Marathon Oil (MRO) 10-Q3 Nov 162016 Q3 Quarterly reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
Document and Entity Information - shares	Sep. 30, 2016	Oct. 31, 2016
Document and Entity Information [Abstract]
Document Type	10-Q
Document Period End Date	Sep. 30, 2016
Document Fiscal Period Focus	Q3
Document Fiscal Year Focus	2,016
Amendment Flag	false
Entity Registrant Name	Marathon Oil Corp
Entity Central Index Key	101,778
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Well Known Seasoned Issuer	Yes
Entity Common Stock Shares Outstanding		847,211,288

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Revenues and other income:
Sales and other operating revenues, including related party	$ 1,020	$ 1,300	$ 2,604	$ 3,887
Marketing revenues	80	84	227	471
Income from equity method investments	59	36	110	98
Net gain (loss) on disposal of assets	47	(109)	281	(108)
Other income	23	12	39	38
Total revenues and other income	1,229	1,323	3,261	4,386
Costs and expenses:
Production	295	406	973	1,300
Marketing, including purchases from related parties	80	84	226	471
Other operating	189	93	393	281
Exploration Expense	83	585	296	786
Depreciation, depletion and amortization	594	717	1,764	2,289
Impairments	47	337	48	381
Taxes other than income	39	46	126	191
General and administrative	105	125	388	464
Total costs and expenses	1,432	2,393	4,214	6,163
Income (loss) from operations	(203)	(1,070)	(953)	(1,777)
Net interest and other	(87)	(75)	(258)	(180)
Income (loss) before income taxes	(290)	(1,145)	(1,211)	(1,957)
Provision (benefit) for income taxes	(98)	(396)	(442)	(546)
Net income (loss)	$ (192)	$ (749)	$ (769)	$ (1,411)
Net income (loss) per share:
Net income (loss), per basic share	$ (0.23)	$ (1.11)	$ (0.95)	$ (2.09)
Net income (loss), per diluted share	(0.23)	(1.11)	(0.95)	(2.09)
Dividends paid, per share	$ 0.05	$ 0.21	$ 0.15	$ 0.63
Weighted average common shares outstanding, basic	847	677	809	677
Weighted average common shares outstanding, diluted	847	677	809	677

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ (192)	$ (749)	$ (769)	$ (1,411)
Postretirement and postemployment plans
Change in actuarial loss and other	0	(2)	(5)	160
Income tax benefit (provision) on postretirement and postemployment plans	0	(1)	2	(58)
Postretirement and postemployment plans, net of tax	0	(3)	(3)	102
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	3	0	1	0
Other comprehensive income (loss)	3	(3)	(2)	102
Comprehensive income (loss)	$ (189)	$ (752)	$ (771)	$ (1,309)

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 1,953	$ 1,221
Receivables, less reserve of $4 and $4	783	912
Inventories	221	313
Other current assets	85	144
Total current assets	3,042	2,590
Equity method investments	931	1,003
Property, plant and equipment, less accumulated depreciation, depletion and amortization of $21,775 and $23,260	25,976	27,061
Goodwill	115	115
Other noncurrent assets	2,246	1,542
Total assets	32,310	32,311
Current liabilities:
Accounts payable	964	1,313
Payroll and benefits payable	121	133
Accrued taxes	66	132
Other current liabilities	256	150
Long-term debt due within one year	1	1
Total current liabilities	1,408	1,729
Long-term debt	7,277	7,276
Deferred tax liabilities	2,399	2,441
Defined benefit postretirement plan obligations	400	403
Asset retirement obligations	1,607	1,601
Deferred credit and other liabilities	297	308
Total liabilities	13,388	13,758
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 and 770 million shares (par value $1 per share, 1.1 billion shares authorized)	937	770
Common stock, securities exchangeable into common stock - no shares issued or outstanding (no par value, 29 million shares authorized)	0	0
Common stock, held in treasury, at cost - 89 million and 93 million shares	(3,406)	(3,554)
Additional paid-in capital	7,442	6,498
Retained earnings	14,086	14,974
Accumulated other comprehensive loss	(137)	(135)
Total stockholders' equity	18,922	18,553
Total liabilities and stockholders' equity	$ 32,310	$ 32,311

Consolidated Balance Sheets Par

Consolidated Balance Sheets Parentheticals - USD ($) shares in Millions, $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Consolidated Balance Sheets Parenthetical [Abstract]
Allowance for Doubtful Accounts Receivable, Current	$ 4	$ 4
Less accumulated depreciation, depletion and amortization	$ (21,775)	$ (23,260)
Preferred stock, no par value	$ 0	$ 0
Preferred stock shares authorized	26	26
Preferred stock shares issued	0	0
Preferred stock shares outstanding	0	0
Common stock, par value per share	$ 1	$ 1
Common stock shares authorized	1,100	1,100
Common stock, shares issued	937	770
Common stock, securities exchangeable, no par value	$ 0	$ 0
Common stock, securities exchangeable, shares authorized	29	29
Common stock, securities exchangeable, shares issued	0	0
Common stock, securities exchangeable, shares outstanding	0	0
Common stock, held in treasury, shares	90	93

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Operating activities:
Net income (loss)	$ (769)	$ (1,411)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	1,764	2,289
Impairments	48	381
Exploratory dry well costs and unproved property impairments	203	708
Gain (Loss) on Disposition of Assets	281	(108)
Deferred income taxes	(504)	(590)
Net (gain) loss on derivative instruments	48	(88)
Net cash received (paid) in settlement of derivative instruments	51	18
Pension and other postretirement benefits, net	2	9
Share-based Compensation	37	34
Equity method investments, net	26	41
Changes in:
Current receivables, changes in	140	738
Inventories, changes in	81	30
Current accounts payable and accrued liabilities, changes in	(236)	(954)
All other operating, net	8	(100)
Net cash provided by operating activities	618	1,213
Investing activities:
Additions to property, plant and equipment	(983)	(2,948)
Payments to Acquire Businesses, Net of Cash Acquired	902	0
Disposal of assets	837	105
Investments - return of capital	47	61
Purchases of short-term investments	0	925
Proceeds from Maturities, Prepayments and Calls of Held-to-maturity Securities	0	225
All other investing, net	2	22
Net cash used in investing activities	(999)	(3,460)
Financing activities:
Borrowings	0	1,996
Debt issuance costs	0	19
Debt repayments	1	34
Common stock issuance	1,236	0
Dividends paid	(119)	(427)
All other financing, net	0	14
Net cash provided by financing activities	1,116	1,530
Effect of Exchange Rate on Cash and Cash Equivalents, Continuing Operations	(3)	(1)
Net increase (decrease) in cash and cash equivalents	732	(718)
Cash and cash equivalents at beginning of period	1,221	2,398
Cash and cash equivalents at end of period	$ 1,953	$ 1,680

Basis of Presentation

Basis of Presentation	9 Months Ended
Basis of Presentation	Sep. 30, 2016
Accounting Policies [Abstract]
Basis of Presentation [Text Block]	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 2015 Annual Report on Form 10-K. The results of operations for the third quarter and first nine months of 2016 are not necessarily indicative of the results to be expected for the full year. A reclassification between operating cash flow categories was made to the prior year's financial information to present it on a basis comparable with the current year's presentation with no impact on net cash provided by operating activities.

Accounting Standards

Accounting Standards	9 Months Ended
Accounting Standards	Sep. 30, 2016
Accounting Standards Disclosure [Abstract]
Accounting Standards [Text Block]	Accounting Standards Not Yet Adopted 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 is effective for us in the first quarter of 2018 and shall be applied on a retrospective basis. Early adoption is permitted. We are evaluating the provisions of this accounting standards update and assessing the impact, if any, it may have on our consolidated statements of cash flows and related disclosures. 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. In March 2016, the FASB issued a new accounting standards update that changes several aspects of accounting for share-based payment transactions, including a requirement to recognize all excess tax benefits and tax deficiencies as income tax expense or benefit in the income statement, classification of awards as either equity or liabilities, and classification on the statement of cash flows. This standard is effective for us in the first quarter of 2017 and varying transition methods (modified retrospective, retrospective or prospective) should be applied to different provisions of the standard. Early adoption is permitted. We continue to evaluate the provisions of this accounting standards update but do not believe it will have a material effect on our consolidated results of operations, financial position or cash flows. 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 is effective for us in the first quarter of 2019 and should be applied using a modified retrospective approach at the beginning of the earliest period presented in the financial statements. Early adoption is permitted. We are evaluating the provisions of this accounting standards update and assessing the impact it will have on our consolidated results of operations, financial position or cash flows. In January 2016, the FASB issued an accounting standards update that addresses certain aspects of recognition, measurement, presentation, and disclosure of financial instruments. This standard is effective for us in the first quarter of 2018. Early adoption is allowed for certain provisions. 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. In July 2015, the FASB issued an update that requires an entity to measure inventory at the lower of cost and net realizable value. This excludes inventory measured using LIFO or the retail inventory method. This standard is effective for us in the first quarter of 2017 and will be applied prospectively. Early adoption is permitted. 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. In August 2014, the FASB issued an update that requires management to assess an entity’s ability to continue as a going concern by incorporating and expanding upon certain principles that are currently in U.S. auditing standards. This standard is effective for us for the annual period ending after December 15, 2016 and for annual periods and interim periods thereafter. Early adoption is permitted. 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. In May 2014, the FASB issued an update that supersedes the existing revenue recognition requirements. This standard includes a five-step revenue recognition model to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. Among other things, the standard requires enhanced disclosures about revenue, provides guidance for transactions that were not previously addressed comprehensively and improves guidance for multiple-element arrangements. While early adoption is permitted, we do not plan to early adopt. This standard is effective for us in the first quarter of 2018 and should be applied retrospectively to each prior reporting period presented or with the cumulative effect of initially applying the update recognized at the date of initial application. We continue to evaluate whether to use the full retrospective or the modified retrospective transition method. We also continue to assess the impact it will have on our consolidated results of operations, financial position or cash flows. Recently Adopted In May 2015, the FASB issued an update that removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share practical expedient. The amendment also removes certain disclosure requirements regarding all investments that are eligible to be measured using the net asset value per share practical expedient and only requires certain disclosures on those investments for which an entity elects to use the net asset value per share expedient. This standard is effective for us in the first quarter of 2016 and was applied on a retrospective basis. This standard only modifies disclosure requirements; as such, there was no impact on our consolidated results of operations, financial position or cash flows. In February 2015, the FASB issued an amendment to the guidance for determining whether an entity is a variable interest entity ("VIE"). The standard does not add or remove any of the five characteristics that determine whether an entity is a VIE. However, it does change the manner in which a reporting entity assesses one of the characteristics. In particular, when decision-making over the entity’s most significant activities has been outsourced, the standard changes how a reporting entity assesses if the equity holders at risk lack decision making rights. This standard is effective for us in the first quarter of 2016. The adoption of this standard did not have a significant impact on our consolidated results of operations, financial position or cash flows.

Variable Interest Entity

Variable Interest Entity	9 Months Ended
Variable Interest Entity	Sep. 30, 2016
Variable Interest Entity, Not Primary Beneficiary, Disclosures [Abstract]
Variable Interest Entity [Text Block]	Variable Interest Entity The owners of the Athabasca Oil Sands Project, in which we hold a 20% undivided interest, contracted with a wholly owned subsidiary of a publicly traded Canadian limited partnership (“Corridor Pipeline”) to provide materials transportation capabilities among the Muskeg River and Jackpine mines, the Scotford upgrader and markets in Edmonton, Alberta, Canada. Costs under this contract are accrued and recorded on a monthly basis, with current liabilities of $2 million recorded at September 30, 2016 and December 31, 2015 . This contract qualifies as a variable interest contractual arrangement, and the Corridor Pipeline qualifies as a VIE. We hold a variable interest but are not the primary beneficiary because our shipments are only 20% of the total; therefore, the Corridor Pipeline is not consolidated by us. Our maximum exposure to loss as a result of our involvement with this VIE is the amount we expect to pay over the contract term, which was $483 million as of September 30, 2016 . The liability on our books related to this contract at any given time will reflect amounts due for the immediately previous month’s activity, which is substantially less than the maximum exposure over the contract term.

Income per Common Share

Income per Common Share	9 Months Ended
Income per Common Share	Sep. 30, 2016
Earnings Per Share [Abstract]
Income (Loss) per Common Share	Income (Loss) 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, provided the effect is not antidilutive. The per share calculations below exclude 13 million stock options for the three and nine month periods ended September 30, 2016 and 13 million stock options for the three and nine month periods ended September 30, 2015 that were antidilutive. Three Months Ended September 30, Nine Months Ended September 30, (In millions, except per share data) 2016 2015 2016 2015 Net income (loss) $ (192 ) $ (749 ) $ (769 ) $ (1,411 ) Weighted average common shares outstanding 847 677 809 677 Weighted average common shares, diluted 847 677 809 677 Net income (loss) per share: Basic $ (0.23 ) $ (1.11 ) $ (0.95 ) $ (2.09 ) Diluted $ (0.23 ) $ (1.11 ) $ (0.95 ) $ (2.09 )

Acquisition (Notes)

Acquisition (Notes)	9 Months Ended
Acquisition (Notes)	Sep. 30, 2016
Acquisitions [Abstract]
Business Combination Disclosure [Text Block]	Acquisitions On August 1, 2016, we closed on our acquisition of PayRock Energy Holdings, LLC ("PayRock"), a portfolio company of EnCap Investments, including approximately 61,000 net surface acres in the oil window of the Anadarko Basin STACK play in Oklahoma. The purchase price of $904 million , subject to closing adjustments was paid with cash on hand. We accounted for this transaction as an asset acquisition, with a majority of the purchase price allocated to property, plant and equipment. Although the purchase price allocation has not been finalized, we do not expect to record any material adjustments to the preliminary purchase price allocation. The pro forma incremental impact on our results of operations for each of the three and nine months ended September 30, 2016 and 2015 is not material.

Dispositions

Dispositions	9 Months Ended
Dispositions	Sep. 30, 2016
Discontinued Operations and Disposal Groups [Abstract]
Dispositions [Text Block]	Dispositions 2016 - North America E&P Segment In September 2016, we entered into an agreement to sell certain non-operated CO2 and waterflood assets in West Texas and New Mexico. The sale closed in late October for proceeds of $235 million , before closing adjustments. These assets are classified as held for sale in the consolidated balance sheet as of September 30, 2016 with total assets of $171 million and total liabilities of $4 million . During the quarter, we sold certain non-operated assets primarily in West Texas and New Mexico to multiple purchasers for combined proceeds of approximately $67 million , subject to certain adjustments, and recognized a total pre-tax gain of $55 million . During the second quarter 2016, we announced the sale of our Wyoming upstream and midstream assets for proceeds of $ 870 million , before closing adjustments, of which approximately $ 690 million was received in the second quarter. A pre-tax gain of $ 266 million was recognized in the second quarter 2016. The remaining asset sales are subject to the receipt of certain tribal consents and are expected to close before year-end. These assets are classified as held for sale in the consolidated balance sheet as of September 30, 2016 with total assets of $ 105 million and total liabilities of $ 5 million . The proceeds for the remaining asset sales were deposited into an escrow account by the buyer. In March and April 2016, we entered into separate agreements to sell our 10% working interest in the outside-operated Shenandoah discovery in the Gulf of Mexico, operated natural gas assets in the Piceance basin in Colorado and certain undeveloped acreage in West Texas for a combined total of approximately $ 80 million in proceeds, before closing adjustments. We closed on certain of the asset sales and recognized a net pre-tax loss on sale of $ 48 million for the nine months ended September 30, 2016, with the remaining asset sales expected to close by year-end. 2015 - North America E&P Segment In the third quarter of 2015, we closed on the sale of our East Texas/North Louisiana and Wilburton, Oklahoma natural gas assets for proceeds of $100 million and recorded a pretax loss of $1 million . During the second quarter of 2015, we recorded a non-cash impairment charge of $44 million related to these assets as a result of the anticipated sale (see Note 14 ). 2015 - International E&P Segment In the third quarter of 2015, we entered into an agreement to sell our East Africa exploration acreage in Ethiopia and Kenya. A pretax loss of $ 109 million was recorded in the third quarter of 2015. This transaction closed during the first quarter of 2016.

Segment Information

Segment Information	9 Months Ended
Segment Information	Sep. 30, 2016
Segment Reporting [Abstract]
Segment Information [Text Block]	Segment Information We have three reportable operating segments. Each of these segments is organized and managed based upon both geographic location and the nature of the products and services it offers. • N.A. E&P – explores for, produces and markets crude oil and condensate, NGLs and natural gas in North America; • Int'l E&P – explores for, produces and markets crude oil and condensate, NGLs and natural gas outside of North America and produces and markets products manufactured from natural gas, such as LNG and methanol, in E.G.; and • Oil Sands Mining (“OSM”) – mines, extracts and transports bitumen from oil sands deposits in Alberta, Canada, and upgrades the bitumen to produce and market synthetic crude oil and vacuum gas oil. 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 segments, net of income taxes, attributable to the operating segments. A portion of our corporate and operations support general and administrative 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, change in tax expense associated with a tax rate change, 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, 2016 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 604 $ 152 $ 239 $ 25 (c) $ 1,020 Marketing revenues 44 36 — — 80 Total revenues 648 188 239 25 1,100 Income from equity method investments — 59 — — 59 Net gain on disposal of assets and other income 19 7 — 44 (d) 70 Less: Production expenses 113 47 135 — 295 Marketing costs 45 35 — — 80 Exploration expenses 35 10 — 38 83 Depreciation, depletion and amortization 443 66 72 13 594 Impairments — — — 47 (e) 47 Other expenses (a) 85 18 9 182 (f) 294 Taxes other than income 35 — 4 — 39 Net interest and other — — — 87 87 Income tax provision (benefit) (30 ) 19 4 (91 ) (98 ) Segment income (loss) / Net income (loss) $ (59 ) $ 59 $ 15 $ (207 ) $ (192 ) Capital expenditures (b) $ 216 $ 18 $ 12 $ 3 $ 249 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized gain on commodity derivative instruments. (d) Primarily related to certain non-operated assets in West Texas and New Mexico. (see Note 6 ). (e) Proved property impairments (see Note 14 ). (f) Includes termination payment on our Gulf of Mexico deepwater drilling rig contract of $ 113 million and pension settlement loss of $14 million (see Note 8 ). Three Months Ended September 30, 2015 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 796 $ 182 $ 242 $ 80 (c) $ 1,300 Marketing revenues 57 25 2 — 84 Total revenues 853 207 244 80 1,384 Income (loss) from equity method investments — 48 — (12 ) (d) 36 Net gain (loss) on disposal of assets and other income 6 6 — (109 ) (e) (97 ) Less: Production expenses 179 61 166 — 406 Marketing costs 56 25 3 — 84 Exploration expenses 22 10 — 553 (f) 585 Depreciation, depletion and amortization 549 79 76 13 717 Impairments — — 4 333 (g) 337 Other expenses (a) 106 25 8 79 (h) 218 Taxes other than income 42 — 5 (1 ) 46 Net interest and other — — — 75 75 Income tax provision (benefit) (34 ) 32 (7 ) (387 ) (396 ) Segment income (loss) / Net income (loss) $ (61 ) $ 29 $ (11 ) $ (706 ) $ (749 ) Capital expenditures (b) $ 564 $ 30 $ (11 ) $ 12 $ 595 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized gain on commodity derivative instruments. (d) Partial impairment of investment in equity method investee (see Note 14 ). (e) Includes loss on sale of East Africa exploration acreage (see Note 6 .). (f) Unproved property impairments associated with lower forecasted commodity prices and change in conventional exploration strategy (see Note 13 ). (g) Proved property impairments (see Note 14 ). (h) Includes pension settlement loss of $18 million (see Note 8 ) and severance related expenses associated with workforce reductions of $4 million . Nine Months Ended September 30, 2016 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 1,714 $ 407 $ 572 $ (89 ) (c) $ 2,604 Marketing revenues 128 74 25 — 227 Total revenues 1,842 481 597 (89 ) 2,831 Income from equity method investments — 110 — — 110 Net gain on disposal of assets and other income 22 20 1 277 (d) 320 Less: Production expenses 376 156 441 — 973 Marketing costs 129 72 25 — 226 Exploration expenses 90 20 7 179 (e) 296 Depreciation, depletion and amortization 1,363 184 181 36 1,764 Impairments 1 — — 47 (f) 48 Other expenses (a) 300 56 25 400 (g) 781 Taxes other than income 112 — 13 1 126 Net interest and other — — — 258 258 Income tax provision (benefit) (183 ) 5 (23 ) (241 ) (442 ) Segment income (loss) / Net income (loss) $ (324 ) $ 118 $ (71 ) $ (492 ) $ (769 ) Capital expenditures (b) $ 684 $ 62 $ 28 $ 11 $ 785 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized loss on commodity derivative instruments. (d) Primarily related to net gain on disposal of assets (see Note 6 ). (e) Primarily associated with impairments associated with decision to not drill remaining Gulf of Mexico undeveloped leases (see Note 13 ). (f) Proved property impairments (see Note 14 ). (g) Includes termination payment on our Gulf of Mexico deepwater drilling rig contract of $ 113 million and includes pension settlement loss of $93 million and severance related expenses associated with workforce reductions of $8 million (see Note 8 ). Nine Months Ended September 30, 2015 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 2,639 $ 575 $ 614 $ 59 (c) $ 3,887 Marketing revenues 345 81 45 — 471 Total revenues 2,984 656 659 59 4,358 Income (loss) from equity method investments — 110 — (12 ) (d) 98 Net gain (loss) on disposal of assets and other income 17 20 1 (108 ) (e) (70 ) Less: Production expenses 560 192 548 — 1,300 Marketing costs 348 79 44 — 471 Exploration expenses 148 85 — 553 (f) 786 Depreciation, depletion and amortization 1,866 214 173 36 2,289 Impairments — — 4 377 (g) 381 Other expenses (a) 322 67 26 330 (h) 745 Taxes other than income 170 — 15 6 191 Net interest and other — — — 180 180 Income tax provision (benefit) (146 ) 56 (43 ) (413 ) (i) (546 ) Segment income (loss) / Net income (loss) $ (267 ) $ 93 $ (107 ) $ (1,130 ) $ (1,411 ) Capital expenditures (b) $ 2,048 $ 275 $ 26 $ 26 $ 2,375 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized gain on commodity derivative instruments. (d) Partial impairment of investment in equity-method investee (see Note 14). (e) Includes loss on sale of East Africa exploration acreage (see Note 6 .). (f) Unproved property impairments associated with lower forecasted commodity prices and change in conventional exploration strategy (see Note 13 ). (g) Proved property impairments (See Note 14 ). (h) Includes pension settlement loss of $ 99 million (see Note 8) and severance related expenses associated with workforce reductions of $47 million . (i) Includes $135 million of deferred tax expense related to Alberta provincial corporate tax rate increase (see Note 9 ).

Defined Benefit Postretirement

Defined Benefit Postretirement Plans	9 Months Ended
Defined Benefit Postretirement Plans	Sep. 30, 2016
Defined Benefit Postretirement Plans Disclosure [Abstract]
Defined Benefit Postretirement Plans [Text Block]	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) 2016 2015 2016 2015 Service cost $ 6 $ 11 $ 1 $ — Interest cost 9 12 3 3 Expected return on plan assets (12 ) (17 ) — — Amortization: – prior service cost (credit) (2 ) (3 ) (1 ) (1 ) – actuarial loss 4 5 — 1 Net settlement loss (a) 14 18 — — Net curtailment loss (b) — 4 — — Net periodic benefit cost $ 19 $ 30 $ 3 $ 3 Nine Months Ended September 30, Pension Benefits Other Benefits (In millions) 2016 2015 2016 2015 Service cost $ 18 $ 35 $ 3 $ 2 Interest cost 30 39 8 8 Expected return on plan assets (40 ) (53 ) — — Amortization: – prior service cost (credit) (7 ) (4 ) (3 ) (3 ) – actuarial loss 11 19 — 1 Net settlement loss (a) 93 99 — — Net curtailment loss (gain) (b) — 5 — (4 ) Net periodic benefit cost $ 105 $ 140 $ 8 $ 4 (a) Settlements are recognized as they occur, once it is probable that lump sum payments from a plan for a given year will exceed the plan's total service and interest cost for that year. (b) Related to workforce reductions, which reduced the future expected years of service for employees participating in the plans and the impact of discounting accruals for future benefits under the U.K. pension plan effective December 31, 2015. During the first nine months of 2016 , 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 2016 , we made contributions of $48 million to our funded pension plans and we expect to make additional contributions up to an estimated $16 million over the remainder of 2016 . During the first nine months of 2016 , we made payments of $47 million and $16 million related to unfunded pension plans and other postretirement benefit plans, respectively.

Income Taxes

Income Taxes	9 Months Ended
Income Taxes	Sep. 30, 2016
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-month and nine-month periods in 2016 and 2015, our effective income tax rates were as follows: 2016 2015 Three months ended September 30 34 % 35 % Nine months ended September 30 37 % 28 % In Libya, reliable estimates of 2016 and 2015 annual ordinary income from our Libyan operations could not be made, and the range of possible scenarios in the worldwide annual effective tax rate calculation demonstrates significant variability. Thus, the tax benefit applicable to Libyan ordinary loss was recorded as a discrete item in the first nine months of 2016 and 2015 . For the first nine months of 2016 and 2015 , estimated annual effective tax rates were calculated excluding Libya and applied to consolidated ordinary income (loss). Excluding Libya, the effective tax rates would be 30% and 35% for the third quarters 2016 and 2015, and 35% and 27% for the first nine months of 2016 and 2015 . The rate change between years for the third quarter was driven by a shift in jurisdictional income and the impact of tax legislation enacted by the U.K. government on September 15, 2016 reducing the rate of the Petroleum Revenue Tax (PRT) from 35% to 0% and reducing the Supplemental Charge Tax (SCT) from 20% to 10%. As a result of this legislation, we reduced our deferred tax asset by $6 million and recorded an expense in the third quarter of 2016. The rate change between years for the first nine months was driven by a shift in jurisdictional income and tax legislation enacted by the Alberta government in Canada on June 29, 2015 to increase the provincial corporate tax rate from 10% to 12% . As a result of this legislation, we recorded additional non-cash deferred tax expense of $135 million in the second quarter of 2015. Deferred Tax Assets In connection with our assessment of the realizability of our deferred tax assets, we consider whether it is more likely than not that some portion or all of our deferred tax assets will not be realized. In the event it is more likely than not that some portion or all of our deferred taxes will not be realized, such assets are reduced by a valuation allowance. This assessment requires analysis of all available positive and negative evidence, including losses in recent years as well as forecasts of future income, assessment of future business assumptions and applicable tax planning strategies. We expect to be in a cumulative loss position in 2017 which constitutes significant objective negative evidence. However, we have concluded that our long-term commodity price forecast, proved reserves and available tax planning strategies provide sufficient positive evidence to support the net deferred tax assets recorded as of September 30, 2016. Future increases to our valuation allowance are possible if our estimates and assumptions (particularly as they relate to our long-term commodity price forecast) are revised such that they reduce estimates of future taxable income during the carryforward period.

Short-Term Investments (Notes)

Short-Term Investments (Notes)	9 Months Ended
Short-Term Investments (Notes)	Sep. 30, 2015
Short-term Investments [Abstract]
Investment [Text Block]	Short-term Investments As of September 30, 2015, we held short-term investments comprised of bank time deposits with original maturities of greater than three months and remaining maturities of less than twelve months. These short-term investments, which were classified as held-to-maturity investments and recorded at amortized cost, matured in the fourth quarter of 2015.

Inventories

Inventories	9 Months Ended
Inventories	Sep. 30, 2016
Inventory Disclosure [Abstract]
Inventories [Text Block]	Inventories Liquid hydrocarbons, natural gas and bitumen are recorded at weighted average cost and carried at the lower of cost or market 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) 2016 2015 Liquid hydrocarbons, natural gas and bitumen $ 26 $ 35 Supplies and other items 195 278 Inventories, at cost $ 221 $ 313

Property, Plant and Equipment

Property, Plant and Equipment	9 Months Ended
Property, Plant and Equipment	Sep. 30, 2016
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment [Text Block]	Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization September 30, December 31, (In millions) 2016 2015 North America E&P $ 14,391 $ 15,226 International E&P 2,440 2,533 Oil Sands Mining 9,043 9,197 Corporate 102 105 Net property, plant and equipment $ 25,976 $ 27,061 Due to civil unrest, our Libya operations were interrupted in mid-2013 as a result of the shutdown of the Es-Sider crude oil terminal, and while temporarily re-opened in July 2014, operations were again interrupted in December 2014. Force Majeure was lifted on September 14, 2016 and production resumed on October 2, 2016 at our Waha concession. The Libya National Oil Corporation has commenced lifting from the Ras Lanuf crude oil terminal and liftings from the Es-Sider terminal may resume as early as the fourth quarter of 2016. As of September 30, 2016 , our net property, plant and equipment investment in Libya is $770 million , and total proved reserves (unaudited) in Libya as of December 31, 2015 are 235 million barrels of oil equivalent ("mmboe"). We and our partners in the Waha concessions continue to assess the situation and the condition of our assets in Libya. Our periodic assessment of the carrying value of our net property, plant and equipment in Libya specifically considers the net investment in the assets, the duration of our concessions and the reserves anticipated to be recoverable in future periods. The undiscounted cash flows related to our Libya assets exceed the carrying value of $770 million by a material amount. However, changes in management's forecast assumptions may cause us to reassess our assets in Libya for impairment and could result in non-cash impairment charges in the future. Exploratory well costs capitalized greater than one year after completion of drilling were $118 million and $85 million as of September 30, 2016 and December 31, 2015 . The $33 million increase primarily relates to the Alba Block Sub Area B offshore Equatorial Guinea where the Rodo well reached total depth in the first quarter of 2015. We have since completed a seismic feasibility study and continue to finalize next steps in the Alba Block Sub Area B exploration program.

Impairments and Exploration Exp

Impairments and Exploration Expense (Notes)	9 Months Ended
Impairments and Exploration Expense (Notes)	Sep. 30, 2016
Impairments and Exploration Expense [Abstract]
Impairments and Exploration Expenses [Text Block]	Impairments and Exploration Expenses The continued decline of commodity prices resulted in a downward revision of our long-term commodity price assumptions which triggered an assessment of certain of our long-lived assets related to oil and gas producing properties for impairment as of September 30, 2016. Similarly, in 2015, a downward revision of our long-term commodity price assumptions triggered an assessment of our long-lived assets related to oil and gas producing properties for impairment as of September 30, 2015. Further changes in management's forecast assumptions may cause us to reassess our long-lived assets for impairment and could result in non-cash impairment charges in the future. The following table summarizes impairment charges of proved properties: Three Months Ended September 30, Nine Months Ended September 30, (in millions) 2016 2015 2016 2015 Total impairments $ 47 $ 337 $ 48 $ 381 Impairments for the three and nine months ended September 30, 2016 consisted primarily of conventional non-core proved properties in Oklahoma as a result of lower forecasted long-term commodity prices. Impairments for the three and nine months ended September 30, 2015 consisted primarily of proved properties in Colorado and the Gulf of Mexico as a result of lower forecasted commodity prices. See Note 7 for relevant detail regarding segment presentation and Note 14 for fair value measurements related to impairments of proved properties. The following table summarizes the components of exploration expenses: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2016 2015 2016 2015 Exploration Expenses Unproved property impairments $ 28 $ 563 $ 172 $ 612 Dry well costs 9 (3 ) 31 96 Geological and geophysical 1 8 1 23 Other 45 17 92 55 Total exploration expenses $ 83 $ 585 $ 296 $ 786 Unproved property impairments for the nine months ended September 30, 2016 primarily consist of non-cash charges of $ 118 million as a result of our decision to not drill any of our remaining Gulf of Mexico undeveloped leases. Included in the unproved property impairments for the three and nine months ended September 30, 2015 are non-cash charges of $553 million as a result of changes in our conventional exploration strategy (Gulf of Mexico and Harir block in the Kurdistan Region of Iraq) and lower forecasted commodity prices (Colorado). See Note 7 for relevant detail regarding segment presentation.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
Fair Value Measurements	Sep. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurements [Text Block]	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, 2016 and December 31, 2015 by fair value hierarchy level. September 30, 2016 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ — $ 4 $ — $ 4 Interest rate — 10 — 10 Derivative instruments, assets $ — $ 14 $ — $ 14 Derivative instruments, liabilities Commodity (a) $ — $ 43 $ — $ 43 Derivative instruments, liabilities $ — $ 43 $ — $ 43 (a) Derivative instruments are recorded on a net basis in our balance sheet (see Note 15 ). December 31, 2015 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ — $ 51 $ — $ 51 Interest rate — 8 — 8 Derivative instruments, assets $ — $ 59 $ — $ 59 Derivative instruments, liabilities Commodity (a) $ — $ 1 $ — $ 1 Derivative instruments, liabilities $ — $ 1 $ — $ 1 (a) Derivative instruments are recorded on a net basis in our balance sheet (see Note 15 ). Commodity derivatives include three-way collars, two-way collars and call options. These instruments are measured at fair value using either the Black-Scholes Model or the Black Model. Inputs to both models include commodity prices, interest rates, and implied volatility. The inputs to these models are categorized as Level 2 because predominantly all assumptions and inputs are observable in active markets throughout the term of the instruments. Both our interest rate swaps and forward starting interest rate swaps are measured at fair value with a market approach using actionable broker quotes, which are Level 2 inputs. See Note 15 for additional discussion of the types of derivative instruments we use. Fair Values – Goodwill Unlike long-lived assets, goodwill must be tested for impairment at least annually, or between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount. Goodwill is tested for impairment at the reporting unit level. We estimate the fair value of our International E&P reporting unit using a combination of market and income approaches. The market approach referenced observable inputs specific to us and our industry, such as the price of our common equity, our enterprise value, and valuation multiples of us and our peers from the investor analyst community. The income approach utilized discounted cash flows, which were based on forecasted assumptions. Key assumptions to the income approach include future liquid hydrocarbon and natural gas pricing, estimated quantities of liquid hydrocarbons and natural gas proved and probable reserves, estimated timing of production, discount rates, future capital requirements, operating expenses and tax rates. The assumptions used in the income approach are consistent with those that management uses to make business decisions. These valuations methodologies represent Level 3 fair value measurements. We performed our annual impairment test in April 2016 and concluded no impairment was required. While the fair value of our International E&P reporting unit exceeded the book value, subsequent commodity price and/or common stock declines may cause us to reassess our goodwill for impairment and could result in non-cash impairment charges in the future. Fair Values- Nonrecurring The following table shows 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, 2016 2015 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 15 $ 47 $ 41 $ 337 Nine Months Ended September 30, 2016 2015 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 15 $ 48 $ 58 $ 381 The continued decline of commodity prices resulted in a downward revision of our long-term commodity price assumptions which triggered an assessment of certain of our long-lived assets related to oil and gas producing properties for impairment as of September 30, 2016. Similarly, in 2015, a downward revision of our long-term commodity price assumptions triggered an assessment of our long-lived assets related to oil and gas producing properties for impairment as of September 30, 2015. Further changes in management's forecast assumptions may cause us to reassess our long-lived assets for impairment and could result in non-cash impairment charges in the future. Long-lived assets held for use that were impaired are discussed below. The fair values of each were measured using an income approach based upon internal estimates of future production levels, prices and discount rate, all of which are Level 3 inputs. 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. 2016 - North America E&P In the third quarter of 2016, impairments of $ 47 million were recorded primarily consisting of conventional non-core proved properties in Oklahoma as a result of lower forecasted long-term commodity prices, to an aggregate fair value of $15 million . 2015- North America E&P In the third quarter of 2015, impairments of $333 million were recorded primarily related to certain producing assets in Colorado and the Gulf of Mexico as a result of lower forecasted commodity prices, to an aggregate fair value of $ 41 million . During the second quarter of 2015, we recorded a non-cash impairment charge of $44 million related to East Texas, North Louisiana and Wilburton, Oklahoma natural gas assets as a result of the anticipated sale (see Note 6 ). The fair values were measured using a probability weighted income approach based on both the anticipated sales price and a held-for-use model. 2015- International E&P In the third quarter of 2015, a partial impairment of $ 12 million was recorded to an investment in an equity method investee as a result of lower forecasted commodity prices, to fair value of $ 604 million . This impairment was reflected in income equity method investments in our consolidated statements of income. Fair Values – Financial Instruments Our current assets and liabilities include financial instruments, the most significant of which are receivables, 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, 2016 and December 31, 2015 . September 30, 2016 December 31, 2015 Fair Carrying Fair Carrying (In millions) Value Amount Value Amount Financial assets Other noncurrent assets $ 112 $ 118 $ 104 $ 118 Total financial assets $ 112 $ 118 $ 104 $ 118 Financial liabilities Other current liabilities $ 49 $ 59 $ 34 $ 33 Long-term debt, including current portion (a) 7,345 7,292 6,723 7,291 Deferred credits and other liabilities 123 117 97 95 Total financial liabilities $ 7,517 $ 7,468 $ 6,854 $ 7,419 (a) Excludes capital leases, debt issuance costs and interest rate swap adjustments. Fair values of our financial assets included in other noncurrent assets, and of our financial liabilities included in other current liabilities and deferred credits and other liabilities, are measured using an income approach and most inputs are internally generated, which results in a Level 3 classification. Estimated future cash flows are discounted using a rate deemed appropriate to obtain the fair value. Most 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 such debt. The fair value of our debt that is not publicly-traded is measured using an income approach. The future debt service payments are discounted using the rate at which we currently expect to borrow. All inputs to this calculation are Level 3.

Derivatives

Derivatives	9 Months Ended
Derivatives	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives [Text Block]	Derivatives For further information regarding the fair value measurement of derivative instruments, see Note 14 . All of our interest rate and commodity 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 where they appear on the consolidated balance sheets. September 30, 2016 (In millions) Asset Liability Net Asset Balance Sheet Location Fair Value Hedges Interest rate $ 8 $ — $ 8 Other noncurrent assets Cash Flow Hedges Interest rate 2 — 2 Other noncurrent assets Total Designated Hedges $ 10 $ — $ 10 September 30, 2016 (In millions) Asset Liability Net Liability Balance Sheet Location Not Designated as Hedges Commodity $ 4 $ 30 $ 26 Other current liabilities Commodity — 13 13 Deferred credits and other liabilities Total Not Designated as Hedges $ 4 $ 43 $ 39 December 31, 2015 (In millions) Asset Liability Net Asset Balance Sheet Location Fair Value Hedges Interest rate $ 8 $ — $ 8 Other noncurrent assets Not Designated as Hedges Commodity $ 51 $ 1 $ 50 Other current assets Derivatives Designated as Fair Value Hedges The following table presents, by maturity date, information about our interest rate swap agreements, including the weighted average, London Interbank Offer Rate (“LIBOR”)-based, floating rate. September 30, 2016 December 31, 2015 Aggregate Notional Amount Weighted Average, LIBOR-Based, Aggregate Notional Amount Weighted Average, LIBOR-Based, Maturity Dates (in millions) Floating Rate (in millions) Floating Rate October 1, 2017 $ 600 5.01 % $ 600 4.73 % March 15, 2018 $ 300 4.86 % $ 300 4.66 % The pretax effects of derivative instruments designated as hedges of fair value in our consolidated statements of income are summarized in the table below. There is no ineffectiveness related to fair value hedges. Gain (Loss) Three Months Ended September 30, Nine Months Ended September 30, (In millions) Income Statement Location 2016 2015 2016 2015 Derivative Interest rate Net interest and other $ (4 ) $ 4 $ — $ 7 Hedged Item Long-term debt Net interest and other $ 4 $ (4 ) $ — $ (7 ) Derivatives Designated as Cash Flow Hedges We may use interest rate derivative instruments to manage the risk of interest rate changes during the period prior to anticipated borrowings and designate them as cash flow hedges. Derivative instruments designated as cash flow hedges are linked to specific assets and liabilities or to specific firm commitments or forecasted transactions. The effective portion of changes in the fair value of a qualifying cash flow hedge are recorded in other comprehensive income until the hedged item is reclassified to net income when the underlying forecasted transaction is recognized in net income. Ineffective portions of a cash flow hedge’s change in fair value are recognized currently within net interest and other on the consolidated statements of income. However, if it is determined that the likelihood of the original forecasted transaction occurring is no longer probable, the entire accumulated gain or loss recognized in other comprehensive income is immediately reclassified into net income. 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 is probable to be refinanced by us in 2018, specifically interest rate risk associated with future changes in the benchmark treasury rate. The occurrence of the forecasted transaction is probable and each respective derivative contract can be tied to an anticipated underlying dollar notional amount. At conclusion of the hedge in the first quarter of 2018, the final value will be reclassified from accumulated other comprehensive income into earnings. At September 30, 2016, the forward starting interest rate swaps continued to qualify as an effective hedge and the ineffective portion was not material. The following table presents, by maturity date, information about our forward starting interest rate swap agreements, including the rate. September 30, 2016 Aggregate Notional Amount Weighted Average, LIBOR Maturity Dates (in millions) Fixed Rate March 15, 2018 $750 1.57% The following table sets forth the net impact of the derivatives designated as cash flow hedges on other comprehensive income (loss). Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2016 2015 2016 2015 Cash Flow Hedges Beginning balance $ — $ — $ — $ — Change in fair value recognized in other comprehensive income 2 — 2 — Reclassification from other comprehensive income — — — — Ending balance $ 2 $ — $ 2 $ — At September 30, 2016, accumulated other comprehensive income included deferred gains of $ 1 million , net of tax, related to interest rate cash flow hedges. We do not expect any reclassification to earnings as an adjustment to net interest and other during the next 12 months. Derivatives not Designated as Hedges 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 North America E&P sales through December 2017. These commodity derivatives consist of three-way collars, two-way collars, and call options. 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, 2016 and the weighted average prices for those contracts: Crude Oil 2016 2017 Fourth Quarter First Quarter Second Quarter Third Quarter Fourth Quarter Three-Way Collars (a) Volume (Bbls/day) 47,000 30,000 30,000 — — Price per Bbl: Ceiling $55.37 $58.19 $58.19 — — Floor $50.23 $49.33 $49.33 — — Sold put $40.96 $42.67 $42.67 — — Sold call options (b) Volume (Bbls/day) 10,000 35,000 35,000 35,000 35,000 Price per Bbl $72.39 $61.91 $61.91 $61.91 $61.91 Two-way Collars Volume (Bbls/day) 10,000 — — — — Price per Bbl: Ceiling $50.00 — — — — Floor $41.55 — — — — (a) Subsequent to September 30, 2016, we entered into 10,000 Bbls/day of three-way collars for January - June 2017 with a ceiling price of $58.27 , a floor price of $49.50 , and a sold put price of $42.50 . (b) Call options settle monthly. Natural Gas 2016 2017 Fourth Quarter First Quarter Second Quarter Third Quarter Fourth Quarter Three-Way Collars (a) Volume (MMBtu/day) 20,000 60,000 60,000 60,000 60,000 Price per MMBtu Ceiling $2.93 $3.46 $3.46 $3.46 $3.46 Floor $2.50 $2.84 $2.84 $2.84 $2.84 Sold put $2.00 $2.35 $2.35 $2.35 $2.35 (a) On our 2016 collars, the counterparty has the option to execute fixed-price swaps (swaptions) at a weighted average price of $2.93 per MMBtu indexed to NYMEX Henry Hub, which is exercisable on December 22, 2016. If the counterparty exercises, the term of the fixed-price swaps would be for the calendar year 2017 and, if all such options are exercised, 20,000 MMBtu per day. The mark-to-market impact and settlement of these commodity derivative instruments appears in sales and other operating revenues in our consolidated statements of income for the three and nine month periods ended September 30, 2016 . The impact was a net gain of $ 42 million and a net loss of $ 48 million compared to a net gain of $108 million and $91 million for the same respective periods in 2015. Net cash received from settlements of commodity derivative instruments for the three and nine month periods ended September 30, 2016 was $ 8 million and $ 54 million compared to $ 18 million and $ 23 million for both of the respective periods in 2015.

Incentive Based Compensation

Incentive Based Compensation	9 Months Ended
Incentive Based Compensation	Sep. 30, 2016
Incentive Based Compensation Plans [Abstract]
Incentive Based Compensation [Text Block]	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 2016 : Stock Options Restricted Stock Awards & Units Number of Shares Weighted Average Exercise Price Awards Weighted Average Grant Date Fair Value Outstanding at December 31, 2015 12,665,419 $29.97 4,017,344 $30.76 Granted 1,680,000 (a) $7.22 5,247,751 $7.93 Options Exercised/Stock Vested — — (1,264,325 ) $32.52 Canceled (1,936,084 ) $23.95 (1,119,975 ) $19.92 Outstanding at September 30, 2016 12,409,335 $27.83 6,880,795 $14.79 (a) The weighted average grant date fair value of stock option awards granted was $1.97 per share. Stock-based performance unit awards During the first nine months of 2016 , we granted 1,205,517 stock-based performance units to certain officers. The grant date fair value per unit was $3.72 . In September of 2016, 377,857 stock-based performance units were canceled.

Debt (Notes)

Debt (Notes)	9 Months Ended
Debt (Notes)	Sep. 30, 2016
Debt Disclosure [Abstract]
Debt	Debt Revolving Credit Facility As of September 30, 2016 , we had no borrowings against our revolving credit facility (the "Credit Facility"), as described below. In March 2016, we increased our $3.0 billion unsecured Credit Facility by $300 million to a total of $3.3 billion . 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, 2016 , we were in compliance with this covenant with a debt-to-capitalization ratio of 28% . Debt Issuance In the second quarter of 2015, we issued $ 2 billion aggregate principal amount of unsecured senior notes and used the aggregate net proceeds to repay our $ 1 billion 0.90% senior notes November 1, 2015, and for general corporate purposes.

Reclassifications out of Accumu

Reclassifications out of Accumulated Other Comprehensive Income	9 Months Ended
	Sep. 30, 2016
Reclassifications out of AOCI [Abstract]
Reclassifications [Text Block]	Reclassifications Out of Accumulated Other Comprehensive Loss The following table presents a summary of amounts reclassified from accumulated other comprehensive loss: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2016 2015 2016 2015 Income Statement Line Postretirement and postemployment plans Amortization of actuarial loss $ (4 ) $ (6 ) $ (11 ) $ (20 ) General and administrative Net settlement loss (14 ) (18 ) (93 ) (99 ) General and administrative Net curtailment loss — (4 ) — (1 ) General and administrative (18 ) (28 ) (104 ) (120 ) Income (loss) from operations 6 10 38 44 Benefit for income taxes Total reclassifications to expense $ (12 ) $ (18 ) $ (66 ) $ (76 ) Net income (loss)

Stockholders' Equity (Notes)

Stockholders' Equity (Notes)	9 Months Ended
Stockholders' Equity (Notes)	Sep. 30, 2016
Stockholders' Equity Attributable to Parent [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Stockholder's Equity In March 2016, we issued 166,750,000 shares of our common stock, par value $1 per share, at a price of $7.65 per share, excluding underwriting discounts and commissions, for net proceeds of $1,236 million . The proceeds were used to strengthen our balance sheet and for general corporate purposes, including funding a portion of our Capital Program.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
Supplemental Cash Flow Information	Sep. 30, 2016
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information [Text Block]	Supplemental Cash Flow Information Nine Months Ended September 30, (In millions) 2016 2015 Net cash (used in) operating activities: Interest paid (net of amounts capitalized) $ (243 ) $ (200 ) Income taxes paid to taxing authorities (68 ) (174 ) Noncash investing activities: Asset retirement cost increase $ 3 $ 12 Asset retirement obligations assumed by buyer 86 23

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
Commitments and Contingencies	Sep. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies 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 reflected in the prices of 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 Accountin

Basis of Presentation Accounting Policy (Policies)	9 Months Ended
Basis of Presentation Accounting Policy (Policies)	Sep. 30, 2016
Accounting Policies [Abstract]
Basis of Accounting, Policy [Policy Text Block]	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 2015 Annual Report on Form 10-K. The results of operations for the third quarter and first nine months of 2016 are not necessarily indicative of the results to be expected for the full year.

Income per Common Share (Tables

Income per Common Share (Tables)	9 Months Ended
Income per Common Share (Tables)	Sep. 30, 2016
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The per share calculations below exclude 13 million stock options for the three and nine month periods ended September 30, 2016 and 13 million stock options for the three and nine month periods ended September 30, 2015 that were antidilutive. Three Months Ended September 30, Nine Months Ended September 30, (In millions, except per share data) 2016 2015 2016 2015 Net income (loss) $ (192 ) $ (749 ) $ (769 ) $ (1,411 ) Weighted average common shares outstanding 847 677 809 677 Weighted average common shares, diluted 847 677 809 677 Net income (loss) per share: Basic $ (0.23 ) $ (1.11 ) $ (0.95 ) $ (2.09 ) Diluted $ (0.23 ) $ (1.11 ) $ (0.95 ) $ (2.09 )

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
Segment Information (Tables)	Sep. 30, 2016
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	Three Months Ended September 30, 2016 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 604 $ 152 $ 239 $ 25 (c) $ 1,020 Marketing revenues 44 36 — — 80 Total revenues 648 188 239 25 1,100 Income from equity method investments — 59 — — 59 Net gain on disposal of assets and other income 19 7 — 44 (d) 70 Less: Production expenses 113 47 135 — 295 Marketing costs 45 35 — — 80 Exploration expenses 35 10 — 38 83 Depreciation, depletion and amortization 443 66 72 13 594 Impairments — — — 47 (e) 47 Other expenses (a) 85 18 9 182 (f) 294 Taxes other than income 35 — 4 — 39 Net interest and other — — — 87 87 Income tax provision (benefit) (30 ) 19 4 (91 ) (98 ) Segment income (loss) / Net income (loss) $ (59 ) $ 59 $ 15 $ (207 ) $ (192 ) Capital expenditures (b) $ 216 $ 18 $ 12 $ 3 $ 249 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized gain on commodity derivative instruments. (d) Primarily related to certain non-operated assets in West Texas and New Mexico. (see Note 6 ). (e) Proved property impairments (see Note 14 ). (f) Includes termination payment on our Gulf of Mexico deepwater drilling rig contract of $ 113 million and pension settlement loss of $14 million (see Note 8 ). Three Months Ended September 30, 2015 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 796 $ 182 $ 242 $ 80 (c) $ 1,300 Marketing revenues 57 25 2 — 84 Total revenues 853 207 244 80 1,384 Income (loss) from equity method investments — 48 — (12 ) (d) 36 Net gain (loss) on disposal of assets and other income 6 6 — (109 ) (e) (97 ) Less: Production expenses 179 61 166 — 406 Marketing costs 56 25 3 — 84 Exploration expenses 22 10 — 553 (f) 585 Depreciation, depletion and amortization 549 79 76 13 717 Impairments — — 4 333 (g) 337 Other expenses (a) 106 25 8 79 (h) 218 Taxes other than income 42 — 5 (1 ) 46 Net interest and other — — — 75 75 Income tax provision (benefit) (34 ) 32 (7 ) (387 ) (396 ) Segment income (loss) / Net income (loss) $ (61 ) $ 29 $ (11 ) $ (706 ) $ (749 ) Capital expenditures (b) $ 564 $ 30 $ (11 ) $ 12 $ 595 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized gain on commodity derivative instruments. (d) Partial impairment of investment in equity method investee (see Note 14 ). (e) Includes loss on sale of East Africa exploration acreage (see Note 6 .). (f) Unproved property impairments associated with lower forecasted commodity prices and change in conventional exploration strategy (see Note 13 ). (g) Proved property impairments (see Note 14 ). (h) Includes pension settlement loss of $18 million (see Note 8 ) and severance related expenses associated with workforce reductions of $4 million . Nine Months Ended September 30, 2016 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 1,714 $ 407 $ 572 $ (89 ) (c) $ 2,604 Marketing revenues 128 74 25 — 227 Total revenues 1,842 481 597 (89 ) 2,831 Income from equity method investments — 110 — — 110 Net gain on disposal of assets and other income 22 20 1 277 (d) 320 Less: Production expenses 376 156 441 — 973 Marketing costs 129 72 25 — 226 Exploration expenses 90 20 7 179 (e) 296 Depreciation, depletion and amortization 1,363 184 181 36 1,764 Impairments 1 — — 47 (f) 48 Other expenses (a) 300 56 25 400 (g) 781 Taxes other than income 112 — 13 1 126 Net interest and other — — — 258 258 Income tax provision (benefit) (183 ) 5 (23 ) (241 ) (442 ) Segment income (loss) / Net income (loss) $ (324 ) $ 118 $ (71 ) $ (492 ) $ (769 ) Capital expenditures (b) $ 684 $ 62 $ 28 $ 11 $ 785 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized loss on commodity derivative instruments. (d) Primarily related to net gain on disposal of assets (see Note 6 ). (e) Primarily associated with impairments associated with decision to not drill remaining Gulf of Mexico undeveloped leases (see Note 13 ). (f) Proved property impairments (see Note 14 ). (g) Includes termination payment on our Gulf of Mexico deepwater drilling rig contract of $ 113 million and includes pension settlement loss of $93 million and severance related expenses associated with workforce reductions of $8 million (see Note 8 ). Nine Months Ended September 30, 2015 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 2,639 $ 575 $ 614 $ 59 (c) $ 3,887 Marketing revenues 345 81 45 — 471 Total revenues 2,984 656 659 59 4,358 Income (loss) from equity method investments — 110 — (12 ) (d) 98 Net gain (loss) on disposal of assets and other income 17 20 1 (108 ) (e) (70 ) Less: Production expenses 560 192 548 — 1,300 Marketing costs 348 79 44 — 471 Exploration expenses 148 85 — 553 (f) 786 Depreciation, depletion and amortization 1,866 214 173 36 2,289 Impairments — — 4 377 (g) 381 Other expenses (a) 322 67 26 330 (h) 745 Taxes other than income 170 — 15 6 191 Net interest and other — — — 180 180 Income tax provision (benefit) (146 ) 56 (43 ) (413 ) (i) (546 ) Segment income (loss) / Net income (loss) $ (267 ) $ 93 $ (107 ) $ (1,130 ) $ (1,411 ) Capital expenditures (b) $ 2,048 $ 275 $ 26 $ 26 $ 2,375 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized gain on commodity derivative instruments. (d) Partial impairment of investment in equity-method investee (see Note 14). (e) Includes loss on sale of East Africa exploration acreage (see Note 6 .). (f) Unproved property impairments associated with lower forecasted commodity prices and change in conventional exploration strategy (see Note 13 ). (g) Proved property impairments (See Note 14 ). (h) Includes pension settlement loss of $ 99 million (see Note 8) and severance related expenses associated with workforce reductions of $47 million . (i) Includes $135 million of deferred tax expense related to Alberta provincial corporate tax rate increase (see Note 9 ).

Defined Benefit Postretiremen31

Defined Benefit Postretirement Plans (Tables)	9 Months Ended
Defined Benefit Postretirement Plans (Tables)	Sep. 30, 2016
Defined Benefit Postretirement Plans Disclosure [Abstract]
Schedule of Defined Benefit Plans Disclosures [Table Text Block]	The following summarizes the components of net periodic benefit cost: Three Months Ended September 30, Pension Benefits Other Benefits (In millions) 2016 2015 2016 2015 Service cost $ 6 $ 11 $ 1 $ — Interest cost 9 12 3 3 Expected return on plan assets (12 ) (17 ) — — Amortization: – prior service cost (credit) (2 ) (3 ) (1 ) (1 ) – actuarial loss 4 5 — 1 Net settlement loss (a) 14 18 — — Net curtailment loss (b) — 4 — — Net periodic benefit cost $ 19 $ 30 $ 3 $ 3 Nine Months Ended September 30, Pension Benefits Other Benefits (In millions) 2016 2015 2016 2015 Service cost $ 18 $ 35 $ 3 $ 2 Interest cost 30 39 8 8 Expected return on plan assets (40 ) (53 ) — — Amortization: – prior service cost (credit) (7 ) (4 ) (3 ) (3 ) – actuarial loss 11 19 — 1 Net settlement loss (a) 93 99 — — Net curtailment loss (gain) (b) — 5 — (4 ) Net periodic benefit cost $ 105 $ 140 $ 8 $ 4 (a) Settlements are recognized as they occur, once it is probable that lump sum payments from a plan for a given year will exceed the plan's total service and interest cost for that year. (b) Related to workforce reductions, which reduced the future expected years of service for employees participating in the plans

Income Taxes Effective Income T

Income Taxes Effective Income Tax Rates (Tables)	3 Months Ended		9 Months Ended
Income Taxes Effective Income Tax Rates (Tables)	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Income Tax Disclosure [Abstract]
Effective Income Tax Rate [Table Text Block]			For the three-month and nine-month periods in 2016 and 2015, our effective income tax rates were as follows: 2016 2015 Three months ended September 30 34 % 35 % Nine months ended September 30 37 % 28 %
Summary of Effective Income Tax Rates	34.00%	35.00%	37.00%	28.00%

Inventories (Tables)

Inventories (Tables)	9 Months Ended
Inventories (Tables)	Sep. 30, 2016
Inventory Disclosure [Abstract]
Schedule of Inventory, Current [Table Text Block]	September 30, December 31, (In millions) 2016 2015 Liquid hydrocarbons, natural gas and bitumen $ 26 $ 35 Supplies and other items 195 278 Inventories, at cost $ 221 $ 313

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	9 Months Ended
Property, Plant and Equipment (Tables)	Sep. 30, 2016
Property, Plant and Equipment [Abstract]
Schedule Of Property Plant And Equipment [Table Text Block]	September 30, December 31, (In millions) 2016 2015 North America E&P $ 14,391 $ 15,226 International E&P 2,440 2,533 Oil Sands Mining 9,043 9,197 Corporate 102 105 Net property, plant and equipment $ 25,976 $ 27,061

Impairments and Exploration E35

Impairments and Exploration Expense (Tables)	9 Months Ended
Impairments and Exploration Expense (Tables)	Sep. 30, 2016
Proved Properties Impairment Expense [Abstract]
Details of Impairment of Long-Lived Assets Held and Used by Asset [Table Text Block]	The following table summarizes impairment charges of proved properties: Three Months Ended September 30, Nine Months Ended September 30, (in millions) 2016 2015 2016 2015 Total impairments $ 47 $ 337 $ 48 $ 381
Exploration Expenses [Table Text Block]	The following table summarizes the components of exploration expenses: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2016 2015 2016 2015 Exploration Expenses Unproved property impairments $ 28 $ 563 $ 172 $ 612 Dry well costs 9 (3 ) 31 96 Geological and geophysical 1 8 1 23 Other 45 17 92 55 Total exploration expenses $ 83 $ 585 $ 296 $ 786

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
Fair Value Measurements (Tables)	Sep. 30, 2016
Fair Value Disclosures [Abstract]
Forward Starting Interest Rate Swap Agreements by Maturity [Table Text Block]	The following table presents, by maturity date, information about our forward starting interest rate swap agreements, including the rate. September 30, 2016 Aggregate Notional Amount Weighted Average, LIBOR Maturity Dates (in millions) Fixed Rate March 15, 2018 $750 1.57%
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2016 and December 31, 2015 by fair value hierarchy level. September 30, 2016 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ — $ 4 $ — $ 4 Interest rate — 10 — 10 Derivative instruments, assets $ — $ 14 $ — $ 14 Derivative instruments, liabilities Commodity (a) $ — $ 43 $ — $ 43 Derivative instruments, liabilities $ — $ 43 $ — $ 43 (a) Derivative instruments are recorded on a net basis in our balance sheet (see Note 15 ). December 31, 2015 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ — $ 51 $ — $ 51 Interest rate — 8 — 8 Derivative instruments, assets $ — $ 59 $ — $ 59 Derivative instruments, liabilities Commodity (a) $ — $ 1 $ — $ 1 Derivative instruments, liabilities $ — $ 1 $ — $ 1
Fair Value, by Balance Sheet Grouping [Table Text Block]	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, 2016 and December 31, 2015 . September 30, 2016 December 31, 2015 Fair Carrying Fair Carrying (In millions) Value Amount Value Amount Financial assets Other noncurrent assets $ 112 $ 118 $ 104 $ 118 Total financial assets $ 112 $ 118 $ 104 $ 118 Financial liabilities Other current liabilities $ 49 $ 59 $ 34 $ 33 Long-term debt, including current portion (a) 7,345 7,292 6,723 7,291 Deferred credits and other liabilities 123 117 97 95 Total financial liabilities $ 7,517 $ 7,468 $ 6,854 $ 7,419 (a) Excludes capital leases, debt issuance costs and interest rate swap adjustments.
Fair Value Measurements, Nonrecurring [Table Text Block]	The following table shows 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, 2016 2015 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 15 $ 47 $ 41 $ 337 Nine Months Ended September 30, 2016 2015 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 15 $ 48 $ 58 $ 381

Derivatives (Tables)

Derivatives (Tables)	9 Months Ended
Derivatives (Tables)	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives as they appear on the balance sheet [Table Text Block]	The following tables present the gross fair values of derivative instruments and the reported net amounts where they appear on the consolidated balance sheets. September 30, 2016 (In millions) Asset Liability Net Asset Balance Sheet Location Fair Value Hedges Interest rate $ 8 $ — $ 8 Other noncurrent assets Cash Flow Hedges Interest rate 2 — 2 Other noncurrent assets Total Designated Hedges $ 10 $ — $ 10 September 30, 2016 (In millions) Asset Liability Net Liability Balance Sheet Location Not Designated as Hedges Commodity $ 4 $ 30 $ 26 Other current liabilities Commodity — 13 13 Deferred credits and other liabilities Total Not Designated as Hedges $ 4 $ 43 $ 39 December 31, 2015 (In millions) Asset Liability Net Asset Balance Sheet Location Fair Value Hedges Interest rate $ 8 $ — $ 8 Other noncurrent assets Not Designated as Hedges Commodity $ 51 $ 1 $ 50 Other current assets
Schedule of Interest Rate Derivatives [Table Text Block]	The following table presents, by maturity date, information about our interest rate swap agreements, including the weighted average, London Interbank Offer Rate (“LIBOR”)-based, floating rate. September 30, 2016 December 31, 2015 Aggregate Notional Amount Weighted Average, LIBOR-Based, Aggregate Notional Amount Weighted Average, LIBOR-Based, Maturity Dates (in millions) Floating Rate (in millions) Floating Rate October 1, 2017 $ 600 5.01 % $ 600 4.73 % March 15, 2018 $ 300 4.86 % $ 300 4.66 %
Effects of derivatives designated as fair value hedges [Table Text Block]	Gain (Loss) Three Months Ended September 30, Nine Months Ended September 30, (In millions) Income Statement Location 2016 2015 2016 2015 Derivative Interest rate Net interest and other $ (4 ) $ 4 $ — $ 7 Hedged Item Long-term debt Net interest and other $ 4 $ (4 ) $ — $ (7 )
Forward Starting Interest Rate Swap Agreements by Maturity [Table Text Block]	The following table presents, by maturity date, information about our forward starting interest rate swap agreements, including the rate. September 30, 2016 Aggregate Notional Amount Weighted Average, LIBOR Maturity Dates (in millions) Fixed Rate March 15, 2018 $750 1.57%
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) [Table Text Block]	The following table sets forth the net impact of the derivatives designated as cash flow hedges on other comprehensive income (loss). Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2016 2015 2016 2015 Cash Flow Hedges Beginning balance $ — $ — $ — $ — Change in fair value recognized in other comprehensive income 2 — 2 — Reclassification from other comprehensive income — — — — Ending balance $ 2 $ — $ 2 $ —
Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block]	These commodity derivatives were not designated as hedges. The following table sets forth outstanding derivative contracts as of September 30, 2016 and the weighted average prices for those contracts: Crude Oil 2016 2017 Fourth Quarter First Quarter Second Quarter Third Quarter Fourth Quarter Three-Way Collars (a) Volume (Bbls/day) 47,000 30,000 30,000 — — Price per Bbl: Ceiling $55.37 $58.19 $58.19 — — Floor $50.23 $49.33 $49.33 — — Sold put $40.96 $42.67 $42.67 — — Sold call options (b) Volume (Bbls/day) 10,000 35,000 35,000 35,000 35,000 Price per Bbl $72.39 $61.91 $61.91 $61.91 $61.91 Two-way Collars Volume (Bbls/day) 10,000 — — — — Price per Bbl: Ceiling $50.00 — — — — Floor $41.55 — — — — (a) Subsequent to September 30, 2016, we entered into 10,000 Bbls/day of three-way collars for January - June 2017 with a ceiling price of $58.27 , a floor price of $49.50 , and a sold put price of $42.50 . (b) Call options settle monthly. Natural Gas 2016 2017 Fourth Quarter First Quarter Second Quarter Third Quarter Fourth Quarter Three-Way Collars (a) Volume (MMBtu/day) 20,000 60,000 60,000 60,000 60,000 Price per MMBtu Ceiling $2.93 $3.46 $3.46 $3.46 $3.46 Floor $2.50 $2.84 $2.84 $2.84 $2.84 Sold put $2.00 $2.35 $2.35 $2.35 $2.35 (a) On our 2016 collars, the counterparty has the option to execute fixed-price swaps (swaptions) at a weighted average price of $2.93 per MMBtu indexed to NYMEX Henry Hub, which is exercisable on December 22, 2016. If the counterparty exercises, the term of the fixed-price swaps would be for the calendar year 2017 and, if all such options are exercised, 20,000 MMBtu per day.

Incentive Based Compensation (T

Incentive Based Compensation (Tables)	9 Months Ended
Incentive Based Compensation (Tables)	Sep. 30, 2016
Incentive Based Compensation Plans [Abstract]
Table of Incentive based compensation activity [Table Text Block]	The following table presents a summary of activity for the first nine months of 2016 : Stock Options Restricted Stock Awards & Units Number of Shares Weighted Average Exercise Price Awards Weighted Average Grant Date Fair Value Outstanding at December 31, 2015 12,665,419 $29.97 4,017,344 $30.76 Granted 1,680,000 (a) $7.22 5,247,751 $7.93 Options Exercised/Stock Vested — — (1,264,325 ) $32.52 Canceled (1,936,084 ) $23.95 (1,119,975 ) $19.92 Outstanding at September 30, 2016 12,409,335 $27.83 6,880,795 $14.79 (a) The weighted average grant date fair value of stock option awards granted was $1.97 per share.

Reclassifications out of Accu39

Reclassifications out of Accumulated Other Comprehensive Income Reclassifications out of Accumulated Other Comprehensive Income (Tables)	9 Months Ended
	Sep. 30, 2016
Reclassifications out of AccumulatedOtherComprehensiveIncome [Abstract]
Schedule of Amounts Reclassified out of Accumulated Other Comprehensive Income [Table Text Block]	The following table presents a summary of amounts reclassified from accumulated other comprehensive loss: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2016 2015 2016 2015 Income Statement Line Postretirement and postemployment plans Amortization of actuarial loss $ (4 ) $ (6 ) $ (11 ) $ (20 ) General and administrative Net settlement loss (14 ) (18 ) (93 ) (99 ) General and administrative Net curtailment loss — (4 ) — (1 ) General and administrative (18 ) (28 ) (104 ) (120 ) Income (loss) from operations 6 10 38 44 Benefit for income taxes Total reclassifications to expense $ (12 ) $ (18 ) $ (66 ) $ (76 ) Net income (loss)

Supplemental Cash Flow Inform40

Supplemental Cash Flow Information (Tables)	9 Months Ended
Supplemental Cash Flow Information (Tables)	Sep. 30, 2016
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information [Table Text Block]	Supplemental Cash Flow Information Nine Months Ended September 30, (In millions) 2016 2015 Net cash (used in) operating activities: Interest paid (net of amounts capitalized) $ (243 ) $ (200 ) Income taxes paid to taxing authorities (68 ) (174 ) Noncash investing activities: Asset retirement cost increase $ 3 $ 12 Asset retirement obligations assumed by buyer 86 23

Variable Interest Entity (Detai

Variable Interest Entity (Details) - Variable Interest Entity, Not Primary Beneficiary [Member] - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Variable Interest Entity [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage	20.00%
Recorded liability related to unconsolidated VIE	$ 2	$ 2
Maximum exposure to loss related to unconsolidated VIE	$ 483

Income per Common Share (Detail

Income per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Earnings Per Share [Abstract]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	13	13	13	13
Net income (loss)	$ (192)	$ (749)	$ (769)	$ (1,411)
Weighted average common shares outstanding, basic	847	677	809	677
Weighted average common shares outstanding, diluted	847	677	809	677
Basic:
Net income (loss), per basic share	$ (0.23)	$ (1.11)	$ (0.95)	$ (2.09)
Diluted:
Net income (loss), per diluted share	$ (0.23)	$ (1.11)	$ (0.95)	$ (2.09)

Acquisition Acquisitions (Detai

Acquisition Acquisitions (Details) $ in Millions	1 Months Ended
Acquisition Acquisitions (Details) $ in Millions	Aug. 31, 2016USD ($)	Jun. 30, 2016a
Business Combinations [Abstract]
Gas and Oil Acres, Undeveloped and Developed, Net \| a		61,000
Business Combination, Consideration Transferred \| $	$ 904

Dispositions Dispositions (Deta

Dispositions Dispositions (Details) - USD ($) $ in Millions	1 Months Ended		2 Months Ended	3 Months Ended			6 Months Ended	9 Months Ended
Dispositions Dispositions (Details) - USD ($) $ in Millions	Oct. 31, 2016	Aug. 31, 2015	Apr. 30, 2016	Sep. 30, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Sep. 30, 2016	Sep. 30, 2015
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								$ 837	$ 105
East Texas/North Louisiana and Wilburton Assets [Member]
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		$ 100
Gain (Loss) on Sale of Assets and Asset Impairment Charges		(1)				$ 44
Kenya and Ethiopia Assets [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain (Loss) on Sale of Assets and Asset Impairment Charges		$ (109)
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] \| West Texas and New Mexico [Domain]
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				$ 67
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal				55
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] \| Wyoming Upstream and Midstream Assets [Member]
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					$ 870
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] \| Wyoming Upstream and Midstream Assets Sold [Member]
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					690
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal					$ 266
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] \| Shenandoah in Gulf of Mexico, Piceance in Colorado, and West Texas [Member]
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			$ 80
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal							$ (48)
Disposal Group, Including Discontinued Operation, Working Capital Interest To Be Disposed Of			10.00%
Disposal Group, Held-for-sale, Not Discontinued Operations [Member] \| West Texas and New Mexico [Domain]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal Group, Including Discontinued Operation, Assets				171				171
Disposal Group, Including Discontinued Operation, Liabilities				4				4
Disposal Group, Held-for-sale, Not Discontinued Operations [Member] \| Wynoming Upstream and Midstream Assets HFS [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal Group, Including Discontinued Operation, Assets				105				105
Disposal Group, Including Discontinued Operation, Liabilities				$ 5				$ 5
Subsequent Event [Member] \| Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] \| West Texas and New Mexico [Domain]
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	$ 235

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions		3 Months Ended				9 Months Ended
Segment Information (Details) - USD ($) $ in Millions		Sep. 30, 2016		Sep. 30, 2015		Sep. 30, 2016		Sep. 30, 2015
Segment Reporting Information [Line Items]
Loss on Contract Termination		$ 113				$ 113
Sales and other operating revenues		1,020		$ 1,300		2,604		$ 3,887
Marketing revenues		80		84		227		471
Total revenues		1,100		1,384		2,831		4,358
Income from equity method investments		59		36		110		98
Net gain ( loss) on disposal of assets and other income		70		(97)		320		(70)
Production expenses		295		406		973		1,300
Marketing costs		80		84		226		471
Exploration Expense		83		585		296		786
Depreciation, depletion and amortization		594		717		1,764		2,289
Impairments		47		337		48		381
Other expenses	[1]	294		218		781		745
Taxes other than income		39		46		126		191
Net interest and other		87		75		258		180
Income tax provision (benefit)		(98)		(396)		(442)		(546)
Segment income (loss) /Loss from continuing operations		(192)		(749)		(769)		(1,411)
Capital expenditures	[2]	249		595		785		2,375
Deferred Income Tax Expense (Benefit)						(504)		(590)
North America Exploration and Production [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		604		796		1,714		2,639
Marketing revenues		44		57		128		345
Total revenues		648		853		1,842		2,984
Income from equity method investments		0		0		0		0
Net gain ( loss) on disposal of assets and other income		19		6		22		17
Production expenses		113		179		376		560
Marketing costs		45		56		129		348
Exploration Expense		35		22		90		148
Depreciation, depletion and amortization		443		549		1,363		1,866
Impairments		0		0		1		0
Other expenses	[1]	85		106		300		322
Taxes other than income		35		42		112		170
Net interest and other		0		0		0		0
Income tax provision (benefit)		(30)		(34)		(183)		(146)
Segment income (loss) /Loss from continuing operations		(59)		(61)		(324)		(267)
Capital expenditures	[2]	216		564		684		2,048
International Exploration and Production [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		152		182		407		575
Marketing revenues		36		25		74		81
Total revenues		188		207		481		656
Income from equity method investments		59		48		110		110
Net gain ( loss) on disposal of assets and other income		7		6		20		20
Production expenses		47		61		156		192
Marketing costs		35		25		72		79
Exploration Expense		10		10		20		85
Depreciation, depletion and amortization		66		79		184		214
Impairments		0		0		0		0
Other expenses	[1]	18		25		56		67
Taxes other than income		0		0		0		0
Net interest and other		0		0		0		0
Income tax provision (benefit)		19		32		5		56
Segment income (loss) /Loss from continuing operations		59		29		118		93
Capital expenditures	[2]	18		30		62		275
Oil Sands Mining Segment [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		239		242		572		614
Marketing revenues		0		2		25		45
Total revenues		239		244		597		659
Income from equity method investments		0		0		0		0
Net gain ( loss) on disposal of assets and other income		0		0		1		1
Production expenses		135		166		441		548
Marketing costs		0		3		25		44
Exploration Expense		0		0		7		0
Depreciation, depletion and amortization		72		76		181		173
Impairments		0		4		0		4
Other expenses	[1]	9		8		25		26
Taxes other than income		4		5		13		15
Net interest and other		0		0		0		0
Income tax provision (benefit)		4		(7)		(23)		(43)
Segment income (loss) /Loss from continuing operations		15		(11)		(71)		(107)
Capital expenditures	[2]	12		(11)		28		26
Corporate and Other [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	[3]	25		80		(89)		59
Marketing revenues		0		0		0		0
Total revenues		25		80		(89)		59
Income from equity method investments		0		(12)		0		(12)
Net gain ( loss) on disposal of assets and other income		44	[4]	(109)		277	[5]	(108)
Production expenses		0		0		0		0
Marketing costs		0		0		0		0
Exploration Expense		38		553		179		553
Depreciation, depletion and amortization		13		13		36		36
Impairments		47		333		47		377
Other expenses		182	[6]	79	[1]	400	[1],[7]	330	[1]
Taxes other than income		0		(1)		1		6
Net interest and other		87		75		258		180
Income tax provision (benefit)		(91)		(387)		(241)		(413)
Segment income (loss) /Loss from continuing operations		(207)		(706)		(492)		(1,130)
Capital expenditures	[2]	3		12		11		26
Workforce reduction				4		8		47
United States and Foreign Pension Plans Defined Benefit [Member]
Segment Reporting Information [Line Items]
Net settlement loss		14		18		93		99	[8]
United States and Foreign Pension Plans Defined Benefit [Member] \| Corporate and Other [Member]
Segment Reporting Information [Line Items]
Net settlement loss	[8]	$ 14		$ 18		$ 93
Alberta Government [Member] \| Foreign Tax Authority [Member]
Segment Reporting Information [Line Items]
Deferred Foreign Income Tax Expense (Benefit)								$ 135

[1]	Includes other operating expenses and general and administrative expenses.
[2]	Includes accruals.
[3]	Unrealized loss on commodity derivative instruments.
[4]	(see Note 6)
[5]	elated to net gain on disposal of assets (see Note 6)
[6]	Includes termination payment on our Gulf of Mexico deepwater drilling rig contract of $113 million and pension settlement loss of $14 million (see Note 8).
[7]	includes pension settlement loss of $93 million and severance related expenses associated with workforce reductions of $8 million (see Note 8)
[8]	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.

Defined Benefit Postretiremen46

Defined Benefit Postretirement Plans (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended	9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2016	Sep. 30, 2016	Sep. 30, 2015
Pension and Other Postretirement Benefit Contributions [Abstract]
Pension Contributions					$ 48
Defined Benefit Plan, Benefits Paid					47
Other Postretirement Benefits Payments					16
Scenario, Forecast [Member]
Pension and Other Postretirement Benefit Contributions [Abstract]
Defined Benefit Plan, Estimated Future Employer Contributions in Current Fiscal Year				$ 16
United States and Foreign Pension Plans Defined Benefit [Member]
Defined Benefit Plan Net Periodic Benefit Cost [Line Items]
Service cost		$ 6	$ 11		18	$ 35
Interest cost		9	12		30	39
Expected return on plan assets		(12)	(17)		(40)	(53)
Amortization:
- prior service cost (credit)		(2)	(3)		(7)	(4)
-actuarial loss (gain)		4	5		11	19
Net settlement loss		14	18		93	99	[1]
Defined Benefit Plan, Curtailments		0	4		0	5
Net periodic benefit cost		19	30		105	140
Other Postretirement Benefit Plans Defined Benefit [Member]
Defined Benefit Plan Net Periodic Benefit Cost [Line Items]
Service cost		1	0		3	2
Interest cost		3	3		8	8
Expected return on plan assets		0	0		0	0
Amortization:
- prior service cost (credit)		(1)	(1)		(3)	(3)
-actuarial loss (gain)		0	1		0	1
Net settlement loss	[1]	0	0		0	0
Defined Benefit Plan, Curtailments		0	0		0	(4)
Net periodic benefit cost		$ 3	$ 3		$ 8	$ 4

[1]	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.

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
Income Taxes (Details) - USD ($) $ in Millions	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Jun. 29, 2016
Income Tax Contingency [Line Items]
Effective income tax rate excluding Libya	30.00%	35.00%	35.00%	27.00%
Reduction in Deferred Tax Asset	$ 6
Foreign Tax Authority [Member] \| Alberta Government [Member]
Income Tax Contingency [Line Items]
Effective Income Tax Rate Reconciliation, Provincial Corporate Tax Rate	12.00%		12.00%		10.00%
Deferred Foreign Income Tax Expense (Benefit)				$ 135

Income Taxes Effective Income48

Income Taxes Effective Income Tax Rates (Details)	3 Months Ended		9 Months Ended
Income Taxes Effective Income Tax Rates (Details)	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Effective Income Tax Rate Table [Abstract]
Summary of Effective Income Tax Rates	34.00%	35.00%	37.00%	28.00%

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Inventory Disclosure [Abstract]
Liquid hydrocarbons natural gas and bitumen	$ 26	$ 35
Supplies and other items	195	278
Total inventories, at cost	$ 221	$ 313

Property, Plant and Equipment50

Property, Plant and Equipment (Details) Boe in Millions, $ in Millions	Sep. 30, 2016USD ($)	Dec. 31, 2015USD ($)Boe
Segment Reporting Information [Line Items]
Property, plant and equipment, net	$ 25,976	$ 27,061
LIBYAN ARAB JAMAHIRIYA
Segment Reporting Information [Line Items]
Property, plant and equipment, net	770
Proved Developed and Undeveloped Reserves, Net (BOE) \| Boe		235
North America Exploration and Production [Member]
Segment Reporting Information [Line Items]
Property, plant and equipment, net	14,391	$ 15,226
International Exploration and Production [Member]
Segment Reporting Information [Line Items]
Property, plant and equipment, net	2,440	2,533
Oil Sands Mining Segment [Member]
Segment Reporting Information [Line Items]
Property, plant and equipment, net	9,043	9,197
Corporate [Member]
Segment Reporting Information [Line Items]
Property, plant and equipment, net	$ 102	$ 105

Property, Plant and Equipment P

Property, Plant and Equipment Property, Plant and Equipment (Details 2) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Capitalized Exploratory Well Costs [Abstract]
Capitalized Exploratory Well Costs that Have Been Capitalized for Period Greater than One Year After Completion of Drilling	$ 118	$ 85
Capitalized Exploratory Well Cost, Period Increase (Decrease)	$ 33

Impairments and Exploration E52

Impairments and Exploration Expense Exploration Expenses (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Exploration Expenses [Line Items]
Impairment Expense - Proved Properties	$ 47	$ 337	$ 48	$ 381
Exploration Expense	83	585	296	786
Corporate and Other [Member]
Exploration Expenses [Line Items]
Exploration Expense	38	553	179	553
Corporate and Other [Member] \| Gulf of Mexico, Kurdistan and Colorado [Member]
Exploration Expenses [Line Items]
Exploration Expense			118	553
Unproved Property Impairments [Member]
Exploration Expenses [Line Items]
Exploration Expense	28	563	172	612
Dry Well Costs [Member]
Exploration Expenses [Line Items]
Exploration Expense	9	(3)	31	96
Geological and Geophysical [Member]
Exploration Expenses [Line Items]
Exploration Expense	1	8	1	23
Other Exploration Expenses [Member]
Exploration Expenses [Line Items]
Exploration Expense	$ 45	$ 17	$ 92	$ 55

Impairments and Exploration E53

Impairments and Exploration Expense Impairment Expense (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Impairment Expense [Abstract]
Impairment Expense - Proved Properties	$ 47	$ 337	$ 48	$ 381

Fair Value Measurements (Detail

Fair Value Measurements (Details-Recurring) - USD ($) $ in Millions		Sep. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Goodwill		$ 115	$ 115
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets		14	59
Derivative Liability		43	1
Fair Value, Measurements, Recurring [Member] \| Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets	[1]	4	51
Derivative Liability	[1]	43	1
Fair Value, Measurements, Recurring [Member] \| Interest rate [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets		10	8
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets		0	0
Derivative Liability		0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member] \| Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets	[1]	0	0
Derivative Liability	[1]	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member] \| Interest rate [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets		0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value Inputs Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets		14	59
Derivative Liability		43	1
Fair Value, Measurements, Recurring [Member] \| Fair Value Inputs Level 2 [Member] \| Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets	[1]	4	51
Derivative Liability	[1]	43	1
Fair Value, Measurements, Recurring [Member] \| Fair Value Inputs Level 2 [Member] \| Interest rate [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets		10	8
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets		0	0
Derivative Liability		0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member] \| Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets	[1]	0	0
Derivative Liability	[1]	0	0
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member] \| Interest rate [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Derivative Assets		$ 0	$ 0

[1]	Derivative instruments are recorded on a net basis in our balance sheet (see Note 15).

Fair Value Measurements (Deta55

Fair Value Measurements (Details 2-Nonrecurring) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Jun. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Impairments	$ 47	$ 337		$ 48	$ 381
Assets, Fair Value Adjustment			$ 44
Goodwill, Impairment Loss				0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Property, Plant, and Equipment, Fair Value Disclosure	15	58		15	58
Assets, Fair Value Adjustment	$ 47	337		$ 48	381
Property, Plant, and Equipment, Fair Value Disclosure, Quarter to Date		41			41
Gulf of Mexico Assets [Member] \| Fair Value, Measurements, Nonrecurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Property, Plant, and Equipment, Fair Value Disclosure		41			41
Gulf of Mexico Assets [Member] \| Fair Value, Measurements, Nonrecurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Impairments		333
EG Equity Method Investment [Member] \| Fair Value, Measurements, Nonrecurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Property, Plant, and Equipment, Fair Value Disclosure		604			$ 604
EG Equity Method Investment [Member] \| Fair Value, Measurements, Nonrecurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items]
Assets, Fair Value Adjustment		$ 12

Fair Value Measurements Fair Va

Fair Value Measurements Fair Value Measurements - Forward Starting Interest Rate Swaps (Details) $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)
Fair Value Disclosures [Abstract]
Derivative, Maturity Date	Mar. 15, 2018
Derivative, Notional Amount	$ 750
Derivative, Fixed Interest Rate	1.57%

Fair Value Measurements (Deta57

Fair Value Measurements (Details 3-Reported) - USD ($) $ in Millions		Sep. 30, 2016	Dec. 31, 2015
Fair Value [Member]
Financial Instruments, Financial Assets, Balance Sheet Groupings [Abstract]
Other noncurrent financial assets		$ 112	$ 104
Total financial assets		112	104
Financial liabilities
Other current financial liabilities		49	34
Long-term debt, including current portion	[1]	7,345	6,723
Deferred credits and other financial liabilities		123	97
Financial Liabilities Fair Value Disclosure		7,517	6,854
Carrying Amount [Member]
Financial Instruments, Financial Assets, Balance Sheet Groupings [Abstract]
Other noncurrent financial assets		118	118
Total financial assets		118	118
Financial liabilities
Other current financial liabilities		59	33
Long-term debt, including current portion	[1]	7,292	7,291
Deferred credits and other financial liabilities		117	95
Financial Liabilities Fair Value Disclosure		$ 7,468	$ 7,419

[1]	Excludes capital leases, debt issuance costs and interest rate swap adjustments.

Derivatives (Details-BS)

Derivatives (Details-BS) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Designated as Hedging Instrument [Member]
Derivatives Fair Value [Line Items]
Derivative Instruments in Hedges, Assets, at Fair Value	$ 10
Derivative Instruments in Hedges, Liabilities, at Fair Value	0
Derivative Instruments in Hedges, at Fair Value, Net	10
Not Designated as Hedging Instrument [Member]
Derivatives Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	43
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	39
Derivative Liability, Fair Value, Gross Asset	4
Commodity Contract [Member] \| Other Noncurrent Assets [Member] \| Not Designated as Hedging Instrument [Member]
Derivatives Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	13
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	13
Derivative Liability, Fair Value, Gross Asset	0
Commodity Contract [Member] \| Other Current Liabilities [Member] \| Not Designated as Hedging Instrument [Member]
Derivatives Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	30
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	26
Derivative Liability, Fair Value, Gross Asset	4
Commodity Contract [Member] \| Other Current Assets [Member] \| Not Designated as Hedging Instrument [Member]
Derivatives Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		$ 51
Derivative Asset, Fair Value, Gross Liability		1
Derivative Asset, Fair Value, Net		50
Fair Value Hedging [Member] \| Interest rate [Member] \| Other Noncurrent Assets [Member] \| Designated as Hedging Instrument [Member]
Derivatives Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	8	8
Derivative Asset, Fair Value, Gross Liability	0	0
Derivative Asset, Fair Value, Net	8	$ 8
Cash Flow Hedging [Member] \| Interest rate [Member] \| Other Noncurrent Assets [Member] \| Designated as Hedging Instrument [Member]
Derivatives Fair Value [Line Items]
Derivative Asset, Fair Value, Net	2
Cash Flow Hedging [Member] \| Interest rate [Member] \| Other Noncurrent Liabilities [Member] \| Designated as Hedging Instrument [Member]
Derivatives Fair Value [Line Items]
Interest Rate Cash Flow Hedge Liability at Fair Value	$ 0

Derivatives (Details 2-Fair Val

Derivatives (Details 2-Fair Value Hedges) - Fair Value Hedging [Member] - Designated as Hedging Instrument [Member] - Interest Rate Contract [Member] - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Debentures Due 2017 [Member]
Derivative [Line Items]
Derivative, Notional Amount	$ 600	$ 600
Weighted-average, LIBOR-based, floating rate	5.01%	4.73%
Debentures Due 2018 [Member]
Derivative [Line Items]
Derivative, Notional Amount	$ 300	$ 300
Weighted-average, LIBOR-based, floating rate	4.86%	4.66%

Derivatives (Details 3-Fair Val

Derivatives (Details 3-Fair Value Hedges IS & OCI) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on Fair Value Hedge Ineffectiveness, Net			$ 0	$ 0
Cash Flow Hedge Ineffectiveness is Immaterial			0
Derivative, Gain (Loss) on Derivative, Net	$ 0		$ 0
Net interest and other [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Change in unrealized gain (loss) on hedged item in fair value hedge	4	$ (4)	0	$ (7)
Interest rate [Member] \| Net interest and other [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative instruments recognized in income	$ (4)	$ 4	$ 0	$ 7

Derivatives Derivatives (Detail

Derivatives Derivatives (Details 4-Non Hedges Commodity) (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016USD ($)MMBTUMMBTU_per_dayBBL / DaysBbls_per_day$ / MMBTU$ / bbl	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)MMBTUMMBTU_per_dayBBL / DaysBbls_per_day$ / MMBTU$ / bbl	Sep. 30, 2015USD ($)	Oct. 05, 2016MMBTU_per_day$ / bbl
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net \| $	$ 0		$ 0
Derivative Cash Settlements Received - Commodity \| $	$ 8	$ 18	$ 54	$ 23
Crude Oil Three-Way Collars [Domain]
Derivative [Line Items]
Volume \| MMBTU_per_day					10,000
Ceiling Price					58.27
Floor Price					49.50
Sold Put Price					42.50
Crude Oil Three-Way Collars For Third Quarter of Year 1 [Member]
Derivative [Line Items]
Volume \| BBL / Days	47,000		47,000
Ceiling Price	55.37		55.37
Floor Price	50.23		50.23
Sold Put Price	40.96		40.96
Crude Oil Three-Way Collars for Fourth Quarter of Year 1
Derivative [Line Items]
Volume \| BBL / Days	30,000		30,000
Ceiling Price	58.19		58.19
Floor Price	49.33		49.33
Sold Put Price	42.67		42.67
Crude Oil Three-Way Collars For Year 2 [Member]
Derivative [Line Items]
Volume \| BBL / Days	0		0
Ceiling Price	0		0
Floor Price	0		0
Sold Put Price	0		0
Crude Oil Options For the Third Quarter of Year 1 [Member]
Derivative [Line Items]
Volume \| Bbls_per_day	10,000		10,000
Option Price	72.39		72.39
Crude Oil Options For the Fourth Quarter of Year 1 [Member]
Derivative [Line Items]
Volume \| Bbls_per_day	35,000		35,000
Option Price	61.91		61.91
Crude Oil Options For Year 2 [Member]
Derivative [Line Items]
Volume \| Bbls_per_day	35,000		35,000
Option Price	61.91		61.91
Crude Oil Swaps For the Third Quarter of Year 1 [Member]
Derivative [Line Items]
Volume \| BBL / Days	10,000		10,000
Ceiling Price	50		50
Floor Price	41.55		41.55
Crude Oil Swaps For the Fourth Quarter of Year 1 [Member]
Derivative [Line Items]
Volume \| BBL / Days	0		0
Ceiling Price	0		0
Floor Price	0		0
Crude Oil Swaps For Year 2 [Member]
Derivative [Line Items]
Volume \| BBL / Days	0		0
Option Price	0		0
Natural Gas Three-Way Collars For the Third Quarter of Year 1 [Member]
Derivative [Line Items]
Volume \| MMBTU	20,000		20,000
Ceiling Price \| $ / MMBTU	2.93		2.93
Floor Price \| $ / MMBTU	2.50		2.50
Sold Put Price \| $ / MMBTU	2		2
Natural Gas Three-Way Collars For the Fourth Quarter of Year 1 [Member]
Derivative [Line Items]
Volume \| MMBTU	60,000		60,000
Ceiling Price \| $ / MMBTU	3.46		3.46
Floor Price \| $ / MMBTU	2.84		2.84
Sold Put Price \| $ / MMBTU	2.35		2.35
Natural Gas Three-Way Collars For Year 2 [Member]
Derivative [Line Items]
Volume \| MMBTU	60,000		60,000
Ceiling Price \| $ / MMBTU	3.46		3.46
Floor Price \| $ / MMBTU	2.84		2.84
Sold Put Price \| $ / MMBTU	2.35		2.35
Swaption [Member]
Derivative [Line Items]
Swap Price	2.93		2.93
Volume \| MMBTU_per_day	20,000		20,000
Sales and other operating revenues [Member] \| Not Designated as Hedging Instrument [Member] \| Commodity [Member]
Derivative [Line Items]
Derivative, Gain (Loss) on Derivative, Net \| $		$ (108)		$ (91)

Derivatives Derivatives (Deta62

Derivatives Derivatives (Details 5-Non Hedges) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 0		$ 0
Net cash received (paid) in settlement of derivative instruments		$ 4	51	$ 18
Derivative Cash Settlements Received - Commodity	$ 8	18	$ 54	23
Not Designated as Hedging Instrument [Member] \| Commodity [Member] \| Sales and other operating revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		$ (108)		$ (91)

Derivatives Derivatives (Deta63

Derivatives Derivatives (Details - 6 Cash Flow Hedges) (Details) $ in Millions	Sep. 30, 2016USD ($)
Derivatives, Fair Value [Line Items]
Deferred Gain on Interest Rate Cash Flow Hedges	$ 1
Cash Flow Hedging [Member] \| Interest Rate Contract [Member] \| Designated as Hedging Instrument [Member] \| Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Interest Rate Cash Flow Hedge Liability at Fair Value	$ 0

Derivatives Cash Flow Hedges -

Derivatives Cash Flow Hedges - OCI Impact (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Reclassification Adjustment out of Accumulated Other Comprehensive Income on Derivatives [Line Items]
Cash Flow Hedges Derivative Instruments at Fair Value, Net	$ 2	$ 0	$ 2	$ 0	$ 0	$ 0	$ 0	$ 0
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	2	0	$ 2	0
Reclassification from Other Comprehensive Income	$ 0	$ 0		$ 0

Incentive Based Compensation (D

Incentive Based Compensation (Details 1-Restricted) - $ / shares		9 Months Ended
		Sep. 30, 2016	Dec. 31, 2015
Incentive Based Compensation Plans [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value		$ 1.97
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Net of Forfeitures	[1]	1,680,000
Share-based Compensation Arrangements by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price		$ 7.22
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number		12,409,335	12,665,419
Restricted Stock
Beginning year unvested restricted stock		4,017,344
Granted restricted stock		5,247,751
Vested restricted stock		(1,264,325)
Forfeited restricted stock		(1,119,975)
End of period unvested restricted stock		6,880,795
Beginning year weighted average grant date fair value unvested restricted stock		$ 30.76
Granted restricted stock weighted average grant date fair value restricted stock		7.93
Vested restricted stock weighted average grant date fair value restricted stock		32.52
Forfeited restricted stock weighted average grant date fair value restricted stock		19.92
End of period weighted average grant date fair value unvested restricted stock		$ 14.79
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period		0
Share-based Compensation Arrangements by Share-based Payment Award, Options, Exercises in Period, Weighted Average Exercise Price		$ 0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period		1,936,084
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price		$ 23.95
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price		$ 27.83	$ 29.97

[1]	The weighted average grant date fair value of stock option awards granted was $1.97 per share.

Incentive Based Compensation 66

Incentive Based Compensation (Details 2-Performance) - $ / shares	1 Months Ended	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 14.79	$ 14.79	$ 30.76
Performance Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award Instruments Other Than Options Performance Unit Granted		1,205,517
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 3.72	$ 3.72
Share Based Awards NonCash Compensation- Cancellation	377,857

Debt - Revolving Credit Facilit

Debt - Revolving Credit Facility (Details)	Sep. 30, 2016USD ($)	Feb. 29, 2016USD ($)	Nov. 01, 2015USD ($)	Sep. 30, 2015USD ($)
Line of Credit Facility [Line Items]
Line of Credit Facility, maximum borrowing capacity	$ 3,300,000,000	$ 3,000,000,000
Line of Credit Facility, increase in borrowing capacity	$ 300,000,000
Ratio of indebtedness to net capital	0.28
Maximum [Member]
Line of Credit Facility [Line Items]
Ratio of indebtedness to net capital	0.65
Unsecured Debt [Member]
Line of Credit Facility [Line Items]
Principal amount				$ 2,000,000,000
Senior Notes 0.90% [Member]
Line of Credit Facility [Line Items]
Principal amount			$ 1,000,000,000
Interest rate			0.90%

Reclassifications out of Accu68

Reclassifications out of Accumulated Other Comprehensive Income Reclassifications out of Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Provision for income taxes	$ 98	$ 396	$ 442	$ 546
Other insignificant, net of tax	(189)	(93)	(393)	(281)
Net income (loss)	(192)	(749)	(769)	(1,411)
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of actuarial loss	(4)	(6)	(11)	(20)
Net settlement loss	(14)	(18)	(93)	(99)
Net curtailment gain (loss)	0	(4)	0	(1)
Income before income taxes	(18)	(28)	(104)	(120)
Provision for income taxes	6	10	38	44
Net income (loss)	$ (12)	$ (18)	$ (66)	$ (76)

Stockholders' Equity (Details)

Stockholders' Equity (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended
	Mar. 31, 2016	Sep. 30, 2016	Dec. 31, 2015
Stockholders' Equity Attributable to Parent [Abstract]
Shares Issued, Price Per Share	$ 7.65
Stock Issued During Period, Shares, New Issues	166,750,000
Common Stock, Par or Stated Value Per Share	$ 1	$ 1	$ 1
Stock Issued	$ 1,236

Supplemental Cash Flow Inform70

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Net cash provided by (used in) operating activities included:
Interest paid (net of amounts capitalized)	$ (243)	$ (200)
Income taxes paid to taxing authorities	(68)	(174)
Noncash investing activities:
Asset retirement costs capitalized	3	12
Asset retirement obligations assumed by buyer	$ 86	$ 23