefit) rate from continuing operations * 29 % 31 % 31 % 37 % * 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 tax rates from continuing operations to be different from our U.S. statutory tax rate of 21% and 35% for 2018 and 2017: • Income taxes for the third quarter 2018 were impacted by a $76 million deferred tax expense due to the reduction in estimated costs relating to our U.K. asset retirement obligation, see Note 12 for further detail. • During the nine months ended September 30, 2018 income taxes were impacted by tax expense in Libya of $162 million and the reduction in estimated costs relating to our U.K. asset retirement obligation. • Income taxes for the third quarter 2017 were impacted by tax expense in Libya of $102 million . During the nine months ended September 30, 2017, we incurred tax expense in Libya of $179 million and settled our 2011-2013 Alaska income tax audit resulting in a tax benefit of $13 million . Excluding Libya, the effective income tax expense rates from continuing operations were an expense of 17% and an expense of 5% for the nine months ended September 30, 2018 and 2017. As a result of the sale of our Libya subsidiary in the first quarter of 2018, see Note 5 for further detail, we do not expect to incur further tax expense related to our Libya subsidiary. During 2018 and 2017, income taxes for Libya were recorded as a discrete item due to the uncertainty around the timing of future production and sales volumes. As a result of progression in the 2010-2011 IRS Federal Tax Audit (“IRS Audit”), during the third quarter of 2018 we have established a receivable classified in other noncurrent assets on the consolidated balance sheet of $136 million related to corporate alternative minimum tax (“AMT") credits. Due to the repeal of corporate AMT with the enactment of the Tax Cuts and Jobs Act (the “Tax Reform Legislation”), discussed below, AMT credits are refundable. We do not currently consider the IRS Audit effectively settled as it is still subject to Joint Committee review. As a result, we have established an uncertain tax position for the same amount resulting in no impact to the consolidated statement of income in the third quarter of 2018 . We are under income tax examination in various jurisdictions in which we operate. We believe it is reasonably possible there could be a change in our uncertain tax positions resulting from the progression of examination or appeals activity, which could impact our annual effective tax rate, in the next 12 months. On December 22, 2017, the U.S. enacted the Tax Reform Legislation. Tax Reform Legislation significantly changes U.S. corporate income tax laws by, among other things, reducing the U.S. corporate income tax rate to 21% starting in 2018, and repeal of the corporate AMT, and a one-time deemed repatriation of accumulated foreign earnings. In the fourth quarter of 2017, we remeasured our deferred taxes at 21% , in accordance with U.S. GAAP standards. We plan to finalize our tax positions taken with respect to Tax Reform Legislation in the fourth quarter of 2018 as we await further guidance from U.S. Treasury, and conclude whether any further adjustments are required to our net tax position as of December 31, 2017. Any adjustments to these provisional amounts will be reported as a component of income tax expense (benefit) in the reporting period in which any such adjustments are determined. As of the third quarter of 2018, there are no material impacts on tax expense with respect to the finalization of tax positions taken due to Tax Reform Legislation.

Inventories

Inventories	9 Months Ended
	Sep. 30, 2018
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. September 30, December 31, (In millions) 2018 2017 Crude oil and natural gas $ 11 $ 9 Supplies and other items 99 117 Inventories $ 110 $ 126

Property, Plant and Equipment,

Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization	9 Months Ended
	Sep. 30, 2018
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization	Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization September 30, December 31, (In millions) 2018 2017 United States E&P $ 16,011 $ 15,867 International E&P 805 1,710 Corporate 83 88 Net property, plant and equipment $ 16,899 $ 17,665 Exploratory well costs capitalized greater than one year after completion of drilling are associated with one project in E.G. with costs of $32 million as of both September 30, 2018 and December 31, 2017 .

Impairments

Impairments	9 Months Ended
	Sep. 30, 2018
Impairment Expense [Abstract]
Impairments	Impairments The following table summarizes impairment charges of proved properties from continuing operations. Additionally, it presents the values of assets, by major category, measured at fair value on a nonrecurring basis in periods subsequent to their initial recognition. Three Months Ended September 30, 2018 2017 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets $ 39 $ 8 $ 169 $ 201 Nine Months Ended September 30, 2018 2017 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets $ 108 $ 50 $ 169 $ 205 • 2018 - During the first nine months of 2018 we recorded pre-tax non-cash proved property impairments of $50 million , to a fair value of $108 million , primarily as a result of anticipated sales proceeds for certain non-core proved properties in our International and United States E&P 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 5 for discussion of the divestitures in further detail. • 2017 - Impairments for the three and nine months ended September 30, 2017 were primarily a result of lower forecasted long-term commodity prices and the anticipated sales of certain non-core proved properties in our International E&P segment of $136 million . The fair values were measured using the market approach, based upon either anticipated sales proceeds less costs to sell or a market comparable sales price per boe. This resulted in a Level 2 classification. Additionally, included in proved property impairments was $65 million relating to the Gulf of Mexico as a result of lower forecasted long-term commodity prices. The fair values were measured using an income approach based upon internal estimates of future production levels, prices and discount rate. Inputs to the fair value measurement include reserve and production estimates made by our reservoir engineers, estimated future commodity prices adjusted for quality and location differentials and forecasted operating expenses for the remaining estimated life of the reservoir. These inputs resulted in a Level 3 classification. The following table summarizes impairment charges of unproved properties included as a component of exploration expenses: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2018 2017 2018 2017 Exploration Expenses Unproved property impairments $ 50 $ 172 $ 131 $ 217 Dry well costs 1 77 13 77 Geological and geophysical (1 ) 2 13 3 Other 6 43 16 55 Total exploration expenses $ 56 $ 294 $ 173 $ 352 • 2017 - Impairments for the three and nine months ended September 30, 2017 were primarily a result of lower forecasted long-term commodity prices and the anticipated sales of certain non-core properties in our International E&P segment, we recorded a non-cash charge of $159 million comprised of $95 million in unproved property impairments and $64 million in dry well costs related to our Diaba License G4-223 in the Republic of Gabon. Also, because of our decision not to develop the Tchicuate offshore Block in the Republic of Gabon, we recorded a non-cash impairment charge of $43 million to unproved property. See Note 5 for relevant detail regarding the disposition of assets.

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations Asset retirement obligations primarily consist of estimated costs to remove, dismantle and restore land or seabed at the end of oil and gas production operations. Changes in asset retirement obligations for the nine months ended were as follows: September 30, September 30, (In millions) 2018 2017 Beginning balance as of January 1, 2018 and 2017 $ 1,483 $ 1,653 Incurred liabilities, including acquisitions 10 19 Settled liabilities, including dispositions (105 ) (40 ) Accretion expense (included in depreciation, depletion and amortization) 53 65 Revisions of estimates (130 ) (113 ) Held for sale (10 ) (2 ) Ending balance $ 1,301 $ 1,582 September 30, 2018 • Settled liabilities include dispositions, primarily related to the sale of non-core, non-operated conventional properties in the Gulf of Mexico as well as retirements in the U.K. • Revisions of estimates were primarily due to the acceleration of U.K. abandonment activities to capture favorable market conditions and lower estimated abandonment costs. • Ending balance includes $58 million classified as short-term at September 30, 2018. September 30, 2017 • Settled liabilities include dispositions, primarily related to the sale of certain conventional assets in Oklahoma as well as retirements in the U.K. and the Gulf of Mexico. • Revisions of estimates were primarily due to changes in estimated costs as well as timing of abandonment activities in the U.K. • Ending balance includes $60 million classified as short-term at September 30, 2017.

Derivatives

Derivatives	9 Months Ended
	Sep. 30, 2018
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 and historical interest rate derivatives are subject to enforceable master netting arrangements or similar agreements under which we may report net amounts. The following tables present the gross fair values of derivative instruments and the reported net amounts along with where they appear on the consolidated balance sheets. September 30, 2018 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity — 196 $ (196 ) Other current liabilities Commodity — 14 $ (14 ) Deferred credits and other liabilities Total Not Designated as Hedges $ — $ 210 $ (210 ) December 31, 2017 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ — $ 138 $ (138 ) Other current liabilities Commodity — 2 (2 ) Deferred credits and other liabilities Total Not Designated as Hedges $ — $ 140 $ (140 ) Derivatives Not Designated as Hedges Terminated Interest Rate Swaps During the third quarter of 2016, we entered into forward starting interest rate swaps to hedge the variations in cash flows related to fluctuations in long term interest rates from debt that were probable to be refinanced by us in 2018, specifically interest rate risk associated with future changes in the benchmark treasury rate. During the second quarter of 2017, we de-designated the forward starting interest rate swaps previously designated as cash flow hedges. In the third quarter of 2017, the forecasted transaction consummated and we issued $1 billion in senior unsecured notes. As a result, in the third quarter of 2017 we terminated our forward starting interest rate swaps for proceeds of $54 million . We recognized a gain of $46 million , related to deferred gains reclassified from accumulated other comprehensive income, in net interest and other during the third quarter of 2017. The following table sets forth the net impact of the terminated forward starting interest rate swap derivatives de-designated as cash flow hedges on other comprehensive income (loss). Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2018 2017 2018 2017 Interest Rate Swaps Beginning balance $ — $ 46 $ — $ 60 Change in fair value recognized in other comprehensive income — — — (13 ) Reclassification from other comprehensive income — (46 ) — (47 ) Ending balance $ — $ — $ — $ — Commodity Derivatives We have entered into multiple crude oil and natural gas derivatives indexed to NYMEX WTI and Henry Hub related to a portion of our forecasted United States E&P sales through 2020. These commodity 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/Henry Hub 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 September 30, 2018 and the weighted average prices for those contracts: Crude Oil 4Q 2018 FY 2019 FY 2020 Three-Way Collars Volume (Bbls/day) 95,000 60,000 — Weighted average price per Bbl: Ceiling $57.65 $73.18 — Floor $52.11 $56.67 — Sold put $45.21 $49.59 — Basis Swaps (a) Volume (Bbls/day) 10,000 10,000 15,000 Weighted average price per Bbl $(0.67) $(0.82) $(0.94) NYMEX Roll Basis Swaps Volume (Bbls/day) — 60,000 — Weighted average price per Bbl — $0.38 — Natural Gas Three-Way Collars (b) Volume (MMBtu/day) 160,000 — — Weighted average price per MMBtu: Ceiling $3.61 — — Floor $3.00 — — Sold put $2.50 — — (a) The basis differential price is between WTI Midland and WTI Cushing. (b) Subsequent to September 30, 2018, we entered into 100,000 MMBTU/day of three-way collars for January - March 2019 with a ceiling price of $3.75 , a floor price of $3.00 , and a sold put price of $2.50 . 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 nine month periods ended September 30, 2018 was a gain of $19 million and a loss of $69 million compared to a loss of $56 million and gain of $64 million for the same respective periods in 2017. Net settlements of commodity derivative instruments for the three and nine month periods ended September 30, 2018 was a loss of $89 million and $255 million compared to a gain of $34 million and $51 million for the respective periods in 2017.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements Fair Values - Recurring The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2018 and December 31, 2017 by fair value hierarchy level. September 30, 2018 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ 19 $ — $ — $ 19 Derivative instruments, assets $ 19 $ — $ — $ 19 Derivative instruments, liabilities Commodity (a) $ — $ (229 ) $ — $ (229 ) Derivative instruments, liabilities $ — $ (229 ) $ — $ (229 ) (a) Derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 13 . December 31, 2017 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Derivative instruments, assets $ — $ — $ — $ — Derivative instruments, liabilities Commodity (a) $ (20 ) $ (120 ) $ — $ (140 ) Derivative instruments, liabilities $ (20 ) $ (120 ) $ — $ (140 ) (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. Historically, both our interest rate swaps and forward starting interest rate swaps were measured at fair value with a market approach using actionable broker quotes, which are Level 2 inputs. See Note 13 for additional discussion of the types of derivative instruments we used. Fair Values - Goodwill As of September 30, 2018, our consolidated balance sheet included goodwill of $97 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 International E&P includes goodwill. We first assess the qualitative factors in order to determine whether the fair value of our International E&P 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 the goodwill impairment test, 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 determined that it is more likely than not the fair value of the International E&P reporting unit is less than its carrying amount, a quantitative goodwill test is performed. During the second quarter of 2018, 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 1 test (second quarter 2017) and noted a general improvement in the qualitative factors above. After assessing the totality of the qualitative factors which could have a positive or negative impact on goodwill, 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 E&P reporting unit. Fair Values – Nonrecurring See Note 5 and Note 11 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 long-term debt and payables. We believe the carrying values of our receivables and payables approximate fair value. Our fair value assessment incorporates a variety of considerations, including (1) the short-term duration of the instruments, (2) our credit rating, and (3) our historical incurrence of and expected future insignificant bad debt expense, which includes an evaluation of counterparty credit risk. The following table summarizes financial instruments, excluding receivables, payables and derivative financial instruments, and their reported fair values by individual balance sheet line item at September 30, 2018 and December 31, 2017 . September 30, 2018 December 31, 2017 Fair Carrying Fair Carrying (In millions) Value Amount Value Amount Financial assets Current assets (a) $ 15 $ 15 $ 762 $ 761 Other noncurrent assets 82 86 135 137 Total financial assets $ 97 $ 101 $ 897 $ 898 Financial liabilities Other current liabilities $ 32 $ 46 $ 32 $ 43 Long-term debt, including current portion (b) 5,777 5,528 5,976 5,526 Deferred credits and other liabilities 97 92 110 103 Total financial liabilities $ 5,906 $ 5,666 $ 6,118 $ 5,672 (a) December 31, 2017 fair value and carrying amounts included our two notes receivable relating to the sale of our Canadian business; both were paid during the first quarter of 2018, see Note 5 for further information. (b) Excludes capital leases and debt issuance costs. Fair values of our notes receivable and 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. All of our long-term debt instruments are publicly traded. A market approach, based upon quotes from major financial institutions, which are Level 2 inputs, is used to measure the fair value of our debt.

Debt

Debt	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Debt	Debt Revolving Credit Facility As of September 30, 2018 , we had no borrowings against our $3.4 billion revolving credit facility (the “Credit Facility”), as described below. In October 2018, we extended the maturity date of our Credit Facility from May 28, 2021 to May 28, 2022 . Fees on the unused commitment to the lenders, as well as the borrowing options under the Credit Facility, remain unaffected by the term extension. We retain the ability to request two one -year extensions and an option to increase the commitment amount by up to an additional $107 million , subject to the consent of any increasing lenders. The sub-facilities for swing-line loans and letters of credit remain unchanged allowing up to an aggregate amount of $100 million and $500 million , respectively. 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 September 30, 2018 , we were in compliance with this covenant with a debt-to-capitalization ratio of 31% . Long-term debt As of September 30, 2018 we had $5.5 billion in long-term debt outstanding, with our next debt maturity in the amount of $600 million due in 2020. In the third quarter 2017, we issued $1 billion of 4.4% senior unsecured notes that will mature on July 15, 2027. Interest on the senior unsecured notes is payable semi-annually beginning January 15, 2018. We may redeem some or all of the senior unsecured notes at any time at the applicable redemption price, plus accrued interest, if any. We used the net proceeds of $990 million plus existing cash on hand to redeem the following senior unsecured notes: • $682 million 6.0% Notes Due in 2017 • $854 million 5.9% Notes Due in 2018 • $228 million 7.5% Notes Due in 2019 As a result of the above redemption of $1.76 billion in senior unsecured notes, we recognized a loss on early extinguishment of debt of $46 million , primarily due to make-whole call provisions. In connection with the redemption of the senior unsecured notes, we terminated our forward starting interest rate swaps, which resulted in proceeds of $54 million and a gain of approximately $46 million into earnings in the third quarter 2017. See Note 13 for further detail on our historical forward starting interest rate swaps.

Stockholders' Equity

Stockholders' Equity	9 Months Ended
	Sep. 30, 2018
Equity [Abstract]
Stockholders' Equity	Stockholders' Equity In the third quarter of 2018 we acquired 16 million of common shares at a cost of $338 million under our share repurchase program. As of September 30, 2018 the total remaining share repurchase authorization was $1.2 billion . Purchases under the program are made at our discretion and may be in either open market transactions, including block purchases, or in privately negotiated transactions using cash on hand, cash generated from operations, proceeds from potential asset sales or cash from available borrowings to acquire shares. This program may be changed based upon our financial condition or changes in market conditions and is subject to termination prior to completion. Shares repurchased as of September 30, 2018 were held as treasury stock.

Incentive Based Compensation

Incentive Based Compensation	9 Months Ended
	Sep. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Incentive Based Compensation	Incentive Based Compensation Stock options, restricted stock awards and restricted stock units The following table presents a summary of activity for the first nine months of 2018 : Stock Options Restricted Stock Awards & Units Number of Shares Weighted Average Exercise Price Awards Weighted Average Grant Date Fair Value Outstanding at December 31, 2017 10,330,776 $25.52 7,572,845 $14.24 Granted 856,890 (a) $14.52 4,741,961 $14.72 Options Exercised/Stock Vested (1,756,797 ) $13.69 (2,783,504 ) $15.84 Canceled (1,783,223 ) $30.27 (756,491 ) $14.03 Outstanding at September 30, 2018 7,647,646 $25.89 8,774,811 $14.01 (a) The weighted average grant date fair value of stock option awards granted was $5.82 per share. Stock-based performance unit awards During the first nine months of 2018 , we granted 754,140 stock-based performance units to certain officers. The grant date fair value per unit was $17.02 .

Defined Benefit Postretirement

Defined Benefit Postretirement Plans	9 Months Ended
	Sep. 30, 2018
Retirement Benefits [Abstract]
Defined Benefit Postretirement Plans	Defined Benefit Postretirement Plans The following summarizes the components of net periodic benefit cost: Three Months Ended September 30, Pension Benefits Other Benefits (In millions) 2018 2017 2018 2017 Service cost $ 4 $ 5 $ — $ — Interest cost 7 7 2 2 Expected return on plan assets (9 ) (10 ) — — Amortization: – prior service cost (credit) (2 ) (3 ) (2 ) (2 ) – actuarial loss 3 3 — — Net settlement loss (a) 10 8 — — Net periodic benefit cost $ 13 $ 10 $ — $ — Nine Months Ended September 30, Pension Benefits Other Benefits (In millions) 2018 2017 2018 2017 Service cost $ 13 $ 16 $ 1 $ 1 Interest cost 20 22 6 6 Expected return on plan assets (26 ) (32 ) — — Amortization: – prior service cost (credit) (7 ) (7 ) (6 ) (5 ) – actuarial loss 9 7 1 — Net settlement loss (a) 16 25 — — Net periodic benefit cost $ 25 $ 31 $ 2 $ 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. During the first nine months of 2018 , we recorded the effects of settlements of our U.S. pension plans. As required, we remeasured the plans’ assets and liabilities as of the applicable balance sheet dates. The cumulative effects of these events are included in the remeasurement and reflected in both the pension liability and net periodic benefit cost. During the first nine months of 2018 , we made contributions of $58 million to our funded pension plans and we expect to make additional contributions up to an estimated $6 million over the remainder of 2018 . During the first nine months of 2018 , we made payments of $12 million and $17 million related to unfunded pension plans and other postretirement benefit plans.

Reclassifications Out of Accumu

Reclassifications Out of Accumulated Other Comprehensive Income (Loss)	9 Months Ended
	Sep. 30, 2018
Equity [Abstract]
Reclassifications Out of Accumulated Other Comprehensive Income (Loss)	Reclassifications Out of Accumulated Other Comprehensive Income (Loss) The following table presents a summary of amounts reclassified from accumulated other comprehensive income (loss): Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2018 2017 2018 2017 Income Statement Line Postretirement and postemployment plans Amortization of prior service credit $ 4 $ 5 $ 13 $ 12 Other net periodic benefit costs Amortization of actuarial loss (3 ) (3 ) (10 ) (7 ) Other net periodic benefit costs Net settlement loss (10 ) (8 ) (16 ) (25 ) Other net periodic benefit costs Derivative hedges Recognized gain on terminated derivative hedge — 46 — 46 Net interest and other Ineffective portion of derivative hedge — — — 1 Net interest and other (9 ) 40 (13 ) 27 Income (loss) from continuing operations before income taxes — (40 ) — (40 ) (Provision) benefit for income taxes Total reclassifications to expense, net of tax (9 ) — (13 ) (13 ) Income (loss) from continuing operations Foreign currency hedges Net recognized loss in discontinued operations, net of tax — — — (30 ) Income (loss) from discontinued operations Total reclassifications to expense $ (9 ) $ — $ (13 ) $ (43 ) Net income (loss)

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2018
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Nine Months Ended September 30, (In millions) 2018 2017 Net cash used in operating activities: Interest paid, net of amounts capitalized $ (187 ) $ (269 ) Income taxes paid to taxing authorities (298 ) (101 ) Noncash investing activities, related to continuing operations: Increase (decrease) in asset retirement costs $ 12 $ (94 ) Asset retirement obligations assumed by buyer 82 14 Notes receivable for disposal of assets — 745 Other noncash investing activities include accrued capital expenditures as of September 30, 2018 and 2017 of $238 million and $361 million .

Equity Method Investments

Equity Method Investments	9 Months Ended
	Sep. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Equity Method Investments During the periods ended September 30, 2018 and December 31, 2017 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 September 30, December 31, (In millions) September 30, 2018 2018 2017 EGHoldings 60% $ 402 $ 456 Alba Plant LLC 52% 170 214 AMPCO 45% 185 177 Total $ 757 $ 847 Summarized financial information for equity method investees is as follows: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2018 2017 2018 2017 Income data: Revenues and other income $ 238 $ 243 $ 664 $ 681 Income from operations 151 147 391 412 Net income 129 125 331 360

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies The U.K. tax authorities have challenged the timing of deductibility for certain Brae area decommissioning costs, which we claimed for U.K. corporation tax purposes. The dispute relates to the timing of the deduction and does not dispute the general deductibility of decommissioning costs. In the fourth quarter of 2017, we received notification from the U.K.’s First-tier Tribunal that the decommissioning cost deductions, which we had claimed, were not allowable. In accordance with U.K. regulations, in the fourth quarter of 2017, we paid the amount of tax and interest in question, approximately $108 million , prior to our appeal. As of October 2018 we no longer intend to progress our appeal against this decision and estimate that any revisions to current and deferred tax liabilities would 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. These audits have been completed through the 2014 tax year, except for tax years 2010 and 2011. 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.

Basis of Presentation (Policies

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2018
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 2017 Annual Report on Form 10-K. The results of operations for the third quarter and first nine months of 2018 are not necessarily indicative of the results to be expected for the full year. As a result of the sale of our Canadian business in 2017, we reflected this business as discontinued operations in all historical periods presented. Disclosures in this report related to results of operations and cash flows are presented on the basis of continuing operations unless otherwise stated. See Note 5 for discussion of this divestiture in further detail. Reclassifications In the first quarter of 2018 we adopted the new Accounting Standards Codification ("ASC") Topic 606, Revenue from Contracts with Customers using the modified retrospective method. To conform the historical presentation to our current presentation, we reclassified gains/losses arising from our commodity derivatives out of the revenues from contracts with customers line into a separate line, net gain (loss) on commodity derivatives, on the consolidated statements of income. Additionally, in the first quarter of 2018 we adopted the new pension accounting standards update on a retrospective basis, and reclassified the required cost elements from general and administrative expense into production expense, exploration expense, and other net periodic benefit costs. See Note 2 for further discussion of the adoption of these accounting standards.

Accounting Standards (Tables)

Accounting Standards (Tables)	9 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	The following tables summarize the impacts of adopting this standard on our historical consolidated income statement for the three and nine month periods ended September 30, 2017. Three Months Ended September 30, 2017 (In millions) Previously Reported As reclassified Effect of Change Higher/(Lower) Production $ 194 $ 197 $ 3 Exploration 294 294 — General and administrative 97 89 (8 ) Income (loss) from operations (377 ) (372 ) 5 Other net periodic benefit costs (a) — 5 5 Nine Months Ended September 30, 2017 (In millions) Previously Reported As reclassified Effect of Change Higher/(Lower) Production $ 521 $ 528 $ 7 Exploration 352 352 — General and administrative 299 276 (23 ) Income from operations (341 ) (325 ) 16 Other net periodic benefit costs (a) — 16 16 (a) Includes net settlement loss and other net periodic benefit costs, excluding service costs (See Note 18 ). The following tables summarize the impacts of adopting the new revenue standard on our consolidated income statement for the three and nine month periods ended September 30, 2018. Three Months Ended September 30, 2018 (In millions) As reported Adjustments Presentation without adoption of ASC Topic 606 Revenues and other income: Revenues from contracts with customers $ 1,538 $ (2 ) $ 1,536 Marketing revenues — 47 47 Other income 119 (1 ) 118 Costs and expenses: Marketing, including purchases from related parties $ — $ 46 $ 46 Shipping, handling and other operating 152 (2 ) 150 Nine Months Ended September 30, 2018 (In millions) As reported Adjustments Presentation without adoption of ASC Topic 606 Revenues and other income: Revenues from contracts with customers $ 4,522 $ (4 ) $ 4,518 Marketing revenues — 122 122 Other income 135 (3 ) 132 Costs and expenses: Marketing, including purchases from related parties $ — $ 122 $ 122 Shipping, handling and other operating 408 (7 ) 401

Income (Loss) and Dividends p_2

Income (Loss) and Dividends per Common Share (Tables)	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	Three Months Ended September 30, Nine Months Ended September 30, (In millions, except per share data) 2018 2017 2018 2017 Income (loss) from continuing operations $ 254 $ (599 ) $ 706 $ (802 ) Income (loss) from discontinued operations — — — (4,893 ) Net income (loss) $ 254 $ (599 ) $ 706 $ (5,695 ) Weighted average common shares outstanding 848 850 852 850 Effect of dilutive securities 1 — 1 — Weighted average common shares, diluted 849 850 853 850 Per basic share: Income (loss) from continuing operations $ 0.30 $ (0.70 ) $ 0.83 $ (0.94 ) Income (loss) from discontinued operations $ — $ — $ — $ (5.76 ) Net income (loss) $ 0.30 $ (0.70 ) $ 0.83 $ (6.70 ) Per diluted share: Income (loss) from continuing operations $ 0.30 $ (0.70 ) $ 0.83 $ (0.94 ) Income (loss) from discontinued operations $ — $ — $ — $ (5.76 ) Net income (loss) $ 0.30 $ (0.70 ) $ 0.83 $ (6.70 ) Dividends per share $ 0.05 $ 0.05 $ 0.15 $ 0.15

Dispositions (Tables)

Dispositions (Tables)	9 Months Ended
	Sep. 30, 2018
Discontinued Operations and Disposal Groups [Abstract]
Disposal Group, Including Discontinued Operation	The following table contains select amounts reported in our historical consolidated statements of income and consolidated statements of cash flows as discontinued operations: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2018 2017 2018 2017 Total revenue and other income $ — $ — $ — $ 431 Net gain (loss) on disposal of assets — — — (43 ) Total revenues and other income — — — 388 Costs and expenses: Production — — — 254 Depreciation, depletion and amortization — — — 40 Impairments — — — 6,636 Other — — — 25 Total costs and expenses — — — 6,955 Pretax income (loss) from discontinued operations — — — (6,567 ) Provision (benefit) for income taxes — — — (1,674 ) Income (loss) from discontinued operations $ — $ — $ — $ (4,893 ) Nine Months Ended September 30, (In millions) 2018 2017 Cash flow from discontinued operations: Operating activities $ — $ 141 Investing activities — (13 ) Changes in cash included in current assets held for sale — 2 Net increase in cash and cash equivalents of discontinued operations $ — $ 130

Revenues (Tables)

Revenues (Tables)	9 Months Ended
	Sep. 30, 2018
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. Three Months Ended September 30, 2018 United States E&P Northern (In millions) Eagle Ford Bakken Oklahoma Delaware Other U.S. Total Crude oil and condensate $ 436 $ 447 $ 114 $ 59 $ 34 $ 1,090 Natural gas liquids 70 19 48 12 3 152 Natural gas 36 9 46 6 5 102 Other — — — — 3 3 Revenues from contracts with customers $ 542 $ 475 $ 208 $ 77 $ 45 $ 1,347 Three Months Ended September 30, 2018 International E&P Other (In millions) E.G. U.K. Libya International Total Crude oil and condensate $ 100 $ 41 $ — $ 20 $ 161 Natural gas liquids 1 1 — — 2 Natural gas 9 11 — — 20 Other — 8 — — 8 Revenues from contracts with customers $ 110 $ 61 $ — $ 20 $ 191 Nine Months Ended September 30, 2018 United States E&P Northern (In millions) Eagle Ford Bakken Oklahoma Delaware Other U.S. Total Crude oil and condensate $ 1,196 $ 1,182 $ 340 $ 173 $ 131 $ 3,022 Natural gas liquids 157 51 130 24 8 370 Natural gas 102 27 127 13 17 286 Other 3 — — — 12 15 Revenues from contracts with customers $ 1,458 $ 1,260 $ 597 $ 210 $ 168 $ 3,693 Nine Months Ended September 30, 2018 International E&P Other (In millions) E.G. U.K. Libya International Total Crude oil and condensate $ 271 $ 207 $ 187 $ 65 $ 730 Natural gas liquids 3 4 — — 7 Natural gas 28 31 9 — 68 Other — 24 — — 24 Revenues from contracts with customers $ 302 $ 266 $ 196 $ 65 $ 829
Contract with Customer, Liability	The following table provides information about receivables and contract assets (liabilities) from contracts with customers. (In millions) September 30, 2018 January 1, 2018 Receivables from contracts with customers, which are included in receivables, less reserves $ 937 $ 811 Contract asset (liability) $ (1 ) $ — Significant changes in the contract asset (liability) balance during the period are as follows. Nine Months Ended (In millions) September 30, 2018 Contract asset balance as of January 1, 2018 $ — Revenue recognized as performance obligations are satisfied 85 Amounts invoiced to customers (86 ) Contract asset (liability) balance as of September 30, 2018 $ (1 )

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2018
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Three Months Ended September 30, 2018 Not Allocated (In millions) U.S. E&P Int'l E&P to Segments Total Revenues from contracts with customers $ 1,347 $ 191 $ — $ 1,538 Net gain (loss) on commodity derivatives (89 ) — 19 (b) (70 ) Income from equity method investments — 64 — 64 Net gain (loss) on disposal of assets — — 16 (c) 16 Other income 2 4 113 (d) 119 Less costs and expenses: Production 172 43 — 215 Shipping, handling and other operating 136 16 — 152 Exploration 55 1 — 56 Depreciation, depletion and amortization 571 49 6 626 Impairments — — 8 (e) 8 Taxes other than income 86 — — 86 General and administrative 37 7 57 101 Net interest and other — — 58 58 Other net periodic benefit costs — (3 ) 11 (f) 8 Income tax provision (benefit) 2 30 71 103 Segment income (loss) / Income (loss) from continuing operations $ 201 $ 116 $ (63 ) $ 254 Capital expenditures (a) $ 691 $ 6 $ 7 $ 704 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 13 ). (c) Sales of certain non-core proved properties in our International and United States E&P segments (See Note 5 ). (d) Reduction of our asset retirement obligation in our International E&P segment (See Note 12 ). (e) Due to the anticipated sale of non-core property in our International E&P segment (See Note 11 ). (f) Includes pension settlement loss of $10 million (See Note 18 ). Three Months Ended September 30, 2017 Not Allocated (In millions) U.S. E&P Int'l E&P to Segments Total Revenues from contracts with customers $ 772 $ 364 $ — $ 1,136 Net gain (loss) on commodity derivatives 34 — (56 ) (b) (22 ) Marketing revenues 12 36 — 48 Income from equity method investments — 63 — 63 Net gain on disposal of assets 1 — 18 (c) 19 Other income 3 — 5 8 Less costs and expenses: Production 121 76 — 197 Marketing costs 14 35 — 49 Shipping, handling and other operating 80 31 (2 ) 109 Exploration 41 3 250 (d) 294 Depreciation, depletion and amortization 531 102 8 641 Impairments — — 201 (e) 201 Taxes other than income 44 — — 44 General and administrative 29 6 54 89 Net interest and other — — 35 (f) 35 Other net periodic benefit costs — — 5 (g) 5 Loss on early extinguishment of debt — — 46 (h) 46 Income tax provision (benefit) — 106 35 141 Segment income (loss) / Income (loss) from continuing operations $ (38 ) $ 104 $ (665 ) $ (599 ) Capital expenditures (a) $ 541 $ 4 $ 9 $ 554 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 13 ). (c) Primarily related to the sale of certain conventional assets in Oklahoma (See Note 5 ). (d) Primarily related to unproved property impairments associated with certain non-core properties within our International E&P segment (See Note 11 ). (e) Primarily related to proved property impairments associated with certain non-core properties within our International E&P segment (See Note 11 ). (f) Includes a gain of $46 million resulting from the termination of our forward starting interest rate swaps (See Note 13 ). (g) Includes pension settlement loss of $8 million (See Note 18 .) (h) Primarily related to the make-whole call provisions paid upon redemption of our senior unsecured notes (See Note 15 ). Nine Months Ended September 30, 2018 Not Allocated (In millions) U.S. E&P Int'l E&P to Segments Total Revenues from contracts with customers $ 3,693 $ 829 $ — $ 4,522 Net gain (loss) on commodity derivatives (255 ) — (69 ) (b) (324 ) Income from equity method investments — 161 — 161 Net gain (loss) on disposal of assets — — 323 (c) 323 Other income 7 7 121 (d) 135 Less costs and expenses: Production 476 162 (1 ) 637 Shipping, handling and other operating 364 45 (1 ) 408 Exploration 170 3 — 173 Depreciation, depletion and amortization 1,655 153 20 1,828 Impairments — — 50 (e) 50 Taxes other than income 218 — (3 ) 215 General and administrative 108 25 173 306 Net interest and other — — 168 168 Other net periodic benefit costs — (7 ) 18 (f) 11 Income tax provision (benefit) 5 226 84 315 Segment income (loss) / Income (loss) from continuing operations $ 449 $ 390 $ (133 ) $ 706 Capital expenditures (a) $ 1,943 $ 28 $ 17 $ 1,988 (a) Includes accruals. (b) Unrealized loss on commodity derivative instruments (See Note 13 ). (c) Primarily related to the gain on sale of our Libya subsidiary (See Note 5 ). (d) Reduction of our asset retirement obligation in our International E&P segment (See Note 12 ). (e) Due to the anticipated sales of certain non-core proved properties in our International and United States E&P segments (See Note 11 ). (f) Includes pension settlement loss of $16 million (See Note 18 ). Nine Months Ended September 30, 2017 Not Allocated (In millions) U.S. E&P Int'l E&P to Segments Total Revenue from contracts with customers $ 2,124 $ 787 $ — $ 2,911 Net gain (loss) on commodity derivatives 51 — 64 (b) 115 Marketing revenues 25 92 — 117 Income from equity method investments — 183 — 183 Net gain (loss) on disposal of assets 2 — 24 (c) 26 Other income 9 14 8 31 Less costs and expenses: Production 348 180 — 528 Marketing costs 30 91 — 121 Shipping, handling and other operating 250 59 — 309 Exploration 97 5 250 (d) 352 Depreciation, depletion and amortization 1,498 266 25 1,789 Impairments 4 — 201 (e) 205 Taxes other than income 116 — 12 128 General and administrative 92 21 163 276 Net interest and other — — 199 (f) 199 Other net periodic benefit costs — (4 ) 20 (g) 16 Loss on early extinguishment of debt — — 46 (h) 46 Income tax provision (benefit) — 202 14 216 Segment income (loss) / Income (loss) from continuing operations $ (224 ) $ 256 $ (834 ) $ (802 ) Capital expenditures (a) $ 1,465 $ 27 $ 20 $ 1,512 (a) Includes accruals. (b) Unrealized gain on commodity derivative instruments (See Note 13 ). (c) Primarily related to the sale of certain conventional assets in Oklahoma (See Note 5 ). (d) Primarily related to unproved property impairments associated with certain non-core properties within our International E&P segment (See Note 11 ). (e) Primarily related to proved property impairments associated with certain non-core properties within our International E&P segment (See Note 11 ). (f) Includes a gain of $46 million resulting from the termination of our forward starting interest rate swaps (See Note 13 ). (g) Includes pension settlement loss of $25 million (See Note 18 ). (h) Primarily related to the make-whole call provisions paid upon redemption of our senior unsecured notes (See Note 15 ).

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2018
Income Tax Disclosure [Abstract]
Effective Income Tax Rate	For the three and nine months ended September 30, 2018 and 2017 , our effective income tax rates from continuing operations were as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Effective income tax expense (benefit) rate from continuing operations * 29 % 31 % 31 % 37 % * In all periods presented, we maintained our valuation allowance on our net federal deferred tax assets in the U.S.

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Sep. 30, 2018
Inventory Disclosure [Abstract]
Schedule of Inventory, Current	September 30, December 31, (In millions) 2018 2017 Crude oil and natural gas $ 11 $ 9 Supplies and other items 99 117 Inventories $ 110 $ 126

Property, Plant and Equipment_2

Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization (Tables)	9 Months Ended
	Sep. 30, 2018
Property, Plant and Equipment [Abstract]
Schedule of Property, Plant and Equipment	September 30, December 31, (In millions) 2018 2017 United States E&P $ 16,011 $ 15,867 International E&P 805 1,710 Corporate 83 88 Net property, plant and equipment $ 16,899 $ 17,665

Impairments (Tables)

Impairments (Tables)	9 Months Ended
	Sep. 30, 2018
Impairment Expense [Abstract]
Fair Value Measurements, Nonrecurring	The following table summarizes impairment charges of proved properties from continuing operations. Additionally, it presents the values of assets, by major category, measured at fair value on a nonrecurring basis in periods subsequent to their initial recognition. Three Months Ended September 30, 2018 2017 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets $ 39 $ 8 $ 169 $ 201 Nine Months Ended September 30, 2018 2017 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets $ 108 $ 50 $ 169 $ 205
Exploration Expenses	The following table summarizes impairment charges of unproved properties included as a component of exploration expenses: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2018 2017 2018 2017 Exploration Expenses Unproved property impairments $ 50 $ 172 $ 131 $ 217 Dry well costs 1 77 13 77 Geological and geophysical (1 ) 2 13 3 Other 6 43 16 55 Total exploration expenses $ 56 $ 294 $ 173 $ 352

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2018
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Changes in Asset Retirement Obligations	Asset retirement obligations primarily consist of estimated costs to remove, dismantle and restore land or seabed at the end of oil and gas production operations. Changes in asset retirement obligations for the nine months ended were as follows: September 30, September 30, (In millions) 2018 2017 Beginning balance as of January 1, 2018 and 2017 $ 1,483 $ 1,653 Incurred liabilities, including acquisitions 10 19 Settled liabilities, including dispositions (105 ) (40 ) Accretion expense (included in depreciation, depletion and amortization) 53 65 Revisions of estimates (130 ) (113 ) Held for sale (10 ) (2 ) Ending balance $ 1,301 $ 1,582

Derivatives (Tables)

Derivatives (Tables)	9 Months Ended
	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments in the Consolidated Balance Sheets	The following tables present the gross fair values of derivative instruments and the reported net amounts along with where they appear on the consolidated balance sheets. September 30, 2018 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity — 196 $ (196 ) Other current liabilities Commodity — 14 $ (14 ) Deferred credits and other liabilities Total Not Designated as Hedges $ — $ 210 $ (210 ) December 31, 2017 (In millions) Asset Liability Net Asset (Liability) Balance Sheet Location Not Designated as Hedges Commodity $ — $ 138 $ (138 ) Other current liabilities Commodity — 2 (2 ) Deferred credits and other liabilities Total Not Designated as Hedges $ — $ 140 $ (140 )
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss)	The following table sets forth the net impact of the terminated forward starting interest rate swap derivatives de-designated as cash flow hedges on other comprehensive income (loss). Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2018 2017 2018 2017 Interest Rate Swaps Beginning balance $ — $ 46 $ — $ 60 Change in fair value recognized in other comprehensive income — — — (13 ) Reclassification from other comprehensive income — (46 ) — (47 ) Ending balance $ — $ — $ — $ —
Schedule of Notional Amounts of Outstanding Derivative Positions	The following table sets forth outstanding derivative contracts as of September 30, 2018 and the weighted average prices for those contracts: Crude Oil 4Q 2018 FY 2019 FY 2020 Three-Way Collars Volume (Bbls/day) 95,000 60,000 — Weighted average price per Bbl: Ceiling $57.65 $73.18 — Floor $52.11 $56.67 — Sold put $45.21 $49.59 — Basis Swaps (a) Volume (Bbls/day) 10,000 10,000 15,000 Weighted average price per Bbl $(0.67) $(0.82) $(0.94) NYMEX Roll Basis Swaps Volume (Bbls/day) — 60,000 — Weighted average price per Bbl — $0.38 — Natural Gas Three-Way Collars (b) Volume (MMBtu/day) 160,000 — — Weighted average price per MMBtu: Ceiling $3.61 — — Floor $3.00 — — Sold put $2.50 — — (a) The basis differential price is between WTI Midland and WTI Cushing. (b) Subsequent to September 30, 2018, we entered into 100,000 MMBTU/day of three-way collars for January - March 2019 with a ceiling price of $3.75 , a floor price of $3.00 , and a sold put price of $2.50 .

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2018 and December 31, 2017 by fair value hierarchy level. September 30, 2018 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ 19 $ — $ — $ 19 Derivative instruments, assets $ 19 $ — $ — $ 19 Derivative instruments, liabilities Commodity (a) $ — $ (229 ) $ — $ (229 ) Derivative instruments, liabilities $ — $ (229 ) $ — $ (229 ) (a) Derivative instruments are recorded on a net basis in our consolidated balance sheet. See Note 13 . December 31, 2017 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Derivative instruments, assets $ — $ — $ — $ — Derivative instruments, liabilities Commodity (a) $ (20 ) $ (120 ) $ — $ (140 ) Derivative instruments, liabilities $ (20 ) $ (120 ) $ — $ (140 ) (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 September 30, 2018 and December 31, 2017 . September 30, 2018 December 31, 2017 Fair Carrying Fair Carrying (In millions) Value Amount Value Amount Financial assets Current assets (a) $ 15 $ 15 $ 762 $ 761 Other noncurrent assets 82 86 135 137 Total financial assets $ 97 $ 101 $ 897 $ 898 Financial liabilities Other current liabilities $ 32 $ 46 $ 32 $ 43 Long-term debt, including current portion (b) 5,777 5,528 5,976 5,526 Deferred credits and other liabilities 97 92 110 103 Total financial liabilities $ 5,906 $ 5,666 $ 6,118 $ 5,672 (a) December 31, 2017 fair value and carrying amounts included our two notes receivable relating to the sale of our Canadian business; both were paid during the first quarter of 2018, see Note 5 for further information. (b) Excludes capital leases and debt issuance costs.

Incentive Based Compensation (T

Incentive Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Stock Options, Restricted Stock Awards and Restricted Stock Units Activity	The following table presents a summary of activity for the first nine months of 2018 : Stock Options Restricted Stock Awards & Units Number of Shares Weighted Average Exercise Price Awards Weighted Average Grant Date Fair Value Outstanding at December 31, 2017 10,330,776 $25.52 7,572,845 $14.24 Granted 856,890 (a) $14.52 4,741,961 $14.72 Options Exercised/Stock Vested (1,756,797 ) $13.69 (2,783,504 ) $15.84 Canceled (1,783,223 ) $30.27 (756,491 ) $14.03 Outstanding at September 30, 2018 7,647,646 $25.89 8,774,811 $14.01 (a) The weighted average grant date fair value of stock option awards granted was $5.82 per share.

Defined Benefit Postretiremen_2

Defined Benefit Postretirement Plans (Tables)	9 Months Ended
	Sep. 30, 2018
Retirement Benefits [Abstract]
Schedule of Net Periodic Benefit Cost	The following summarizes the components of net periodic benefit cost: Three Months Ended September 30, Pension Benefits Other Benefits (In millions) 2018 2017 2018 2017 Service cost $ 4 $ 5 $ — $ — Interest cost 7 7 2 2 Expected return on plan assets (9 ) (10 ) — — Amortization: – prior service cost (credit) (2 ) (3 ) (2 ) (2 ) – actuarial loss 3 3 — — Net settlement loss (a) 10 8 — — Net periodic benefit cost $ 13 $ 10 $ — $ — Nine Months Ended September 30, Pension Benefits Other Benefits (In millions) 2018 2017 2018 2017 Service cost $ 13 $ 16 $ 1 $ 1 Interest cost 20 22 6 6 Expected return on plan assets (26 ) (32 ) — — Amortization: – prior service cost (credit) (7 ) (7 ) (6 ) (5 ) – actuarial loss 9 7 1 — Net settlement loss (a) 16 25 — — Net periodic benefit cost $ 25 $ 31 $ 2 $ 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.

Reclassifications Out of Accu_2

Reclassifications Out of Accumulated Other Comprehensive Income (Loss) (Tables)	9 Months Ended
	Sep. 30, 2018
Equity [Abstract]
Schedule of Amounts Reclassified out of Accumulated Other Comprehensive Income (Loss)	The following table presents a summary of amounts reclassified from accumulated other comprehensive income (loss): Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2018 2017 2018 2017 Income Statement Line Postretirement and postemployment plans Amortization of prior service credit $ 4 $ 5 $ 13 $ 12 Other net periodic benefit costs Amortization of actuarial loss (3 ) (3 ) (10 ) (7 ) Other net periodic benefit costs Net settlement loss (10 ) (8 ) (16 ) (25 ) Other net periodic benefit costs Derivative hedges Recognized gain on terminated derivative hedge — 46 — 46 Net interest and other Ineffective portion of derivative hedge — — — 1 Net interest and other (9 ) 40 (13 ) 27 Income (loss) from continuing operations before income taxes — (40 ) — (40 ) (Provision) benefit for income taxes Total reclassifications to expense, net of tax (9 ) — (13 ) (13 ) Income (loss) from continuing operations Foreign currency hedges Net recognized loss in discontinued operations, net of tax — — — (30 ) Income (loss) from discontinued operations Total reclassifications to expense $ (9 ) $ — $ (13 ) $ (43 ) Net income (loss)

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2018
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Nine Months Ended September 30, (In millions) 2018 2017 Net cash used in operating activities: Interest paid, net of amounts capitalized $ (187 ) $ (269 ) Income taxes paid to taxing authorities (298 ) (101 ) Noncash investing activities, related to continuing operations: Increase (decrease) in asset retirement costs $ 12 $ (94 ) Asset retirement obligations assumed by buyer 82 14 Notes receivable for disposal of assets — 745

Equity Method Investments (Tabl

Equity Method Investments (Tables)	9 Months Ended
	Sep. 30, 2018
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 September 30, December 31, (In millions) September 30, 2018 2018 2017 EGHoldings 60% $ 402 $ 456 Alba Plant LLC 52% 170 214 AMPCO 45% 185 177 Total $ 757 $ 847 Summarized financial information for equity method investees is as follows: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2018 2017 2018 2017 Income data: Revenues and other income $ 238 $ 243 $ 664 $ 681 Income from operations 151 147 391 412 Net income 129 125 331 360

Accounting Standards - Revenue

Accounting Standards - Revenue Recognition Standard (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenues and other income:
Revenues from contracts with customers	$ 1,538	$ 1,136	$ 4,522	$ 2,911
Marketing revenues		48		117
Other income	119	8	135	31
Costs and expenses:
Marketing, including purchases from related parties		49		121
Shipping, handling and other operating	152	$ 109	408	$ 309
Presentation without adoption of ASC Topic 606
Revenues and other income:
Revenues from contracts with customers	1,536		4,518
Marketing revenues	47		122
Other income	118		132
Costs and expenses:
Marketing, including purchases from related parties	46		122
Shipping, handling and other operating	150		401
Accounting Standards Update 2014-09 | Adjustments
Revenues and other income:
Revenues from contracts with customers	(2)		(4)
Marketing revenues	47		122
Other income	(1)		(3)
Costs and expenses:
Marketing, including purchases from related parties	46		122
Shipping, handling and other operating	$ (2)		$ (7)

Accounting Standards - Pension

Accounting Standards - Pension Accounting Standard (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Production	$ 215	$ 197	$ 637	$ 528
Exploration	56	294	173	352
General and administrative	101	89	306	276
Income (loss) from operations	423	(372)	1,200	(325)
Other net periodic benefit costs	$ 8	5	$ 11	16
Previously Reported
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Production		194		521
Exploration		294		352
General and administrative		97		299
Income (loss) from operations		(377)		(341)
Other net periodic benefit costs		0		0
Accounting Standards Update 2017-07 | Effect of Change Higher/(Lower)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Production		3		7
Exploration		0		0
General and administrative		(8)		(23)
Income (loss) from operations		5		16
Other net periodic benefit costs		$ 5		$ 16

Income (Loss) and Dividends p_3

Income (Loss) and Dividends per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Earnings Per Share [Abstract]
Antidilutive securities excluded from computation of earnings per share (in shares)	5	10	6	11
Income (loss) from continuing operations	$ 254	$ (599)	$ 706	$ (802)
Income (loss) from discontinued operations	0	0	0	(4,893)
Net income (loss)	$ 254	$ (599)	$ 706	$ (5,695)
Weighted average common shares outstanding (in shares)	848	850	852	850
Effect of dilutive securities (in shares)	1	0	1	0
Weighted average common shares, diluted (in shares)	849	850	853	850
Per basic share:
Income (loss) from continuing operations (in dollars per share)	$ 0.30	$ (0.70)	$ 0.83	$ (0.94)
Income (loss) from discontinued operations (in dollars per share)	0	0	0	(5.76)
Net income (loss) (in dollars per share)	0.30	(0.70)	0.83	(6.70)
Per diluted share:
Income (loss) from continuing operations (in dollars per share)	0.30	(0.70)	0.83	(0.94)
Income (loss) from discontinued operations (in dollars per share)	0	0	0	(5.76)
Net income (loss) (in dollars per share)	0.30	(0.70)	0.83	(6.70)
Dividends per share (in dollars per share)	$ 0.05	$ 0.05	$ 0.15	$ 0.15

Acquisitions (Details)

Acquisitions (Details) a in Thousands, $ in Millions	3 Months Ended	9 Months Ended
	Jun. 30, 2017USD ($)aacquisition	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)
Business Acquisition [Line Items]
Number of acquisitions | acquisition	2
Payments to acquire businesses		$ 25	$ 1,828
Permian Basin
Business Acquisition [Line Items]
Gas and oil acres acquired (in acres) | a	91
Permian Basin | BC Operating, Inc
Business Acquisition [Line Items]
Payments to acquire businesses	$ 1,100
Permian Basin | Black Mountain Oil & Gas
Business Acquisition [Line Items]
Payments to acquire businesses	$ 700

Dispositions - United States E&

Dispositions - United States E&P Segment (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 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			$ 1,249	$ 1,757
United States E&P | Gulf of Mexico - non-core properties | 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	$ 16
Net gain (loss) on disposal of assets	$ 32
United States E&P | Conventional Assets in Oklahoma | 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		$ 25
Net gain (loss) on disposal of assets		$ 21

Dispositions - International E&

Dispositions - International E&P Segment (Details) - USD ($) $ in Millions	3 Months Ended				9 Months Ended
	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 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					$ 1,249	$ 1,757
International E&P | Non-Core Property, Second Quarter 2018 Agreement | Disposal Group, Held-for-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		$ 56
Disposal group, assets	$ 73				73
Disposal group, liabilities	13				$ 13
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
Ownership percentage by parent			16.33%
Net gain (loss) on disposal of assets			$ 255
International E&P | Non-Core Property, Third Quarter 2017 Agreement | 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				$ 53
Net gain (loss) on disposal of assets	$ (18)

Dispositions - Canadian Busines

Dispositions - Canadian Business - Discontinued Operations (Details) $ in Millions	May 31, 2017USD ($)notes_receivable	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2017USD ($)	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Dec. 31, 2017notes_receivable
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						$ 1,249	$ 1,757
Impairments		$ 8	$ 201			50	205
Net loss on disposal of assets		(16)	(19)			(323)	(26)
Canadian Business
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairments					$ 6,600
Impairments, net of tax					$ 4,960
Canadian Business | Discontinued Operations, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration received on disposition	$ 2,500
Proceeds from sale of oil and gas property and equipment	$ 1,800
Number of notes receivable | notes_receivable	2							2
Impairments		0	0			0	6,636
Net loss on disposal of assets		$ 0	$ 0	$ 43		$ 0	$ 43
Variable Interest Entity, Not Primary Beneficiary | Canadian Business | Discontinued Operations, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Variable interest entity, ownership percentage	20.00%
Notes Receivable [Member] | Canadian Business | Discontinued Operations, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Notes receivable	$ 750

Dispositions - Consolidated Sta

Dispositions - Consolidated Statements of Income and Consolidated Statements of Cash Flows (Details) - USD ($) $ in Millions	3 Months Ended				9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Sep. 30, 2018	Sep. 30, 2017
Consolidated Statements of Income [Abstract]
Net gain (loss) on disposal of assets	$ 16	$ 19			$ 323	$ 26
Costs and expenses:
Impairments	8	201			50	205
Income (loss) from discontinued operations					0	(4,893)
Cash flow from discontinued operations:
Net increase in cash and cash equivalents of discontinued operations					0	130
Canadian Business
Costs and expenses:
Impairments				$ 6,600
Discontinued Operations, Disposed of by Sale | Canadian Business
Consolidated Statements of Income [Abstract]
Total revenue and other income	0	0			0	431
Net gain (loss) on disposal of assets	0	0	$ (43)		0	(43)
Total revenues and other income	0	0			0	388
Costs and expenses:
Production	0	0			0	254
Depreciation, depletion and amortization	0	0			0	40
Impairments	0	0			0	6,636
Other	0	0			0	25
Total costs and expenses	0	0			0	6,955
Pretax income (loss) from discontinued operations	0	0			0	(6,567)
Provision (benefit) for income taxes	0	0			0	(1,674)
Income (loss) from discontinued operations	$ 0	$ 0			0	(4,893)
Cash flow from discontinued operations:
Operating activities					0	141
Investing activities					0	(13)
Changes in cash included in current assets held for sale					0	2
Net increase in cash and cash equivalents of discontinued operations					$ 0	$ 130

Revenues - Revenues from Contra

Revenues - Revenues from Contracts with Customers by Product Type and Geographic Areas (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 1,538	$ 1,136	$ 4,522	$ 2,911
United States E&P
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,347		3,693
United States E&P | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	542		1,458
United States E&P | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	475		1,260
United States E&P | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	208		597
United States E&P | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	77		210
United States E&P | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	45		168
United States E&P | Crude oil and condensate
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,090		3,022
United States E&P | Crude oil and condensate | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	436		1,196
United States E&P | Crude oil and condensate | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	447		1,182
United States E&P | Crude oil and condensate | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	114		340
United States E&P | Crude oil and condensate | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	59		173
United States E&P | Crude oil and condensate | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	34		131
United States E&P | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	152		370
United States E&P | Natural gas liquids | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	70		157
United States E&P | Natural gas liquids | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	19		51
United States E&P | Natural gas liquids | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	48		130
United States E&P | Natural gas liquids | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	12		24
United States E&P | Natural gas liquids | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3		8
United States E&P | Natural gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	102		286
United States E&P | Natural gas | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	36		102
United States E&P | Natural gas | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	9		27
United States E&P | Natural gas | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	46		127
United States E&P | Natural gas | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6		13
United States E&P | Natural gas | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5		17
United States E&P | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3		15
United States E&P | Other | Eagle Ford
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0		3
United States E&P | Other | Bakken
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0		0
United States E&P | Other | Oklahoma
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0		0
United States E&P | Other | Northern Delaware
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0		0
United States E&P | Other | Other U.S.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3		12
International E&P
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	191		829
International E&P | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	110		302
International E&P | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	61		266
International E&P | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0		196
International E&P | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	20		65
International E&P | Crude oil and condensate
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	161		730
International E&P | Crude oil and condensate | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	100		271
International E&P | Crude oil and condensate | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	41		207
International E&P | Crude oil and condensate | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0		187
International E&P | Crude oil and condensate | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	20		65
International E&P | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2		7
International E&P | Natural gas liquids | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1		3
International E&P | Natural gas liquids | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1		4
International E&P | Natural gas liquids | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0		0
International E&P | Natural gas liquids | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0		0
International E&P | Natural gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	20		68
International E&P | Natural gas | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	9		28
International E&P | Natural gas | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	11		31
International E&P | Natural gas | Libya
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0		9
International E&P | Natural gas | Other International
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0		0
International E&P | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8		24
International E&P | Other | E.G.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0		0
International E&P | Other | U.K.
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8		24
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	$ 0		$ 0

Revenues - Contract Receivables

Revenues - Contract Receivables and Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Revenue from Contract with Customer [Abstract]
Receivables from contracts with customers, which are included in receivables, less reserves	$ 937	$ 811
Contract asset (liability)	$ (1)	$ 0

Revenues - Significant Changes

Revenues - Significant Changes in the Contract Liability Balance (Details) $ in Millions	9 Months Ended
	Sep. 30, 2018USD ($)
Change In Contract With Customer, Liability [Roll Forward]
Contract asset (liability) balance, beginning	$ 0
Revenue recognized as performance obligations are satisfied	85
Amounts invoiced to customers	(86)
Contract asset (liability) balance, ending	$ (1)

Segment Information (Details)

Segment Information (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)segment	Sep. 30, 2017USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segment			2
Revenues from contracts with customers	$ 1,538	$ 1,136	$ 4,522	$ 2,911
Net gain (loss) on commodity derivatives	(70)	(22)	(324)	115
Marketing revenues		48		117
Income from equity method investments	64	63	161	183
Net gain (loss) on disposal of assets	16	19	323	26
Other income	119	8	135	31
Less costs and expenses:
Production	215	197	637	528
Marketing costs		49		121
Shipping, handling and other operating	152	109	408	309
Exploration	56	294	173	352
Depreciation, depletion and amortization	626	641	1,828	1,789
Impairments	8	201	50	205
Taxes other than income	86	44	215	128
General and administrative	101	89	306	276
Net interest and other	58	35	168	199
Other net periodic benefit costs	8	5	11	16
Loss on early extinguishment of debt	0	46	0	46
Income tax provision (benefit)	103	141	315	216
Income (loss) from continuing operations	254	(599)	706	(802)
Capital expenditures	704	554	1,988	1,512
Reclassification of gains on terminated derivative hedges	0	46	0	47
Pension Plan
Less costs and expenses:
Other net periodic benefit costs	10	8	16	25
Not Allocated to Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	0	0	0	0
Net gain (loss) on commodity derivatives	19	(56)	(69)	64
Marketing revenues		0		0
Income from equity method investments	0	0	0	0
Net gain (loss) on disposal of assets	16	18	323	24
Other income	113	5	121	8
Less costs and expenses:
Production	0	0	(1)	0
Marketing costs		0		0
Shipping, handling and other operating	0	(2)	(1)	0
Exploration	0	250	0	250
Depreciation, depletion and amortization	6	8	20	25
Impairments	8	201	50	201
Taxes other than income	0	0	(3)	12
General and administrative	57	54	173	163
Net interest and other	58	35	168	199
Other net periodic benefit costs	11	5	18	20
Loss on early extinguishment of debt		46		46
Income tax provision (benefit)	71	35	84	14
Income (loss) from continuing operations	(63)	(665)	(133)	(834)
Capital expenditures	7	9	17	20
United States E&P
Segment Reporting Information [Line Items]
Revenues from contracts with customers	1,347		3,693
United States E&P | Operating Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	1,347	772	3,693	2,124
Net gain (loss) on commodity derivatives	(89)	34	(255)	51
Marketing revenues		12		25
Income from equity method investments	0	0	0	0
Net gain (loss) on disposal of assets	0	1	0	2
Other income	2	3	7	9
Less costs and expenses:
Production	172	121	476	348
Marketing costs		14		30
Shipping, handling and other operating	136	80	364	250
Exploration	55	41	170	97
Depreciation, depletion and amortization	571	531	1,655	1,498
Impairments	0	0	0	4
Taxes other than income	86	44	218	116
General and administrative	37	29	108	92
Net interest and other	0	0	0	0
Other net periodic benefit costs	0	0	0	0
Loss on early extinguishment of debt		0		0
Income tax provision (benefit)	2	0	5	0
Income (loss) from continuing operations	201	(38)	449	(224)
Capital expenditures	691	541	1,943	1,465
Int'l E&P
Segment Reporting Information [Line Items]
Revenues from contracts with customers	191		829
Int'l E&P | Operating Segments
Segment Reporting Information [Line Items]
Revenues from contracts with customers	191	364	829	787
Net gain (loss) on commodity derivatives	0	0	0	0
Marketing revenues		36		92
Income from equity method investments	64	63	161	183
Net gain (loss) on disposal of assets	0	0	0	0
Other income	4	0	7	14
Less costs and expenses:
Production	43	76	162	180
Marketing costs		35		91
Shipping, handling and other operating	16	31	45	59
Exploration	1	3	3	5
Depreciation, depletion and amortization	49	102	153	266
Impairments	0	0	0	0
Taxes other than income	0	0	0	0
General and administrative	7	6	25	21
Net interest and other	0	0	0	0
Other net periodic benefit costs	(3)	0	(7)	(4)
Loss on early extinguishment of debt		0		0
Income tax provision (benefit)	30	106	226	202
Income (loss) from continuing operations	116	104	390	256
Capital expenditures	$ 6	4	$ 28	27
Interest Rate Swaps
Less costs and expenses:
Reclassification of gains on terminated derivative hedges		$ 46		$ 46

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Income Tax Contingency [Line Items]
Effective income tax expense (benefit) rate from continuing operations	29.00%	31.00%	31.00%	37.00%
Deferred tax expense from reduction in estimated costs for U.K. asset retirement obligation	$ 76		$ 76
Income tax provision (benefit)	103	$ 141	$ 315	$ 216
Effective income tax rate excluding Libya			17.00%	5.00%
Income tax receivable related to refundable AMT credits	$ 136		$ 136
Foreign Tax Authority | Libya Tax Authority
Income Tax Contingency [Line Items]
Income tax provision (benefit)		102	$ 162	$ 179
Domestic Tax Authority
Income Tax Contingency [Line Items]
Tax benefit from settlement with taxing authority		$ 13		$ 13

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Inventory Disclosure [Abstract]
Crude oil and natural gas	$ 11	$ 9
Supplies and other items	99	117
Inventories	$ 110	$ 126

Property, Plant and Equipment_3

Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 16,899	$ 17,665
Exploratory well costs capitalized greater than one year after completion of drilling	32	32
Operating Segments | United States E&P
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	16,011	15,867
Operating Segments | International E&P
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	805	1,710
Corporate
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 83	$ 88

Impairments - Fair Value Measur

Impairments - Fair Value Measurements, Nonrecurring (Details) - Nonrecurring - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets held-for-sale, Fair Value	$ 39		$ 39
Long-lived assets, Fair Value	108	$ 169	108	$ 169
Long-lived assets, Impairment	$ 8	$ 201	$ 50	$ 205

Impairments - Narrative (Detail

Impairments - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairments	$ 8	$ 201	$ 50	$ 205
Exploration	56	294	173	352
Nonrecurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-lived assets, Impairment	8	201	50	205
Long-lived assets, fair value	108	169	108	169
Gulf of Mexico - non-core properties | Nonrecurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairments				65
International E&P | Nonrecurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairments				136
Unproved property impairments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Exploration	50	172	131	217
Dry well costs
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Exploration	$ 1	$ 77	$ 13	77
Diaba
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Exploration				159
Diaba | Unproved property impairments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Exploration				95
Diaba | Dry well costs
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Exploration				64
Tchicuate | Unproved property impairments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Exploration				$ 43

Impairments - Exploration Expen

Impairments - Exploration Expenses (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Exploration Expenses [Line Items]
Total exploration expenses	$ 56	$ 294	$ 173	$ 352
Unproved property impairments
Exploration Expenses [Line Items]
Total exploration expenses	50	172	131	217
Dry well costs
Exploration Expenses [Line Items]
Total exploration expenses	1	77	13	77
Geological and geophysical
Exploration Expenses [Line Items]
Total exploration expenses	(1)	2	13	3
Other
Exploration Expenses [Line Items]
Total exploration expenses	$ 6	$ 43	$ 16	$ 55

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation, beginning balance	$ 1,483	$ 1,653
Incurred liabilities, including acquisitions	10	19
Settled liabilities, including dispositions	(105)	(40)
Accretion expense (included in depreciation, depletion and amortization)	53	65
Revisions of estimates	(130)	(113)
Held for sale	(10)	(2)
Asset retirement obligation, ending balance	1,301	1,582
Asset retirement obligation, current	$ 58	$ 60

Derivatives - Schedule of Deriv

Derivatives - Schedule of Derivative Instruments in the Consolidated Balance Sheets (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Asset	$ 0	$ 0
Liability	210	140
Net Asset (Liability)	(210)	(140)
Commodity | Other current liabilities | Not Designated as Hedges
Derivatives, Fair Value [Line Items]
Asset	0	0
Liability	196	138
Net Asset (Liability)	(196)	(138)
Commodity | Deferred credits and other liabilities | Not Designated as Hedges
Derivatives, Fair Value [Line Items]
Asset	0	0
Liability	14	2
Net Asset (Liability)	$ (14)	$ (2)

Derivatives - Narrative (Detail

Derivatives - Narrative (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Derivative Instruments, Gain (Loss) [Line Items]
Reclassification of gains on terminated derivative hedges	$ 0	$ 46,000,000	$ 0	$ 47,000,000
Net gain (loss) on commodity derivatives	(70,000,000)	(22,000,000)	(324,000,000)	115,000,000
Not Allocated to Segments
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on commodity derivatives	19,000,000	(56,000,000)	(69,000,000)	64,000,000
United States E&P | Operating Segments
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on commodity derivatives	(89,000,000)	34,000,000	(255,000,000)	51,000,000
Unsecured Debt
Derivative Instruments, Gain (Loss) [Line Items]
Debt instrument, face amount		1,000,000,000		1,000,000,000
Interest Rate Swaps
Derivative Instruments, Gain (Loss) [Line Items]
Cash proceeds received from derivatives		54,000,000
Reclassification of gains on terminated derivative hedges		46,000,000		46,000,000
Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on commodity derivatives	19,000,000	(56,000,000)	(69,000,000)	64,000,000
Net gain (loss) on settlements, net	$ (89,000,000)	$ 34,000,000	$ (255,000,000)	$ 51,000,000

Derivatives - Terminated Forwar

Derivatives - Terminated Forward Starting Interest Rate Swap Derivatives (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Cash Flow Hedges Derivative Instruments at Fair Value, Net [Roll Forward]
Reclassification from other comprehensive income	$ 0	$ (46)	$ 0	$ (47)
Interest Rate Swaps
Cash Flow Hedges Derivative Instruments at Fair Value, Net [Roll Forward]
Reclassification from other comprehensive income		(46)		(46)
Interest Rate Swaps | Not Designated as Hedges
Cash Flow Hedges Derivative Instruments at Fair Value, Net [Roll Forward]
Beginning balance	0	46	0	60
Change in fair value recognized in other comprehensive income	0	0	0	(13)
Reclassification from other comprehensive income	0	(46)	0	(47)
Ending balance	$ 0	$ 0	$ 0	$ 0

Derivatives - Outstanding Deriv

Derivatives - Outstanding Derivative Contracts (Details) - Not Designated as Hedges MMBTU in Thousands, Bbls_per_day in Thousands, BBL / Days in Thousands	Nov. 08, 2018MMBTU$ / MMBTU	Sep. 30, 2018MMBTUBBL / DaysBbls_per_day$ / MMBTU$ / bbl
Crude Oil, Three-Way Collars, 4Q 2018
Derivative [Line Items]
Volume | BBL / Days		95
Ceiling (in dollars per Bbl)		57.65
Floor (in dollars per Bbl)		52.11
Sold put (in dollars per Bbl)		45.21
Crude Oil, Three-Way Collars, FY 2019
Derivative [Line Items]
Volume | BBL / Days		60
Ceiling (in dollars per Bbl)		73.18
Floor (in dollars per Bbl)		56.67
Sold put (in dollars per Bbl)		49.59
Crude Oil, Basis Swaps, 4Q 2018
Derivative [Line Items]
Volume | Bbls_per_day		10
Weighted average price per Bbl (in dollars per Bbl)		(0.67)
Crude Oil, Basis Swaps, FY 2019
Derivative [Line Items]
Volume | Bbls_per_day		10
Weighted average price per Bbl (in dollars per Bbl)		(0.82)
Crude Oil, Basis Swaps, FY 2020
Derivative [Line Items]
Volume | Bbls_per_day		15
Weighted average price per Bbl (in dollars per Bbl)		(0.94)
Crude Oil, NYMEX Roll Basis Swaps, FY 2019
Derivative [Line Items]
Volume | Bbls_per_day		60
Weighted average price per Bbl (in dollars per Bbl)		0.38
Natural Gas, Three-Way Collars, 4Q 2018
Derivative [Line Items]
Volume | MMBTU		160
Ceiling (in dollars per Bbl) | $ / MMBTU		3.61
Floor (in dollars per Bbl) | $ / MMBTU		3
Sold put (in dollars per Bbl) | $ / MMBTU		2.50
Natural Gas, Three-Way Collars, 1Q 2019 | Subsequent Event
Derivative [Line Items]
Volume | MMBTU	100
Ceiling (in dollars per Bbl) | $ / MMBTU	3.75
Floor (in dollars per Bbl) | $ / MMBTU	3
Sold put (in dollars per Bbl) | $ / MMBTU	2.50

Fair Value Measurements - Fair

Fair Value Measurements - Fair Values - Recurring (Details) - Recurring - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	$ 19	$ 0
Derivative instruments, liabilities	(229)	(140)
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	19
Derivative instruments, liabilities	(229)	(140)
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	19	0
Derivative instruments, liabilities	0	(20)
Level 1 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	19
Derivative instruments, liabilities	0	(20)
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	0	0
Derivative instruments, liabilities	(229)	(120)
Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, assets	0
Derivative instruments, liabilities	(229)	(120)
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
Derivative instruments, liabilities	$ 0	$ 0

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Goodwill	$ 97	$ 115

Fair Value Measurements - Fai_2

Fair Value Measurements - Fair Values - Financial Instruments (Details) $ in Millions	Sep. 30, 2018USD ($)	Dec. 31, 2017USD ($)notes_receivable	May 31, 2017notes_receivable
Canadian Business | Discontinued Operations, Disposed of by Sale
Financial liabilities
Number of notes receivable | notes_receivable		2	2
Fair Value
Financial assets
Current assets	$ 15	$ 762
Other noncurrent assets	82	135
Total financial assets	97	897
Financial liabilities
Other current liabilities	32	32
Long-term debt, including current portion	5,777	5,976
Deferred credits and other liabilities	97	110
Total financial liabilities	5,906	6,118
Carrying Amount
Financial assets
Current assets	15	761
Other noncurrent assets	86	137
Total financial assets	101	898
Financial liabilities
Other current liabilities	46	43
Long-term debt, including current portion	5,528	5,526
Deferred credits and other liabilities	92	103
Total financial liabilities	$ 5,666	$ 5,672

Debt - Revolving Credit Facilit

Debt - Revolving Credit Facility (Details)	9 Months Ended
	Sep. 30, 2018USD ($)extension
Revolving Credit Facility
Line of Credit Facility [Line Items]
Line of credit	$ 0
Maximum borrowing capacity	$ 3,400,000,000
Number of one year extensions | extension	2
Extension term	1 year
Increase commitment amount (up to)	$ 107,000,000
Covenant, ratio of indebtedness to net capital, maximum	0.65
Ratio of indebtedness to net capital	0.31
Swing-line loans
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 100,000,000
Letter of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 500,000,000

Debt - Long-Term Debt (Details)

Debt - Long-Term Debt (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Debt Instrument [Line Items]
Long-term debt	$ 5,498,000,000		$ 5,498,000,000		$ 5,494,000,000
Long-term debt maturing in 2020	600,000,000		600,000,000
Repayments of long-term debt			0	$ 1,764,000,000
Gain (loss) on early extinguishment of debt	0	$ (46,000,000)	0	(46,000,000)
Reclassification of gains on terminated derivative hedges	0	46,000,000	0	47,000,000
Interest Rate Swaps
Debt Instrument [Line Items]
Cash proceeds received from derivatives		54,000,000
Reclassification of gains on terminated derivative hedges		46,000,000		46,000,000
Interest Rate Swaps | Not Designated as Hedges
Debt Instrument [Line Items]
Cash proceeds received from derivatives		54,000,000
Reclassification of gains on terminated derivative hedges	$ 0	46,000,000	$ 0	47,000,000
Unsecured Debt
Debt Instrument [Line Items]
Debt instrument, face amount		1,000,000,000		1,000,000,000
Repayments of long-term debt		1,760,000,000
Unsecured Debt | Notes Due in 2027
Debt Instrument [Line Items]
Debt instrument, face amount		$ 1,000,000,000		$ 1,000,000,000
Interest rate, stated percentage		4.40%		4.40%
Proceeds from issuance of debt		$ 990,000,000
Unsecured Debt | Notes Due in 2017
Debt Instrument [Line Items]
Interest rate, stated percentage		6.00%		6.00%
Repayments of long-term debt		$ 682,000,000
Unsecured Debt | Notes Due in 2018
Debt Instrument [Line Items]
Interest rate, stated percentage		5.90%		5.90%
Repayments of long-term debt		$ 854,000,000
Unsecured Debt | Notes Due in 2019
Debt Instrument [Line Items]
Interest rate, stated percentage		7.50%		7.50%
Repayments of long-term debt		$ 228,000,000

Stockholders' Equity (Details)

Stockholders' Equity (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2018	Sep. 30, 2017
Equity, Class of Treasury Stock [Line Items]
Shares repurchased		$ 349	$ 9
Share Repurchase Program
Equity, Class of Treasury Stock [Line Items]
Shares repurchased (in shares)	16
Shares repurchased	$ 338
Stock repurchase program, remaining authorized repurchase amount	$ 1,200	$ 1,200

Incentive Based Compensation -

Incentive Based Compensation - Stock Options, Restricted Stock Awards and Restricted Stock Units (Details)	9 Months Ended
	Sep. 30, 2018$ / sharesshares
Number of Shares
Outstanding, beginning (in shares) | shares	10,330,776
Granted (in shares) | shares	856,890
Options Exercised (in shares) | shares	(1,756,797)
Canceled (in shares) | shares	(1,783,223)
Outstanding, ending (in shares) | shares	7,647,646
Weighted Average Exercise Price
Outstanding, beginning (in dollars per share)	$ 25.52
Granted (in dollars per share)	14.52
Options Exercised (in dollars per share)	13.69
Canceled (in dollars per share)	30.27
Outstanding, ending (in dollars per share)	25.89
Weighted Average Grant Date Fair Value
Weighted average grant date fair value (in dollars per share)	$ 5.82
Restricted Stock Awards & Units
Awards
Outstanding, beginning (in shares) | shares	7,572,845
Granted (in shares) | shares	4,741,961
Stock Vested (in shares) | shares	(2,783,504)
Canceled (in shares) | shares	(756,491)
Outstanding, ending (in shares) | shares	8,774,811
Weighted Average Grant Date Fair Value
Outstanding, beginning (in dollars per share)	$ 14.24
Granted (in dollars per share)	14.72
Stock Vested (in dollars per share)	15.84
Canceled (in dollars per share)	14.03
Outstanding, ending (in dollars per share)	$ 14.01

Incentive Based Compensation _2

Incentive Based Compensation - Stock-based Performance Unit Awards (Details) - Performance Unit Awards	9 Months Ended
	Sep. 30, 2018$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares) | shares	754,140
Grant date fair value (in dollars per share) | $ / shares	$ 17.02

Defined Benefit Postretiremen_3

Defined Benefit Postretirement Plans (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Amortization:
Net settlement loss	$ 8	$ 5	$ 11	$ 16
Estimated future contributions over the remainder of 2018	6		6
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	5	13	16
Interest cost	7	7	20	22
Expected return on plan assets	(9)	(10)	(26)	(32)
Amortization:
prior service cost (credit)	(2)	(3)	(7)	(7)
actuarial loss	3	3	9	7
Net settlement loss	10	8	16	25
Net periodic benefit cost	13	10	25	31
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	0	1	1
Interest cost	2	2	6	6
Expected return on plan assets	0	0	0	0
Amortization:
prior service cost (credit)	(2)	(2)	(6)	(5)
actuarial loss	0	0	1	0
Net settlement loss	0	0	0	0
Net periodic benefit cost	$ 0	$ 0	2	$ 2
Payment for other postretirement benefit plans			17
Funded Plan
Amortization:
Payment for pension benefits			58
Unfunded Plan
Amortization:
Payment for pension benefits			$ 12

Reclassifications Out of Accu_3

Reclassifications Out of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other net periodic benefit costs	$ (8)	$ (5)	$ (11)	$ (16)
Net interest and other	(58)	(35)	(168)	(199)
Income (loss) from continuing operations before income taxes	357	(458)	1,021	(586)
(Provision) benefit for income taxes	(103)	(141)	(315)	(216)
Income (loss) from continuing operations	254	(599)	706	(802)
Income (loss) from discontinued operations	0	0	0	(4,893)
Net income (loss)	254	(599)	706	(5,695)
Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income (loss) from continuing operations before income taxes	(9)	40	(13)	27
(Provision) benefit for income taxes	0	(40)	0	(40)
Income (loss) from continuing operations	(9)	0	(13)	(13)
Net income (loss)	(9)	0	(13)	(43)
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	(4)	(5)	(13)	(12)
Amortization of actuarial loss | Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other net periodic benefit costs	(3)	(3)	(10)	(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	(10)	(8)	(16)	(25)
Recognized gain on terminated derivative hedge | Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net interest and other	0	46	0	46
Ineffective portion of derivative hedge | Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net interest and other	0	0	0	1
Foreign currency hedges | Reclassification out of Accumulated Other Comprehensive Income (Loss)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income (loss) from discontinued operations	$ 0	$ 0	$ 0	$ (30)

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Net cash used in operating activities:
Interest paid, net of amounts capitalized	$ (187)	$ (269)
Income taxes paid to taxing authorities	(298)	(101)
Noncash investing activities, related to continuing operations:
Increase (decrease) in asset retirement costs	12	(94)
Asset retirement obligations assumed by buyer	82	14
Notes receivable for disposal of assets	0	745
Capital expenditures incurred but not yet paid	$ 238	$ 361

Equity Method Investments (Deta

Equity Method Investments (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 757		$ 757		$ 847
Income data:
Revenues and other income	238	$ 243	664	$ 681
Income from operations	151	147	391	412
Net income	$ 129	$ 125	$ 331	$ 360
EGHoldings
Schedule of Equity Method Investments [Line Items]
Ownership percentage	60.00%		60.00%
Equity method investments	$ 402		$ 402		456
Alba Plant LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage	52.00%		52.00%
Equity method investments	$ 170		$ 170		214
AMPCO
Schedule of Equity Method Investments [Line Items]
Ownership percentage	45.00%		45.00%
Equity method investments	$ 185		$ 185		$ 177

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