Newfield Exploration (NFX) 10-K 21 Feb 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Feb. 16, 2017	Jun. 30, 2016
Document and Entity Information [Abstract]
Entity Registrant Name	NEWFIELD EXPLORATION CO /DE/
Entity Central Index Key	912,750
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$ 8,654,807,040
Entity Common Stock, Shares Outstanding		198,963,323

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 555	$ 5
Short-term investments	25	0
Accounts receivable, net	232	262
Inventories	16	34
Derivative assets	75	284
Other current assets	46	40
Total current assets	949	625
Oil and gas properties, net — full cost method ($1,238 and $780 were excluded from amortization at December 31, 2016 and 2015, respectively)	3,140	3,819
Other property and equipment, net	167	172
Derivative assets	0	105
Long-term investments	19	20
Restricted cash	25	13
Other assets	12	14
Total assets	4,312	4,768
Current liabilities:
Accounts payable	33	41
Accrued liabilities	498	533
Advances from joint owners	54	58
Asset retirement obligations	2	2
Derivative liabilities	97	13
Total current liabilities	684	647
Other liabilities	63	48
Derivative liabilities	3	9
Long-term debt	2,431	2,467
Asset retirement obligations	154	192
Deferred taxes	39	26
Total long-term liabilities	2,690	2,742
Stockholders' equity:
Preferred stock ($0.01 par value, 5,000,000 shares authorized; no shares issued)	0	0
Common stock ($0.01 par value, 300,000,000 shares authorized at December 31, 2016 and 2015; 200,150,392 and 164,102,786 shares issued at December 31, 2016 and 2015, respectively)	2	2
Additional paid-in capital	3,247	2,436
Treasury stock (at cost, 1,195,809 and 612,469 shares at December 31, 2016 and 2015, respectively)	(44)	(22)
Accumulated other comprehensive income (loss)	(2)	(2)
Retained earnings (deficit)	(2,265)	(1,035)
Total stockholders’ equity	938	1,379
Total liabilities and stockholders’ equity	$ 4,312	$ 4,768

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
ASSETS
Property and Equipment, at cost	$ 1,238,000,000	$ 780,000,000
Stockholders' equity:
Preferred stock ($0.01 par value)	$ 0.01	$ 0.01
Preferred stock (5,000,000 shares authorized)	5,000,000	5,000,000
Preferred stock (no shares issued)	0	0
Common stock ($0.01 par value)	$ 0.01	$ 0.01
Common stock, shares authorized	300,000,000	300,000,000
Common stock, shares issued	200,150,392	164,102,786
Treasury Stock, shares	1,195,809	612,469
Commitments and contingencies	$ 0	$ 0

Consolidated Statement of Opera

Consolidated Statement of Operations - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating expenses:
Depreciation, depletion and amortization	$ 572	$ 917	$ 903
Ceiling test and other impairments	1,028	4,904	0
Other income (expenses):
Interest expense	(154)	(164)	(200)
Capitalized interest	51	33	53
Commodity derivative income (expense)	(191)	259	610
Other, net	5	(14)	(6)
Total other income (expense)	(289)	114	457
Income (loss) from continuing operations before income taxes	(1,208)	(4,947)	1,032
Income tax provision (benefit):
Current	9	17	5
Deferred	13	(1,602)	377
Total income tax provision (benefit)	22	(1,585)	382
Income (loss) from continuing operations	(1,230)	(3,362)	650
Income (loss) from discontinued operations, net of tax	0	0	250
Net income (loss)	$ (1,230)	$ (3,362)	$ 900
Earnings Per Share [Abstract]
Income (loss) from continuing operations	$ (6.36)	$ (21.18)	$ 4.76
Income (loss) from discontinued operations	0	0	1.83
Basic earnings (loss) per share	(6.36)	(21.18)	6.59
Income (loss) from continuing operations	(6.36)	(21.18)	4.71
Income (loss) from discontinued operations	0	0	1.81
Diluted earnings (loss) per share	$ (6.36)	$ (21.18)	$ 6.52
Weighted-average number of shares outstanding for basic earnings (loss) per share	193	159	137
Weighted-average number of shares outstanding for diluted earnings (loss) per share	193	159	138
Continuing Operations [Member]
Oil, gas and NGL revenues	$ 1,472	$ 1,557	$ 2,288
Operating expenses:
Lease operating	244	285	311
Transportation and processing	272	212	174
Production and other taxes	42	46	111
Depreciation, depletion and amortization	572	917	870
General and administrative	213	244	222
Ceiling test and other impairments	1,028	4,904	0
Other	20	10	25
Total operating expenses	2,391	6,618	1,713
Income (loss) from operations	$ (919)	$ (5,061)	$ 575

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net Income (Loss) Attributable to Parent [Abstract]
Net income (loss)	$ (1,230)	$ (3,362)	$ 900
Other comprehensive income (loss):
Unrealized gain (loss) on post-retirement benefits, net of tax of $0 for the years ended December 31, 2016 and 2015, and $2 for the year ended December 31, 2014	0	(1)	(3)
Other comprehensive income (loss), net of tax	0	(1)	(3)
Comprehensive income (loss)	$ (1,230)	$ (3,363)	$ 897

Consolidated Statement of Comp6

Consolidated Statement of Comprehensive Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent, Parenthetical Disclosures [Abstract]
Unrealized gain (loss) on post-retirement benefits tax	$ 0	$ 0	$ 2

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash flows from operating activities:
Net income (loss)	$ (1,230)	$ (3,362)	$ 900
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	572	917	903
Deferred tax provision (benefit)	13	(1,602)	509
Stock-based compensation	22	25	28
Unrealized (gain) loss on derivative contracts	392	246	(649)
Gain on sale of Malaysia business	0	0	(373)
Ceiling test and other impairments	1,028	4,904	0
Other, net	13	43	21
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	22	83	47
Increase (decrease) in accounts payable and accrued liabilities	(3)	(45)	21
Other items, net	(3)	0	(20)
Net cash provided by (used in) operating activities	826	1,209	1,387
Cash flows from investing activities:
Additions to oil and gas properties	(868)	(1,607)	(2,064)
Acquisitions of oil and gas properties	(486)	(125)	(33)
Proceeds from sales of oil and gas properties	405	90	620
Proceeds received from sale of Malaysia business, net	0	0	809
Additions to other property and equipment	(17)	(13)	(31)
Redemptions of investments	0	0	39
Proceeds from insurance settlement, net	0	57	0
Purchases of investments	(25)	0	0
Net cash provided by (used in) investing activities	(991)	(1,598)	(660)
Cash flows from financing activities:
Proceeds from borrowings under credit arrangements	536	1,908	2,949
Repayments of borrowings under credit arrangements	(575)	(2,315)	(3,152)
Proceeds from issuance of senior notes	0	691	0
Repayment of senior subordinated notes	0	(700)	(600)
Debt issue costs	0	(8)	0
Proceeds from issuances of common stock, net	779	819	6
Purchases of treasury stock, net	(22)	(12)	(11)
Other	(3)	(3)	0
Net cash provided by (used in) financing activities	715	380	(808)
Increase (decrease) in cash and cash equivalents	550	(9)	(81)
Cash and cash equivalents, beginning of period	5	14	95
Cash and cash equivalents, end of period	$ 555	$ 5	$ 14

Consolidated Statement of Stock

Consolidated Statement of Stockholders' Equity - USD ($) $ in Millions	Total	Common Stock	Treasury Stock	Additional Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Income (Loss)
Common Stock Value	$ 1
Treasury Stock, Shares	(500,000)
Treasury Stock	$ (13)
Additional paid-in capital	1,539
Retained Earnings (Accumulated Deficit)	1,427
Accumulated other comprehensive income (loss)	2
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 2,956
Common Stock, Shares, Issued	136,700,000
Stock-based compensation	$ 45			$ 45
Stock Issued During Period, Shares, Treasury Stock Reissued			(200,000)
Stock Issued During Period, Value, Treasury Stock Reissued	(11)		$ (3)	(14)
Net income (loss)	900				$ 900
Other Comprehensive Income (Loss), Net of Tax	(3)					$ (3)
Stock Issued During Period, Shares, Restricted Stock Award, Net of Forfeitures		900,000
Stock Issued During Period, Value, Restricted Stock Award, Net of Forfeitures	6	$ 0		6
Common Stock Value	$ 1
Treasury Stock, Shares	(300,000)
Treasury Stock	$ (10)
Additional paid-in capital	1,576
Retained Earnings (Accumulated Deficit)	2,327
Accumulated other comprehensive income (loss)	(1)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 3,893
Common Stock, Shares, Issued	137,600,000
Stock-based compensation	$ 42			42
Stock Issued During Period, Shares, Treasury Stock Reissued			(300,000)
Stock Issued During Period, Value, Treasury Stock Reissued	(12)		$ (12)	0
Net income (loss)	(3,362)				(3,362)
Other Comprehensive Income (Loss), Net of Tax	(1)					$ (1)
Stock Issued During Period, Shares, Restricted Stock Award, Net of Forfeitures		26,500,000
Stock Issued During Period, Value, Restricted Stock Award, Net of Forfeitures	819	$ 1		818
Common Stock Value	$ 2
Treasury Stock, Shares	(612,469)
Treasury Stock	$ (22)
Additional paid-in capital	2,436
Retained Earnings (Accumulated Deficit)	(1,035)
Accumulated other comprehensive income (loss)	(2)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 1,379
Common Stock, Shares, Issued	164,102,786
Stock-based compensation	$ 32			32
Stock Issued During Period, Shares, Treasury Stock Reissued			(600,000)
Stock Issued During Period, Value, Treasury Stock Reissued	(22)		$ (22)	0
Net income (loss)	(1,230)				$ (1,230)
Stock Issued During Period, Shares, Restricted Stock Award, Net of Forfeitures		36,100,000
Stock Issued During Period, Value, Restricted Stock Award, Net of Forfeitures	779	$ 0		$ 779
Common Stock Value	$ 2
Treasury Stock, Shares	(1,195,809)
Treasury Stock	$ (44)
Additional paid-in capital	3,247
Retained Earnings (Accumulated Deficit)	(2,265)
Accumulated other comprehensive income (loss)	(2)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 938
Common Stock, Shares, Issued	200,150,392

Organization and Summary of Sig

Organization and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Organization and Summary of Significant Accounting Policies	Organization and Principles of Consolidation We are an independent energy company engaged in the exploration, development and production of crude oil, natural gas and natural gas liquids (NGLs). Our U.S. operations are onshore and focus primarily on large scale, liquids-rich resource plays. Our principal areas of operation are the Anadarko and Arkoma basins of Oklahoma, the Williston Basin of North Dakota and the Uinta Basin of Utah. In addition, we have oil producing assets offshore China. Our consolidated financial statements include the accounts of Newfield Exploration Company, a Delaware corporation, and its subsidiaries. We proportionately consolidate our interests in oil and natural gas exploration and production ventures and partnerships in accordance with industry practice. All significant intercompany balances and transactions have been eliminated. Unless otherwise specified or the context otherwise requires, all references in these notes to "Newfield," "we," "us," "our" or the "Company" are to Newfield Exploration Company and its subsidiaries. Risks and Uncertainties As an independent oil and natural gas producer, our revenue, profitability and future rate of growth are substantially dependent on prevailing prices for oil, natural gas and NGLs. Historically, the energy markets have been very volatile, and there can be no assurance that commodity prices will not be subject to wide fluctuations in the future. A substantial or extended decline in commodity prices could have a material adverse effect on our financial position, results of operations, cash flows, access to capital and on the quantities of oil, natural gas and NGL reserves that we can economically produce. Other risks and uncertainties that could affect us in the current commodity price environment include, but are not limited to, counterparty credit risk for our receivables, responsibility for decommissioning liabilities for offshore interests we no longer own, inability to access credit markets, regulatory risks and our ability to meet financial ratios and covenants in our financing agreements. Use of Estimates The preparation of financial statements in accordance with accounting principles generally accepted in the United States of America (US GAAP) requires our management to make estimates and assumptions that affect the reported amounts of assets and liabilities; disclosure of contingent assets and liabilities at the date of the financial statements; the reported amounts of revenues and expenses during the reporting period; and the quantities and values of proved oil, natural gas and NGL reserves used in calculating depletion and assessing impairment of our oil and gas properties. Actual results could differ significantly from these estimates. Our most significant estimates are associated with the quantities of proved oil, natural gas and NGL reserves, the timing and amount of transfers of our unevaluated properties into our amortizable full cost pool, the recoverability of our deferred tax assets and the fair value of our derivative contracts. Restructuring Costs Restructuring costs include severance and related benefit costs, costs associated with abandoned office space, employee relocation costs and other associated costs. Employee severance and related benefit costs are recognized on a straight-line basis over the required service period, if any. Employee relocation costs are expensed as incurred. On the date a leased property ceases to be used, a liability for non-cancellable office-lease costs associated with restructuring is recognized and measured at fair value on our consolidated balance sheet. Fair value estimates include assumptions regarding estimated future sublease payments. These estimates could materially differ from actual results and may require revision to initial estimates of the liability. See Note 17 , " Restructuring Costs ," for additional disclosures. Reclassifications Certain reclassifications have been made to prior years’ reported amounts in order to conform to the current year presentation. These reclassifications did not impact our net income (loss), stockholders’ equity or cash flows. Discontinued Operations The results of our Malaysia operations are reflected separately as discontinued operations in the consolidated statement of operations on a line immediately after "Income (loss) from continuing operations." See Note 20 , " Discontinued Operations ," for additional disclosures, as well as information regarding the sale of our Malaysia business, which closed in February 2014. These financial statements and notes are inclusive of our Malaysia operations through the closing date unless otherwise noted. Revenue Recognition Substantially all of our oil, natural gas and NGLs are sold at market-based prices to a variety of purchasers, primarily under short-term contracts (less than 12 months). We also have long-term contracts in the Uinta Basin at market-based prices, less a variable differential that becomes fixed below certain market price thresholds. We record revenue when we deliver our production to the customer and collectability is reasonably assured. Revenues from the production of oil, natural gas and NGLs on properties in which we have joint ownership are recorded under the sales method. Under the sales method, the Company and other joint owners may sell more or less than their entitled share of production. Should the Company’s excess sales exceed our share of estimated remaining recoverable reserves, a liability is recorded. Differences between sales and our entitled share of production are not material. Foreign Currency The functional currency for our China operations is the U.S. dollar. Gains and losses incurred on transactions in a currency other than the U.S. dollar are recorded under the caption "Other income (expense) — Other, net" on our consolidated statement of operations. Cash and Cash Equivalents Cash and cash equivalents include highly liquid investments with a maturity of three months or less when acquired and are stated at cost, which approximates fair value. We invest cash in excess of near-term capital and operating requirements in U.S. Treasury Notes, Eurodollar time deposits and money market funds, which are classified as cash and cash equivalents on our consolidated balance sheet. Restricted Cash Restricted cash consists of amounts held in escrow accounts to satisfy future plug and abandonment obligations for our China operations. These amounts are restricted as to their current use and will be released as we plug and abandon wells and facilities in China. Consistent with our other plug and abandonment activities, changes in restricted cash are included in cash flows from operating activities in our consolidated statement of cash flows. Investments Our short-term investment at December 31, 2016 was a $25 million certificate of deposit, which is classified as "held-to-maturity" and stated at cost. Accordingly, no unrealized gains and losses are recognized. Long-term investments consist of debt and equity securities, a majority of which are classified as "available-for-sale" and stated at fair value. Accordingly, unrealized gains and losses and the related deferred income tax effects are excluded from earnings and reported in other comprehensive income within our consolidated statement of stockholders' equity. At December 31, 2016 , 2015 and 2014 , the portion of accumulated other comprehensive income within our consolidated statement of stockholders' equity related to investments was $1 million . Realized gains or losses are computed based on specific identification of the securities sold. We regularly assess our investments for impairment and consider any impairment to be other than temporary if we intend to sell the security, it is more likely than not that we will be required to sell the security, or we do not expect to recover our cost of the security. Allowance for Doubtful Accounts We routinely assess material trade and other receivables to determine their collectability. Many of our receivables are from joint interest owners of properties we operate. Thus, we may have the ability to withhold future revenue disbursements to recover any non-payment of related joint interest billings. Generally, our oil and gas receivables are collected within 45 to 60 days of production. We accrue a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected. Inventories Inventories primarily consist of tubular goods and well equipment held for use in our oil and natural gas operations and oil produced but not sold in our China operations. Inventories are carried at the lower of cost or market. Substantially all of the crude oil from our offshore operations in China is produced into floating storage facilities and sold periodically as barge quantities accumulate. The carrying value of oil inventory is the sum of related production costs and depletion expense. See Note 3 , " Inventories ," for further discussion. Oil and Gas Properties We use the full cost method of accounting for our oil and gas activities. Under this method, all costs incurred in the acquisition, exploration and development of oil and gas properties, including salaries, benefits, interest and other internal costs directly attributable to these activities, are capitalized into country-based cost centers. Proceeds from the sale of oil and gas properties are applied to reduce the costs in the applicable cost center unless the reduction would significantly alter the relationship between capitalized costs and proved reserves, in which case a gain or loss is recognized. During the first quarter of 2014, we sold our Malaysia business, which constituted the entire full cost pool for Malaysia. See Note 20 , " Discontinued Operations ," for further discussion. Capitalized costs and estimated future development costs are amortized using a unit-of-production method based on proved reserves associated with the applicable cost center. For each cost center, the net capitalized costs of oil and gas properties are limited to the lower of the unamortized cost or the cost center ceiling. A particular cost center ceiling is equal to the sum of: • the present value ( 10% per annum discount rate) of estimated future net revenues from proved reserves using oil, natural gas and NGL reserve estimation requirements, which require use of the unweighted average first-day-of-the-month commodity prices for the prior 12 months (SEC pricing), adjusted for market differentials applicable to our reserves (including the effects of derivative contracts that are designated for hedge accounting, if any); plus • the costs of properties not included in the costs being amortized, if any; less • related income tax effects. If net capitalized costs of oil and gas properties exceed the cost center ceiling, we are subject to a ceiling test impairment to the extent of such excess. If required, a ceiling test impairment reduces earnings and stockholders’ equity in the period of occurrence and, holding other factors constant, results in lower depreciation, depletion and amortization expense in future periods. The risk that we will be required to impair the carrying value of our oil and gas properties increases when oil, natural gas and NGL prices decrease significantly for a prolonged period, or if we have substantial downward revisions in our estimated proved reserves. Costs associated with unevaluated properties are excluded from our full cost pool until we have evaluated the properties or impairment is indicated. The costs associated with unevaluated leasehold acreage, related seismic data and capitalized interest and direct internal costs are initially excluded from our full cost pool. Leasehold costs are either transferred to our full cost pool with the costs of drilling a well on the lease or are assessed at least annually for possible impairment or reduction in value. Leasehold costs are transferred to our full cost pool to the extent a reduction in value has occurred, or a charge is made against earnings if the costs were incurred in a country for which a reserve base has not been established. See Note 6 , " Oil and Gas Properties ," for a detailed discussion regarding our oil and gas property and our asset acquisitions and sales transactions. Other Property and Equipment Furniture, fixtures and equipment are recorded at cost and depreciated using the straight-line method over their estimated useful lives, which range from three to seven years. Gathering systems and equipment are recorded at cost and depreciated using the straight-line method over their estimated useful lives of 25 years. Accounting for Asset Retirement Obligations If a reasonable estimate of the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon wells can be made, we record a liability (an asset retirement obligation or ARO) on our consolidated balance sheet and capitalize the present value of the asset retirement cost in oil and gas properties in the period in which the ARO is incurred. Settlements include payments made to satisfy the AROs, as well as transfer of the AROs to purchasers of our divested properties. In general, the amount of the initial recorded ARO and the costs capitalized will equal the estimated future costs to satisfy the abandonment obligation assuming normal operation of the asset, using current prices that are escalated by an assumed inflation factor up to the estimated settlement date, which is then discounted back to the date that the abandonment obligation was incurred using the credit adjusted risk-free rate for our Company. After recording these amounts, the ARO is accreted to its future estimated value and the original capitalized costs are depreciated on a unit-of-production basis within the related full cost pool. Both the accretion and depreciation are included in depreciation, depletion and amortization expense on our consolidated statement of operations. See Note 10 , " Asset Retirement Obligations ," for further discussion. Contingencies We are subject to legal proceedings, claims, liabilities and environmental matters that arise in the ordinary course of business. We accrue for losses when such losses are considered probable and the amounts can be reasonably estimated. See Note 12 , " Commitments and Contingencies ," for a more detailed discussion regarding our contingencies. Environmental Matters Environmental costs that relate to current operations are expensed as incurred. Remediation costs that relate to an existing condition caused by past operations are accrued when it is probable that those costs will be incurred and can be reasonably estimated based upon evaluations of currently available facts related to each site. Income Taxes We use the liability method of accounting for income taxes. Under this method, deferred tax assets and liabilities are determined by applying tax regulations existing at the end of a reporting period to the cumulative temporary differences between the tax bases of assets and liabilities and their reported amounts in our financial statements. We assess the available positive and negative evidence to estimate if sufficient taxable income will be generated to utilize deferred tax assets. A valuation allowance is established to reduce deferred tax assets if it is more likely than not that the related tax benefits will not be realized. We also evaluate potential uncertain tax positions, and if necessary, establish accruals for such items. See Note 8 , " Income Taxes ," for further discussion. Stock-Based Compensation We apply a fair value-based method of accounting for stock-based compensation, which requires recognition in the financial statements of the cost of services received in exchange for equity and liability awards. For equity awards, compensation expense is based on the fair value on the grant or modification date and is recognized in our financial statements over the vesting period. We utilize the Black-Scholes option-pricing model to measure the fair value of stock options and a Monte Carlo lattice-based model for our performance- and market-based restricted stock and restricted stock units. We also have cash-settled restricted stock units that are accounted for under the liability method, which requires us to recognize the fair value of each award based on the Company's stock price at the end of each period. See Note 15 , " Stock-Based Compensation ," for a full discussion of our stock-based compensation. Concentration of Credit Risk We operate a substantial portion of our oil and gas properties. As the operator of a property, we make full payment for costs associated with the property and seek reimbursement from the other joint interest owners in the property for their share of those costs. In addition, when warranted, we require prepayments from our joint interest owners for drilling and completion projects. Our joint interest owners consist primarily of independent oil and gas producers whose ability to reimburse us could be negatively impacted by adverse market conditions. The purchasers of our oil, gas and NGL production consist primarily of independent marketers, major oil and gas companies, refiners and gas pipeline companies. We perform credit evaluations of the purchasers of our production and monitor their financial condition on an ongoing basis. Based on our evaluations and monitoring, we obtain cash escrows, letters of credit or parental guarantees from some purchasers. All of our derivative transactions were carried out in the over-the-counter market and are not typically subject to margin-deposit requirements. The use of derivative transactions involves the risk that the counterparties will be unable to meet the financial terms of such transactions. We monitor the credit ratings of our derivative counterparties on an ongoing basis. Although we have entered into derivative contracts with multiple counterparties to mitigate our exposure to any individual counterparty, if any of our counterparties were to default on its obligations to us under the derivative contracts or seek bankruptcy protection, it could have a material adverse effect on our ability to fund our planned activities and could result in a larger percentage of our future production being subject to commodity price volatility. In addition, in poor economic environments and tight financial markets, the risk of a counterparty default is heightened and fewer counterparties may participate in derivative transactions, which could result in greater concentration of our exposure to any one counterparty or a larger percentage of our future production being subject to commodity price changes. Major Customers China National Offshore Oil Corporation Ltd. accounted for 12% of our total revenues in 2016 . During 2015 , China National Offshore Oil Corporation Ltd., MidCon Gathering LLC and Sunoco Logistics Partners Operations GP LLC accounted for 13% , 11% and 10% , respectively, of our total revenues. During 2014 , Tesoro Corporation and Sunoco Logistics Partners Operations GP LLC accounted for 12% and 10% , respectively, of our total revenues. We believe that the loss of a major customer would not have a material adverse effect on us because alternative purchasers are available. Derivative Financial Instruments Our derivative instruments are recorded on the consolidated balance sheet at fair value as either an asset or a liability with changes in fair value recognized currently in earnings. While we utilize our derivative instruments to manage the price risk attributable to our expected oil and gas production, we have elected not to designate our derivative instruments as accounting hedges under the accounting guidance. The related cash flow impact of our derivative activities is reflected as cash flows from operating activities unless the derivatives are determined to have a significant financing element at inception, in which case they are classified within financing activities. See Note 4 , " Derivative Financial Instruments ," for a more detailed discussion of our derivative activities. Offsetting Assets and Liabilities Our derivative financial instruments are subject to master netting arrangements and are reflected on our consolidated balance sheet accordingly. See Note 4 , " Derivative Financial Instruments ," for details regarding the gross amounts, as well as the impact of our netting arrangements on our net derivative position. New Accounting Requirements In November 2016, the Financial Accounting Standards Board (FASB) issued guidance regarding the classification and presentation of changes in restricted cash on the statement of cash flows. The guidance requires that a statement of cash flows explains the change during the period in the total of cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents using a retrospective approach. The guidance is effective for interim and annual periods beginning after December 15, 2017. We are currently evaluating the impact of this guidance on our financial statements. In March 2016, the FASB issued guidance regarding the simplification of employee share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. We adopted this guidance in the second quarter of 2016 as permitted by the guidance. Adoption of this guidance did not impact our financial statements, except for the simplification in accounting for income taxes using a modified retrospective approach. Upon adoption, we recorded a related deferred tax asset for previously unrecognized excess tax benefits of $37 million . As we consider it more likely than not that the deferred tax asset will not be realized, we recorded a full valuation allowance of $37 million , resulting in no net effect on our consolidated statement of operations. We elected to continue our current policy of estimating forfeitures. In February 2016, the FASB issued guidance regarding the accounting for leases. The guidance requires recognition of most leases on the balance sheet. The guidance requires lessees and lessors to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The guidance is effective for interim and annual periods beginning after December 15, 2018. We are currently evaluating the impact of this guidance on our financial statements. In January 2016, the FASB issued guidance regarding several broad topics related to the recognition and measurement of financial assets and liabilities. The guidance is effective for interim and annual periods beginning after December 15, 2017. We do not expect this guidance to have a material impact on our financial statements. In May 2014, the FASB issued guidance regarding the accounting for revenue from contracts with customers. In April 2016, May 2016 and December 2016, the FASB issued additional guidance, addressed implementation issues and provided technical corrections. The guidance may be applied retrospectively or using a modified retrospective approach to adjust retained earnings (deficit). The guidance is effective for interim and annual periods beginning after December 15, 2017. We are currently evaluating the impact of this guidance on our financial statements.

Accounts Receivable

Accounts Receivable	12 Months Ended
	Dec. 31, 2016
Accounts Receivable, Net, Current [Abstract]
Loans, Notes, Trade and Other Receivables Disclosure [Text Block]	Accounts Receivable Accounts receivable consisted of the following at December 31: 2016 2015 (In millions) Revenue $ 163 $ 94 Joint interest 53 125 Other 32 59 Reserve for doubtful accounts (16 ) (16 ) Total accounts receivable, net $ 232 $ 262 Reserve for doubtful accounts at December 31, 2016 and 2015 includes an allowance for $15 million related to discontinued operations. See Note 20 , " Discontinued Operations ."

Inventories Inventories (Notes)

Inventories Inventories (Notes)	12 Months Ended
	Dec. 31, 2016
Inventories [Abstract]
Inventory Disclosure [Text Block]	During 2016 , 2015 and 2014 , we had inventory writedowns of $1 million , $5 million and $9 million , respectively. These writedowns are included in "Operating expenses — Other" on our consolidated statement of operations. At December 31, 2016 and 2015 , the crude oil inventory from our China operations consisted of approximately 11,500 and 335,000 barrels of crude oil, respectively.

Derivative Financial Instrument

Derivative Financial Instruments	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedges, Assets [Abstract]
Derivative Financial Instruments Text Block	Derivative Financial Instruments Commodity Derivative Instruments We utilize derivative strategies that consist of either a single derivative instrument or a combination of instruments to manage the variability in cash flows associated with the forecasted sale of our future domestic oil and natural gas production. While the use of derivative instruments may limit or partially reduce the downside risk of adverse commodity price movements, their use also may limit future income from favorable commodity price movements. • Fixed-price swaps. With respect to a swap position, the counterparty is required to make a payment to us if the settlement price for any settlement period is less than the swap strike price, and we are required to make a payment to the counterparty if the settlement price for any settlement period is greater than the swap strike price. • Collars (combination of purchased put options (floor) and sold call options (ceiling)) . For a collar position, the counterparty is required to make a payment to us if the settlement price for any settlement period is below the floor strike price while we are required to make payment to the counterparty if the settlement price for any settlement period is above the ceiling strike price. Neither party is required to make a payment to the other party if the settlement price for any settlement period is equal to or greater than the floor strike price and equal to or less than the ceiling strike price. • Fixed-price swaps with sold puts. A swap with a sold put position consists of a standard swap position plus a put sold by us with a strike price below the associated fixed-price swap. This structure enables us to increase the fixed-price swap with the value received through the sale of the put. If the settlement price for any settlement period falls equal to or below the put strike price, then we will only receive the difference between the swap price and the put strike price. If the settlement price is greater than the put strike price, the result is the same as it would have been with a standard swap only. • Collars with sold puts. A collar with a sold put position consists of a standard collar position plus a put sold by us with a strike price below the floor strike price of the collar. This structure enables us to improve the collar strike prices with the value received through the sale of the additional put. If the settlement price for any settlement period falls equal to or below the additional put strike price, then we will receive the difference between the floor strike price and the additional put strike price. If the settlement price is greater than the additional put strike price, the result is the same as it would have been with a standard collar only. • Purchased calls. Purchased calls are options that require a counterparty to make a payment to us if the settlement price is above the call strike price (excluding the effects of the deferred premium owed by us to the counterparty). As a result, these positions lock in the value of a portion of our corresponding oil swaps with sold puts as well as collars with sold puts. • Swaptions. A swaption is an option to exercise a swap where the buyer (counterparty) of the swaption purchases the right from the seller (Newfield), but not the obligation, to enter into a fixed-price swap with the seller on a predetermined date (expiration date). The swap price is a fixed price determined at the time of the swaption contract. If the swaption is exercised, the contract will become a swap treated consistent with our other fixed-price swaps. For discussion of the accounting policies associated with our derivative financial instruments (including the offsetting of derivative assets and liabilities), see Note 1 , " Organization and Summary of Significant Accounting Policies ." Our oil and gas derivative contracts are settled based upon reported prices on the NYMEX. The estimated fair value of these contracts is based upon various factors, including closing exchange prices on the NYMEX, over-the-counter quotations, estimated volatility, non-performance risk adjustments using counterparty rates of default and time to maturity. The calculation of the fair value of options requires the use of an option-pricing model. See Note 5 , " Fair Value Measurements ." At December 31, 2016 , we had outstanding derivative positions as set forth in the tables below. Crude Oil NYMEX Contract Price Per Bbl Collars Estimated Fair Value Period and Type of Instrument Volume in MBbls Swaps Purchased Calls (Weighted Average) (2) Sold Puts(Weighted Average) (1) Floors Ceilings (In millions) 2017: Fixed-price swaps 6,205 $ 45.43 $ — $ — $ — $ — $ (67 ) Fixed-price swaps with sold puts: 4,468 Fixed-price swaps 88.37 — — — — 142 Sold puts — — 73.28 — — (79 ) Collars with sold puts: 2,080 Collars — — — 90.00 95.59 71 Sold puts — — 75.00 — — (41 ) Purchased calls 6,548 — 73.81 — — — 3 Total $ 29 _________________ (1) For the volumes with sold puts, if the market prices remain below our sold puts at contract settlement, we will receive the market price plus the following: • the difference between our floors and our sold puts for collars with sold puts; or • the difference between our swaps and our sold puts for fixed-price swaps with sold puts. We have effectively locked in the spreads noted above (less the deferred call premium) for all of the volumes with sold puts using purchased calls. (2) We deferred the premiums related to the purchased calls until contract settlement. At December 31, 2016 , the deferred premiums totaled $10 million . Natural Gas Period and Type of Instrument NYMEX Contract Price Per MMBtu Collars Volume in MMMBtus Swaps (Weighted Average) Floors(Weighted Average) Ceilings(Weighted Average) Estimated Fair Value Asset (Liability) (In millions) 2017: Fixed-price swaps 27,375 $ 2.73 $ — $ — $ (24 ) Collars 53,860 — 2.82 3.23 (27 ) 2018: Fixed-price swaps 10,950 3.01 — — (1 ) Collars 18,150 — 3.00 3.55 (2 ) Total $ (54 ) Additional Disclosures about Derivative Financial Instruments We had derivative financial instruments recorded in our consolidated balance sheet as assets (liabilities) at their respective estimated fair value, as set forth below. Derivative Assets Derivative Liabilities Gross Fair Value Offset in Balance Sheet Balance Sheet Location Gross Fair Value Offset in Balance Sheet Balance Sheet Location Current Noncurrent Current Noncurrent December 31, 2016 (In millions) (In millions) Oil positions $ 226 $ (151 ) $ 75 $ — $ (197 ) $ 151 $ (46 ) $ — Natural gas positions 10 (10 ) — — (64 ) 10 (51 ) (3 ) Total $ 236 $ (161 ) $ 75 $ — $ (261 ) $ 161 $ (97 ) $ (3 ) December 31, 2015 Oil positions $ 1,005 $ (638 ) $ 262 $ 105 $ (660 ) $ 638 $ (13 ) $ (9 ) Natural gas positions 22 — 22 — — — — — Total $ 1,027 $ (638 ) $ 284 $ 105 $ (660 ) $ 638 $ (13 ) $ (9 ) The amount of gain (loss) recognized in "Commodity derivative income (expense)" in our consolidated statement of operations related to our derivative financial instruments follows: Year Ended December 31, 2016 2015 2014 (In millions) Derivatives not designated as hedging instruments: Realized gain (loss) on oil positions $ 199 $ 375 $ (3 ) Realized gain (loss) on natural gas positions 2 130 (36 ) Total realized gain (loss) 201 505 (39 ) Unrealized gain (loss) on oil positions (316 ) (165 ) 535 Unrealized gain (loss) on natural gas positions (76 ) (81 ) 114 Total unrealized gain (loss) (392 ) (246 ) 649 Total $ (191 ) $ 259 $ 610 The use of derivative transactions involves the risk that the counterparties, which generally are financial institutions, will be unable to meet the financial terms of such transactions. Our derivative contracts are with multiple counterparties to minimize our exposure to any individual counterparty, and we have netting arrangements with all of our counterparties that provide for offsetting payables against receivables from the separate derivative instruments with that counterparty. At December 31, 2016 , 10 of our 16 counterparties accounted for approximately 85% of our contracted volumes, with the largest counterparty accounting for approximately 14% . At December 31, 2016 , approximately 84% of our volumes subject to derivative instruments are with lenders under our credit facility. Our credit facility, senior notes and substantially all of our derivative instruments contain provisions that provide for cross defaults and acceleration of those debt and derivative instruments in certain situations.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurements Text Block	Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). The authoritative guidance requires disclosure of the framework for measuring fair value and requires that fair value measurements be classified and disclosed in one of the following categories: Level 1: Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. We consider active markets as those in which transactions for the assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis. Level 2: Quoted prices in markets that are not active, or inputs that are observable, either directly or indirectly, for substantially the full term of the asset or liability. This category includes those derivative instruments that we value using observable market data. Substantially all of these inputs are observable in the marketplace throughout the full term of the derivative instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange traded derivatives such as over-the-counter commodity fixed-price swaps. Level 3: Measured based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable from objective sources (i.e., supported by little or no market activity). Level 3 instruments primarily include derivative instruments, such as commodity options (i.e., price collars, sold puts, purchased calls or swaptions). • We use a modified Black-Scholes option pricing valuation model for option and swaption derivative contracts that considers various inputs including: (a) forward prices for commodities, (b) time value, (c) volatility factors, (d) counterparty credit risk and (e) current market and contractual prices for the underlying instruments. • Our valuation model for the Stockholder Value Appreciation Program (SVAP) was a Monte Carlo simulation that was based on a probability model and considered various inputs including: (a) the measurement date stock price, (b) time value and (c) historical and implied volatility. Financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy. The determination of the fair values of our derivative contracts incorporates various factors, which include not only the impact of our non-performance risk on our liabilities but also the credit standing of the counterparties involved. We utilize counterparty rate of default values to assess the impact of non-performance risk when evaluating both our liabilities to, and receivables from, counterparties. Recurring Fair Value Measurements The following table summarizes the valuation of our assets and liabilities that are measured at fair value on a recurring basis. Fair Value Measurement Classification Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total (In millions) As of December 31, 2015: Money market fund investments $ 2 $ — $ — $ 2 Deferred compensation plan assets 5 — — 5 Equity securities available-for-sale 8 — — 8 Oil and gas derivative swap contracts — 675 — 675 Oil and gas derivative option contracts — — (308 ) (308 ) Stock-based compensation liability awards (12 ) — — (12 ) Total $ 3 $ 675 $ (308 ) $ 370 As of December 31, 2016: Money market fund investments $ 320 $ — $ — $ 320 Deferred compensation plan assets 6 — — 6 Equity securities available-for-sale 9 — — 9 Oil and gas derivative swap contracts — 50 — 50 Oil and gas derivative option contracts — — (75 ) (75 ) Stock-based compensation liability awards (11 ) — — (11 ) Total $ 324 $ 50 $ (75 ) $ 299 Level 3 Fair Value Measurements The following table sets forth a reconciliation of changes in the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy for the indicated periods. Investments Derivatives Stock-Based Compensation Total (In millions) Balance at January 1, 2014 $ 39 $ (8 ) $ (5 ) $ 26 Unrealized gains (losses) included in earnings — (381 ) (38 ) (419 ) Purchases, issuances, sales and settlements: Sales (39 ) — — (39 ) Settlements — 5 40 45 Transfers into Level 3 — — — — Transfers out of Level 3 (1) — 3 — 3 Balance at December 31, 2014 $ — $ (381 ) $ (3 ) $ (384 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at December 31, 2014 $ — $ (375 ) $ 2 $ (373 ) Balance at January 1, 2015 $ — $ (381 ) $ (3 ) $ (384 ) Unrealized gains (losses) included in earnings — (217 ) 3 (214 ) Purchases, issuances, sales and settlements: Settlements — 290 — 290 Transfers into Level 3 — — — — Transfers out of Level 3 — — — — Balance at December 31, 2015 $ — $ (308 ) $ — $ (308 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at December 31, 2015 $ — $ (143 ) $ 3 $ (140 ) Balance at January 1, 2016 $ — $ (308 ) $ — $ (308 ) Unrealized gains (losses) included in earnings — (33 ) — (33 ) Purchases, issuances, sales and settlements: Settlements — 220 — 220 Transfers into Level 3 — — — — Transfers out of Level 3 (2) — 46 — 46 Balance at December 31, 2016 $ — $ (75 ) $ — $ (75 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at December 31, 2016 $ — $ 13 $ — $ 13 _________________ (1) During the second quarter of 2014, we transferred $3 million of derivative option contracts out of the Level 3 category, resulting from the exercise of our Level 3 swaptions by the counterparties to swaps in May 2014. (2) During the second quarter of 2016, we transferred $46 million of derivative option contracts out of the Level 3 category, resulting from the exercise of our Level 3 swaptions by the counterparties to swaps in June 2016. Qualitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements Investments. During the first quarter of 2014, all auction rate securities that we held as of January 1, 2014, were sold for $39 million . Derivatives. The calculation of the fair value of our option contracts requires the use of an option-pricing model. The estimated future prices are compared to the strike prices fixed by our derivative contracts, and the resulting estimated future cash inflows or outflows over the contractual life are discounted to calculate the fair value. These pricing and discounting variables are sensitive to market volatility as well as changes in future price forecasts and interest rates. Significant increases (decreases) in the quoted forward prices for commodities generally lead to corresponding decreases (increases) in the fair value measurement of our oil and gas derivative contracts. Significant changes in the volatility factors utilized in our option-pricing model can cause significant changes in the fair value measurement of our oil and gas derivative contracts. Historically, we have not experienced significant changes in the fair value of our derivative contracts resulting from changes in counterparty credit risk as the counterparties for all of our derivative transactions have an "investment grade" credit rating. See Note 4 , " Derivative Financial Instruments ," for additional discussion of our derivative instruments. Stock-Based Compensation. The calculation of the fair value of the SVAP liability required the use of a probability-based Monte Carlo simulation, which included unobservable inputs. The simulation predicted multiple scenarios of future stock returns over the performance period, which were discounted to calculate the fair value. The fair value was recognized over a service period derived from the simulation. The SVAP performance period and program ended December 31, 2015. Quantitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements Estimated Fair Value Asset (Liability) Quantitative Information about Level 3 Fair Value Measurements Instrument Type Valuation Technique Unobservable Input Range (In millions) Oil option contracts $ (46 ) Modified Black-Scholes Oil price volatility 23.13 % — 66.5% Credit risk 0.01 % — 1.45% Natural gas option contracts $ (29 ) Modified Black-Scholes Natural gas price volatility 23.53 % — 53.39% Credit risk 0.01 % — 1.45% Fair Value of Debt The estimated fair value of our notes, based on quoted prices in active markets (Level 1) as of December 31, was as follows: 2016 2015 (In millions) 5¾% Senior Notes due 2022 $ 789 $ 668 5⅝% Senior Notes due 2024 1,044 831 5⅜% Senior Notes due 2026 714 542 Any amounts outstanding under our revolving credit facility and money market lines of credit as of the indicated dates are stated at cost, which approximates fair value. See Note 11 , " Debt ."

Oil and Gas Properties

Oil and Gas Properties	12 Months Ended
	Dec. 31, 2016
Oil and Gas Property [Abstract]
Oil and Gas Assets Text Block	At December 31, oil and gas properties consisted of the following: 2016 2015 (In millions) Proved $ 21,998 $ 21,568 Unproved 1,238 780 Gross oil and gas properties 23,236 22,348 Accumulated depreciation, depletion and amortization (9,587 ) (9,048 ) Accumulated impairment (10,509 ) (9,481 ) Net oil and gas properties $ 3,140 $ 3,819 Costs withheld from amortization as of December 31, 2016 consisted of the following: Costs Incurred In 2016 2015 2014 2013 Total (In millions) Acquisition costs $ 540 $ 339 $ 162 $ 74 $ 1,115 Exploration costs 4 — — — 4 Capitalized interest 51 33 35 — 119 Total costs withheld from amortization (unproved) $ 595 $ 372 $ 197 $ 74 $ 1,238 We capitalized approximately $121 million , $107 million and $199 million of interest and direct internal costs in 2016 , 2015 and 2014 , respectively. During the second quarter of 2015, we finalized a settlement agreement with our insurance carriers related to an August 2013 LF-7 topside incident in China and recorded a $57 million receivable (the Company's share) and associated reduction to capital expenditures. The settlement proceeds were collected in July 2015. Ceiling Test Impairments Under the full cost method, we are subject to quarterly calculations of a "ceiling" or limitation on the amount of oil and gas property costs that can be capitalized on our balance sheet. Ceiling test impairments during 2015 and 2016 consisted of the following: SEC Pricing Domestic Ceiling Test Impairments China Ceiling Test Impairments Total Ceiling Test Impairments Oil Natural Gas Gross Net of Tax (1) Gross Net of Tax (1) Gross Net of Tax (1) (Per Bbl) (Per MMBtu) (In millions) 2015 Quarter Ended: March 31 (2) $ 82.60 $ 3.88 $ 788 $ 496 $ — $ — $ 788 $ 496 June 30 71.56 3.39 1,521 958 — — 1,521 958 September 30 59.09 3.06 1,817 1,193 72 29 1,889 1,222 December 31 50.11 2.59 656 620 46 31 702 651 Total 2015 (2) $ 4,782 $ 3,267 $ 118 $ 60 $ 4,900 $ 3,327 2016 Quarter Ended: March 31 $ 46.23 $ 2.40 $ 461 $ 461 $ 45 $ 45 $ 506 $ 506 June 30 43.14 2.24 501 501 21 21 522 522 September 30 41.73 2.28 — — — — — — December 31 42.82 2.48 — — — — — — Total 2016 $ 962 $ 962 $ 66 $ 66 $ 1,028 $ 1,028 _________________ (1) Starting in the first quarter of 2016, there was no tax impact due to a full valuation allowance on our deferred tax assets. See Note 8 , " Income Taxes ," for additional information regarding the deferred tax asset valuation allowance. (2) Excludes domestic rig impairment of $4 million . Using SEC pricing at December 31, 2016, the domestic and China cost center ceilings exceeded the net capitalized costs of oil and gas properties by approximately $873 million and $7 million , respectively, and as such, no ceiling test impairments were required. Future declines in SEC pricing or downward revisions to our estimated proved reserves could result in additional ceiling test impairments of our oil and gas properties in subsequent periods. Texas Asset Sale In September 2016, we closed on the sale of substantially all of our oil and gas assets in Texas for approximately $380 million , subject to customary post-close adjustments. The sales of our Texas assets did not significantly alter the relationship between capitalized costs and proved reserves, and as such, all proceeds were recorded as adjustments to our domestic full cost pool with no gain or loss recognized. These consolidated financial statements include the results of our Texas operations through the date of sale. Anadarko Basin Acquisition In June 2016, we acquired additional properties in the Anadarko Basin STACK play for an adjusted cash purchase price of $476 million , subject to customary post-close adjustments. We also assumed asset retirement obligations of $8 million . We allocated $398 million to unproved properties and wells in progress and $86 million to proved oil and gas properties. Granite Wash Asset Sale In September 2014, we closed on the sale of our Granite Wash assets, located primarily in Texas, for approximately $588 million . The sale of our Granite Wash assets did not significantly alter the relationship between capitalized costs and proved reserves, and as such, all proceeds were recorded as adjustments to our domestic full cost pool with no gain or loss recognized. These consolidated financial statements include the results of our Granite Wash operations through the date of sale. Other Asset Acquisitions and Sales During 2016 , 2015 and 2014 , we acquired various other oil and gas properties for approximately $7 million , $125 million and $33 million , respectively, and sold certain other oil and gas properties for proceeds of approximately $39 million , $90 million and $69 million , respectively. The cash flows and results of operations for the assets included in a sale are included in our consolidated financial statements up to the date of sale. All of the proceeds associated with our asset sales were recorded as adjustments to our domestic full cost pool

Other Property and Equipment Ot

Other Property and Equipment Other Property and Equipment	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment Disclosure [Text Block]	Other Property and Equipment At December 31, other property and equipment consisted of the following: 2016 2015 (In millions) Furniture, fixtures and equipment $ 150 $ 152 Gathering systems and equipment 115 115 Accumulated depreciation and amortization (98 ) (95 ) Net other property and equipment $ 167 $ 172

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes Text Block	For the years ended December 31, income (loss) from continuing operations before income taxes consisted of the following: 2016 2015 2014 (In millions) U.S. $ (1,181 ) $ (4,865 ) $ 1,022 International (27 ) (82 ) 10 Total income (loss) before income taxes $ (1,208 ) $ (4,947 ) $ 1,032 For the years ended December 31, the total provision (benefit) for income taxes for continuing operations consisted of the following: 2016 2015 2014 (In millions) Current taxes: U.S. federal $ (13 ) $ (12 ) $ — U.S. state — (2 ) 2 International 22 31 3 Deferred taxes: U.S. federal 10 (1,507 ) 350 U.S. state 13 (27 ) 25 International (10 ) (68 ) 2 Total provision (benefit) for income taxes $ 22 $ (1,585 ) $ 382 The following table presents a reconciliation of the United States statutory income tax rate to our effective income tax rate. 2016 2015 2014 U.S. statutory income tax rate 35.0 % 35.0 % 35.0 % State and local income taxes, net of federal effect — 0.9 1.7 Valuation allowance, domestic (35.5 ) (4.0 ) — Valuation allowance, international (2.4 ) (0.3 ) — Foreign tax on foreign earnings 0.6 0.4 0.2 Other 0.5 — 0.1 Effective income tax rate (1.8 )% 32.0 % 37.0 % The provision for state deferred income taxes on the consolidated statement of operations for the year ended December 31, 2016 was attributable to Oklahoma state deferred tax expense. Other state taxing jurisdictions were in a net deferred tax asset position for which a corresponding valuation allowance was recorded resulting in zero deferred tax benefit for those jurisdictions. The amount for state income taxes in the rate reconciliation table above is the net of deferred tax expenses and benefits before valuation allowances, if any, generated from all states. Our effective tax rate for 2016 differs from the U.S. statutory rate primarily due to domestic and international deferred tax asset valuation allowances discussed below. At December 31, the components of our deferred tax asset (liability) were as follows: 2016 2015 (In millions) Deferred tax asset: Net operating loss carryforwards $ 301 $ 243 Alternative minimum tax credit 73 87 Stock-based compensation 15 23 Oil and gas properties 306 13 Commodity derivatives 9 — Foreign tax credit 593 572 Other 13 17 Total deferred tax asset 1,310 955 Deferred tax asset valuation allowances (1,310 ) (790 ) Net deferred tax asset — 165 Deferred tax liability: Commodity derivatives — (119 ) Oil and gas properties (39 ) (72 ) Total deferred tax liability (39 ) (191 ) Net deferred tax liability $ (39 ) $ (26 ) As of December 31, 2016 and 2015 , we had gross net operating loss (NOL) carryforwards of approximately $849 million and $852 million for federal income tax, respectively and $1.8 billion for state income tax purposes, which may be used in future years to offset taxable income. NOL carryforwards of $138 million are subject to annual limitations due to stock ownership changes. We currently estimate that we will not be able to utilize $173 million of our various gross state NOLs because we do not have sufficient estimated future taxable income in the appropriate jurisdictions. To the extent not utilized, the federal NOL carryforwards will begin to expire during the years 2019 through 2036. As of December 31, 2016 and 2015 , we had foreign tax credits of approximately $593 million and $572 million , respectively, which will expire during the years 2022 through 2026. Utilization of deferred tax assets is dependent upon generating sufficient future taxable income in the appropriate jurisdictions within the carryforward period. Estimates of future taxable income can be significantly affected by changes in oil, gas and NGL prices; estimates of the timing and amount of future production; and estimates of future operating and capital costs. Therefore, no certainty exists that we will be able to fully utilize our existing deferred tax assets. The change in our deferred tax asset valuation allowance is as follows at December 31: 2016 2015 2014 (In millions) Balance at the beginning of the year $ (790 ) $ (549 ) $ (584 ) Charged to provision for income taxes: U.S. state net operating loss carryforwards (4 ) (1 ) 1 U.S. federal and state valuation allowance (466 ) (202 ) — Malaysia valuation allowance — — 40 Foreign tax credit valuation allowance (21 ) (25 ) (12 ) Brazil and other international valuation allowance — — 6 China valuation allowance (29 ) (13 ) — Balance at the end of the year $ (1,310 ) $ (790 ) $ (549 ) Due to the ceiling test impairments of our oil and gas properties in 2015, we moved from a deferred tax liability position to a deferred tax asset position in most taxing jurisdictions. With the continuation of current commodity price levels, we consider it more likely than not that the related tax benefits will not be realized and therefore, we recorded a full valuation allowance on our domestic deferred tax assets of $466 million and $202 million for the years ended December 31, 2016 and 2015, respectively. The net change in the domestic valuation allowance for 2016 of $466 million includes an increase of $37 million for the early adoption of the simplification of employee share-based payment transactions. We recorded a full valuation allowance on our China deferred tax assets of $29 million and $13 million , for the years ended December 31, 2016 and 2015, respectively. As the result of the divestiture of the Malaysia operations in 2014, all of the deferred tax asset and related valuation allowance were transferred to the buyer. In the fourth quarter of 2014, we wrote off the other international deferred tax assets and related valuation allowances since we have ceased operating in these jurisdictions and it is remote that the NOL carryforwards will be realized in the future. In fourth quarter of 2016 , 2015 and 2014 , we recorded valuation allowances related to insufficient estimated future domestic taxable income to fully utilize foreign tax credits before they expire of $21 million , $25 million and $12 million , respectively. The foreign tax credit deferred tax asset is fully offset by a valuation allowance. As of December 31, 2016 , we did not have a liability for uncertain tax positions, and as such, we did not accrue related interest or penalties. The tax years 2013 through 2015 remain open to examination for federal income tax purposes and by the other major taxing jurisdictions to which we are subject. Unrealized derivative gains and losses are treated differently for income tax purposes in the various state taxing jurisdictions to which we are subject. As a result, our effective tax rate fluctuates in periods with significant commodity price volatility. These effective tax rate fluctuations are magnified when income before taxes approaches zero.

Accrued Liabilities

Accrued Liabilities	12 Months Ended
	Dec. 31, 2016
Accrued Liabilities, Current [Abstract]
Accounts Payable and Accrued Liabilities Disclosure [Text Block]	Accrued Liabilities Accrued liabilities consisted of the following at December 31: 2016 2015 (In millions) Revenue payable $ 196 $ 164 Accrued capital costs 92 128 Accrued lease operating expenses 37 48 Employee incentive expense 48 53 Accrued interest on debt 67 66 Taxes payable 15 25 Other 43 49 Total accrued liabilities $ 498 $ 533

Asset Retirement Obligations (N

Asset Retirement Obligations (Notes)	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation Disclosure [Text Block]	Asset Retirement Obligations The change in our ARO for continuing operations for each of the three years ended December 31, is set forth below: 2016 2015 2014 (In millions) Balance at January 1 $ 194 $ 186 $ 122 Accretion expense 10 10 8 Additions (1) 15 6 58 Revisions (23 ) (2 ) 16 Settlements (2) (40 ) (6 ) (18 ) Balance at December 31 156 194 186 Less: Current portion of ARO at December 31 (2 ) (2 ) (3 ) Total long-term ARO at December 31 $ 154 $ 192 $ 183 _________________ (1) For the year ended December 31, 2016 , additions include $8 million of abandonment obligations assumed through our Anadarko Basin acquisition. See Note 6 , " Oil and Gas Properties ." For the year ended December 31, 2014, additions include $28 million for our Pearl development in offshore China and $30 million for abandonment obligations in our domestic business. (2) For the year ended December 31, 2016 , settlements include $35 million related to the sale of our Texas assets. For the year ended December 31, 2014, settlements include $10 million related to the sale of our Granite Wash assets. See Note 6 , " Oil and Gas Properties ."

Debt

Debt	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Debt Text Block	Debt At December 31, our debt consisted of the following: 2016 2015 (In millions) Senior unsecured debt: Revolving credit facility — LIBOR based loans (matures in June 2020) $ — $ — Money market lines of credit — 39 Total credit arrangements — 39 5¾% Senior Notes due 2022 750 750 5⅝% Senior Notes due 2024 1,000 1,000 5⅜% Senior Notes due 2026 700 700 Total senior unsecured debt 2,450 2,489 Debt issuance costs (19 ) (22 ) Total long-term debt $ 2,431 $ 2,467 Credit Arrangements In March 2016, we entered into the fifth amendment to our Credit Agreement. This amendment changed certain definitions related to our financial covenants and decreased our interest coverage ratio from 3.0 :1.0 to 2.5 :1.0. Our borrowing capacity remains at $1.8 billion and the facility maturity date remains June 2020. We incurred approximately $3 million of financing costs related to this amendment, which were included in "Interest expense" on our consolidated statement of operations. As of December 31, 2016 , the largest individual loan commitment by any lender was 12% of total commitments. During 2016, our debt rating was downgraded by rating agencies, and as a result, our borrowing costs under the credit facility increased by 25 basis points. In addition, our available borrowing capacity (before any amounts drawn) under our money market lines of credit with various institutions, the availability of which is at the discretion of those financial institutions, was reduced from $195 million at December 31, 2015 to $125 million at December 31, 2016 . This borrowing capacity is subject to compliance with restrictive covenants in our credit facility. Loans under the credit facility bear interest, at our option, equal to (a) a rate per annum equal to the higher of the prime rate announced from time to time by JPMorgan Chase Bank, N.A. or the weighted average of the rates on overnight federal funds transactions with members of the Federal Reserve System during the last preceding business day plus 50 basis points, plus a margin that is based on a grid of our debt rating ( 100 basis points per annum at December 31, 2016 ) or (b) the London Interbank Offered Rate, plus a margin that is based on a grid of our debt rating ( 200 basis points per annum at December 31, 2016 ). Under our credit facility, we pay commitment fees on available but undrawn amounts based on a grid of our debt rating ( 37.5 basis points per annum at December 31, 2016 ). We incurred aggregate commitment fees under our credit facility of approximately $7 million , $5 million and $4 million for each of the years ended December 31, 2016 , 2015 and 2014 , respectively, which were recorded in “Interest expense” on our consolidated statement of operations. Our credit facility has restrictive financial covenants that include the maintenance of a ratio of total debt to book capitalization not to exceed 0.6 to 1.0 and the maintenance of a ratio of earnings before gain or loss on the disposition of assets, interest expense, income taxes and noncash items (such as depreciation, depletion and amortization expense, unrealized gains and losses on commodity derivatives and ceiling test impairments) to interest expense of at least 2.5 to 1.0. At December 31, 2016 , we were in compliance with all of our debt covenants. As of December 31, 2016 , we had no letters of credit outstanding under our credit facility. Letters of credit are subject to a fronting fee of 20 basis points and annual fees based on a grid of our debt rating ( 200 basis points at December 31, 2016 ). The credit facility includes events of default relating to customary matters, including, among other things, nonpayment of principal, interest or other amounts; violation of covenants; inaccuracy of representations and warranties in any material respect when made; a change of control; or certain other material adverse changes in our business. Our senior notes also contain standard events of default. If any of the foregoing defaults were to occur, our lenders under the credit facility could terminate future lending commitments, and our lenders under both the credit facility and our notes could declare the outstanding borrowings due and payable. In addition, our credit facility, senior notes and substantially all of our derivative arrangements contain provisions that provide for cross defaults and acceleration of those debt and derivative instruments in certain situations. See Note 1 , " Organization and Summary of Significant Accounting Policies – Concentration of Credit Risk ," for additional details. Senior Notes and Senior Subordinated Notes In March 2015, we issued $700 million of 5⅜% Senior Notes due 2026 and received net proceeds of $691 million (net of offering costs of approximately $9 million ). These notes were issued at par to yield 5⅜%. In April 2015, we redeemed our $700 million aggregate principal amount of 6⅞% Senior Subordinated Notes due 2020. In connection with the redemption, we paid a premium of $24 million . The premium was recorded under the caption "Other income (expense) — Other, net" on our consolidated statement of income. In addition, associated unamortized offering costs and discounts of approximately $8 million were charged to interest expense during the second quarter of 2015 as a result of the redemption. Interest on our senior notes is payable semi-annually. The notes are unsecured and unsubordinated obligations and rank equally with all of our other existing and future unsecured and unsubordinated obligations. We may redeem some or all of our senior notes at any time before their maturity at a redemption price based on a make-whole amount plus accrued and unpaid interest to the date of redemption. The indentures governing our senior notes contain covenants that may limit our ability to, among other things, incur debt secured by liens; enter into sale/leaseback transactions; and enter into merger or consolidation transactions. The indentures also provide that if any of our subsidiaries guarantee any of our indebtedness at any time in the future, then we will cause our senior notes to be equally and ratably guaranteed by that subsidiary.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies Text Block	Commitments and Contingencies We have various commitments for firm transportation, operating lease agreements for office space and other agreements. As of December 31, 2016 , future minimum payments under these non-cancelable agreements are as follows: Firm Transportation Operating Leases (Office Space) Drilling-Related Other Total (In millions) Year Ending December 31, 2017 $ 74 $ 21 $ 64 $ 16 $ 175 2018 57 19 5 12 93 2019 45 16 — 9 70 2020 10 15 — 5 30 2021 3 15 — 4 22 Thereafter 4 2 — 20 26 Total minimum future payments $ 193 $ 88 $ 69 $ 66 $ 416 Firm transportation is comprised of various agreements with third parties for oil and gas gathering and transportation. Rent expense with respect to our lease commitments for office space for the years ended December 31, 2016 , 2015 and 2014 was $21 million , $35 million and $20 million , respectively. Our other agreements are primarily other equipment leases. Payments under our drilling-related contracts are accounted for as capital additions to our oil and gas properties and could be less than the gross obligation disclosed. We have crude oil minimum volume delivery commitments that relate to our Uinta Basin production with two Salt Lake City, Utah refiners. One delivery commitment is for approximately 15,000 barrels of oil per day through May 2020. The second commitment is for 20,000 barrels of oil per day through August 2025. As of December 31, 2016 , our delivery commitments through 2025 were as follows: Oil Year Ending December 31, (MBbls) 2017 12,775 2018 12,775 2019 12,775 2020 9,600 2021 7,300 Thereafter 26,800 Total delivery commitments 82,025 Given the volatility in oil and natural gas prices and the related impact on our 2017 planned capital investments, as well as the potential impact on development plans in future years, we could fail to deliver the minimum production required under these commitments. In the event that we are unable to meet our crude oil volume delivery commitments, we would incur deficiency fees ranging from $3.50 to $6.50 per barrel. During 2016, we incurred $16 million of Uinta Basin deficiency fees. Litigation In May 2015, a lawsuit was filed against the Company alleging certain plugging and abandonment predecessor-in-interest liabilities related to offshore assets sold by the Company in 2010. The Company responded to the petition, denied the allegations and vigorously defended the case. The court held that the Company must bear a "portion" of the plugging and abandonment costs, but the "exact percentage" of such costs should be determined in arbitration and stayed the case pending arbitration. Through settlement negotiations surrounding the arbitration proceeding, the Company and the plaintiff reached a mutual settlement on September 23, 2016 involving a cash payment by the Company totaling $18 million . The settlement was recorded under the caption "Operating expenses — Other" on our consolidated statement of operations. On October 3, 2016, the court dismissed the case with prejudice. We have been named as a defendant in a number of lawsuits and are involved in various other disputes, all arising in the ordinary course of our business, such as (a) claims from royalty owners for disputed royalty payments, (b) commercial disputes, (c) personal injury claims and (d) property damage claims. Although the outcome of these lawsuits and disputes cannot be predicted with certainty, we do not expect these matters to have a material adverse effect on our financial position, cash flows or results of operations.

Stockholders' Equity Activity (

Stockholders' Equity Activity (Notes)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Stockholders' Equity Activity Common Stock During the first quarter of 2016, we issued 34.5 million additional shares of common stock through a public equity offering for net proceeds of approximately $776 million . A portion of the proceeds was used to acquire additional properties in the Anadarko Basin STACK play and to repay borrowings under our credit facility and money market lines of credit. The remainder is available for general corporate purposes. During the first quarter of 2015, we issued 25.3 million additional shares of common stock through a public equity offering. We received net proceeds of approximately $815 million , which were used primarily to repay all borrowings under our credit facility and money market lines of credit that were outstanding at that time. In May 2015, our stockholders approved an amendment to the Company's Certificate of Incorporation that increased the total authorized shares of common stock from 200 million to 300 million shares. Treasury Stock Upon vesting of employee restricted stock awards and restricted stock units, we typically repurchase a portion of the vested shares for payment of employee tax withholding. Such repurchases are not part of a publicly announced program to repurchase shares of our common stock. During 2016 , Newfield repurchased 583,340 shares.

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2016
Earnings Per Share [Abstract]
Earnings Per Share Text Block	Earnings Per Share Basic earnings per share (EPS) is calculated by dividing net income less any applicable adjustments (the numerator) by the weighted-average number of shares of common stock (excluding unvested restricted stock and restricted stock units) outstanding during the period (the denominator). Diluted EPS incorporates the dilutive impact of outstanding stock options and unvested restricted stock and restricted stock units (using the treasury stock method). Under the treasury stock method, the amount the employee must pay for exercising stock options, the amount of unrecognized compensation expense related to unvested stock-based compensation grants and the amount of excess tax benefits that would be recorded when the award becomes deductible are assumed to be used to repurchase shares. See Note 15 , " Stock-Based Compensation ." The following is the calculation of basic and diluted weighted-average shares outstanding and EPS for the indicated years: 2016 2015 2014 (In millions, except per share data) Income (numerator): Income (loss) from continuing operations $ (1,230 ) $ (3,362 ) $ 650 Income (loss) from discontinued operations — — 250 Net income (loss) $ (1,230 ) $ (3,362 ) $ 900 Weighted-average shares (denominator): Weighted-average shares — basic 193 159 137 Dilution effect of stock options and unvested restricted stock and restricted stock units outstanding at end of period — — 1 Weighted-average shares — diluted 193 159 138 Excluded due to anti-dilutive effect 2 3 1 Earnings (loss) per share: Basic: Income (loss) from continuing operations $ (6.36 ) $ (21.18 ) $ 4.76 Income (loss) from discontinued operations — — 1.83 Basic earnings (loss) per share $ (6.36 ) $ (21.18 ) $ 6.59 Diluted: Income (loss) from continuing operations $ (6.36 ) $ (21.18 ) $ 4.71 Income (loss) from discontinued operations — — 1.81 Diluted earnings (loss) per share $ (6.36 ) $ (21.18 ) $ 6.52

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2016
Share-based Compensation [Abstract]
Stock-Based Compensation Text Block	For the years ended December 31, our stock-based compensation expense consisted of the following: 2016 2015 2014 (In millions) Equity awards $ 32 $ 42 $ 47 Liability awards: Cash-settled restricted stock units 21 15 20 Stockholder Value Appreciation Program — (3 ) 38 Total liability awards 21 12 58 Total stock-based compensation 53 54 105 Capitalized in oil and gas properties (17 ) (18 ) (40 ) Net stock-based compensation expense $ 36 $ 36 $ 65 As of December 31, 2016 , we had approximately $61 million of total unrecognized stock-based compensation expense related to unvested stock-based compensation awards that vest within four years . On December 31, 2016 , the last reported sales price of our common stock on the New York Stock Exchange was $40.50 per share. Equity Awards Equity awards consist of service-based and performance- or market-based restricted stock awards and restricted stock units, stock options and stock purchase options under the Employee Stock Purchase Plan (ESPP). Stock-based compensation classified as equity awards are currently granted under the 2011 Omnibus Stock Plan, as amended (2011 Plan), to employees and non-employee directors. The fair value of grants is determined utilizing the Black-Scholes option-pricing model for stock options and a Monte Carlo lattice-based model for our performance- and market-based restricted stock and restricted stock units. Compensation expense for equity awards is expected to be recognized on a straight-line basis over the applicable remaining vesting periods. Shares available for grant under our 2011 Plan are reduced by 1.87 times the number of shares of restricted stock or restricted stock units awarded under the plan and are reduced by 1 times the number of shares subject to stock options awarded under the plan. In May 2015, our stockholders approved an additional 7.0 million shares available for issuance under our 2011 Plan, resulting in approximately (1) 5.1 million shares available for issuance under our 2011 Plan if all future awards are stock options, or (2) 2.7 million additional shares available for issuance under our 2011 Plan if all future awards are restricted stock awards or restricted stock units. Thus far, all awards under our 2011 Plan have been granted as restricted stock or restricted stock unit awards. We issue common shares on the grant date for restricted stock awards and on the exercise or vesting date for options and restricted stock units. Restricted Stock. At December 31, 2016 , our employees held approximately 1.6 million shares of non-vested restricted stock awards and restricted stock units. These shares primarily vest over three to five years and vesting is dependent upon the employee’s continued service with our Company. In addition, at December 31, 2016 , our employees held approximately 0.9 million shares of restricted stock units subject to performance-based vesting criteria (all of which are currently considered market-based restricted stock under authoritative accounting guidance). The following table provides information about restricted stock awards and restricted stock unit activity. Service-Based Shares Weighted- Average Grant Date Fair Value per Share Performance/ Market-Based Shares (1) Weighted- Average Grant Date Fair Value per Share Total Shares (In thousands, except per share data) Non-vested shares outstanding at January 1, 2014 2,999 $ 33.45 706 $ 34.22 3,705 Granted 465 30.40 338 18.59 803 Forfeited (416 ) 28.20 (69 ) 27.56 (485 ) Vested (1,146 ) 36.65 (30 ) 39.43 (1,176 ) Non-vested shares outstanding at December 31, 2014 1,902 30.79 945 28.61 2,847 Granted 1,036 31.20 414 22.85 1,450 Forfeited (367 ) 21.69 (97 ) 36.72 (464 ) Vested (871 ) 32.10 (188 ) 39.42 (1,059 ) Non-vested shares outstanding at December 31, 2015 1,700 30.30 1,074 23.76 2,774 Granted 990 37.95 436 28.94 1,426 Forfeited (217 ) 29.15 (77 ) 43.04 (294 ) Vested (899 ) 29.34 (574 ) 21.36 (1,473 ) Non-vested shares outstanding at December 31, 2016 1,574 $ 35.56 859 $ 26.28 2,433 _________________ (1) In February 2016, we granted approximately 436,000 restricted stock units, which based on achievement of certain performance criteria, could vest within a range of 0% to 200% of shares granted upon completion of the performance period ending December 2018. The total fair value of all restricted stock awards and restricted stock units that vested during the years ended December 31, 2016 , 2015 and 2014 was $39 million , $35 million and $43 million , respectively. Stock Options. Options generally expire ten years from the grant date and become exercisable at the rate of 20% per year. The exercise price of options cannot be less than the fair market value per share of our common stock on the grant date. We issue new shares of stock when stock options are exercised. No stock options have been granted since 2008, except for ESPP options as discussed in the Employee Stock Purchase Plan section below. The following table provides information about outstanding stock options. Number of Shares Underlying Options Weighted-Average Exercise Price per Share Weighted-Average Remaining Contractual Life Aggregate Intrinsic Value (1) (In thousands) (In years) (In millions) Outstanding and exercisable at: December 31, 2014 301 $ 43.93 2.2 $ — December 31, 2015 195 48.45 2.1 — December 31, 2016 177 48.45 1.1 — _________________ (1) The intrinsic value of a stock option is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the option. Employee Stock Purchase Plan . In May 2010, our stockholders approved the Newfield Exploration Company 2010 Employee Stock Purchase Plan (ESPP) with one million shares of our common stock available for issuance. Pursuant to our employee stock purchase plan, for each six-month period beginning on January 1 or July 1 during the plan term, each eligible employee has the opportunity to purchase our common stock for a purchase price equal to 85% of the lesser of the fair market value of our common stock on the first or last day of the period. Each employee may purchase up to $25,000 in common stock per calendar year. Employees of our China business are not eligible to participate in the plan. At December 31, 2016 , approximately 121,000 shares of our common stock remained available for issuance under the current plan. The fair value of the options granted was determined using the Black-Scholes option valuation method assuming no dividends and an expected life of six months. For the years ended December 31, our ESPP issuances and valuation assumptions consisted of the following: Options Issued Weighted-Average Fair Value per Share Risk-free Interest Rate Weighted-Average Volatility (In thousands) 2014 168 $ 7.91 0.07 % 32.05 % 2015 136 8.71 0.12 49.41 2016 99 10.51 0.43 47.94 Liability Awards Liability awards consist of service-based awards that are settled in cash instead of shares, as discussed below. Cash-Settled Restricted Stock Units. The value of the cash-settled restricted stock units, and the associated stock-based compensation expense, is based on the Company's stock price at the end of each period. As of December 31, 2016 , we had a liability of $11 million for estimated future cash settlement upon vesting of awards. The following table provides information about cash-settled restricted stock unit activity. Cash-Settled Restricted Stock Units (In thousands) Non-vested units outstanding at January 1, 2014 1,170 Granted 759 Forfeited (126 ) Vested (587 ) Non-vested units outstanding at December 31, 2014 1,216 Granted 211 Forfeited (257 ) Vested (462 ) Non-vested units outstanding at December 31, 2015 708 Granted 299 Forfeited (101 ) Vested (446 ) Non-vested units outstanding at December 31, 2016 460 Stockholder Value Appreciation Program. In 2013, the Compensation and Management Development Committee of the Board approved the SVAP to be administered under the 2011 Plan. The SVAP paid substantially all full-time domestic, nonexecutive employees a cash payment based on a percentage of salary upon each incremental $5 increase in our 30 calendar-day average share price. Each price threshold could be reached only once during the term of the program. The first price threshold that triggered a payment under the SVAP was $27.50 during the fourth quarter of 2013. The second and third price thresholds for the SVAP were $32.50 and $37.50 , respectively, which were reached during the second quarter of 2014. The fourth price threshold for the SVAP of $42.50 was reached in July 2014. Each of the SVAP payments was approximately $13 million . No liability existed at December 31, 2015 or thereafter, as the SVAP's performance period ended on that date.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2016
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Compensation and Employee Benefit Plans [Text Block]	Employee Benefit Plans Post-Retirement Medical Plan We sponsor a post-retirement medical plan that covers all retired employees until they reach age 65 . At December 31, 2016 , both our accumulated benefit obligation and our accrued benefit costs were $20 million . Our net periodic benefit cost was approximately $3 million for each of the years ended December 31, 2016 and 2015 , and $2 million for the year ended December 31, 2014 . The expected future benefit payments under our post-retirement medical plan for the next ten years include $7 million for the five-year period 2017 through 2021 and $8 million for the five-year period 2022 through 2026. Annual Cash Incentive Compensation Plan During 2010, our Board of Directors, with the recommendation of the Compensation & Management Development Committee, approved a new annual cash incentive compensation plan for all employees (the 2011 Annual Incentive Plan). Under the 2011 Annual Incentive Plan, the Compensation & Management Development Committee determines the annual award pool for all employees based upon a number of factors including the Company’s performance against stated performance goals and in comparison with peer companies in our industry. All employees are eligible if employed on October 1 and December 31 of the performance period. Beginning with the year ended December 31, 2010, our annual cash incentive compensation is paid in a single payment to employees during the first quarter after the performance period ends. Total incentive compensation expense under the 2011 Annual Incentive Plan for the years ended December 31, 2016 , 2015 and 2014 was $35 million , $41 million and $45 million , respectively. 401(k) and Deferred Compensation Plans We sponsor a 401(k) profit sharing plan under Section 401(k) of the Internal Revenue Code. This plan covers all of our employees, excluding those of our foreign subsidiaries. We match $1.00 for each $1.00 of employee deferral, with our contribution not to exceed 8% of an employee’s salary, subject to limitations imposed by the IRS. We also sponsor a highly compensated employee deferred compensation plan. This non-qualified plan allows an eligible employee to defer a portion of his or her salary or bonus on an annual basis. We match $1.00 for each $1.00 of employee deferral, with our contribution not to exceed 8% of an employee’s salary, subject to limitations imposed by the plan. Our contribution with respect to each participant in the deferred compensation plan is reduced by the amount of contribution made by us to our 401(k) plan for that participant. Our combined contributions to these two plans was $6 million , $7 million and $10 million for the years ended December 31, 2016 , 2015 and 2014 , respectively.

Restructuring Costs Restructuri

Restructuring Costs Restructuring Costs	12 Months Ended
	Dec. 31, 2016
Restructuring and Related Activities [Abstract]
Restructuring and Related Activities Disclosure [Text Block]	Restructuring Costs Restructuring costs include severance and related benefit costs, costs associated with abandoned office space, employee relocation costs and other associated costs. Employee severance and related benefit costs are recognized on a straight-line basis over the required service period, if any. Employee relocation costs are expensed as incurred. On the date a leased property ceases to be used, a liability for non-cancellable office-lease costs associated with restructuring is recognized and measured at fair value on our consolidated balance sheet. Fair value estimates include assumptions regarding estimated future sublease payments. These estimates could materially differ from actual results and may require revision to initial estimates of the liability. See Note 17 , " Restructuring Costs ," for additional disclosures. Restructuring Costs In May 2016, we announced plans to consolidate and reorganize domestic operating functions to our headquarters in The Woodlands, Texas, which resulted in a significant reduction of employees located in the Tulsa, Oklahoma office during the third quarter of 2016. Our decision to restructure the organization was primarily in response to the oil and gas commodity price environment. Substantially all restructuring-related costs have been incurred as of December 31, 2016. We abandoned our Tulsa, Oklahoma office space during the third quarter of 2016 and recorded a liability for the remaining contracted payments. In April 2015, we announced plans to combine our onshore Gulf Coast and Rocky Mountain business units. Our decision to restructure the organization, which only affected our Gulf Coast and Rocky Mountain business units, was primarily in response to the oil and gas commodity price environment. Substantially all restructuring-related costs were incurred by December 31, 2015. We abandoned our Denver, Colorado office space during the third quarter of 2015 and recorded a loss for the remaining contracted payments net of expected sublease income. We closed our North Houston (Greenspoint area) office in the first quarter of 2016. Restructuring costs recorded in our consolidated statement of operations for the year ended December 31 are set forth below. Type of Restructuring Cost Location in the Consolidated Statement of Operations 2016 2015 (In millions) Severance and related benefit costs Operating expenses - General and administrative $ 17 $ 7 Relocation costs Operating expenses - General and administrative 5 5 Office-lease abandonment costs Operating expenses - General and administrative 6 14 Other associated costs Operating expenses - Depreciation, depletion and amortization — 1 Total $ 28 $ 27 The following table summarizes our restructuring costs and related accruals. Severance and Related Benefit Costs Office-lease Abandonment Costs Relocation Costs Other Associated Costs Total (In millions) Restructuring liability at January 1, 2015 $ — $ — $ — $ — $ — Additions 7 14 5 1 27 Settlements (6 ) (1 ) (5 ) (1 ) (13 ) Revisions — — — — — Restructuring liability at December 31, 2015 $ 1 $ 13 $ — $ — $ 14 Cumulative costs as of December 31, 2015 $ 7 $ 14 $ 5 $ 1 $ 27 Restructuring liability at January 1, 2016 $ 1 $ 13 $ — $ — $ 14 Additions 17 3 5 — 25 Settlements (17 ) (5 ) (5 ) — (27 ) Revisions — 3 — — 3 Restructuring liability at December 31, 2016 (1) $ 1 $ 14 $ — $ — $ 15 Cumulative costs as of December 31, 2016 $ 24 $ 20 $ 10 $ 1 $ 55 Expected total costs $ 24 $ 20 $ 11 $ 1 $ 56 _________________ (1) Substantially all of the remaining liability relates to accrued losses on abandoned office space in Denver, Colorado and Tulsa, Oklahoma. This liability will be reduced by lease payments made on these leases over the next six years.

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segment Reporting Disclosure [Text Block]	Segment Information While we only have operations in the oil and gas exploration and production industry, we are organizationally structured along geographic operating segments. Our current operating segments are the United States and China. The accounting policies of our operating segments are the same as those described in Note 1 , " Organization and Summary of Significant Accounting Policies ." The following tables provide the geographic operating segment information for our continuing operations for the years ended December 31, 2016 , 2015 and 2014 . Income tax allocations have been determined based on statutory rates in the applicable geographic segment. Our income tax allocation of our China operations is based on the combined statutory rates for China and the United States. Domestic China Total (In millions) Year Ended December 31, 2016: Oil, gas and NGL revenues $ 1,255 $ 217 $ 1,472 Operating expenses: Lease operating 189 55 244 Transportation and processing 272 — 272 Production and other taxes 41 1 42 Depreciation, depletion and amortization 458 114 572 General and administrative 205 8 213 Ceiling test and other impairments 962 66 1,028 Other 20 — 20 Allocated income tax (benefit) (330 ) (16 ) Net income (loss) from oil and gas properties $ (562 ) $ (11 ) Total operating expenses 2,391 Income (loss) from continuing operations (919 ) Interest expense, net of interest income, capitalized interest and other (98 ) Commodity derivative income (expense) (191 ) Income (loss) from continuing operations before income taxes $ (1,208 ) Total assets $ 4,166 $ 146 $ 4,312 Additions to long-lived assets $ 1,304 $ — $ 1,304 Domestic China Total (In millions) Year Ended December 31, 2015: Oil, gas and NGL revenues $ 1,295 $ 262 $ 1,557 Operating expenses: Lease operating 231 54 285 Transportation and processing 212 — 212 Production and other taxes 45 1 46 Depreciation, depletion and amortization 754 163 917 General and administrative 237 7 244 Ceiling test and other impairments 4,786 118 4,904 Other 9 1 10 Allocated income tax (benefit) (1,842 ) (49 ) Net income (loss) from oil and gas properties $ (3,137 ) $ (33 ) Total operating expenses 6,618 Income (loss) from continuing operations (5,061 ) Interest expense, net of interest income, capitalized interest and other (145 ) Commodity derivative income (expense) 259 Income (loss) from continuing operations before income taxes $ (4,947 ) Total assets $ 4,452 $ 316 $ 4,768 Additions to long-lived assets $ 1,521 $ 17 $ 1,538 Domestic China Total (In millions) Year Ended December 31, 2014: Oil, gas and NGL revenues $ 2,249 $ 39 $ 2,288 Operating expenses: Lease operating 299 12 311 Transportation and processing 174 — 174 Production and other taxes 105 6 111 Depreciation, depletion and amortization 857 13 870 General and administrative 221 1 222 Other 25 — 25 Allocated income tax (benefit) 210 5 Net income (loss) from oil and gas properties $ 358 $ 2 Total operating expenses 1,713 Income (loss) from continuing operations 575 Interest expense, net of interest income, capitalized interest and other (153 ) Commodity derivative income (expense) 610 Income (loss) from continuing operations before income taxes $ 1,032 Total assets $ 8,852 $ 728 $ 9,580 Additions to long-lived assets $ 2,037 $ 156 $ 2,193

Supplemental Cash Flows Informa

Supplemental Cash Flows Information	12 Months Ended
	Dec. 31, 2016
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flows Information Text Block	Supplemental Cash Flows Information The following table presents information about supplemental cash flows for each of the years in the three-year period ended December 31: 2016 2015 2014 (In millions) Cash Payments: Interest payments $ 97 $ 119 $ 144 Income tax payments 17 25 4 Non-cash investing and financing activities excluded from the statement of cash flows: (Increase) decrease in receivables for property sales $ 6 $ 6 $ (17 ) (Increase) decrease in accrued capital expenditures 33 225 (1 ) (Increase) decrease in asset retirement costs 46 (4 ) (56 )

Discontinued Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2016
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	Discontinued Operations In 2013, we met the criteria to classify our Malaysia business as held for sale and discontinued operations. In February 2014, we closed the sale of our Malaysia business to SapuraKencana Petroleum Berhad (SapuraKencana), a Malaysian public company, for $898 million . As a result of the sale, we recorded a gain in the first quarter of 2014 of approximately $388 million ( $252 million , after tax). In the fourth quarter of 2014, we recorded an allowance against a receivable from SapuraKencana and reduced the previously recognized gain by $15 million ( $10 million , after tax) due to uncertainty associated with collectability. There are no other assets and liabilities in the consolidated balance sheet attributable to discontinued operations as of December 31, 2016 or 2015 . Results of Discontinued Operations Year Ended December 31, 2014 (In millions) Oil and gas revenues (1) $ 90 Operating expenses 69 Income from discontinued operations 21 Gain on sale of Malaysia business 373 Income from discontinued operations before income taxes 394 Income tax provision (benefit): Current 12 Deferred 132 Total income tax provision (benefit) 144 Income (loss) from discontinued operations, net of tax $ 250 ________________ (1) Certain payments to foreign governments made on our behalf that are part of the revenue process are recorded as a reduction of the related oil and gas revenues. Income Taxes Historically, our effective tax rate in Malaysia was approximately 38% . As a result of our December 2012 decision to repatriate earnings from our international operations, we experienced higher international effective tax rates due to these earnings being taxed in both the U.S. and the local country. The effective tax rate for our discontinued operations for the year ended December 31, 2014 was 37% , as the majority of our income from discontinued operations resulted from the gain on the sale of our Malaysia business, which was only taxable in the U.S.

Quarterly Results of Operations

Quarterly Results of Operations	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information Text Block	Quarterly Results of Operations (Unaudited) The results of operations by quarter for the indicated periods are as follows: 2016 Quarter Ended March 31 June 30 September 30 December 31 (In millions, except per share data) Oil, gas and NGL revenues $ 284 $ 381 $ 392 $ 415 Ceiling test and other impairments 506 522 — — Income (loss) from operations (2) (578 ) (498 ) 45 112 Net income (loss) (2) (624 ) (667 ) 48 13 Basic earnings (loss) per share (1) (3.52 ) (3.36 ) 0.24 0.07 Diluted earnings (loss) per share (1) (3.52 ) (3.36 ) 0.24 0.07 2015 Quarter Ended March 31 June 30 September 30 December 31 (In millions, except per share data) Oil, gas and NGL revenues $ 349 $ 469 $ 377 $ 362 Ceiling test and other impairments 792 1,521 1,889 702 Income (loss) from operations (884 ) (1,496 ) (1,951 ) (730 ) Net income (loss) (480 ) (992 ) (1,227 ) (663 ) Basic earnings (loss) per share (1) (3.30 ) (6.09 ) (7.52 ) (4.06 ) Diluted earnings (loss) per share (1) (3.30 ) (6.09 ) (7.52 ) (4.06 ) _________________ (1) The sum of the individual quarterly earnings (loss) per share may not agree with year-to-date earnings (loss) per share as each quarterly computation is based on the income or loss for that quarter and the weighted-average number of shares outstanding during that quarter. (2) Income (loss) from operations and Net income (loss) for the third quarter of 2016 include a legal settlement of $ 18 million . See Note 12 , " Commitments and Contingencies — Litigation " for additional information.

Subsequent Events (Notes)

Subsequent Events (Notes)	12 Months Ended
	Dec. 31, 2016
Subsequent Events [Abstract]
Subsequent Events [Text Block]	Subsequent Events On January 23, 2017, we signed a sales agreement, subject to customary regulatory approval, with certain of our joint venture partners to divest our non-operated interest in the Bohai Bay field in China for approximately $39 million , subject to customary post-close adjustments. We expect that the sale will significantly alter the relationship between capitalized costs and proved reserves for our China full cost pool, and as such, a gain or loss may be recognized upon closing. We expect this transaction to close in mid-2017.

Organization and Summary of S31

Organization and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Organization and Principles of Consolidation	Organization and Principles of Consolidation We are an independent energy company engaged in the exploration, development and production of crude oil, natural gas and natural gas liquids (NGLs). Our U.S. operations are onshore and focus primarily on large scale, liquids-rich resource plays. Our principal areas of operation are the Anadarko and Arkoma basins of Oklahoma, the Williston Basin of North Dakota and the Uinta Basin of Utah. In addition, we have oil producing assets offshore China. Our consolidated financial statements include the accounts of Newfield Exploration Company, a Delaware corporation, and its subsidiaries. We proportionately consolidate our interests in oil and natural gas exploration and production ventures and partnerships in accordance with industry practice. All significant intercompany balances and transactions have been eliminated. Unless otherwise specified or the context otherwise requires, all references in these notes to "Newfield," "we," "us," "our" or the "Company" are to Newfield Exploration Company and its subsidiaries.
Dependence on Oil and Gas Prices	Risks and Uncertainties As an independent oil and natural gas producer, our revenue, profitability and future rate of growth are substantially dependent on prevailing prices for oil, natural gas and NGLs. Historically, the energy markets have been very volatile, and there can be no assurance that commodity prices will not be subject to wide fluctuations in the future. A substantial or extended decline in commodity prices could have a material adverse effect on our financial position, results of operations, cash flows, access to capital and on the quantities of oil, natural gas and NGL reserves that we can economically produce. Other risks and uncertainties that could affect us in the current commodity price environment include, but are not limited to, counterparty credit risk for our receivables, responsibility for decommissioning liabilities for offshore interests we no longer own, inability to access credit markets, regulatory risks and our ability to meet financial ratios and covenants in our financing agreements.
Use of Estimates	Use of Estimates The preparation of financial statements in accordance with accounting principles generally accepted in the United States of America (US GAAP) requires our management to make estimates and assumptions that affect the reported amounts of assets and liabilities; disclosure of contingent assets and liabilities at the date of the financial statements; the reported amounts of revenues and expenses during the reporting period; and the quantities and values of proved oil, natural gas and NGL reserves used in calculating depletion and assessing impairment of our oil and gas properties. Actual results could differ significantly from these estimates. Our most significant estimates are associated with the quantities of proved oil, natural gas and NGL reserves, the timing and amount of transfers of our unevaluated properties into our amortizable full cost pool, the recoverability of our deferred tax assets and the fair value of our derivative contracts.
Restructuring and Related Activities Disclosure [Text Block]	Restructuring Costs Restructuring costs include severance and related benefit costs, costs associated with abandoned office space, employee relocation costs and other associated costs. Employee severance and related benefit costs are recognized on a straight-line basis over the required service period, if any. Employee relocation costs are expensed as incurred. On the date a leased property ceases to be used, a liability for non-cancellable office-lease costs associated with restructuring is recognized and measured at fair value on our consolidated balance sheet. Fair value estimates include assumptions regarding estimated future sublease payments. These estimates could materially differ from actual results and may require revision to initial estimates of the liability. See Note 17 , " Restructuring Costs ," for additional disclosures. Restructuring Costs In May 2016, we announced plans to consolidate and reorganize domestic operating functions to our headquarters in The Woodlands, Texas, which resulted in a significant reduction of employees located in the Tulsa, Oklahoma office during the third quarter of 2016. Our decision to restructure the organization was primarily in response to the oil and gas commodity price environment. Substantially all restructuring-related costs have been incurred as of December 31, 2016. We abandoned our Tulsa, Oklahoma office space during the third quarter of 2016 and recorded a liability for the remaining contracted payments. In April 2015, we announced plans to combine our onshore Gulf Coast and Rocky Mountain business units. Our decision to restructure the organization, which only affected our Gulf Coast and Rocky Mountain business units, was primarily in response to the oil and gas commodity price environment. Substantially all restructuring-related costs were incurred by December 31, 2015. We abandoned our Denver, Colorado office space during the third quarter of 2015 and recorded a loss for the remaining contracted payments net of expected sublease income. We closed our North Houston (Greenspoint area) office in the first quarter of 2016. Restructuring costs recorded in our consolidated statement of operations for the year ended December 31 are set forth below. Type of Restructuring Cost Location in the Consolidated Statement of Operations 2016 2015 (In millions) Severance and related benefit costs Operating expenses - General and administrative $ 17 $ 7 Relocation costs Operating expenses - General and administrative 5 5 Office-lease abandonment costs Operating expenses - General and administrative 6 14 Other associated costs Operating expenses - Depreciation, depletion and amortization — 1 Total $ 28 $ 27 The following table summarizes our restructuring costs and related accruals. Severance and Related Benefit Costs Office-lease Abandonment Costs Relocation Costs Other Associated Costs Total (In millions) Restructuring liability at January 1, 2015 $ — $ — $ — $ — $ — Additions 7 14 5 1 27 Settlements (6 ) (1 ) (5 ) (1 ) (13 ) Revisions — — — — — Restructuring liability at December 31, 2015 $ 1 $ 13 $ — $ — $ 14 Cumulative costs as of December 31, 2015 $ 7 $ 14 $ 5 $ 1 $ 27 Restructuring liability at January 1, 2016 $ 1 $ 13 $ — $ — $ 14 Additions 17 3 5 — 25 Settlements (17 ) (5 ) (5 ) — (27 ) Revisions — 3 — — 3 Restructuring liability at December 31, 2016 (1) $ 1 $ 14 $ — $ — $ 15 Cumulative costs as of December 31, 2016 $ 24 $ 20 $ 10 $ 1 $ 55 Expected total costs $ 24 $ 20 $ 11 $ 1 $ 56 _________________ (1) Substantially all of the remaining liability relates to accrued losses on abandoned office space in Denver, Colorado and Tulsa, Oklahoma. This liability will be reduced by lease payments made on these leases over the next six years.
Reclassifications	Reclassifications Certain reclassifications have been made to prior years’ reported amounts in order to conform to the current year presentation. These reclassifications did not impact our net income (loss), stockholders’ equity or cash flows.
Discontinued Operations, Policy [Policy Text Block]	Discontinued Operations The results of our Malaysia operations are reflected separately as discontinued operations in the consolidated statement of operations on a line immediately after "Income (loss) from continuing operations." See Note 20 , " Discontinued Operations ," for additional disclosures, as well as information regarding the sale of our Malaysia business, which closed in February 2014. These financial statements and notes are inclusive of our Malaysia operations through the closing date unless otherwise noted.
Revenue Recognition	Revenue Recognition Substantially all of our oil, natural gas and NGLs are sold at market-based prices to a variety of purchasers, primarily under short-term contracts (less than 12 months). We also have long-term contracts in the Uinta Basin at market-based prices, less a variable differential that becomes fixed below certain market price thresholds. We record revenue when we deliver our production to the customer and collectability is reasonably assured. Revenues from the production of oil, natural gas and NGLs on properties in which we have joint ownership are recorded under the sales method. Under the sales method, the Company and other joint owners may sell more or less than their entitled share of production. Should the Company’s excess sales exceed our share of estimated remaining recoverable reserves, a liability is recorded. Differences between sales and our entitled share of production are not material.
Foreign Currency	Foreign Currency The functional currency for our China operations is the U.S. dollar. Gains and losses incurred on transactions in a currency other than the U.S. dollar are recorded under the caption "Other income (expense) — Other, net" on our consolidated statement of operations.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and cash equivalents include highly liquid investments with a maturity of three months or less when acquired and are stated at cost, which approximates fair value. We invest cash in excess of near-term capital and operating requirements in U.S. Treasury Notes, Eurodollar time deposits and money market funds, which are classified as cash and cash equivalents on our consolidated balance sheet.
Cash and Cash Equivalents, Restricted Cash and Cash Equivalents, Policy [Policy Text Block]	Restricted Cash Restricted cash consists of amounts held in escrow accounts to satisfy future plug and abandonment obligations for our China operations. These amounts are restricted as to their current use and will be released as we plug and abandon wells and facilities in China. Consistent with our other plug and abandonment activities, changes in restricted cash are included in cash flows from operating activities in our consolidated statement of cash flows.
Investments	Investments Our short-term investment at December 31, 2016 was a $25 million certificate of deposit, which is classified as "held-to-maturity" and stated at cost. Accordingly, no unrealized gains and losses are recognized. Long-term investments consist of debt and equity securities, a majority of which are classified as "available-for-sale" and stated at fair value. Accordingly, unrealized gains and losses and the related deferred income tax effects are excluded from earnings and reported in other comprehensive income within our consolidated statement of stockholders' equity. At December 31, 2016 , 2015 and 2014 , the portion of accumulated other comprehensive income within our consolidated statement of stockholders' equity related to investments was $1 million . Realized gains or losses are computed based on specific identification of the securities sold. We regularly assess our investments for impairment and consider any impairment to be other than temporary if we intend to sell the security, it is more likely than not that we will be required to sell the security, or we do not expect to recover our cost of the security.
Allowance for Doubtful Accounts	Allowance for Doubtful Accounts We routinely assess material trade and other receivables to determine their collectability. Many of our receivables are from joint interest owners of properties we operate. Thus, we may have the ability to withhold future revenue disbursements to recover any non-payment of related joint interest billings. Generally, our oil and gas receivables are collected within 45 to 60 days of production. We accrue a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected.
Inventories	Inventories Inventories primarily consist of tubular goods and well equipment held for use in our oil and natural gas operations and oil produced but not sold in our China operations. Inventories are carried at the lower of cost or market. Substantially all of the crude oil from our offshore operations in China is produced into floating storage facilities and sold periodically as barge quantities accumulate. The carrying value of oil inventory is the sum of related production costs and depletion expense. See Note 3 , " Inventories ," for further discussion.
Oil and Gas Properties	Oil and Gas Properties We use the full cost method of accounting for our oil and gas activities. Under this method, all costs incurred in the acquisition, exploration and development of oil and gas properties, including salaries, benefits, interest and other internal costs directly attributable to these activities, are capitalized into country-based cost centers. Proceeds from the sale of oil and gas properties are applied to reduce the costs in the applicable cost center unless the reduction would significantly alter the relationship between capitalized costs and proved reserves, in which case a gain or loss is recognized. During the first quarter of 2014, we sold our Malaysia business, which constituted the entire full cost pool for Malaysia. See Note 20 , " Discontinued Operations ," for further discussion. Capitalized costs and estimated future development costs are amortized using a unit-of-production method based on proved reserves associated with the applicable cost center. For each cost center, the net capitalized costs of oil and gas properties are limited to the lower of the unamortized cost or the cost center ceiling. A particular cost center ceiling is equal to the sum of: • the present value ( 10% per annum discount rate) of estimated future net revenues from proved reserves using oil, natural gas and NGL reserve estimation requirements, which require use of the unweighted average first-day-of-the-month commodity prices for the prior 12 months (SEC pricing), adjusted for market differentials applicable to our reserves (including the effects of derivative contracts that are designated for hedge accounting, if any); plus • the costs of properties not included in the costs being amortized, if any; less • related income tax effects. If net capitalized costs of oil and gas properties exceed the cost center ceiling, we are subject to a ceiling test impairment to the extent of such excess. If required, a ceiling test impairment reduces earnings and stockholders’ equity in the period of occurrence and, holding other factors constant, results in lower depreciation, depletion and amortization expense in future periods. The risk that we will be required to impair the carrying value of our oil and gas properties increases when oil, natural gas and NGL prices decrease significantly for a prolonged period, or if we have substantial downward revisions in our estimated proved reserves. Costs associated with unevaluated properties are excluded from our full cost pool until we have evaluated the properties or impairment is indicated. The costs associated with unevaluated leasehold acreage, related seismic data and capitalized interest and direct internal costs are initially excluded from our full cost pool. Leasehold costs are either transferred to our full cost pool with the costs of drilling a well on the lease or are assessed at least annually for possible impairment or reduction in value. Leasehold costs are transferred to our full cost pool to the extent a reduction in value has occurred, or a charge is made against earnings if the costs were incurred in a country for which a reserve base has not been established. See Note 6 , " Oil and Gas Properties ," for a detailed discussion regarding our oil and gas property and our asset acquisitions and sales transactions.
Other Property and Equipment	Other Property and Equipment Furniture, fixtures and equipment are recorded at cost and depreciated using the straight-line method over their estimated useful lives, which range from three to seven years. Gathering systems and equipment are recorded at cost and depreciated using the straight-line method over their estimated useful lives of 25 years.
Accounting for Asset Retirement Obligations	Accounting for Asset Retirement Obligations If a reasonable estimate of the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon wells can be made, we record a liability (an asset retirement obligation or ARO) on our consolidated balance sheet and capitalize the present value of the asset retirement cost in oil and gas properties in the period in which the ARO is incurred. Settlements include payments made to satisfy the AROs, as well as transfer of the AROs to purchasers of our divested properties. In general, the amount of the initial recorded ARO and the costs capitalized will equal the estimated future costs to satisfy the abandonment obligation assuming normal operation of the asset, using current prices that are escalated by an assumed inflation factor up to the estimated settlement date, which is then discounted back to the date that the abandonment obligation was incurred using the credit adjusted risk-free rate for our Company. After recording these amounts, the ARO is accreted to its future estimated value and the original capitalized costs are depreciated on a unit-of-production basis within the related full cost pool. Both the accretion and depreciation are included in depreciation, depletion and amortization expense on our consolidated statement of operations. See Note 10 , " Asset Retirement Obligations ," for further discussion.
Contingencies	Contingencies We are subject to legal proceedings, claims, liabilities and environmental matters that arise in the ordinary course of business. We accrue for losses when such losses are considered probable and the amounts can be reasonably estimated. See Note 12 , " Commitments and Contingencies ," for a more detailed discussion regarding our contingencies.
Environmental Matters	Environmental Matters Environmental costs that relate to current operations are expensed as incurred. Remediation costs that relate to an existing condition caused by past operations are accrued when it is probable that those costs will be incurred and can be reasonably estimated based upon evaluations of currently available facts related to each site.
Income Taxes	Income Taxes We use the liability method of accounting for income taxes. Under this method, deferred tax assets and liabilities are determined by applying tax regulations existing at the end of a reporting period to the cumulative temporary differences between the tax bases of assets and liabilities and their reported amounts in our financial statements. We assess the available positive and negative evidence to estimate if sufficient taxable income will be generated to utilize deferred tax assets. A valuation allowance is established to reduce deferred tax assets if it is more likely than not that the related tax benefits will not be realized. We also evaluate potential uncertain tax positions, and if necessary, establish accruals for such items. See Note 8 , " Income Taxes ," for further discussion.
Stock-Based Compensation	Stock-Based Compensation We apply a fair value-based method of accounting for stock-based compensation, which requires recognition in the financial statements of the cost of services received in exchange for equity and liability awards. For equity awards, compensation expense is based on the fair value on the grant or modification date and is recognized in our financial statements over the vesting period. We utilize the Black-Scholes option-pricing model to measure the fair value of stock options and a Monte Carlo lattice-based model for our performance- and market-based restricted stock and restricted stock units. We also have cash-settled restricted stock units that are accounted for under the liability method, which requires us to recognize the fair value of each award based on the Company's stock price at the end of each period. See Note 15 , " Stock-Based Compensation ," for a full discussion of our stock-based compensation.
Concentration of Credit Risk	Concentration of Credit Risk We operate a substantial portion of our oil and gas properties. As the operator of a property, we make full payment for costs associated with the property and seek reimbursement from the other joint interest owners in the property for their share of those costs. In addition, when warranted, we require prepayments from our joint interest owners for drilling and completion projects. Our joint interest owners consist primarily of independent oil and gas producers whose ability to reimburse us could be negatively impacted by adverse market conditions. The purchasers of our oil, gas and NGL production consist primarily of independent marketers, major oil and gas companies, refiners and gas pipeline companies. We perform credit evaluations of the purchasers of our production and monitor their financial condition on an ongoing basis. Based on our evaluations and monitoring, we obtain cash escrows, letters of credit or parental guarantees from some purchasers. All of our derivative transactions were carried out in the over-the-counter market and are not typically subject to margin-deposit requirements. The use of derivative transactions involves the risk that the counterparties will be unable to meet the financial terms of such transactions. We monitor the credit ratings of our derivative counterparties on an ongoing basis. Although we have entered into derivative contracts with multiple counterparties to mitigate our exposure to any individual counterparty, if any of our counterparties were to default on its obligations to us under the derivative contracts or seek bankruptcy protection, it could have a material adverse effect on our ability to fund our planned activities and could result in a larger percentage of our future production being subject to commodity price volatility. In addition, in poor economic environments and tight financial markets, the risk of a counterparty default is heightened and fewer counterparties may participate in derivative transactions, which could result in greater concentration of our exposure to any one counterparty or a larger percentage of our future production being subject to commodity price changes.
Major Customers	Major Customers China National Offshore Oil Corporation Ltd. accounted for 12% of our total revenues in 2016 . During 2015 , China National Offshore Oil Corporation Ltd., MidCon Gathering LLC and Sunoco Logistics Partners Operations GP LLC accounted for 13% , 11% and 10% , respectively, of our total revenues. During 2014 , Tesoro Corporation and Sunoco Logistics Partners Operations GP LLC accounted for 12% and 10% , respectively, of our total revenues. We believe that the loss of a major customer would not have a material adverse effect on us because alternative purchasers are available.
Derivative Financial Instruments	Derivative Financial Instruments Our derivative instruments are recorded on the consolidated balance sheet at fair value as either an asset or a liability with changes in fair value recognized currently in earnings. While we utilize our derivative instruments to manage the price risk attributable to our expected oil and gas production, we have elected not to designate our derivative instruments as accounting hedges under the accounting guidance. The related cash flow impact of our derivative activities is reflected as cash flows from operating activities unless the derivatives are determined to have a significant financing element at inception, in which case they are classified within financing activities. See Note 4 , " Derivative Financial Instruments ," for a more detailed discussion of our derivative activities.
Offsetting Fair Value	Offsetting Assets and Liabilities Our derivative financial instruments are subject to master netting arrangements and are reflected on our consolidated balance sheet accordingly. See Note 4 , " Derivative Financial Instruments ," for details regarding the gross amounts, as well as the impact of our netting arrangements on our net derivative position.
New Accounting Requirements	New Accounting Requirements In November 2016, the Financial Accounting Standards Board (FASB) issued guidance regarding the classification and presentation of changes in restricted cash on the statement of cash flows. The guidance requires that a statement of cash flows explains the change during the period in the total of cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents using a retrospective approach. The guidance is effective for interim and annual periods beginning after December 15, 2017. We are currently evaluating the impact of this guidance on our financial statements. In March 2016, the FASB issued guidance regarding the simplification of employee share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. We adopted this guidance in the second quarter of 2016 as permitted by the guidance. Adoption of this guidance did not impact our financial statements, except for the simplification in accounting for income taxes using a modified retrospective approach. Upon adoption, we recorded a related deferred tax asset for previously unrecognized excess tax benefits of $37 million . As we consider it more likely than not that the deferred tax asset will not be realized, we recorded a full valuation allowance of $37 million , resulting in no net effect on our consolidated statement of operations. We elected to continue our current policy of estimating forfeitures. In February 2016, the FASB issued guidance regarding the accounting for leases. The guidance requires recognition of most leases on the balance sheet. The guidance requires lessees and lessors to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The guidance is effective for interim and annual periods beginning after December 15, 2018. We are currently evaluating the impact of this guidance on our financial statements. In January 2016, the FASB issued guidance regarding several broad topics related to the recognition and measurement of financial assets and liabilities. The guidance is effective for interim and annual periods beginning after December 15, 2017. We do not expect this guidance to have a material impact on our financial statements. In May 2014, the FASB issued guidance regarding the accounting for revenue from contracts with customers. In April 2016, May 2016 and December 2016, the FASB issued additional guidance, addressed implementation issues and provided technical corrections. The guidance may be applied retrospectively or using a modified retrospective approach to adjust retained earnings (deficit). The guidance is effective for interim and annual periods beginning after December 15, 2017. We are currently evaluating the impact of this guidance on our financial statements.

Accounts Receivable (Tables)

Accounts Receivable (Tables)	12 Months Ended
	Dec. 31, 2016
Accounts Receivable, Net, Current [Abstract]
Schedule of Accounts, Notes, Loans and Financing Receivable [Table Text Block]	Accounts receivable consisted of the following at December 31: 2016 2015 (In millions) Revenue $ 163 $ 94 Joint interest 53 125 Other 32 59 Reserve for doubtful accounts (16 ) (16 ) Total accounts receivable, net $ 232 $ 262 Reserve for doubtful accounts at December 31, 2016 and 2015 includes an allowance for $15 million related to discontinued operations. See Note 20 , " Discontinued Operations ."

Derivative Financial Instrume33

Derivative Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedges, Assets [Abstract]
Percent of future hedged production with primary counterparties	85.00%
Outstanding contracts that are not designated for hedge accounting	At December 31, 2016 , we had outstanding derivative positions as set forth in the tables below. Crude Oil NYMEX Contract Price Per Bbl Collars Estimated Fair Value Period and Type of Instrument Volume in MBbls Swaps Purchased Calls (Weighted Average) (2) Sold Puts(Weighted Average) (1) Floors Ceilings (In millions) 2017: Fixed-price swaps 6,205 $ 45.43 $ — $ — $ — $ — $ (67 ) Fixed-price swaps with sold puts: 4,468 Fixed-price swaps 88.37 — — — — 142 Sold puts — — 73.28 — — (79 ) Collars with sold puts: 2,080 Collars — — — 90.00 95.59 71 Sold puts — — 75.00 — — (41 ) Purchased calls 6,548 — 73.81 — — — 3 Total $ 29 _________________ (1) For the volumes with sold puts, if the market prices remain below our sold puts at contract settlement, we will receive the market price plus the following: • the difference between our floors and our sold puts for collars with sold puts; or • the difference between our swaps and our sold puts for fixed-price swaps with sold puts. We have effectively locked in the spreads noted above (less the deferred call premium) for all of the volumes with sold puts using purchased calls. (2) We deferred the premiums related to the purchased calls until contract settlement. At December 31, 2016 , the deferred premiums totaled $10 million . Natural Gas Period and Type of Instrument NYMEX Contract Price Per MMBtu Collars Volume in MMMBtus Swaps (Weighted Average) Floors(Weighted Average) Ceilings(Weighted Average) Estimated Fair Value Asset (Liability) (In millions) 2017: Fixed-price swaps 27,375 $ 2.73 $ — $ — $ (24 ) Collars 53,860 — 2.82 3.23 (27 ) 2018: Fixed-price swaps 10,950 3.01 — — (1 ) Collars 18,150 — 3.00 3.55 (2 ) Total $ (54 )
Derivative financial instruments recorded in balance sheet	We had derivative financial instruments recorded in our consolidated balance sheet as assets (liabilities) at their respective estimated fair value, as set forth below. Derivative Assets Derivative Liabilities Gross Fair Value Offset in Balance Sheet Balance Sheet Location Gross Fair Value Offset in Balance Sheet Balance Sheet Location Current Noncurrent Current Noncurrent December 31, 2016 (In millions) (In millions) Oil positions $ 226 $ (151 ) $ 75 $ — $ (197 ) $ 151 $ (46 ) $ — Natural gas positions 10 (10 ) — — (64 ) 10 (51 ) (3 ) Total $ 236 $ (161 ) $ 75 $ — $ (261 ) $ 161 $ (97 ) $ (3 ) December 31, 2015 Oil positions $ 1,005 $ (638 ) $ 262 $ 105 $ (660 ) $ 638 $ (13 ) $ (9 ) Natural gas positions 22 — 22 — — — — — Total $ 1,027 $ (638 ) $ 284 $ 105 $ (660 ) $ 638 $ (13 ) $ (9 )
Schedule of Derivative Instruments, Gain (Loss) in Statement of Operations [Table Text Block]	The amount of gain (loss) recognized in "Commodity derivative income (expense)" in our consolidated statement of operations related to our derivative financial instruments follows: Year Ended December 31, 2016 2015 2014 (In millions) Derivatives not designated as hedging instruments: Realized gain (loss) on oil positions $ 199 $ 375 $ (3 ) Realized gain (loss) on natural gas positions 2 130 (36 ) Total realized gain (loss) 201 505 (39 ) Unrealized gain (loss) on oil positions (316 ) (165 ) 535 Unrealized gain (loss) on natural gas positions (76 ) (81 ) 114 Total unrealized gain (loss) (392 ) (246 ) 649 Total $ (191 ) $ 259 $ 610

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Fair value by measurement classification and type Table	The following table summarizes the valuation of our assets and liabilities that are measured at fair value on a recurring basis. Fair Value Measurement Classification Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total (In millions) As of December 31, 2015: Money market fund investments $ 2 $ — $ — $ 2 Deferred compensation plan assets 5 — — 5 Equity securities available-for-sale 8 — — 8 Oil and gas derivative swap contracts — 675 — 675 Oil and gas derivative option contracts — — (308 ) (308 ) Stock-based compensation liability awards (12 ) — — (12 ) Total $ 3 $ 675 $ (308 ) $ 370 As of December 31, 2016: Money market fund investments $ 320 $ — $ — $ 320 Deferred compensation plan assets 6 — — 6 Equity securities available-for-sale 9 — — 9 Oil and gas derivative swap contracts — 50 — 50 Oil and gas derivative option contracts — — (75 ) (75 ) Stock-based compensation liability awards (11 ) — — (11 ) Total $ 324 $ 50 $ (75 ) $ 299
Fair value changes level 3 Table	The following table sets forth a reconciliation of changes in the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy for the indicated periods. Investments Derivatives Stock-Based Compensation Total (In millions) Balance at January 1, 2014 $ 39 $ (8 ) $ (5 ) $ 26 Unrealized gains (losses) included in earnings — (381 ) (38 ) (419 ) Purchases, issuances, sales and settlements: Sales (39 ) — — (39 ) Settlements — 5 40 45 Transfers into Level 3 — — — — Transfers out of Level 3 (1) — 3 — 3 Balance at December 31, 2014 $ — $ (381 ) $ (3 ) $ (384 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at December 31, 2014 $ — $ (375 ) $ 2 $ (373 ) Balance at January 1, 2015 $ — $ (381 ) $ (3 ) $ (384 ) Unrealized gains (losses) included in earnings — (217 ) 3 (214 ) Purchases, issuances, sales and settlements: Settlements — 290 — 290 Transfers into Level 3 — — — — Transfers out of Level 3 — — — — Balance at December 31, 2015 $ — $ (308 ) $ — $ (308 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at December 31, 2015 $ — $ (143 ) $ 3 $ (140 ) Balance at January 1, 2016 $ — $ (308 ) $ — $ (308 ) Unrealized gains (losses) included in earnings — (33 ) — (33 ) Purchases, issuances, sales and settlements: Settlements — 220 — 220 Transfers into Level 3 — — — — Transfers out of Level 3 (2) — 46 — 46 Balance at December 31, 2016 $ — $ (75 ) $ — $ (75 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at December 31, 2016 $ — $ 13 $ — $ 13 _________________ (1) During the second quarter of 2014, we transferred $3 million of derivative option contracts out of the Level 3 category, resulting from the exercise of our Level 3 swaptions by the counterparties to swaps in May 2014. (2) During the second quarter of 2016, we transferred $46 million of derivative option contracts out of the Level 3 category, resulting from the exercise of our Level 3 swaptions by the counterparties to swaps in June 2016.
Quantitative disclosures about unobservable inputs	Estimated Fair Value Asset (Liability) Quantitative Information about Level 3 Fair Value Measurements Instrument Type Valuation Technique Unobservable Input Range (In millions) Oil option contracts $ (46 ) Modified Black-Scholes Oil price volatility 23.13 % — 66.5% Credit risk 0.01 % — 1.45% Natural gas option contracts $ (29 ) Modified Black-Scholes Natural gas price volatility 23.53 % — 53.39% Credit risk 0.01 % — 1.45%
Estimated fair value of the debt instrument at the balance sheet date	The estimated fair value of our notes, based on quoted prices in active markets (Level 1) as of December 31, was as follows: 2016 2015 (In millions) 5¾% Senior Notes due 2022 $ 789 $ 668 5⅝% Senior Notes due 2024 1,044 831 5⅜% Senior Notes due 2026 714 542

Oil and Gas Properties (Tables)

Oil and Gas Properties (Tables)	12 Months Ended
	Dec. 31, 2016
Oil and Gas Property [Abstract]
Costs incurred by year for oil and gas properties not subject to amortization	Costs withheld from amortization as of December 31, 2016 consisted of the following: Costs Incurred In 2016 2015 2014 2013 Total (In millions) Acquisition costs $ 540 $ 339 $ 162 $ 74 $ 1,115 Exploration costs 4 — — — 4 Capitalized interest 51 33 35 — 119 Total costs withheld from amortization (unproved) $ 595 $ 372 $ 197 $ 74 $ 1,238
Capitalized Costs Relating to Oil and Gas Producing Activities and Other PPE [Table Text Block]	At December 31, oil and gas properties consisted of the following: 2016 2015 (In millions) Proved $ 21,998 $ 21,568 Unproved 1,238 780 Gross oil and gas properties 23,236 22,348 Accumulated depreciation, depletion and amortization (9,587 ) (9,048 ) Accumulated impairment (10,509 ) (9,481 ) Net oil and gas properties $ 3,140 $ 3,819

Other Property and Equipment 36

Other Property and Equipment Other Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2016
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment [Table Text Block]	At December 31, other property and equipment consisted of the following: 2016 2015 (In millions) Furniture, fixtures and equipment $ 150 $ 152 Gathering systems and equipment 115 115 Accumulated depreciation and amortization (98 ) (95 ) Net other property and equipment $ 167 $ 172

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income (loss) before income taxes	For the years ended December 31, income (loss) from continuing operations before income taxes consisted of the following: 2016 2015 2014 (In millions) U.S. $ (1,181 ) $ (4,865 ) $ 1,022 International (27 ) (82 ) 10 Total income (loss) before income taxes $ (1,208 ) $ (4,947 ) $ 1,032
Total provision (benefit) for income taxes	For the years ended December 31, the total provision (benefit) for income taxes for continuing operations consisted of the following: 2016 2015 2014 (In millions) Current taxes: U.S. federal $ (13 ) $ (12 ) $ — U.S. state — (2 ) 2 International 22 31 3 Deferred taxes: U.S. federal 10 (1,507 ) 350 U.S. state 13 (27 ) 25 International (10 ) (68 ) 2 Total provision (benefit) for income taxes $ 22 $ (1,585 ) $ 382
Provision for income taxes using federal statutory rate	The following table presents a reconciliation of the United States statutory income tax rate to our effective income tax rate. 2016 2015 2014 U.S. statutory income tax rate 35.0 % 35.0 % 35.0 % State and local income taxes, net of federal effect — 0.9 1.7 Valuation allowance, domestic (35.5 ) (4.0 ) — Valuation allowance, international (2.4 ) (0.3 ) — Foreign tax on foreign earnings 0.6 0.4 0.2 Other 0.5 — 0.1 Effective income tax rate (1.8 )% 32.0 % 37.0 %
Components of deferred tax asset and deferred tax liability	At December 31, the components of our deferred tax asset (liability) were as follows: 2016 2015 (In millions) Deferred tax asset: Net operating loss carryforwards $ 301 $ 243 Alternative minimum tax credit 73 87 Stock-based compensation 15 23 Oil and gas properties 306 13 Commodity derivatives 9 — Foreign tax credit 593 572 Other 13 17 Total deferred tax asset 1,310 955 Deferred tax asset valuation allowances (1,310 ) (790 ) Net deferred tax asset — 165 Deferred tax liability: Commodity derivatives — (119 ) Oil and gas properties (39 ) (72 ) Total deferred tax liability (39 ) (191 ) Net deferred tax liability $ (39 ) $ (26 )
Roll forward of deferred tax asset valuation allowance	The change in our deferred tax asset valuation allowance is as follows at December 31: 2016 2015 2014 (In millions) Balance at the beginning of the year $ (790 ) $ (549 ) $ (584 ) Charged to provision for income taxes: U.S. state net operating loss carryforwards (4 ) (1 ) 1 U.S. federal and state valuation allowance (466 ) (202 ) — Malaysia valuation allowance — — 40 Foreign tax credit valuation allowance (21 ) (25 ) (12 ) Brazil and other international valuation allowance — — 6 China valuation allowance (29 ) (13 ) — Balance at the end of the year $ (1,310 ) $ (790 ) $ (549 )

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2016
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities [Table Text Block]	Accrued liabilities consisted of the following at December 31: 2016 2015 (In millions) Revenue payable $ 196 $ 164 Accrued capital costs 92 128 Accrued lease operating expenses 37 48 Employee incentive expense 48 53 Accrued interest on debt 67 66 Taxes payable 15 25 Other 43 49 Total accrued liabilities $ 498 $ 533

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation [Table Text Block]	The change in our ARO for continuing operations for each of the three years ended December 31, is set forth below: 2016 2015 2014 (In millions) Balance at January 1 $ 194 $ 186 $ 122 Accretion expense 10 10 8 Additions (1) 15 6 58 Revisions (23 ) (2 ) 16 Settlements (2) (40 ) (6 ) (18 ) Balance at December 31 156 194 186 Less: Current portion of ARO at December 31 (2 ) (2 ) (3 ) Total long-term ARO at December 31 $ 154 $ 192 $ 183 _________________ (1) For the year ended December 31, 2016 , additions include $8 million of abandonment obligations assumed through our Anadarko Basin acquisition. See Note 6 , " Oil and Gas Properties ." For the year ended December 31, 2014, additions include $28 million for our Pearl development in offshore China and $30 million for abandonment obligations in our domestic business. (2) For the year ended December 31, 2016 , settlements include $35 million related to the sale of our Texas assets. For the year ended December 31, 2014, settlements include $10 million related to the sale of our Granite Wash assets. See Note 6 , " Oil and Gas Properties ."

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Instrument [Line Items]
Debt	At December 31, our debt consisted of the following: 2016 2015 (In millions) Senior unsecured debt: Revolving credit facility — LIBOR based loans (matures in June 2020) $ — $ — Money market lines of credit — 39 Total credit arrangements — 39 5¾% Senior Notes due 2022 750 750 5⅝% Senior Notes due 2024 1,000 1,000 5⅜% Senior Notes due 2026 700 700 Total senior unsecured debt 2,450 2,489 Debt issuance costs (19 ) (22 ) Total long-term debt $ 2,431 $ 2,467

Commitments and Contingencies (

Commitments and Contingencies (Tables) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Future minimum payments under non-cancellable agreements		As of December 31, 2016 , future minimum payments under these non-cancelable agreements are as follows: Firm Transportation Operating Leases (Office Space) Drilling-Related Other Total (In millions) Year Ending December 31, 2017 $ 74 $ 21 $ 64 $ 16 $ 175 2018 57 19 5 12 93 2019 45 16 — 9 70 2020 10 15 — 5 30 2021 3 15 — 4 22 Thereafter 4 2 — 20 26 Total minimum future payments $ 193 $ 88 $ 69 $ 66 $ 416
Oil and gas production volume delivery commitments		As of December 31, 2016 , our delivery commitments through 2025 were as follows: Oil Year Ending December 31, (MBbls) 2017 12,775 2018 12,775 2019 12,775 2020 9,600 2021 7,300 Thereafter 26,800 Total delivery commitments 82,025
Loss Contingency, Damages Paid, Value	$ 18	$ 18

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2016
Earnings Per Share [Abstract]
Earnings Per Share Table	The following is the calculation of basic and diluted weighted-average shares outstanding and EPS for the indicated years: 2016 2015 2014 (In millions, except per share data) Income (numerator): Income (loss) from continuing operations $ (1,230 ) $ (3,362 ) $ 650 Income (loss) from discontinued operations — — 250 Net income (loss) $ (1,230 ) $ (3,362 ) $ 900 Weighted-average shares (denominator): Weighted-average shares — basic 193 159 137 Dilution effect of stock options and unvested restricted stock and restricted stock units outstanding at end of period — — 1 Weighted-average shares — diluted 193 159 138 Excluded due to anti-dilutive effect 2 3 1 Earnings (loss) per share: Basic: Income (loss) from continuing operations $ (6.36 ) $ (21.18 ) $ 4.76 Income (loss) from discontinued operations — — 1.83 Basic earnings (loss) per share $ (6.36 ) $ (21.18 ) $ 6.59 Diluted: Income (loss) from continuing operations $ (6.36 ) $ (21.18 ) $ 4.71 Income (loss) from discontinued operations — — 1.81 Diluted earnings (loss) per share $ (6.36 ) $ (21.18 ) $ 6.52

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2016
Share-based Compensation [Abstract]
Employee Stock Purchase Plan [Table Text Block]	For the years ended December 31, our ESPP issuances and valuation assumptions consisted of the following: Options Issued Weighted-Average Fair Value per Share Risk-free Interest Rate Weighted-Average Volatility (In thousands) 2014 168 $ 7.91 0.07 % 32.05 % 2015 136 8.71 0.12 49.41 2016 99 10.51 0.43 47.94
Schedule of Stock Based Compensation Expense Table	For the years ended December 31, our stock-based compensation expense consisted of the following: 2016 2015 2014 (In millions) Equity awards $ 32 $ 42 $ 47 Liability awards: Cash-settled restricted stock units 21 15 20 Stockholder Value Appreciation Program — (3 ) 38 Total liability awards 21 12 58 Total stock-based compensation 53 54 105 Capitalized in oil and gas properties (17 ) (18 ) (40 ) Net stock-based compensation expense $ 36 $ 36 $ 65
Stock Option Activity Table	The following table provides information about outstanding stock options. Number of Shares Underlying Options Weighted-Average Exercise Price per Share Weighted-Average Remaining Contractual Life Aggregate Intrinsic Value (1) (In thousands) (In years) (In millions) Outstanding and exercisable at: December 31, 2014 301 $ 43.93 2.2 $ — December 31, 2015 195 48.45 2.1 — December 31, 2016 177 48.45 1.1 — _________________ (1) The intrinsic value of a stock option is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the option.
Restricted Stock and Restricted Stock Unit Activity Table	The following table provides information about restricted stock awards and restricted stock unit activity. Service-Based Shares Weighted- Average Grant Date Fair Value per Share Performance/ Market-Based Shares (1) Weighted- Average Grant Date Fair Value per Share Total Shares (In thousands, except per share data) Non-vested shares outstanding at January 1, 2014 2,999 $ 33.45 706 $ 34.22 3,705 Granted 465 30.40 338 18.59 803 Forfeited (416 ) 28.20 (69 ) 27.56 (485 ) Vested (1,146 ) 36.65 (30 ) 39.43 (1,176 ) Non-vested shares outstanding at December 31, 2014 1,902 30.79 945 28.61 2,847 Granted 1,036 31.20 414 22.85 1,450 Forfeited (367 ) 21.69 (97 ) 36.72 (464 ) Vested (871 ) 32.10 (188 ) 39.42 (1,059 ) Non-vested shares outstanding at December 31, 2015 1,700 30.30 1,074 23.76 2,774 Granted 990 37.95 436 28.94 1,426 Forfeited (217 ) 29.15 (77 ) 43.04 (294 ) Vested (899 ) 29.34 (574 ) 21.36 (1,473 ) Non-vested shares outstanding at December 31, 2016 1,574 $ 35.56 859 $ 26.28 2,433 The following table provides information about cash-settled restricted stock unit activity. Cash-Settled Restricted Stock Units (In thousands) Non-vested units outstanding at January 1, 2014 1,170 Granted 759 Forfeited (126 ) Vested (587 ) Non-vested units outstanding at December 31, 2014 1,216 Granted 211 Forfeited (257 ) Vested (462 ) Non-vested units outstanding at December 31, 2015 708 Granted 299 Forfeited (101 ) Vested (446 ) Non-vested units outstanding at December 31, 2016 460

Restructuring Costs Restructu44

Restructuring Costs Restructuring Costs (Tables)	12 Months Ended
	Dec. 31, 2016
Restructuring and Related Activities [Abstract]
Restructuring and Related Costs [Table Text Block]	Restructuring costs recorded in our consolidated statement of operations for the year ended December 31 are set forth below. Type of Restructuring Cost Location in the Consolidated Statement of Operations 2016 2015 (In millions) Severance and related benefit costs Operating expenses - General and administrative $ 17 $ 7 Relocation costs Operating expenses - General and administrative 5 5 Office-lease abandonment costs Operating expenses - General and administrative 6 14 Other associated costs Operating expenses - Depreciation, depletion and amortization — 1 Total $ 28 $ 27
Schedule of Restructuring Reserve by Type of Cost [Table Text Block]	The following table summarizes our restructuring costs and related accruals. Severance and Related Benefit Costs Office-lease Abandonment Costs Relocation Costs Other Associated Costs Total (In millions) Restructuring liability at January 1, 2015 $ — $ — $ — $ — $ — Additions 7 14 5 1 27 Settlements (6 ) (1 ) (5 ) (1 ) (13 ) Revisions — — — — — Restructuring liability at December 31, 2015 $ 1 $ 13 $ — $ — $ 14 Cumulative costs as of December 31, 2015 $ 7 $ 14 $ 5 $ 1 $ 27 Restructuring liability at January 1, 2016 $ 1 $ 13 $ — $ — $ 14 Additions 17 3 5 — 25 Settlements (17 ) (5 ) (5 ) — (27 ) Revisions — 3 — — 3 Restructuring liability at December 31, 2016 (1) $ 1 $ 14 $ — $ — $ 15 Cumulative costs as of December 31, 2016 $ 24 $ 20 $ 10 $ 1 $ 55 Expected total costs $ 24 $ 20 $ 11 $ 1 $ 56

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting [Abstract]
Segment Information Table	Domestic China Total (In millions) Year Ended December 31, 2016: Oil, gas and NGL revenues $ 1,255 $ 217 $ 1,472 Operating expenses: Lease operating 189 55 244 Transportation and processing 272 — 272 Production and other taxes 41 1 42 Depreciation, depletion and amortization 458 114 572 General and administrative 205 8 213 Ceiling test and other impairments 962 66 1,028 Other 20 — 20 Allocated income tax (benefit) (330 ) (16 ) Net income (loss) from oil and gas properties $ (562 ) $ (11 ) Total operating expenses 2,391 Income (loss) from continuing operations (919 ) Interest expense, net of interest income, capitalized interest and other (98 ) Commodity derivative income (expense) (191 ) Income (loss) from continuing operations before income taxes $ (1,208 ) Total assets $ 4,166 $ 146 $ 4,312 Additions to long-lived assets $ 1,304 $ — $ 1,304	Domestic China Total (In millions) Year Ended December 31, 2015: Oil, gas and NGL revenues $ 1,295 $ 262 $ 1,557 Operating expenses: Lease operating 231 54 285 Transportation and processing 212 — 212 Production and other taxes 45 1 46 Depreciation, depletion and amortization 754 163 917 General and administrative 237 7 244 Ceiling test and other impairments 4,786 118 4,904 Other 9 1 10 Allocated income tax (benefit) (1,842 ) (49 ) Net income (loss) from oil and gas properties $ (3,137 ) $ (33 ) Total operating expenses 6,618 Income (loss) from continuing operations (5,061 ) Interest expense, net of interest income, capitalized interest and other (145 ) Commodity derivative income (expense) 259 Income (loss) from continuing operations before income taxes $ (4,947 ) Total assets $ 4,452 $ 316 $ 4,768 Additions to long-lived assets $ 1,521 $ 17 $ 1,538 Domestic China Total (In millions) Year Ended December 31, 2014: Oil, gas and NGL revenues $ 2,249 $ 39 $ 2,288 Operating expenses: Lease operating 299 12 311 Transportation and processing 174 — 174 Production and other taxes 105 6 111 Depreciation, depletion and amortization 857 13 870 General and administrative 221 1 222 Other 25 — 25 Allocated income tax (benefit) 210 5 Net income (loss) from oil and gas properties $ 358 $ 2 Total operating expenses 1,713 Income (loss) from continuing operations 575 Interest expense, net of interest income, capitalized interest and other (153 ) Commodity derivative income (expense) 610 Income (loss) from continuing operations before income taxes $ 1,032 Total assets $ 8,852 $ 728 $ 9,580 Additions to long-lived assets $ 2,037 $ 156 $ 2,193	Domestic China Total (In millions) Year Ended December 31, 2014: Oil, gas and NGL revenues $ 2,249 $ 39 $ 2,288 Operating expenses: Lease operating 299 12 311 Transportation and processing 174 — 174 Production and other taxes 105 6 111 Depreciation, depletion and amortization 857 13 870 General and administrative 221 1 222 Other 25 — 25 Allocated income tax (benefit) 210 5 Net income (loss) from oil and gas properties $ 358 $ 2 Total operating expenses 1,713 Income (loss) from continuing operations 575 Interest expense, net of interest income, capitalized interest and other (153 ) Commodity derivative income (expense) 610 Income (loss) from continuing operations before income taxes $ 1,032 Total assets $ 8,852 $ 728 $ 9,580 Additions to long-lived assets $ 2,037 $ 156 $ 2,193

Supplemental Cash Flows Infor46

Supplemental Cash Flows Information (Tables)	12 Months Ended
	Dec. 31, 2016
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flows Information Schedule (Table)	The following table presents information about supplemental cash flows for each of the years in the three-year period ended December 31: 2016 2015 2014 (In millions) Cash Payments: Interest payments $ 97 $ 119 $ 144 Income tax payments 17 25 4 Non-cash investing and financing activities excluded from the statement of cash flows: (Increase) decrease in receivables for property sales $ 6 $ 6 $ (17 ) (Increase) decrease in accrued capital expenditures 33 225 (1 ) (Increase) decrease in asset retirement costs 46 (4 ) (56 )

Discontinued Operations (Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2016
Discontinued Operations and Disposal Groups [Abstract]
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	Results of Discontinued Operations Year Ended December 31, 2014 (In millions) Oil and gas revenues (1) $ 90 Operating expenses 69 Income from discontinued operations 21 Gain on sale of Malaysia business 373 Income from discontinued operations before income taxes 394 Income tax provision (benefit): Current 12 Deferred 132 Total income tax provision (benefit) 144 Income (loss) from discontinued operations, net of tax $ 250 ________________ (1) Certain payments to foreign governments made on our behalf that are part of the revenue process are recorded as a reduction of the related oil and gas revenues.

Quarterly Results of Operatio48

Quarterly Results of Operations (Tables)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information Table	The results of operations by quarter for the indicated periods are as follows: 2016 Quarter Ended March 31 June 30 September 30 December 31 (In millions, except per share data) Oil, gas and NGL revenues $ 284 $ 381 $ 392 $ 415 Ceiling test and other impairments 506 522 — — Income (loss) from operations (2) (578 ) (498 ) 45 112 Net income (loss) (2) (624 ) (667 ) 48 13 Basic earnings (loss) per share (1) (3.52 ) (3.36 ) 0.24 0.07 Diluted earnings (loss) per share (1) (3.52 ) (3.36 ) 0.24 0.07 2015 Quarter Ended March 31 June 30 September 30 December 31 (In millions, except per share data) Oil, gas and NGL revenues $ 349 $ 469 $ 377 $ 362 Ceiling test and other impairments 792 1,521 1,889 702 Income (loss) from operations (884 ) (1,496 ) (1,951 ) (730 ) Net income (loss) (480 ) (992 ) (1,227 ) (663 ) Basic earnings (loss) per share (1) (3.30 ) (6.09 ) (7.52 ) (4.06 ) Diluted earnings (loss) per share (1) (3.30 ) (6.09 ) (7.52 ) (4.06 ) _________________ (1) The sum of the individual quarterly earnings (loss) per share may not agree with year-to-date earnings (loss) per share as each quarterly computation is based on the income or loss for that quarter and the weighted-average number of shares outstanding during that quarter. (2) Income (loss) from operations and Net income (loss) for the third quarter of 2016 include a legal settlement of $ 18 million . See Note 12 , " Commitments and Contingencies — Litigation " for additional information.

Organization and Summary of S49

Organization and Summary of Significant Accounting Policies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Jun. 30, 2016
Revenue, Major Customer [Line Items]
Document Fiscal Year Focus	2,016
Property, Plant and Equipment, Useful Life	25 years
Discount rate	10.00%
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Share-based Compensation Cost	$ 15	$ 23		$ 37
Deferred Tax Asset Valuation Allowance, Share Based Payments				$ 37
Short-term Investments [Abstract]
Short-term investments	$ 25	$ 0
Minimum [Member]
Property, Plant and Equipment, Useful Life	3 years
Maximum [Member]
Property, Plant and Equipment, Useful Life	7 years
Sunoco Logistics Partners [Member]
Revenue, Major Customer [Line Items]
Concentration Risk, Percentage		10.00%	10.00%
Tesoro Corporation [Member]
Revenue, Major Customer [Line Items]
Concentration Risk, Percentage			12.00%
MidCon Gathering LLC [Member]
Revenue, Major Customer [Line Items]
Concentration Risk, Percentage		11.00%
China National Offshore Oil Corporation [Member]
Revenue, Major Customer [Line Items]
Concentration Risk, Percentage	12.00%	13.00%

Organization and Summary of S50

Organization and Summary of Significant Accounting Policies AOCI related to Investments (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
AOCI related to Investments [Abstract]
Accumulated Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	$ 1	$ 1	$ 1

Accounts Receivable (Details)

Accounts Receivable (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Accounts Notes And Loans Receivable [Line Items]
Malaysia Reserve for Doubtful Accounts Allowance	$ 15	$ 15
Accounts receivable, net	232	262
Allowance for Doubtful Accounts Receivable, Current	(16)	(16)
Revenue [Member]
Accounts Notes And Loans Receivable [Line Items]
Accounts receivable, net	163	94
Oil and Gas Joint Interest Billing [Member]
Accounts Notes And Loans Receivable [Line Items]
Accounts receivable, net	53	125
Other accounts receivable [Member]
Accounts Notes And Loans Receivable [Line Items]
Accounts receivable, net	$ 32	$ 59

Inventories Inventories (Detail

Inventories Inventories (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)MBbls	Dec. 31, 2015USD ($)MBbls	Dec. 31, 2014USD ($)
Inventory [Line Items]
Inventory Write-down | $	$ 1	$ 5	$ 9
Crude oil inventory in barrels | MBbls	11,500	335,000

Derivative Financial Instrume53

Derivative Financial Instruments (Textuals) (Details) $ in Millions	Dec. 31, 2016USD ($)MMBTU$ / bbl$ / MMBTUMBbls
Derivative [Line Items]
Deferred Premium	$ 10
Percentage of contracted volumes held by the largest counterparty.	14.00%
Primary Derivative Counterparties	10
Total Derivative Counterparties	16
Percent of future hedged production with primary counterparties	85.00%
ConcentrationOfCounterpartiesUnderCreditFacility	84.00%
Natural gas contracts [Member]
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (54)
Oil contracts [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Total	$ 29
Year2018 [Member] | Natural gas contracts [Member] | Swap [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / MMBTU	3.01
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (1)
Volume In Mmbtus | MMBTU	10,950,000
Year2018 [Member] | Natural gas contracts [Member] | Collars [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price | $ / MMBTU	3
Derivative, Average Cap Price | $ / MMBTU	3.55
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (2)
Volume In Mmbtus | MMBTU	18,150,000
Year2017 [Member] | Natural gas contracts [Member] | Swap [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / MMBTU	2.73
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (24)
Volume In Mmbtus | MMBTU	27,375,000
Year2017 [Member] | Natural gas contracts [Member] | Collars [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price | $ / MMBTU	2.82
Derivative, Average Cap Price | $ / MMBTU	3.23
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (27)
Volume In Mmbtus | MMBTU	53,860,000
Year2017 [Member] | Oil contracts [Member] | Swap [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	6,205
Derivative, Swap Type, Average Fixed Price | $ / bbl	45.430
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (67)
Year2017 [Member] | Oil contracts [Member] | Fixed Price Swaps With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	4,468
Year2017 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Swap [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / bbl	88.37
Derivative Asset, Fair Value, Total	$ 142
Year2017 [Member] | Oil contracts [Member] | Collars With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	2,080
Year2017 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price | $ / bbl	73.28
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (79)
Year2017 [Member] | Oil contracts [Member] | Collars with Sold Puts - Collar [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price | $ / bbl	90
Derivative, Average Cap Price | $ / bbl	95.59
Derivative Asset, Fair Value, Total	$ 71
Year2017 [Member] | Oil contracts [Member] | Collars with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price | $ / bbl	75
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (41)
Year2017 [Member] | Oil contracts [Member] | Call Option [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	6,548
Derivative, Average Cap Price | $ / bbl	73.81
Derivative Asset, Fair Value, Total	$ 3

Derivative Financial Instrume54

Derivative Financial Instruments Recorded in Balance Sheet (Details) $ in Millions	Dec. 31, 2016USD ($)MMBTU$ / bbl$ / MMBTU	Dec. 31, 2015USD ($)
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Asset	$ 161	$ 638
Derivative Asset Not Designated As Hedging Instrument, Fair Value	236	1,027
Derivative Asset, Fair Value, Gross Liability	(161)	(638)
Derivative Asset, Current	75	284
Derivative Asset, Noncurrent	0	105
Derivative Liability, Current	(97)	(13)
Derivative Liability, Noncurrent	(3)	(9)
Derivative Liability, Fair Value, Gross Liability	(261)	(660)
Derivative Liability Not Designated as Hedging Instrument Fair Value	(261)	(660)
Natural gas contracts [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Asset	10	0
Derivative Liability, Fair Value, Total	(54)
Derivative Asset Not Designated As Hedging Instrument, Fair Value	10	22
Derivative Asset, Fair Value, Gross Liability	(10)	0
Derivative Asset, Current	0	22
Derivative Asset, Noncurrent	0	0
Derivative Liability, Current	(51)	0
Derivative Liability, Noncurrent	(3)	0
Derivative Liability, Fair Value, Gross Liability	(64)	0
Derivative Liability Not Designated as Hedging Instrument Fair Value	(64)	0
Oil contracts [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Asset	151	638
Derivative Asset, Fair Value, Total	(29)
Derivative Asset Not Designated As Hedging Instrument, Fair Value	226	1,005
Derivative Asset, Fair Value, Gross Liability	(151)	(638)
Derivative Asset, Current	75	262
Derivative Asset, Noncurrent	0	105
Derivative Liability, Current	(46)	(13)
Derivative Liability, Noncurrent	0	(9)
Derivative Liability, Fair Value, Gross Liability	(197)	(660)
Derivative Liability Not Designated as Hedging Instrument Fair Value	(197)	$ (660)
Year2017 [Member] | Collars [Member] | Natural gas contracts [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Total	$ (27)
Volume In Mmbtus | MMBTU	53,860,000
Derivative, Average Floor Price | $ / MMBTU	2.82
Derivative, Average Cap Price | $ / MMBTU	3.23
Year2017 [Member] | Swap [Member] | Natural gas contracts [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Total	$ (24)
Volume In Mmbtus | MMBTU	27,375,000
Derivative, Swap Type, Average Fixed Price | $ / MMBTU	2.73
Year2017 [Member] | Swap [Member] | Oil contracts [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Total	$ (67)
Derivative, Swap Type, Average Fixed Price | $ / bbl	45.430
Year2018 [Member] | Collars [Member] | Natural gas contracts [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Total	$ (2)
Volume In Mmbtus | MMBTU	18,150,000
Derivative, Average Floor Price | $ / MMBTU	3
Derivative, Average Cap Price | $ / MMBTU	3.55
Year2018 [Member] | Swap [Member] | Natural gas contracts [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Total	$ (1)
Volume In Mmbtus | MMBTU	10,950,000
Derivative, Swap Type, Average Fixed Price | $ / MMBTU	3.01

Amount of Gain Loss Recognized

Amount of Gain Loss Recognized in Income Related to Derivative Financial Instruments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	$ 201	$ 505	$ (39)
Unrealized Gain (Loss) on Derivatives	(392)	(246)	649
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(191)	259	610
Natural gas contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	2	130	(36)
Unrealized Gain (Loss) on Derivatives	(76)	(81)	114
Oil contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	199	375	(3)
Unrealized Gain (Loss) on Derivatives	$ (316)	$ (165)	$ 535

Fair Value Measurements (Textua

Fair Value Measurements (Textuals) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2014	Dec. 31, 2016	Dec. 31, 2015
Money Market Funds, at Carrying Value		$ 320	$ 2
Deferred Compensation Plan Assets		6	5
Obligations, Fair Value Disclosure		(11)	(12)
Assets, Fair Value Disclosure		299	370
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member]
Money Market Funds, at Carrying Value		320	2
Deferred Compensation Plan Assets		6	5
Obligations, Fair Value Disclosure		(11)	(12)
Assets, Fair Value Disclosure		324	3
Fair Value, Inputs, Level 2 [Member]
Money Market Funds, at Carrying Value		0	0
Deferred Compensation Plan Assets		0	0
Obligations, Fair Value Disclosure		0	0
Assets, Fair Value Disclosure		50	675
Fair Value, Inputs, Level 3 [Member]
Money Market Funds, at Carrying Value		0	0
Deferred Compensation Plan Assets		0	0
Obligations, Fair Value Disclosure		0	0
Financial and Nonfinancial Liabilities, Fair Value Disclosure		(75)	(308)
Equity Securities [Member]
Available-for-sale Securities		9	8
Proceeds from Sale of Available-for-sale Securities	$ 39
Equity Securities [Member] | Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member]
Available-for-sale Securities		9	8
Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]
Available-for-sale Securities		0	0
Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Available-for-sale Securities		0	0
Swap [Member]
Derivative Assets		50	675
Swap [Member] | Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member]
Derivative Assets		0	0
Swap [Member] | Fair Value, Inputs, Level 2 [Member]
Derivative Assets		50	675
Swap [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative Assets		0	0
Commodity Option [Member]
Derivative Liability		(75)	(308)
Commodity Option [Member] | Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member]
Derivative Assets		0	0
Commodity Option [Member] | Fair Value, Inputs, Level 2 [Member]
Derivative Assets		0	0
Commodity Option [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative Liability		$ (75)	$ (308)

Reconciliation of Changes in Fa

Reconciliation of Changes in Fair Value of Financial Assets and Liabilities Classified as Level Three In Fair Value Hierarchy (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Jun. 30, 2016	Jun. 30, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance					$ 26
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value			$ (75)	$ (308)	(384)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings			(33)	(214)	(419)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales					(39)
Liability Settlements			220	290	45
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3					0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers Into Level 3			0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3			46	0	3
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)			13	(140)	(373)
Equity Securities [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Available-for-sale Securities			9	8
Derivatives [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales					0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3				0	0
Investments [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance			0	0	39
Included in earnings			0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales					(39)
Settlements			0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3			0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3			0	0	0
Ending Balance			0	0	0
Change in unrealized gains (losses) relating to investments and derivatives still held			0	0	0
Stock Compensation Plan [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales					0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3					0
Derivative Financial Instruments, Liabilities [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value					(381)	$ (8)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings					(381)
Liability Settlements					5
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers Into Level 3			0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	$ 46	$ 3	46	0	3
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)				(143)	(375)
Derivatives [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value			(75)	(308)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings			(33)	(217)
Liability Settlements			220	290
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)			13
Stock Compensation Plan [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value			0	0	(3)	$ (5)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings			0	3	(38)
Liability Settlements			0	0	40
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers Into Level 3			0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3			0	0	0
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)			0	3	$ 2
Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Available-for-sale Securities			$ 0	$ 0

Quantitative Information about

Quantitative Information about Level 3 Fair Value Measurements (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Liability Value	$ (75)	$ (308)	$ (384)
Natural gas contracts [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Derivative Liability, Fair Value, Total	(54)
Natural gas contracts [Member] | Options Held [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Derivative Liability, Fair Value, Total	$ (29)
Natural gas contracts [Member] | Options Held [Member] | Minimum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Credit Risk	0.01%
Fair Value Assumptions Expected Volatility Curves	23.53%
Natural gas contracts [Member] | Options Held [Member] | Maximum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Credit Risk	1.45%
Fair Value Assumptions Expected Volatility Curves	53.39%
Oil contracts [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Derivative Asset, Fair Value, Total	$ 29
Oil contracts [Member] | Options Held [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Derivative Liability, Fair Value, Total	$ (46)
Oil contracts [Member] | Options Held [Member] | Minimum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Credit Risk	0.01%
Fair Value Assumptions Expected Volatility Curves	23.13%
Oil contracts [Member] | Options Held [Member] | Maximum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Credit Risk	1.45%
Fair Value Assumptions Expected Volatility Curves	66.50%

Estimated Fair Value of Notes B

Estimated Fair Value of Notes Based on Quoted Market Prices (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
5.75 %Senior Notes Due 2022 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of debt	$ 789	$ 668
5.625% Senior Notes Due 2024 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of debt	1,044	831
Senior Notes Due 2026 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of debt	$ 714	$ 542

Oil and Gas Properties (Details

Oil and Gas Properties (Details) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016USD ($)$ / bbl$ / MMBTU	Sep. 30, 2016USD ($)$ / bbl$ / MMBTU	Jun. 30, 2016USD ($)$ / bbl$ / MMBTU	Mar. 31, 2016USD ($)$ / bbl$ / MMBTU	Dec. 31, 2015USD ($)$ / bbl$ / MMBTU	Sep. 30, 2015USD ($)$ / bbl$ / MMBTU	Jun. 30, 2015USD ($)$ / bbl$ / MMBTU	Mar. 31, 2015USD ($)$ / bbl$ / MMBTU	Dec. 31, 2016USD ($)$ / bbl$ / MMBTU	Dec. 31, 2015USD ($)$ / bbl$ / MMBTU	Dec. 31, 2014USD ($)
Oil and gas properties:
Capitalized Costs, Proved Properties	$ 21,998				$ 21,568				$ 21,998	$ 21,568
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	1,238				780				1,238	780
Capitalized Costs, Oil and Gas Producing Activities, Gross	23,236				22,348				23,236	22,348
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance Relating to Oil and Gas Producing Activities	(9,587)				(9,048)				(9,587)	(9,048)
Capitalized Costs, Accumulated Impairment Relating to Oil and Gas Producing Activities	(10,509)				(9,481)				(10,509)	(9,481)
Capitalized Costs, Oil and Gas Producing Activities, Net	3,140				3,819				3,140	3,819
Cost of oil and gas properties not subject to amortization
Acquisition costs	1,115								1,115
Exploration costs	4								4
Capitalized interest	119								119
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	$ 1,238				780				1,238	780
Oil and Gas Assets (Textuals) [Abstract]
Capitalization Of Internal Costs									$ 121	107	$ 199
Document Fiscal Year Focus									2,016
Insurance Recoveries Decrease to Capital					$ 57					$ 57
Asset Impairment Charges								$ 4
Unweighted average commodity price of oil based on first day of month prices for prior twelve months | $ / bbl	42.82	41.73	43.14	46.23	50.11	59.09	71.56	82.60	42.82	50.11
Unweighted average commodity price of natural gas based on first day of month prices for prior twelve months | $ / MMBTU	2.48	2.28	2.24	2.40	2.59	3.06	3.39	3.88	2.48	2.59
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitation Expense Gross	$ 0	$ 0	$ 522	$ 506	$ 702	$ 1,889	$ 1,521	$ 788	$ 1,028	$ 4,900
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitations, Expense	0	0	522	506	651	1,222	958	496	1,028	3,327
Proceeds from Sale of Oil and Gas Property and Equipment									405	90	620
Value of Assets acquired									486	125	33
Asset Retirement Obligation, Liabilities Incurred									15	6	58
Granite Wash [Member]
Oil and Gas Assets (Textuals) [Abstract]
Proceeds from Sale of Oil and Gas Property and Equipment											588
Anadarko Basin Acquisition [Member]
Oil and Gas Assets (Textuals) [Abstract]
Value of Assets acquired									476
Costs Incurred, Acquisition of Unproved Oil and Gas Properties									398
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves									86
Texas Asset Sale [Member]
Oil and Gas Assets (Textuals) [Abstract]
Proceeds from Sale of Oil and Gas Property and Equipment									380
UNITED STATES
Oil and Gas Assets (Textuals) [Abstract]
Ceiling Limitation Exceed Unamortized Costs Capitalized	873								873
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitation Expense Gross	0	0	501	461	656	1,817	1,521	788	962	4,782
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitations, Expense	0	0	501	461	620	1,193	958	496	962	3,267
China [Member]
Oil and Gas Assets (Textuals) [Abstract]
Ceiling Limitation Exceed Unamortized Costs Capitalized	7								7
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitation Expense Gross	0	0	21	45	46	72	0	0	66	118
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitations, Expense	0	$ 0	$ 21	$ 45	$ 31	$ 29	$ 0	$ 0	66	60
Costs incurred in 2016 not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	595								595
Cost of oil and gas properties not subject to amortization
Acquisition costs	540								540
Exploration costs	4								4
Capitalized interest	51								51
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	595								595
Costs incurred in 2015 and prior not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	372								372
Cost of oil and gas properties not subject to amortization
Acquisition costs	339								339
Exploration costs	0								0
Capitalized interest	33								33
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	372								372
Costs incurred in 2014 not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	197								197
Cost of oil and gas properties not subject to amortization
Acquisition costs	162								162
Exploration costs	0								0
Capitalized interest	35								35
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	197								197
Costs incurred in 2013 not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	74								74
Cost of oil and gas properties not subject to amortization
Acquisition costs	74								74
Exploration costs	0								0
Capitalized interest	0								0
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	$ 74								74
Other Property [Member]
Oil and Gas Assets (Textuals) [Abstract]
Proceeds from Sale of Oil and Gas Property and Equipment									39	90	69
Value of Assets acquired									$ 7	$ 125	$ 33

Oil and Gas Properties Ceiling

Oil and Gas Properties Ceiling Test Impairment (Details) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016USD ($)$ / bbl$ / MMBTU	Sep. 30, 2016USD ($)$ / bbl$ / MMBTU	Jun. 30, 2016USD ($)$ / bbl$ / MMBTU	Mar. 31, 2016USD ($)$ / bbl$ / MMBTU	Dec. 31, 2015USD ($)$ / bbl$ / MMBTU	Sep. 30, 2015USD ($)$ / bbl$ / MMBTU	Jun. 30, 2015USD ($)$ / bbl$ / MMBTU	Mar. 31, 2015USD ($)$ / bbl$ / MMBTU	Dec. 31, 2016USD ($)$ / bbl$ / MMBTU	Dec. 31, 2015USD ($)$ / bbl$ / MMBTU
Ceiling Test Impairment [Line Items]
Unweighted average commodity price of oil based on first day of month prices for prior twelve months | $ / bbl	42.82	41.73	43.14	46.23	50.11	59.09	71.56	82.60	42.82	50.11
Unweighted average commodity price of natural gas based on first day of month prices for prior twelve months | $ / MMBTU	2.48	2.28	2.24	2.40	2.59	3.06	3.39	3.88	2.48	2.59
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitation Expense Gross	$ 0	$ 0	$ 522	$ 506	$ 702	$ 1,889	$ 1,521	$ 788	$ 1,028	$ 4,900
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitations, Expense	0	0	522	506	651	1,222	958	496	1,028	3,327
UNITED STATES
Ceiling Test Impairment [Line Items]
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitation Expense Gross	0	0	501	461	656	1,817	1,521	788	962	4,782
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitations, Expense	0	0	501	461	620	1,193	958	496	962	3,267
China [Member]
Ceiling Test Impairment [Line Items]
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitation Expense Gross	0	0	21	45	46	72	0	0	66	118
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitations, Expense	$ 0	$ 0	$ 21	$ 45	$ 31	$ 29	$ 0	$ 0	$ 66	$ 60

Other Property and Equipment 62

Other Property and Equipment Other Property and Equipment (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Accumulated depreciation and amortization	$ (98)	$ (95)
Net other property and equipment	167	172
Furniture and Fixtures [Member]
Property, Plant and Equipment [Line Items]
Other property and equipment	150	152
Gas Gathering and Processing Equipment [Member]
Property, Plant and Equipment [Line Items]
Other property and equipment	$ 115	$ 115

Income Taxes (Details)

Income Taxes (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Jun. 30, 2016	Dec. 31, 2013
Operating Loss Carryforwards [Line Items]
Net operating loss carryforwards subject to annual limitations	$ 138,000,000
US state NOLs that we do not anticipate utilizing	173,000,000
EffectiveTaxRateReconciliation [Line Items]
Amount computed using the statutory rate	$ 0.35	$ 0.35	$ 0.35
State and local income taxes, net of federal effect	0.00%	0.90%	1.70%
Effective Income Tax Rate Reconciliation, Foreign Income Tax Rate Differential, Percent	0.60%	0.40%	0.20%
Effective Income Tax Rate Reconciliation, Other Adjustments, Percent	0.50%	0.00%	0.10%
Effective Income Tax Rate Reconciliation, Percent	(1.80%)	32.00%	37.00%
Income (loss) from continuing operations before income taxes	$ (1,208,000,000)	$ (4,947,000,000)	$ 1,032,000,000
Current Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	(13,000,000)	(12,000,000)	0
U.S. state	0	(2,000,000)	2,000,000
Foreign	22,000,000	31,000,000	3,000,000
Deferred taxes:
U.S. federal	10,000,000	(1,507,000,000)	350,000,000
U.S. state	13,000,000	(27,000,000)	25,000,000
Foreign	(10,000,000)	(68,000,000)	2,000,000
Income Tax Expense (Benefit)	22,000,000	(1,585,000,000)	382,000,000
Deferred tax asset:
Net operating loss carryforwards	301,000,000	243,000,000
Alternative minimum tax credit	73,000,000	87,000,000
Stock compensation	15,000,000	23,000,000		$ 37,000,000
Deferred Tax Assets, Property, Plant and Equipment	306,000,000	13,000,000
Deferred Tax Assets, Derivative Instruments	9,000,000	0
Foreign tax credit	593,000,000	572,000,000
Other	13,000,000	17,000,000
Deferred Tax Assets, Gross	1,310,000,000	955,000,000
Valuation Allowance	(1,310,000,000)	(790,000,000)	$ (549,000,000)		$ (584,000,000)
Deferred tax asset	0	165,000,000
Deferred tax liability:
Commodity derivatives	0	(119,000,000)
Deferred Tax Liabilities, Property, Plant and Equipment	(39,000,000)	(72,000,000)
Deferred Tax Liabilities, Gross	(39,000,000)	(191,000,000)
Deferred tax liability	(39,000,000)	(26,000,000)
Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	849,000,000	852,000,000
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 1,800,000,000	$ 1,800,000,000
Domestic [Member]
EffectiveTaxRateReconciliation [Line Items]
Net effect of different tax rates in non-U.S. jurisdictions	(35.50%)	(4.00%)	0.00%
Income (loss) from continuing operations before income taxes	$ (1,181,000,000)	$ (4,865,000,000)	$ 1,022,000,000
Foreign [Member]
EffectiveTaxRateReconciliation [Line Items]
Net effect of different tax rates in non-U.S. jurisdictions	(2.40%)	(0.30%)	0.00%
Income (loss) from continuing operations before income taxes	$ (27,000,000)	$ (82,000,000)	$ 10,000,000

Income Taxes- DTA Valuation Rol

Income Taxes- DTA Valuation Rollforward (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Jun. 30, 2016
Valuation Allowance [Line Items]
Deferred Tax Asset Valuation Allowance, Share Based Payments				$ 37
Balance at the beginning of the year	$ (790)	$ (549)	$ (584)
Balance at the end of the year	(1,310)	(790)	(549)
State and Local Jurisdiction [Member]
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	(4)	(1)	1
Domestic Tax Authority [Member]
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	(466)	(202)	0
Malaysia [Member]
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	0	0	40
Foreign [Member]
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	(21)	(25)	(12)
Other International [Member]
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	0	0	6
China [Member]
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	$ (29)	$ (13)	$ 0

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Accrued Liabilities [Line Items]
Accrued liabilities	$ 498	$ 533
Revenue payable [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	196	164
Accrued capital costs [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	92	128
Accrued lease operating expenses [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	37	48
Employee incentive expense [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	48	53
Accrued interest on debt [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	67	66
Taxes payable [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	15	25
Other accrued liabilities [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	$ 43	$ 49

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Change in asset retirement obligations [Line Items]
Document Fiscal Year Focus	2,016
Asset Retirement Obligation	$ 156	$ 194	$ 186	$ 122
Asset Retirement Obligation, Accretion Expense	10	10	8
Asset Retirement Obligation, Liabilities Incurred	15	6	58
Asset Retirement Obligation, Revision of Estimate	(23)	(2)	16
Asset Retirement Obligation, Liabilities Settled	40	6	18
Asset Retirement Obligation, Current	(2)	(2)	(3)
Asset Retirement Obligations, Noncurrent	154	$ 192	183
Anadarko Basin Acquisition [Member]
Change in asset retirement obligations [Line Items]
Asset Retirement Obligation, Liabilities Incurred	8
China [Member]
Change in asset retirement obligations [Line Items]
Asset Retirement Obligation, Liabilities Incurred			28
Domestic Tax Authority [Member]
Change in asset retirement obligations [Line Items]
Asset Retirement Obligation, Liabilities Incurred			30
Texas Asset Sale [Member]
Change in asset retirement obligations [Line Items]
Asset retirement obligation liabilities settled through property sales	$ 35
Granite Wash [Member]
Change in asset retirement obligations [Line Items]
Asset retirement obligation liabilities settled through property sales			$ 10

Debt (Details)

Debt (Details)	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding	$ 0	$ 39,000,000
Long-term debt	(2,431,000,000)	(2,467,000,000)
Debt issuance costs	(19,000,000)	(22,000,000)
Net proceeds from issuance of Senior Notes		691,000,000
Payments of Debt Issuance Costs	0	8,000,000	$ 0
Early Repayment of Subordinated Debt	0	700,000,000	600,000,000
Payments Of Debt Extinguishment Costs		24,000,000
Write off of Deferred Debt Issuance Cost		8,000,000
Payments of Financing Costs	$ 3,000,000
Debt (Textuals)
Largest individual loan commitment by any lender of total commitments	12.00%
Percentage of basis points to be added for calculation of interest rate	0.50%
Percent added to prime rate based on grid of our debt rating	1.00%
Percentage added to LIBOR based on grid of our debt rating	2.00%
Commitment fee percentage on unused capacity of line of credit	0.375%
Commitment fees incurred	$ 7,000,000	$ 5,000,000	4,000,000
Ratio of Indebtedness to Net Capital 1	0.6
Ratio of total debt to earnings before gain or loss on disposition of assets, interest expense, income taxes and noncash items	2.5	3
Letters of Credit Outstanding, Amount	$ 0
Issuance fees percentage on letter of credit	0.20%
Percentage based on a grid of our debt rating on which letters of credit fees are based.	2.00%
Ratio of earnings before gain or loss on the disposition of assets, interest expense, income taxes and noncash items to interest expense	2.5	3
Percentage added to Credit Facility Margins	0.25%
Senior Notes Due 2026 [Member]
Debt Instrument [Line Items]
Long-term debt	$ (700,000,000)	$ (700,000,000)
Debt Instrument, Interest Rate, Stated Percentage	5.375%	5.375%
Payments of Debt Issuance Costs		$ 9,000,000
5.625% Senior Notes Due 2024 [Member]
Debt Instrument [Line Items]
Long-term debt	$ (1,000,000,000)	$ (1,000,000,000)
Debt Instrument, Interest Rate, Stated Percentage	5.625%	5.625%
Senior Subordinated Notes due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt			$ (700,000,000)
Total senior unsecured debt
Debt Instrument [Line Items]
Long-term debt	$ (2,450,000,000)	$ (2,489,000,000)
Money market lines of credit [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity	125,000,000	195,000,000
Line of Credit Facility, Amount Outstanding	0	39,000,000
5.75 %Senior Notes Due 2022 [Member]
Debt Instrument [Line Items]
Long-term debt	$ (750,000,000)	$ (750,000,000)
Debt Instrument, Interest Rate, Stated Percentage	5.75%	5.75%
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,800,000,000
Line of Credit Facility, Amount Outstanding	$ 0	$ 0

Commitments and Contingencies68

Commitments and Contingencies (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)MBbls	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Future minimum payments under non-cancellable agreements
2,017	$ 175
2,018	93
2,019	70
2,020	30
2,021	22
Thereafter	26
Total minimum future payments	$ 416
Delivery Commitments, Current (2017) | MBbls	12,775
Delivery Commitments, Due In Two Years (2018) | MBbls	12,775
Delivery Commitments, Due In Three Years (2019) | MBbls	12,775
Delivery Commitments, Due In Four Years (2020) | MBbls	9,600
Delivery Commitments, Due In Five Years (2021) | MBbls	7,300
Delivery Commitments, Due Thereafter | MBbls	26,800
Total Delivery Commitments | MBbls	82,025
Commitments and Contingencies (Textuals) [Abstract]
Rent expense under lease commitments	$ 21	$ 35	$ 20
Firm Transportation [Member]
Future minimum payments under non-cancellable agreements
2,017	74
2,018	57
2,019	45
2,020	10
2,021	3
Thereafter	4
Total minimum future payments	193
Operating Leases [Member]
Future minimum payments under non-cancellable agreements
2,017	21
2,018	19
2,019	16
2,020	15
2,021	15
Thereafter	2
Total minimum future payments	88
Drilling-Related Leases [Member]
Future minimum payments under non-cancellable agreements
2,017	64
2,018	5
2,019	0
2,020	0
2,021	0
Thereafter	0
Total minimum future payments	69
Other Commitments [Member]
Future minimum payments under non-cancellable agreements
2,017	16
2,018	12
2,019	9
2,020	5
2,021	4
Thereafter	20
Total minimum future payments	$ 66

Delivery Commitments (Details)

Delivery Commitments (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)bbls$ / bblMBbls
Delivery Commitments [Line Items]
Delivery Commitments, Current (2017)	12,775
Delivery Commitments, Due In Two Years (2018)	12,775
Delivery Commitments, Due In Three Years (2019)	12,775
Delivery Commitments, Due In Four Years (2020)	9,600
Delivery Commitments, Due In Five Years (2021)	7,300
Delivery Commitments, Due Thereafter	26,800
Total Delivery Commitments	82,025
Deficiency fees | $	$ 16
Minimum [Member]
Delivery Commitments [Line Items]
Deficiency fees per barrel | $ / bbl	3.50
Maximum [Member]
Delivery Commitments [Line Items]
Deficiency fees per barrel | $ / bbl	6.50
2017 to 2025 [Member]
Delivery Commitments [Line Items]
Oil and Gas Delivery Commitments and Contracts, Daily Production | bbls	20,000
2017 to 2020 [Member]
Delivery Commitments [Line Items]
Oil and Gas Delivery Commitments and Contracts, Daily Production | bbls	15,000

Stockholders' Equity Activity70

Stockholders' Equity Activity (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Equity, Class of Treasury Stock [Line Items]
Document Fiscal Year Focus			2,016
Treasury Stock, Shares, Acquired			583,340
Stock Issued During Period, Shares, New Issues	34,500,000	25,300,000
Proceeds from Issuance of Common Stock	$ 776	$ 815	$ 779	$ 819	$ 6
Common Stock, Shares Authorized		200,000,000	300,000,000	300,000,000

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income (numerator):
Income (Loss) from Continuing Operations Attributable to Parent									$ (1,230)	$ (3,362)	$ 650
Income (loss) from discontinued operations, net of tax									0	0	250
Net income (loss)	$ 13	$ 48	$ (667)	$ (624)	$ (663)	$ (1,227)	$ (992)	$ (480)	$ (1,230)	$ (3,362)	$ 900
Weighted average shares (denominator):
Weighted average shares - basic									193	159	137
Dilution effect of stock options and unvested restricted stock and restricted stock units outstanding at end of period									0	0	1
Weighted average shares - diluted									193	159	138
Basic --
Income (loss) from continuing operations									$ (6.36)	$ (21.18)	$ 4.76
Income (loss) from discontinued operations									0	0	1.83
Earnings (Loss) Per Share, Basic	$ 0.07	$ 0.24	$ (3.36)	$ (3.52)	$ (4.06)	$ (7.52)	$ (6.09)	$ (3.30)	(6.36)	(21.18)	6.59
Diluted --
Income (loss) from continuing operations									(6.36)	(21.18)	4.71
Income (loss) from discontinued operations									0	0	1.81
Earnings (Loss) Per Share, Diluted	$ 0.07	$ 0.24	$ (3.36)	$ (3.52)	$ (4.06)	$ (7.52)	$ (6.09)	$ (3.30)	$ (6.36)	$ (21.18)	$ 6.52
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]									The following is the calculation of basic and diluted weighted-average shares outstanding and EPS for the indicated years: 2016 2015 2014 (In millions, except per share data) Income (numerator): Income (loss) from continuing operations $ (1,230 ) $ (3,362 ) $ 650 Income (loss) from discontinued operations — — 250 Net income (loss) $ (1,230 ) $ (3,362 ) $ 900 Weighted-average shares (denominator): Weighted-average shares — basic 193 159 137 Dilution effect of stock options and unvested restricted stock and restricted stock units outstanding at end of period — — 1 Weighted-average shares — diluted 193 159 138 Excluded due to anti-dilutive effect 2 3 1 Earnings (loss) per share: Basic: Income (loss) from continuing operations $ (6.36 ) $ (21.18 ) $ 4.76 Income (loss) from discontinued operations — — 1.83 Basic earnings (loss) per share $ (6.36 ) $ (21.18 ) $ 6.59 Diluted: Income (loss) from continuing operations $ (6.36 ) $ (21.18 ) $ 4.71 Income (loss) from discontinued operations — — 1.81 Diluted earnings (loss) per share $ (6.36 ) $ (21.18 ) $ 6.52
Earnings Per Share (Textuals) [Abstract]
Incremental shares attributable to the assumed exercise of outstanding stock options and the assumed vesting of unvested restricted stock and restricted stock units									2	3	1

Stock-Based Compensation (Detai

Stock-Based Compensation (Details) $ / shares in Units, $ in Millions	3 Months Ended							12 Months Ended
	Mar. 31, 2016shares	Sep. 30, 2015$ / shares	Jun. 30, 2015$ / sharesshares	Sep. 30, 2014USD ($)	Jun. 30, 2014USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2013$ / sharesshares	Dec. 31, 2016USD ($)$ / sharesshares	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost								$ 53	$ 54	$ 105
Total stock-based compensation expense								36	36	65
Capitalized in oil and gas properties								$ (17)	$ (18)	$ (40)
Share-based Compensation Arrangement by Share-based Payment Award, Number of Additional Shares Authorized | shares			7,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period | shares								1,426,000	1,450,000	803,000
Number of restricted stock shares vested | shares								1,473,000	1,059,000	1,176,000
Number of restricted stock shares outstanding | shares							3,705,000	2,433,000	2,774,000	2,847,000
Fair value of units vested during the period								$ 39	$ 35	$ 43
Share Based Compensation Arrangement Exercise Rate								20.00%
Nonvested Awards, Total Compensation Cost Not yet Recognized								$ 61
Liability Value								75	308	384
Liability Settlements								220	290	45
Obligations, Fair Value Disclosure								$ 11	12
Stock-Based Compensation (Textuals) [Abstract]
Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition								4 years
Last reported sales price of our common stock on the New York Stock Exchange per share | $ / shares								$ 40.50
Equity [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost								$ 32	42	47
Liability [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost								$ 21	12	58
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Reduction factor multiplied by number of shares awarded								1
Additional shares available for issuance | shares								5,100,000
Cash-Settled Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost								$ 21	$ 15	$ 20
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period | shares								299,000	211,000	759,000
Number of restricted stock shares vested | shares								446,000	462,000	587,000
Number of restricted stock shares outstanding | shares							1,170,000	460,000	708,000	1,216,000
Obligations, Fair Value Disclosure								$ 11
Stockholder Value Appreciation Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost								$ 0	$ (3)	$ 38
SVAP Incremental Price Threshold | $ / shares									$ 5
Service - Based Shares [Member]
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, Grants in Period | shares								990,000	1,036,000	465,000
Number of restricted stock shares vested | shares								899,000	871,000	1,146,000
Number of restricted stock shares outstanding | shares							2,999,000	1,574,000	1,700,000	1,902,000
Performance Market Based Shares [Member]
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, Grants in Period | shares	436,000							436,000	414,000	338,000
Number of restricted stock shares vested | shares								574,000	188,000	30,000
Number of restricted stock shares outstanding | shares							706,000	859,000	1,074,000	945,000
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Reduction factor multiplied by number of shares awarded								1.87
Additional shares available for issuance | shares								2,700,000
$42.50 [Member] | Stockholder Value Appreciation Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Liability Settlements				$ 13
SVAP Price Threshold | $ / shares		$ 42.50
$37.50 [Member] | Stockholder Value Appreciation Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Liability Settlements					$ 13
SVAP Price Threshold | $ / shares			$ 37.50
$32.50 [Member] | Stockholder Value Appreciation Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Liability Settlements					$ 13
SVAP Price Threshold | $ / shares			$ 32.50
$27.50 [Member] | Stockholder Value Appreciation Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Liability Settlements						$ 13
SVAP Price Threshold | $ / shares							$ 27.50

Stock-Based Compensation- Stock

Stock-Based Compensation- Stock Option Activity (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Outstanding, Beginning Balance, Number of Shares Underlying Options	195	301
Outstanding, Ending Balance, Number of Shares Underlying Options	177	195	301
Outstanding, Beginning Balance, Weighted Average Exercise Price per Share	$ 48.45	$ 43.93
Outstanding, Ending Balance, Weighted Average Exercise Price per Share	$ 48.45	$ 48.45	$ 43.93
Options Outstanding, Weighted Average Remaining Contractual Life (In years)	1 year 1 month 6 days	2 years 1 month 6 days	2 years 2 months 12 days
Outstanding, Beginning Balance, Aggregate Intrinsic Value	$ 0	$ 0
Outstanding, Ending Balance, Aggregate Intrinsic Value	$ 0	$ 0	$ 0

Stock-Based Compensation- Sto74

Stock-Based Compensation- Stock Option Summary (Details) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Options Outstanding, Number of Shares Underlying Options	177	195	301
Options Outstanding, Weighted Average Remaining Contractual Life (In years)	1 year 1 month 6 days	2 years 1 month 6 days	2 years 2 months 12 days
Options Outstanding, Weighted Average Exercise Price per Share	$ 48.45	$ 48.45	$ 43.93

Stock-Based Compensation- Restr

Stock-Based Compensation- Restricted Stock and Restricted Stock Units Activity (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Obligations, Fair Value Disclosure		$ 11	$ 12
Non-vested shares outstanding, Beginning balance	2,774,000	2,774,000	2,847,000	3,705,000
Granted		1,426,000	1,450,000	803,000
Forfeited		(294,000)	(464,000)	(485,000)
Vested		(1,473,000)	(1,059,000)	(1,176,000)
Non-vested shares outstanding, Ending balance		2,433,000	2,774,000	2,847,000
Performance Market Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	1,074,000	1,074,000	945,000	706,000
Granted	436,000	436,000	414,000	338,000
Forfeited		(77,000)	(97,000)	(69,000)
Vested		(574,000)	(188,000)	(30,000)
Non-vested shares outstanding, Ending balance		859,000	1,074,000	945,000
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Beginning balance	$ 23.76	$ 23.76	$ 28.61	$ 34.22
Granted, Weighted Average Grant Date Fair Value per Share		28.94	22.85	18.59
Forfeited, Weighted Average Grant Date Fair Value per Share		43.04	36.72	27.56
Vested, Weighted Average Grant Date Fair Value per Share		21.36	39.42	39.43
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Ending balance		$ 26.28	$ 23.76	$ 28.61
Performance Market Based Shares [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	0.00%
Performance Market Based Shares [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	200.00%
Service - Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	1,700,000	1,700,000	1,902,000	2,999,000
Granted		990,000	1,036,000	465,000
Forfeited		(217,000)	(367,000)	(416,000)
Vested		(899,000)	(871,000)	(1,146,000)
Non-vested shares outstanding, Ending balance		1,574,000	1,700,000	1,902,000
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Beginning balance	$ 30.30	$ 30.30	$ 30.79	$ 33.45
Granted, Weighted Average Grant Date Fair Value per Share		37.95	31.20	30.40
Forfeited, Weighted Average Grant Date Fair Value per Share		29.15	21.69	28.20
Vested, Weighted Average Grant Date Fair Value per Share		29.34	32.10	36.65
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Ending balance		$ 35.56	$ 30.30	$ 30.79
Cash-Settled Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Obligations, Fair Value Disclosure		$ 11
Non-vested shares outstanding, Beginning balance	708,000	708,000	1,216,000	1,170,000
Granted		299,000	211,000	759,000
Forfeited		(101,000)	(257,000)	(126,000)
Vested		(446,000)	(462,000)	(587,000)
Non-vested shares outstanding, Ending balance		460,000	708,000	1,216,000

Stock-Based Compensation- Emplo

Stock-Based Compensation- Employee Stock Purchase Plan (Details) - Employee Stock [Member] - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2010
Employee Stock Purchase Plan ESPP Disclosures [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Percentage of Market Price, Purchase Date	85.00%
Maximum amount of common stock that an employee can purchase under Employee Stock Purchase Plan in any calendar year	$ 25,000
Additional shares available for issuance	121,000			1,000,000
Options To Purchase Common Stock Shares	99,000	136,000	168,000
Weighted average fair value of each option	$ 10.51	$ 8.71	$ 7.91
Expected volatility	47.94%	49.41%	32.05%
Risk-free weighted average interest rate	0.43%	0.12%	0.07%

Employee Benefit Plans (Details

Employee Benefit Plans (Details)	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Expected future benefit payments in years one through five for post-retirement medical plan	$ 7,000,000
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter	$ 8,000,000
Maximum age for retire employees to be covered under post-retirement medical plan	65
Defined Benefit Plan, Benefit Obligation	$ 20,000,000
Defined Benefit Plan, Net Periodic Benefit Cost	3,000,000	$ 3,000,000	$ 2,000,000
Other Labor-related Expenses	35,000,000	41,000,000	45,000,000
Employer matching contribution for each $1 of employee deferral	$ 1
Employee contribution to be matched by the Company	8.00%
Defined Contribution Plan, Employer Discretionary Contribution Amount	$ 6,000,000	$ 7,000,000	$ 10,000,000

Restructuring Costs Restructu78

Restructuring Costs Restructuring Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Restructuring Cost and Reserve [Line Items]
Document Fiscal Year Focus	2,016
Restructuring Reserve [Roll Forward]
Restructuring Reserve	$ 15	$ 14	$ 0
Restructuring Charges	28	27
Restructuring and Related Cost, Incurred Cost	25	27
Payments for Restructuring	(27)	(13)
Restructuring Reserve, Accrual Adjustment	3	0
Restructuring and Related Cost, Cost Incurred to Date	55	27
Restructuring and Related Cost, Expected Cost	56
Employee Severance [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve	1	1	0
Restructuring and Related Cost, Incurred Cost	17	7
Payments for Restructuring	(17)	(6)
Restructuring Reserve, Accrual Adjustment	0	0
Restructuring and Related Cost, Cost Incurred to Date	24	7
Restructuring and Related Cost, Expected Cost	24
Contract Termination [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve	14	13	0
Restructuring and Related Cost, Incurred Cost	3	14
Payments for Restructuring	(5)	(1)
Restructuring Reserve, Accrual Adjustment	3	0
Restructuring and Related Cost, Cost Incurred to Date	20	14
Restructuring and Related Cost, Expected Cost	20
Employee Relocation [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve	0	0	0
Restructuring and Related Cost, Incurred Cost	5	5
Payments for Restructuring	(5)	(5)
Restructuring Reserve, Accrual Adjustment	0	0
Restructuring and Related Cost, Cost Incurred to Date	10	5
Restructuring and Related Cost, Expected Cost	11
Other Restructuring [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve	0	0	$ 0
Restructuring and Related Cost, Incurred Cost	0	1
Restructuring Reserve, Settled without Cash	0	(1)
Restructuring Reserve, Accrual Adjustment	0	0
Restructuring and Related Cost, Cost Incurred to Date	1	1
Restructuring and Related Cost, Expected Cost	1
General and Administrative Expense [Member] | Employee Severance [Member]
Restructuring Reserve [Roll Forward]
Restructuring Charges	17	7
General and Administrative Expense [Member] | Contract Termination [Member]
Restructuring Reserve [Roll Forward]
Restructuring Charges	6	14
General and Administrative Expense [Member] | Employee Relocation [Member]
Restructuring Reserve [Roll Forward]
Restructuring Charges	5	5
Depreciation Depletion and Amortization [Member] | Other Restructuring [Member]
Restructuring Reserve [Roll Forward]
Restructuring Charges	$ 0	$ 1

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating expenses:
Depreciation, depletion and amortization									$ 572	$ 917	$ 903
Impairment of Oil and Gas Properties	$ 0	$ 0	$ 522	$ 506	$ 702	$ 1,889	$ 1,521	$ 792	1,028	4,904	0
Allocated income tax (benefit)									22	(1,585)	382
Commodity derivative income (expense)									191	(259)	(610)
Income (loss) before income taxes									(1,208)	(4,947)	1,032
Total assets	4,312				4,768				4,312	4,768	9,580
Additions to long-lived assets									1,304	1,538	2,193
UNITED STATES
Segment Information [Line Items]
Oil, gas and NGL revenues									1,255	1,295	2,249
Operating expenses:
Lease operating									189	231	299
Transportation and processing									272	212	174
Production and other taxes									41	45	105
Depreciation, depletion and amortization									458	754	857
General and administrative									205	237	221
Impairment of Oil and Gas Properties									962	4,786
Other									20	9	25
Allocated income tax (benefit)									(330)	(1,842)	210
Net income (loss) from oil and gas properties									(562)	(3,137)	358
Total assets	4,166				4,452				4,166	4,452	8,852
Additions to long-lived assets									1,304	1,521	2,037
China [Member]
Segment Information [Line Items]
Oil, gas and NGL revenues									217	262	39
Operating expenses:
Lease operating									55	54	12
Transportation and processing									0	0	0
Production and other taxes									1	1	6
Depreciation, depletion and amortization									114	163	13
General and administrative									8	7	1
Impairment of Oil and Gas Properties									66	118
Other									0	1	0
Allocated income tax (benefit)									(16)	(49)	5
Net income (loss) from oil and gas properties									(11)	(33)	2
Total assets	$ 146				$ 316				146	316	728
Additions to long-lived assets									0	17	156
Continuing Operations [Member]
Segment Information [Line Items]
Oil, gas and NGL revenues									1,472	1,557	2,288
Operating expenses:
Lease operating									244	285	311
Transportation and processing									272	212	174
Production and other taxes									42	46	111
Depreciation, depletion and amortization									572	917	870
General and administrative									213	244	222
Impairment of Oil and Gas Properties									1,028	4,904
Other									20	10	25
Total operating expenses									2,391	6,618	1,713
Income (loss) from operations									(919)	(5,061)	575
Interest expenses, net of interest income, capitalized interest and other									(98)	(145)	(153)
Commodity derivative income (expense)									191	(259)	(610)
Income (loss) before income taxes									$ (1,208)	$ (4,947)	$ 1,032

Supplemental Cash Flows Infor80

Supplemental Cash Flows Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash Payments [Abstract]
Interest payments, net of capitalized interest	$ 97	$ 119	$ 144
Income tax payments	17	25	4
Increase (Decrease) in Other Receivables	6	6	(17)
Non Cash Items Excluded From Statement of Cash Flows [Abstract]
(Increase) decrease in accrued capital expenditures	33	225	(1)
Increase in asset retirement costs	$ 46	$ (4)	$ (56)

Discontinued Operations (Detail

Discontinued Operations (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operation, Tax Effect of Discontinued Operation					$ 144
Disposal Group, Including Discontinued Operation, Consideration	$ 898				898
Gain on Sale of Malaysia, Before Income Tax	15	$ (388)	$ 0	$ 0	$ (373)
Gain on Sale of Malaysia, Net of Tax	10	(252)
Historical Effective Tax Rate, Discontinuing Operations					38.00%
Effective Income Tax Rate, Discontinuing Operations					37.00%
Disposal Group, Including Discontinued Operation, Revenue					$ 90
Disposal Group, Including Discontinued Operation, Operating Expense					69
Disposal Group, Including Discontinued Operation, Operating Income (Loss)					21
Gain on Sale of Malaysia, Before Income Tax	$ 15	$ (388)	0	0	(373)
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax					394
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent			$ 0	$ 0	250
Current [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operation, Tax Effect of Discontinued Operation					12
Deferred [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operation, Tax Effect of Discontinued Operation					$ 132

Quarterly Results of Operatio82

Quarterly Results of Operations (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended										12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Loss Contingency, Damages Paid, Value		$ 18									$ 18
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitation Expense Gross	$ 0	0	$ 522	$ 506	$ 702	$ 1,889	$ 1,521	$ 788			1,028	$ 4,900
Ceiling test and other impairments	0	0	522	506	702	1,889	1,521	792			1,028	4,904	$ 0
Income (Loss) from Continuing Operations Attributable to Parent											(1,230)	(3,362)	650
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent											0	0	250
Net Income (Loss) Attributable to Parent	$ 13	$ 48	$ (667)	$ (624)	$ (663)	$ (1,227)	$ (992)	$ (480)			$ (1,230)	$ (3,362)	$ 900
Income (loss) from continuing operations											$ (6.36)	$ (21.18)	$ 4.76
Income (loss) from discontinued operations											0	0	1.83
Earnings (Loss) Per Share, Basic	$ 0.07	$ 0.24	$ (3.36)	$ (3.52)	$ (4.06)	$ (7.52)	$ (6.09)	$ (3.30)			(6.36)	(21.18)	6.59
Income (loss) from continuing operations											(6.36)	(21.18)	4.71
Income (loss) from discontinued operations											0	0	1.81
Earnings (Loss) Per Share, Diluted	$ 0.07	$ 0.24	$ (3.36)	$ (3.52)	$ (4.06)	$ (7.52)	$ (6.09)	$ (3.30)			$ (6.36)	$ (21.18)	$ 6.52
Gain on Sale of Malaysia, Before Income Tax									$ (15)	$ 388	$ 0	$ 0	$ 373
Gain on Sale of Malaysia, Net of Tax									$ (10)	$ 252
Continuing Operations [Member]
Oil and Gas Revenue	$ 415	$ 392	$ 381	$ 284	$ 362	$ 377	$ 469	$ 349			1,472	1,557	2,288
Ceiling test and other impairments											1,028	4,904	0
Income (loss) from operations	112	45	(498)	(578)	(730)	(1,951)	(1,496)	(884)			(919)	(5,061)	575
UNITED STATES
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitation Expense Gross	$ 0	$ 0	$ 501	$ 461	$ 656	$ 1,817	$ 1,521	$ 788			962	4,782
Oil and Gas Revenue											1,255	1,295	$ 2,249
Ceiling test and other impairments											$ 962	$ 4,786

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ in Millions	Jan. 23, 2017	Dec. 31, 2014
Subsequent Event [Line Items]
Disposal Group, Including Discontinued Operation, Consideration		$ 898
Subsequent Event [Member]
Subsequent Event [Line Items]
Disposal Group, Including Discontinued Operation, Consideration	$ 39