Newfield Exploration (NFX) 10-Q 2 May 17 2017 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	3 Months Ended
	Mar. 31, 2017	Apr. 27, 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-Q
Document Period End Date	Mar. 31, 2017
Amendment Flag	false
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q1
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		199,194,558

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 469	$ 555
Short-term investments	25	25
Accounts receivable, net	243	232
Inventories	25	16
Derivative assets	52	75
Other current assets	51	46
Total current assets	865	949
Oil and gas properties, net — full cost method ($1,240 and $1,238 were excluded from amortization at March 31, 2017 and December 31, 2016, respectively)	3,294	3,140
Other property and equipment, net	166	167
Derivative assets	2	0
Long-term investments	22	19
Restricted cash	28	25
Other assets	11	12
Total assets	4,388	4,312
Current liabilities:
Accounts payable	40	33
Accrued liabilities	434	498
Advances from joint owners	61	54
Asset retirement obligations	2	2
Derivative liabilities	(46)	(97)
Total current liabilities	583	684
Other liabilities	65	63
Derivative liabilities	0	(3)
Long-term debt	2,432	2,431
Asset retirement obligations	160	154
Deferred taxes	48	39
Total long-term liabilities	2,705	2,690
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 March 31, 2017 and December 31, 2016; 200,187,352 and 200,150,392 shares issued at March 31, 2017 and December 31, 2016, respectively)	2	2
Additional paid-in capital	3,263	3,247
Treasury stock (at cost, 1,220,606 and 1,195,809 shares at March 31, 2017 and December 31, 2016, respectively)	(45)	(44)
Accumulated other comprehensive income (loss)	(2)	(2)
Retained earnings (deficit)	(2,118)	(2,265)
Total stockholders' equity	1,100	938
Total liabilities and stockholders' equity	$ 4,388	$ 4,312

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
ASSETS
Property and equipment, at cost, based on the full cost method of accounting for oil and gas properties	$ 1,240	$ 1,238
Stockholders' equity:
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, shares issued	0	0
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	300,000,000	300,000,000
Common stock, shares issued	200,187,352	200,150,392
Treasury stock, shares	1,220,606	1,195,809
Commitments and Contingencies	$ 0	$ 0

Consolidated Statement of Opera

Consolidated Statement of Operations - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Income Statement [Abstract]
Oil, gas and NGL revenues	$ 417	$ 284
Operating expenses:
Lease operating	56	61
Transportation and processing	72	63
Production and other taxes	14	10
Depreciation, depletion and amortization	106	177
General and administrative	47	44
Ceiling test and other impairments	0	506
Other	1	1
Total operating expenses	296	862
Income (loss) from operations	121	(578)
Other income (expense):
Interest expense	(38)	(41)
Capitalized interest	16	9
Commodity derivative income (expense)	(53)	17
Other, net	2	1
Total other income (expense)	33	(48)
Income (loss) before income taxes	154	(626)
Income tax provision (benefit):
Current	(2)	(2)
Deferred	9	0
Total income tax provision (benefit)	7	(2)
Net income (loss)	$ 147	$ (624)
Earnings Per Share [Abstract]
Basic	$ 0.74	$ (3.52)
Diluted	$ 0.73	$ (3.52)
Weighted-average number of shares outstanding for basic earnings (loss) per share	199	177
Weighted-average number of shares outstanding for diluted earnings (loss) per share	200	177
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	$ 0	$ 0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$ 147	$ (624)

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Cash flows from operating activities:
Net income (loss)	$ 147	$ (624)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	106	177
Deferred	9	0
Stock-based compensation	12	8
Unrealized (gain) loss on derivative contracts	(33)	99
Ceiling test and other impairments	0	506
Other, net	2	4
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	(11)	15
Increase (decrease) in accounts payable and accrued liabilities	(58)	(102)
Other items, net	(7)	(11)
Net cash provided by (used in) operating activities	167	72
Cash flows from investing activities:
Additions to oil and gas properties	(239)	(273)
Acquisitions of oil and gas properties	(4)	(1)
Proceeds (purchase price adjustments) from sales of oil and gas properties	(5)	3
Additions to other property and equipment	(3)	(4)
Redemptions of investments	25	0
Purchases of investments	(25)	0
Net cash provided by (used in) investing activities	(251)	(275)
Cash flows from financing activities:
Proceeds from borrowings under credit arrangements	0	536
Repayments of borrowings under credit arrangements	0	(575)
Proceeds from issuances of common stock, net	0	776
Purchases of treasury stock, net	(1)	(2)
Other	(1)	0
Net cash provided by (used in) financing activities	(2)	735
Increase (decrease) in cash and cash equivalents	(86)	532
Cash and cash equivalents, beginning of period	555	5
Cash and cash equivalents, end of period	$ 469	$ 537

Consolidated Statement of Stock

Consolidated Statement of Stockholders' Equity - USD ($) $ in Millions	Total	Treasury Stock	Additional Paid-in Capital	Retained Earnings
Common Stock, Shares, Issued	200,150,392
Common Stock, Value, Issued	$ 2
Treasury Stock, Shares	(1,195,809)
Treasury Stock, Value	$ (44)
Additional Paid in Capital	3,247
Retained Earnings (Accumulated Deficit)	(2,265)
Accumulated Other Comprehensive Income (Loss), Net of Tax	(2)
BOP Stockholders' Equity Balance at Dec. 31, 2016	938
EOP Stockholders' Equity Balance at Mar. 31, 2017	1,100
Stock-based compensation	16		$ 16
Treasury stock, net, shares		0
Treasury stock, net, value	(1)	$ (1)	$ 0
Net income (loss)	$ 147			$ 147
Common Stock, Shares, Issued	200,187,352
Common Stock, Value, Issued	$ 2
Treasury Stock, Shares	(1,220,606)
Treasury Stock, Value	$ (45)
Additional Paid in Capital	3,263
Retained Earnings (Accumulated Deficit)	(2,118)
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ (2)

Organization and Summary of Sig

Organization and Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2017
Accounting Policies [Abstract]
Organization and Summary of Significant Accounting Policies	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. These unaudited consolidated financial statements reflect, in the opinion of our management, all adjustments, consisting only of normal and recurring adjustments, necessary to fairly state our financial position as of, and results of operations, for the periods presented. These financial statements have been prepared in accordance with the instructions to Form 10-Q and, therefore, do not include all disclosures required for financial statements prepared in conformity with accounting principles generally accepted in the United States of America (U.S. GAAP). Interim period results are not necessarily indicative of results of operations or cash flows for a full year. These consolidated financial statements and notes should be read in conjunction with our audited consolidated financial statements and the notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2016 . 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 U.S. 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. 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. 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 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. The guidance is effective for interim and annual periods beginning after December 15, 2017 and may be applied retrospectively or using a modified retrospective approach to adjust retained earnings (deficit). We are currently evaluating the impact of this guidance on our financial statements.

Accounts Receivable

Accounts Receivable	3 Months Ended
	Mar. 31, 2017
Accounts Receivable, Net, Current [Abstract]
Accounts Receivable Text Block	Accounts Receivable Accounts receivable consisted of the following: March 31, December 31, (In millions) Revenue $ 149 $ 163 Joint interest 78 53 Other 32 32 Reserve for doubtful accounts (16 ) (16 ) Total accounts receivable, net $ 243 $ 232

Inventories (Notes)

Inventories (Notes)	3 Months Ended
	Mar. 31, 2017
Inventory Disclosure [Abstract]
Inventory Disclosure [Text Block]	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. At March 31, 2017 and December 31, 2016 , the crude oil inventory from our China operations consisted of approximately 239,000 and 11,500 barrels of crude oil, respectively.

Derivative Financial Instrument

Derivative Financial Instruments	3 Months Ended
	Mar. 31, 2017
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. Our derivative strategies are outlined in our Annual Report on Form 10-K for the year ended December 31, 2016 . 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 March 31, 2017 , 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 (1) Floors Ceilings (In millions) 2017: Fixed-price swaps 4,675 $ 45.43 $ — $ — $ — $ — $ (29 ) Fixed-price swaps with sold puts: 3,118 Fixed-price swaps 87.99 — — — — 112 Sold puts — — 73.09 — — (68 ) Collars with sold puts: 910 Collars — — — 90.00 95.69 36 Sold puts — — 75.00 — — (22 ) Purchased calls 4,028 — 73.52 — — — 1 Total $ 30 _________________ (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 March 31, 2017 , the deferred premiums totaled $7 million . Natural Gas NYMEX Contract Price Per MMBtu Collars Estimated Fair Value Asset (Liability) Period and Type of Instrument Volume in MMMBtus Swaps (Weighted Average) Floors (Weighted Average) Ceilings (Weighted Average) (In millions) 2017: Fixed-price swaps 20,625 $ 2.73 $ — $ — $ (12 ) Collars 41,260 — 2.82 3.23 (10 ) 2018: Fixed-price swaps 10,950 3.01 — — — Collars 18,150 — 3.00 3.55 — Total $ (22 ) 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 (In millions) (In millions) March 31, 2017 Oil positions $ 156 $ (104 ) $ 52 $ — $ (126 ) $ 104 $ (22 ) $ — Natural gas positions 10 (8 ) — 2 (32 ) 8 (24 ) — Total $ 166 $ (112 ) $ 52 $ 2 $ (158 ) $ 112 $ (46 ) $ — December 31, 2016 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 ) The amount of gain (loss) recognized in "Commodity derivative income (expense)" in our consolidated statement of operations and comprehensive income related to our derivative financial instruments follows: Three Months Ended 2017 2016 (In millions) Derivatives not designated as hedging instruments: Realized gain (loss) on oil positions $ 26 $ 71 Realized gain (loss) on natural gas positions (6 ) 11 Total realized gain (loss) 20 82 Unrealized gain (loss) on oil positions 1 (83 ) Unrealized gain (loss) on natural gas positions 32 (16 ) Total unrealized gain (loss) 33 (99 ) Total $ 53 $ (17 ) 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 March 31, 2017 , 10 of our 15 counterparties accounted for approximately 84% of our contracted volumes, with the largest counterparty accounting for approximately 13% . At March 31, 2017 , approximately 83% 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	3 Months Ended
	Mar. 31, 2017
Fair Value Disclosures [Abstract]
Fair Value Measurements Text Block	Fair Value Measurements 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. 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, 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 As of March 31, 2017: Money market fund investments $ 236 $ — $ — $ 236 Deferred compensation plan assets 6 — — 6 Equity securities available-for-sale 11 — — 11 Oil and gas derivative swap contracts — 71 — 71 Oil and gas derivative option contracts — — (63 ) (63 ) Stock-based compensation liability awards (12 ) — — (12 ) Total $ 241 $ 71 $ (63 ) $ 249 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. Derivatives (In millions) Balance at January 1, 2016 $ (308 ) Unrealized gains (losses) included in earnings (46 ) Purchases, issuances, sales and settlements: Settlements 92 Transfers into Level 3 — Transfers out of Level 3 — Balance at March 31, 2016 $ (262 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at March 31, 2016 $ (32 ) Balance at January 1, 2017 $ (75 ) Unrealized gains (losses) included in earnings (6 ) Purchases, issuances, sales and settlements: Settlements 18 Transfers into Level 3 — Transfers out of Level 3 — Balance at March 31, 2017 $ (63 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at March 31, 2017 $ (4 ) Qualitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements 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 ." 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 $ (53 ) Modified Black-Scholes Oil price volatility 22.57 % — 118.40% Credit risk 0.01 % — 1.25% Natural gas option contracts $ (10 ) Modified Black-Scholes Natural gas price volatility 24.33 % — 41.31% Credit risk 0.01 % — 1.25% Fair Value of Debt The estimated fair value of our notes, based on quoted prices in active markets (Level 1) as of the indicated dates, was as follows: March 31, December 31, (In millions) 5¾% Senior Notes due 2022 $ 796 $ 789 5⅝% Senior Notes due 2024 1,054 1,044 5⅜% Senior Notes due 2026 731 714 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 10 , "Debt."

Oil and Gas Assets

Oil and Gas Assets	3 Months Ended
	Mar. 31, 2017
Oil and Gas Property [Abstract]
Oil and Gas Assets Text Block	Oil and Gas Properties Oil and gas properties consisted of the following: March 31, December 31, (In millions) Proved $ 22,253 $ 21,998 Unproved 1,240 1,238 Gross oil and gas properties 23,493 23,236 Accumulated depreciation, depletion and amortization (9,690 ) (9,587 ) Accumulated impairment (10,509 ) (10,509 ) Net oil and gas properties $ 3,294 $ 3,140 Costs withheld from amortization as of March 31, 2017 consisted of the following: Costs Incurred In 2017 2016 2015 2014 & Prior Total (In millions) Acquisition costs $ 40 $ 532 $ 339 $ 196 $ 1,107 Exploration costs — 2 — — 2 Capitalized interest 16 51 33 31 131 Total costs withheld from amortization $ 56 $ 585 $ 372 $ 227 $ 1,240 We capitalized approximately $33 million and $26 million of interest and direct internal costs during the three months ended March 31, 2017 and 2016 , respectively. At March 31, 2017 , the ceiling value of our reserves was calculated based upon SEC pricing of $47.65 per barrel for oil and $2.73 per MMBtu for natural gas. Using these prices, our ceiling for the U.S. exceeded the net capitalized costs of oil and gas properties and no ceiling test impairment was required at March 31, 2017 . Using SEC pricing, our ceiling for China exceeded the net capitalized costs of oil and gas properties and no ceiling test impairment was required at March 31, 2017 . 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. Bohai Bay (China) Sales Agreement 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. The transaction is scheduled to close in mid-2017.

Other Property and Equipment Ot

Other Property and Equipment Other Property and Equipment	3 Months Ended
	Mar. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment Disclosure [Text Block]	Other Property and Equipment Other property and equipment consisted of the following: March 31, December 31, (In millions) Furniture, fixtures and equipment $ 153 $ 150 Gathering systems and equipment 116 115 Accumulated depreciation and amortization (103 ) (98 ) Net other property and equipment $ 166 $ 167

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2017
Income Tax Disclosure [Abstract]
Income Taxes Text Block	Income Taxes The effective tax rates for the three months ended March 31, 2017 and 2016 were 4.5% and 0.3% , respectively. 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. 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 and China deferred tax assets. As of March 31, 2017 , 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 2016 remain open to examination for federal income tax purposes and by the other major taxing jurisdictions to which we are subject.

Accrued Liabilities

Accrued Liabilities	3 Months Ended
	Mar. 31, 2017
Accrued Liabilities, Current [Abstract]
Accrued Liabilities Text Block	Accrued Liabilities Accrued liabilities consisted of the following: March 31, December 31, (In millions) Revenue payable $ 210 $ 196 Accrued capital costs 96 92 Accrued lease operating expenses 31 37 Employee incentive expense 16 48 Accrued interest on debt 32 67 Taxes payable 13 15 Other 36 43 Total accrued liabilities $ 434 $ 498

Debt

Debt	3 Months Ended
	Mar. 31, 2017
Debt Disclosure [Abstract]
Debt Text Block	Debt Our debt consisted of the following: March 31, December 31, (In millions) Senior unsecured debt: 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 2,450 Debt issuance costs (18 ) (19 ) Total long-term debt $ 2,432 $ 2,431 Credit Arrangements We have a revolving credit facility that matures in June 2020 and provides borrowing capacity of $1.8 billion . As of March 31, 2017 , the largest individual loan commitment by any lender was 12% of total commitments. Subject to compliance with restrictive covenants in our credit facility, 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 $125 million at March 31, 2017 . Loans under the credit facility bear interest, at our option, equal to (a) the Alternate Base Rate (as defined in the Credit Agreement), plus a margin that is based on a grid of our debt rating (100 basis points per annum at March 31, 2017 ) or (b) the Adjusted Eurodollar Rate (as defined in the Credit Agreement), plus a margin that is based on a grid of our debt rating (200 basis points per annum at March 31, 2017 ). 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 March 31, 2017 ). We incurred aggregate commitment fees under our credit facility of approximately $2 million for each of the three-month periods ended March 31, 2017 and 2016 , which were recorded in “Interest expense” on our consolidated statement of operations and comprehensive income. We incurred approximately $3 million of financing costs related to amending our revolving credit facility in March 2016, which were also included in "Interest expense" on our consolidated statement of operations and comprehensive income. 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 net income 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 March 31, 2017 , we were in compliance with all of our debt covenants. As of March 31, 2017 , 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 March 31, 2017 ). 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.

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2017
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. For further information, see Note 12, "Commitments and Contingencies," in our Annual Report on Form 10-K for the year ended December 31, 2016. There have been no material changes to the commitments disclosed at year-end 2016, other than noted below. In March 2017, we signed an agreement for firm natural gas transportation capacity for production from the Anadarko Basin. The table below summarizes the value of the obligation by year as of March 31, 2017. Total 2017 2018 2019 2020 2021 Thereafter (In millions) Firm transportation $ 186 $ — $ 9 $ 18 $ 18 $ 18 $ 123 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)	3 Months Ended
	Mar. 31, 2017
Equity [Abstract]
CommonStock [Text Block]	Stockholders' Equity Activity 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 was available for general corporate purposes.

Earnings Per Share

Earnings Per Share	3 Months Ended
	Mar. 31, 2017
Earnings Per Share [Abstract]
Earnings Per Share Text Block	Earnings Per Share The following is the calculation of basic and diluted weighted-average shares outstanding and earnings per share (EPS) for the indicated periods. Three Months Ended 2017 2016 (In millions, except per share data) Net income (loss) $ 147 $ (624 ) Weighted-average shares (denominator): Weighted-average shares — basic 199 177 Dilution effect of stock options and unvested restricted stock awards and restricted stock units outstanding at end of period 1 — Weighted-average shares — diluted 200 177 Excluded due to anti-dilutive effect 1 1 Earnings (loss) per share: Basic $ 0.74 $ (3.52 ) Diluted $ 0.73 $ (3.52 )

Stock-Based Compensation

Stock-Based Compensation	3 Months Ended
	Mar. 31, 2017
Share-based Compensation [Abstract]
Stock-Based Compensation Text Block	Stock-Based Compensation Our stock-based compensation expense consisted of the following: Three Months Ended 2017 2016 (In millions) Equity awards $ 16 $ 9 Liability awards — cash-settled restricted stock units 2 3 Total stock-based compensation 18 12 Capitalized in oil and gas properties (5 ) (4 ) Net stock-based compensation expense $ 13 $ 8 As of March 31, 2017 , we had approximately $76 million of total unrecognized stock-based compensation expense related to unvested stock-based compensation awards that vest within four years . On March 31, 2017 , the last reported sales price of our common stock on the New York Stock Exchange was $36.91 per share. During the first quarter of 2017, we changed our qualified retirement requirements for existing market-based restricted stock units and all subsequently issued equity and liability awards. An employee becomes eligible for qualified retirement based on a combination of years of service and age. Qualified retirement allows an employee to continue vesting between 50% and 100% of awards with no additional service requirement beyond a six-month notification period. This change resulted in the accelerated recognition of stock-based compensation expense for awards issued to eligible employees. Equity Awards Equity awards consist of service-based and market-based restricted stock awards and restricted stock units, stock options and stock purchase options under the Employee Stock Purchase Plan (ESPP). At March 31, 2017 , we had approximately (1) 4.0 million shares available for issuance under our 2011 Omnibus Stock Plan, as amended (2011 Plan), if all future awards are stock options, or (2) 2.1 million shares available for issuance under our 2011 Plan if all future awards are restricted stock awards or restricted stock units. Restricted Stock. 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 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, 2017 1,574 $ 35.56 859 $ 26.28 2,433 Granted 268 39.56 323 50.22 591 Forfeited (19 ) 18.70 — — (19 ) Vested (37 ) 25.38 — — (37 ) Non-vested shares outstanding at March 31, 2017 1,786 $ 36.41 1,182 $ 32.81 2,968 ________ (1) In February 2017, we granted approximately 323,000 restricted stock units, which based on achievement of certain criteria, could vest within a range of 0% to 200% of shares granted upon completion of the period ending December 31, 2019. Employee Stock Purchase Plan. During the first three months of 2017 , options to purchase approximately 54,000 shares of our common stock were granted under our ESPP. The fair value of each option was $10.73 per share. The fair value of the options granted was determined using the Black-Scholes option valuation method assuming no dividends, a risk-free interest rate of 0.61% , an expected life of six months and weighted-average volatility of 40.2% . Stock Options. As of March 31, 2017 , we had approximately 177,000 stock options outstanding and exercisable. These outstanding stock options expire in January 2018. No stock options have been granted since 2008, except for ESPP options as discussed above. 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 March 31, 2017 , we had a liability of $12 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, 2017 460 Granted 235 Forfeited (12 ) Vested (26 ) Non-vested units outstanding at March 31, 2017 657

Restructuring Costs Restructuri

Restructuring Costs Restructuring Costs	3 Months Ended
	Mar. 31, 2017
Restructuring and Related Activities [Abstract]
Restructuring and Related Activities Disclosure [Text Block]	Restructuring Costs In April 2015 and May 2016, we announced plans to consolidate and reorganize domestic operating functions to our headquarters in The Woodlands, Texas, which resulted in a reduction of employees and closure of our offices in Denver, Colorado; North Houston (Greenspoint), Texas; and Tulsa, Oklahoma. 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 recognized as expense as of December 31, 2016. The following table summarizes our restructuring costs and related liability for the first quarter of 2017. Severance and Related Benefit Costs Office-lease Abandonment Costs (1) Relocation Costs Other Associated Costs Total (In millions) Restructuring liability at January 1, 2017 $ 1 $ 14 $ — $ — $ 15 Additions — — 1 — 1 Settlements (1 ) (1 ) (1 ) — (3 ) Revisions — (1 ) — — (1 ) Restructuring liability at March 31, 2017 $ — $ 12 $ — $ — $ 12 Cumulative costs as of March 31, 2017 $ 24 $ 19 $ 11 $ 1 $ 55 Expected total costs as of March 31, 2017 $ 24 $ 19 $ 11 $ 1 $ 55 _________________ (1) The office-lease abandonment liability will be relieved while lease payments are made and sublease income is received over the life of the lease ending 2022. Restructuring costs recorded in our consolidated statement of operations and comprehensive income for office-lease abandonment costs and relocation costs are included in "Operating expenses - General and administrative."

Segment Information

Segment Information	3 Months Ended
	Mar. 31, 2017
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," in our Annual Report on Form 10-K for the year ended December 31, 2016 . The following tables provide the geographic operating segment information for the three-month periods ended March 31, 2017 and 2016 . 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) Three Months Ended March 31, 2017: Oil, gas and NGL revenues $ 383 $ 34 $ 417 Operating expenses: Lease operating 48 8 56 Transportation and processing 72 — 72 Production and other taxes 14 — 14 Depreciation, depletion and amortization 96 10 106 General and administrative 46 1 47 Other 1 — 1 Allocated income tax (benefit) 39 9 Net income (loss) from oil and gas properties $ 67 $ 6 Total operating expenses 296 Income (loss) from operations 121 Interest expense, net of interest income, capitalized interest and other (20 ) Commodity derivative income (expense) 53 Income (loss) from operations before income taxes $ 154 Total assets $ 4,248 $ 140 $ 4,388 Additions to long-lived assets $ 257 $ — $ 257 Domestic China Total (In millions) Three Months Ended March 31, 2016: Oil, gas and NGL revenues $ 235 $ 49 $ 284 Operating expenses: Lease operating 47 14 61 Transportation and processing 63 — 63 Production and other taxes 10 — 10 Depreciation, depletion and amortization 133 44 177 General and administrative 43 1 44 Ceiling test and other impairments 461 45 506 Other 1 — 1 Allocated income tax (benefit) (194 ) (33 ) Net income (loss) from oil and gas properties $ (329 ) $ (22 ) Total operating expenses 862 Income (loss) from operations (578 ) Interest expense, net of interest income, capitalized interest and other (31 ) Commodity derivative income (expense) (17 ) Income (loss) from operations before income taxes $ (626 ) Total assets $ 4,540 $ 237 $ 4,777 Additions to long-lived assets $ 261 $ — $ 261

Supplemental Cash Flows Informa

Supplemental Cash Flows Information	3 Months Ended
	Mar. 31, 2017
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flows Information Text Block	Supplemental Cash Flow Information The following table presents information about investing and financing activities that affect recognized assets and liabilities but do not result in cash receipts or payments for the indicated periods. Three Months Ended 2017 2016 (In millions) Non-cash investing and financing activities excluded from the statement of cash flows: (Increase) decrease in receivables for property sales $ — $ 2 (Increase) decrease in accrued capital expenditures (4 ) 20 (Increase) decrease in asset retirement costs (4 ) —

Organization and Summary of S24

Organization and Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2017
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. These unaudited consolidated financial statements reflect, in the opinion of our management, all adjustments, consisting only of normal and recurring adjustments, necessary to fairly state our financial position as of, and results of operations, for the periods presented. These financial statements have been prepared in accordance with the instructions to Form 10-Q and, therefore, do not include all disclosures required for financial statements prepared in conformity with accounting principles generally accepted in the United States of America (U.S. GAAP). Interim period results are not necessarily indicative of results of operations or cash flows for a full year. These consolidated financial statements and notes should be read in conjunction with our audited consolidated financial statements and the notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2016 .
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 U.S. 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.
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.
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 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. The guidance is effective for interim and annual periods beginning after December 15, 2017 and may be applied retrospectively or using a modified retrospective approach to adjust retained earnings (deficit). We are currently evaluating the impact of this guidance on our financial statements.

Accounts Receivable (Tables)

Accounts Receivable (Tables)	3 Months Ended
	Mar. 31, 2017
Accounts Receivable, Net, Current [Abstract]
Accounts Receivable	Accounts receivable consisted of the following: March 31, December 31, (In millions) Revenue $ 149 $ 163 Joint interest 78 53 Other 32 32 Reserve for doubtful accounts (16 ) (16 ) Total accounts receivable, net $ 243 $ 232

Derivative Financial Instrume26

Derivative Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2017
Derivative Instruments and Hedges, Assets [Abstract]
Outstanding contracts that are not designated for hedge accounting	At March 31, 2017 , 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 (1) Floors Ceilings (In millions) 2017: Fixed-price swaps 4,675 $ 45.43 $ — $ — $ — $ — $ (29 ) Fixed-price swaps with sold puts: 3,118 Fixed-price swaps 87.99 — — — — 112 Sold puts — — 73.09 — — (68 ) Collars with sold puts: 910 Collars — — — 90.00 95.69 36 Sold puts — — 75.00 — — (22 ) Purchased calls 4,028 — 73.52 — — — 1 Total $ 30 _________________ (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 March 31, 2017 , the deferred premiums totaled $7 million . Natural Gas NYMEX Contract Price Per MMBtu Collars Estimated Fair Value Asset (Liability) Period and Type of Instrument Volume in MMMBtus Swaps (Weighted Average) Floors (Weighted Average) Ceilings (Weighted Average) (In millions) 2017: Fixed-price swaps 20,625 $ 2.73 $ — $ — $ (12 ) Collars 41,260 — 2.82 3.23 (10 ) 2018: Fixed-price swaps 10,950 3.01 — — — Collars 18,150 — 3.00 3.55 — Total $ (22 )
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 (In millions) (In millions) March 31, 2017 Oil positions $ 156 $ (104 ) $ 52 $ — $ (126 ) $ 104 $ (22 ) $ — Natural gas positions 10 (8 ) — 2 (32 ) 8 (24 ) — Total $ 166 $ (112 ) $ 52 $ 2 $ (158 ) $ 112 $ (46 ) $ — December 31, 2016 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 )
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table 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. Our derivative strategies are outlined in our Annual Report on Form 10-K for the year ended December 31, 2016 . 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 March 31, 2017 , 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 (1) Floors Ceilings (In millions) 2017: Fixed-price swaps 4,675 $ 45.43 $ — $ — $ — $ — $ (29 ) Fixed-price swaps with sold puts: 3,118 Fixed-price swaps 87.99 — — — — 112 Sold puts — — 73.09 — — (68 ) Collars with sold puts: 910 Collars — — — 90.00 95.69 36 Sold puts — — 75.00 — — (22 ) Purchased calls 4,028 — 73.52 — — — 1 Total $ 30 _________________ (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 March 31, 2017 , the deferred premiums totaled $7 million . Natural Gas NYMEX Contract Price Per MMBtu Collars Estimated Fair Value Asset (Liability) Period and Type of Instrument Volume in MMMBtus Swaps (Weighted Average) Floors (Weighted Average) Ceilings (Weighted Average) (In millions) 2017: Fixed-price swaps 20,625 $ 2.73 $ — $ — $ (12 ) Collars 41,260 — 2.82 3.23 (10 ) 2018: Fixed-price swaps 10,950 3.01 — — — Collars 18,150 — 3.00 3.55 — Total $ (22 ) 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 (In millions) (In millions) March 31, 2017 Oil positions $ 156 $ (104 ) $ 52 $ — $ (126 ) $ 104 $ (22 ) $ — Natural gas positions 10 (8 ) — 2 (32 ) 8 (24 ) — Total $ 166 $ (112 ) $ 52 $ 2 $ (158 ) $ 112 $ (46 ) $ — December 31, 2016 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 ) The amount of gain (loss) recognized in "Commodity derivative income (expense)" in our consolidated statement of operations and comprehensive income related to our derivative financial instruments follows: Three Months Ended 2017 2016 (In millions) Derivatives not designated as hedging instruments: Realized gain (loss) on oil positions $ 26 $ 71 Realized gain (loss) on natural gas positions (6 ) 11 Total realized gain (loss) 20 82 Unrealized gain (loss) on oil positions 1 (83 ) Unrealized gain (loss) on natural gas positions 32 (16 ) Total unrealized gain (loss) 33 (99 ) Total $ 53 $ (17 ) 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 March 31, 2017 , 10 of our 15 counterparties accounted for approximately 84% of our contracted volumes, with the largest counterparty accounting for approximately 13% . At March 31, 2017 , approximately 83% 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.
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 and comprehensive income related to our derivative financial instruments follows: Three Months Ended 2017 2016 (In millions) Derivatives not designated as hedging instruments: Realized gain (loss) on oil positions $ 26 $ 71 Realized gain (loss) on natural gas positions (6 ) 11 Total realized gain (loss) 20 82 Unrealized gain (loss) on oil positions 1 (83 ) Unrealized gain (loss) on natural gas positions 32 (16 ) Total unrealized gain (loss) 33 (99 ) Total $ 53 $ (17 )

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2017
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, 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 As of March 31, 2017: Money market fund investments $ 236 $ — $ — $ 236 Deferred compensation plan assets 6 — — 6 Equity securities available-for-sale 11 — — 11 Oil and gas derivative swap contracts — 71 — 71 Oil and gas derivative option contracts — — (63 ) (63 ) Stock-based compensation liability awards (12 ) — — (12 ) Total $ 241 $ 71 $ (63 ) $ 249
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. Derivatives (In millions) Balance at January 1, 2016 $ (308 ) Unrealized gains (losses) included in earnings (46 ) Purchases, issuances, sales and settlements: Settlements 92 Transfers into Level 3 — Transfers out of Level 3 — Balance at March 31, 2016 $ (262 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at March 31, 2016 $ (32 ) Balance at January 1, 2017 $ (75 ) Unrealized gains (losses) included in earnings (6 ) Purchases, issuances, sales and settlements: Settlements 18 Transfers into Level 3 — Transfers out of Level 3 — Balance at March 31, 2017 $ (63 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at March 31, 2017 $ (4 )
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 $ (53 ) Modified Black-Scholes Oil price volatility 22.57 % — 118.40% Credit risk 0.01 % — 1.25% Natural gas option contracts $ (10 ) Modified Black-Scholes Natural gas price volatility 24.33 % — 41.31% Credit risk 0.01 % — 1.25%
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 the indicated dates, was as follows: March 31, December 31, (In millions) 5¾% Senior Notes due 2022 $ 796 $ 789 5⅝% Senior Notes due 2024 1,054 1,044 5⅜% Senior Notes due 2026 731 714

Oil and Gas Assets (Tables)

Oil and Gas Assets (Tables)	3 Months Ended
	Mar. 31, 2017
Oil and Gas Property [Abstract]
Costs incurred by year for oil and gas properties not subject to amortization	Costs withheld from amortization as of March 31, 2017 consisted of the following: Costs Incurred In 2017 2016 2015 2014 & Prior Total (In millions) Acquisition costs $ 40 $ 532 $ 339 $ 196 $ 1,107 Exploration costs — 2 — — 2 Capitalized interest 16 51 33 31 131 Total costs withheld from amortization $ 56 $ 585 $ 372 $ 227 $ 1,240
Capitalized Costs Relating to Oil and Gas Producing Activities [Table Text Block]	Oil and gas properties consisted of the following: March 31, December 31, (In millions) Proved $ 22,253 $ 21,998 Unproved 1,240 1,238 Gross oil and gas properties 23,493 23,236 Accumulated depreciation, depletion and amortization (9,690 ) (9,587 ) Accumulated impairment (10,509 ) (10,509 ) Net oil and gas properties $ 3,294 $ 3,140

Other Property and Equipment 29

Other Property and Equipment Other Property and Equipment (Tables)	3 Months Ended
	Mar. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment [Table Text Block]	Other property and equipment consisted of the following: March 31, December 31, (In millions) Furniture, fixtures and equipment $ 153 $ 150 Gathering systems and equipment 116 115 Accumulated depreciation and amortization (103 ) (98 ) Net other property and equipment $ 166 $ 167

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	3 Months Ended
	Mar. 31, 2017
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	Accrued liabilities consisted of the following: March 31, December 31, (In millions) Revenue payable $ 210 $ 196 Accrued capital costs 96 92 Accrued lease operating expenses 31 37 Employee incentive expense 16 48 Accrued interest on debt 32 67 Taxes payable 13 15 Other 36 43 Total accrued liabilities $ 434 $ 498

Debt (Tables)

Debt (Tables)	3 Months Ended
	Mar. 31, 2017
Debt Disclosure [Abstract]
Debt	Our debt consisted of the following: March 31, December 31, (In millions) Senior unsecured debt: 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 2,450 Debt issuance costs (18 ) (19 ) Total long-term debt $ 2,432 $ 2,431

Commitments and Contingencies (

Commitments and Contingencies (Tables) $ in Millions	3 Months Ended
	Mar. 31, 2017USD ($)
Long-term Purchase Commitment [Line Items]
Operating Leases of Lessee Disclosure [Table Text Block]	In March 2017, we signed an agreement for firm natural gas transportation capacity for production from the Anadarko Basin. The table below summarizes the value of the obligation by year as of March 31, 2017. Total 2017 2018 2019 2020 2021 Thereafter (In millions) Firm transportation $ 186 $ — $ 9 $ 18 $ 18 $ 18 $ 123
Firm Transportation [Member]
Long-term Purchase Commitment [Line Items]
Contractual Obligation, Due in Next Fiscal Year	$ 0
Contractual Obligation, Due in Second Year	9
Contractual Obligation, Due in Third Year	18
Contractual Obligation, Due in Fourth Year	18
Contractual Obligation, Due in Fifth Year	18
Contractual Obligation, Due after Fifth Year	123
Contractual Obligation	$ 186

Earnings Per Share (Tables)

Earnings Per Share (Tables)	3 Months Ended
	Mar. 31, 2017
Earnings Per Share [Abstract]
Earnings Per Share Table	The following is the calculation of basic and diluted weighted-average shares outstanding and earnings per share (EPS) for the indicated periods. Three Months Ended 2017 2016 (In millions, except per share data) Net income (loss) $ 147 $ (624 ) Weighted-average shares (denominator): Weighted-average shares — basic 199 177 Dilution effect of stock options and unvested restricted stock awards and restricted stock units outstanding at end of period 1 — Weighted-average shares — diluted 200 177 Excluded due to anti-dilutive effect 1 1 Earnings (loss) per share: Basic $ 0.74 $ (3.52 ) Diluted $ 0.73 $ (3.52 )

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2017
Share-based Compensation [Abstract]
Schedule of Stock Based Compensation Expense Table	Our stock-based compensation expense consisted of the following: Three Months Ended 2017 2016 (In millions) Equity awards $ 16 $ 9 Liability awards — cash-settled restricted stock units 2 3 Total stock-based compensation 18 12 Capitalized in oil and gas properties (5 ) (4 ) Net stock-based compensation expense $ 13 $ 8
Restricted Stock and Restricted Stock Unit Activity Table	Cash-Settled Restricted Stock Units (In thousands) Non-vested units outstanding at January 1, 2017 460 Granted 235 Forfeited (12 ) Vested (26 ) Non-vested units outstanding at March 31, 2017 657 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 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, 2017 1,574 $ 35.56 859 $ 26.28 2,433 Granted 268 39.56 323 50.22 591 Forfeited (19 ) 18.70 — — (19 ) Vested (37 ) 25.38 — — (37 ) Non-vested shares outstanding at March 31, 2017 1,786 $ 36.41 1,182 $ 32.81 2,968 ________ (1) In February 2017, we granted approximately 323,000 restricted stock units, which based on achievement of certain criteria, could vest within a range of 0% to 200% of shares granted upon completion of the period ending December 31, 2019.

Restructuring Costs Restructu35

Restructuring Costs Restructuring Costs (Tables)	3 Months Ended
	Mar. 31, 2017
Restructuring and Related Activities [Abstract]
Schedule of Restructuring Reserve Rollforward [Table Text Block]	The following table summarizes our restructuring costs and related liability for the first quarter of 2017. Severance and Related Benefit Costs Office-lease Abandonment Costs (1) Relocation Costs Other Associated Costs Total (In millions) Restructuring liability at January 1, 2017 $ 1 $ 14 $ — $ — $ 15 Additions — — 1 — 1 Settlements (1 ) (1 ) (1 ) — (3 ) Revisions — (1 ) — — (1 ) Restructuring liability at March 31, 2017 $ — $ 12 $ — $ — $ 12 Cumulative costs as of March 31, 2017 $ 24 $ 19 $ 11 $ 1 $ 55 Expected total costs as of March 31, 2017 $ 24 $ 19 $ 11 $ 1 $ 55 _________________ (1) The office-lease abandonment liability will be relieved while lease payments are made and sublease income is received over the life of the lease ending 2022.

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting [Abstract]
Segment Information Table	Domestic China Total (In millions) Three Months Ended March 31, 2017: Oil, gas and NGL revenues $ 383 $ 34 $ 417 Operating expenses: Lease operating 48 8 56 Transportation and processing 72 — 72 Production and other taxes 14 — 14 Depreciation, depletion and amortization 96 10 106 General and administrative 46 1 47 Other 1 — 1 Allocated income tax (benefit) 39 9 Net income (loss) from oil and gas properties $ 67 $ 6 Total operating expenses 296 Income (loss) from operations 121 Interest expense, net of interest income, capitalized interest and other (20 ) Commodity derivative income (expense) 53 Income (loss) from operations before income taxes $ 154 Total assets $ 4,248 $ 140 $ 4,388 Additions to long-lived assets $ 257 $ — $ 257	Domestic China Total (In millions) Three Months Ended March 31, 2016: Oil, gas and NGL revenues $ 235 $ 49 $ 284 Operating expenses: Lease operating 47 14 61 Transportation and processing 63 — 63 Production and other taxes 10 — 10 Depreciation, depletion and amortization 133 44 177 General and administrative 43 1 44 Ceiling test and other impairments 461 45 506 Other 1 — 1 Allocated income tax (benefit) (194 ) (33 ) Net income (loss) from oil and gas properties $ (329 ) $ (22 ) Total operating expenses 862 Income (loss) from operations (578 ) Interest expense, net of interest income, capitalized interest and other (31 ) Commodity derivative income (expense) (17 ) Income (loss) from operations before income taxes $ (626 ) Total assets $ 4,540 $ 237 $ 4,777 Additions to long-lived assets $ 261 $ — $ 261

Supplemental Cash Flows Infor37

Supplemental Cash Flows Information (Tables)	3 Months Ended
	Mar. 31, 2017
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flows Information Schedule (Table)	The following table presents information about investing and financing activities that affect recognized assets and liabilities but do not result in cash receipts or payments for the indicated periods. Three Months Ended 2017 2016 (In millions) Non-cash investing and financing activities excluded from the statement of cash flows: (Increase) decrease in receivables for property sales $ — $ 2 (Increase) decrease in accrued capital expenditures (4 ) 20 (Increase) decrease in asset retirement costs (4 ) —

Accounts Receivable (Details)

Accounts Receivable (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	$ 243	$ 232
Allowance for Doubtful Accounts Receivable, Current	(16)	(16)
Revenue
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	149	163
Joint interest
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	78	53
Other
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	$ 32	$ 32

Inventories (Details)

Inventories (Details) - bbl	Mar. 31, 2017	Dec. 31, 2016
Inventory Disclosure [Abstract]
Crude oil inventory in barrels	239,000	11,500

Derivative Financial Instrume40

Derivative Financial Instruments (Textuals) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017USD ($)MMBTU$ / bbl$ / MMBTUMBbls	Mar. 31, 2016USD ($)
Derivative [Line Items]
Schedule of Derivative Instruments [Table Text Block]	At March 31, 2017 , 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 (1) Floors Ceilings (In millions) 2017: Fixed-price swaps 4,675 $ 45.43 $ — $ — $ — $ — $ (29 ) Fixed-price swaps with sold puts: 3,118 Fixed-price swaps 87.99 — — — — 112 Sold puts — — 73.09 — — (68 ) Collars with sold puts: 910 Collars — — — 90.00 95.69 36 Sold puts — — 75.00 — — (22 ) Purchased calls 4,028 — 73.52 — — — 1 Total $ 30 _________________ (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 March 31, 2017 , the deferred premiums totaled $7 million . Natural Gas NYMEX Contract Price Per MMBtu Collars Estimated Fair Value Asset (Liability) Period and Type of Instrument Volume in MMMBtus Swaps (Weighted Average) Floors (Weighted Average) Ceilings (Weighted Average) (In millions) 2017: Fixed-price swaps 20,625 $ 2.73 $ — $ — $ (12 ) Collars 41,260 — 2.82 3.23 (10 ) 2018: Fixed-price swaps 10,950 3.01 — — — Collars 18,150 — 3.00 3.55 — Total $ (22 )
Realized Gain Loss On Derivatives	$ 20	$ 82
Unrealized Gain (Loss) on Derivatives	33	(99)
Deferred Premium	7
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ 53	(17)
ConcentrationOfCounterpartiesUnderCreditFacility	83.00%
Total Derivative Counterparties	15
Primary Derivative Counterparties	10
Percent of future hedged production with primary counterparties	84.00%
Percentage of contracted volumes held by the largest counterparty.	13.00%
Natural gas contracts [Member]
Derivative [Line Items]
Realized Gain Loss On Derivatives	$ (6)	11
Unrealized Gain (Loss) on Derivatives	32	(16)
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	(22)
Oil contracts [Member]
Derivative [Line Items]
Realized Gain Loss On Derivatives	26	71
Unrealized Gain (Loss) on Derivatives	1	$ (83)
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 30
Year 2017 [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	$ (12)
Volume In Mmbtus | MMBTU	20,625,000
Year 2017 [Member] | Natural gas contracts [Member] | Collars [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price | $ / MMBTU	2.82
Derivative, Weighted Average Ceiling Price | $ / MMBTU	3.23
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (10)
Volume In Mmbtus | MMBTU	41,260,000
Year 2017 [Member] | Oil contracts [Member] | Swap [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	4,675
Derivative, Swap Type, Average Fixed Price | $ / bbl	45.43
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (29)
Year 2017 [Member] | Oil contracts [Member] | Fixed Price Swaps With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	3,118
Year 2017 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price | $ / bbl	73.09
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (68)
Year 2017 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Swap [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / bbl	87.99
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 112
Year 2017 [Member] | Oil contracts [Member] | Collars With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	910
Year 2017 [Member] | Oil contracts [Member] | Collars with Sold Puts - Collar [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price | $ / bbl	90
Derivative, Weighted Average Ceiling Price | $ / bbl	95.69
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 36
Year 2017 [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	$ (22)
Year 2017 [Member] | Oil contracts [Member] | Call Option [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	4,028
Derivative, Weighted Average Ceiling Price | $ / bbl	73.52
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 1
Year 2018 [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	$ 0
Volume In Mmbtus | MMBTU	10,950,000
Year 2018 [Member] | Natural gas contracts [Member] | Collars [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price | $ / MMBTU	3
Derivative, Weighted Average Ceiling Price | $ / MMBTU	3.55
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ 0
Volume In Mmbtus | MMBTU	18,150,000

Derivative Financial Instrume41

Derivative Financial Instruments Derivative Financial Instruments Recorded in Balance Sheet(Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Derivative, Fair Value, Net [Abstract]
Derivative Liability Not Designated as Hedging Instrument Fair Value	$ (158)	$ (261)
Derivative Liability, Fair Value, Gross Asset	112	161
Derivative Asset, Fair Value, Gross Liability	(112)	(161)
Derivative Asset Not Designated As Hedging Instrument, Fair Value	166	236
Derivative Asset, Current	52	75
Derivative Asset, Noncurrent	2	0
Derivative Liability, Current	46	97
Derivative Liability, Noncurrent	0	3
Natural gas contracts [Member]
Derivative, Fair Value, Net [Abstract]
Derivative Liability Not Designated as Hedging Instrument Fair Value	(32)	(64)
Derivative Liability, Fair Value, Gross Asset	8	10
Derivative Asset, Fair Value, Gross Liability	(8)	(10)
Derivative Asset Not Designated As Hedging Instrument, Fair Value	10	10
Derivative Asset, Current	0	0
Derivative Asset, Noncurrent	2	0
Derivative Liability, Current	24	51
Derivative Liability, Noncurrent	0	3
Oil contracts [Member]
Derivative, Fair Value, Net [Abstract]
Derivative Liability Not Designated as Hedging Instrument Fair Value	(126)	(197)
Derivative Liability, Fair Value, Gross Asset	104	151
Derivative Asset, Fair Value, Gross Liability	(104)	(151)
Derivative Asset Not Designated As Hedging Instrument, Fair Value	156	226
Derivative Asset, Current	52	75
Derivative Asset, Noncurrent	0	0
Derivative Liability, Current	22	46
Derivative Liability, Noncurrent	$ 0	$ 0

Amount of Gain Loss Recognized

Amount of Gain Loss Recognized in Income Related to Derivative Financial Instruments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	$ 20	$ 82
Unrealized Gain (Loss) on Derivatives	33	(99)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	53	(17)
Natural gas contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	(6)	11
Unrealized Gain (Loss) on Derivatives	32	(16)
Oil contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	26	71
Unrealized Gain (Loss) on Derivatives	$ 1	$ (83)

Fair Value Measurements (Textua

Fair Value Measurements (Textuals) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016	Mar. 31, 2016	Dec. 31, 2015
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value	$ (63)	$ (75)	$ (262)	$ (308)
5¾% Senior Notes due 2022
Debt Instrument, Fair Value Disclosure	796	789
5⅝% Senior Notes due 2024
Debt Instrument, Fair Value Disclosure	1,054	1,044
5⅜% Senior Notes due 2026
Debt Instrument, Fair Value Disclosure	$ 731	$ 714

Valuation of Investments and Fi

Valuation of Investments and Financial Instrument Assets Liabilities By Pricing Levels (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Money market fund investments	$ 236	$ 320
Deferred Compensation Plan Assets	6	6
Available-for-sale Securities	11	9
Obligations, Fair Value Disclosure	12	11
Total	249	299
Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts	71	50
Commodity Option [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Liability	(63)	(75)
Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Money market fund investments	236	320
Deferred Compensation Plan Assets	6	6
Available-for-sale Securities	11	9
Obligations, Fair Value Disclosure	12	11
Total	241	324
Fair Value, Inputs, Level 1 [Member] | Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts		0
Derivative Liability	0
Fair Value, Inputs, Level 1 [Member] | Commodity Option [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts	0	0
Significant Other Observable Fair Value Inputs (Level 2) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Money market fund investments	0	0
Deferred Compensation Plan Assets	0	0
Available-for-sale Securities	0	0
Obligations, Fair Value Disclosure	0	0
Total	71	50
Significant Other Observable Fair Value Inputs (Level 2) [Member] | Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts	71	50
Significant Other Observable Fair Value Inputs (Level 2) [Member] | Commodity Option [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts	0	0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Money market fund investments	0	0
Deferred Compensation Plan Assets	0	0
Available-for-sale Securities	0	0
Obligations, Fair Value Disclosure	0	0
Financial and Nonfinancial Liabilities, Fair Value Disclosure	(63)	(75)
Fair Value, Inputs, Level 3 [Member] | Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts		0
Derivative Liability	0
Fair Value, Inputs, Level 3 [Member] | Commodity Option [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Liability	$ (63)	$ (75)

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
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract]
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value	$ (63)	$ (262)	$ (75)	$ (308)
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	(6)	(46)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	18	92
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	0	0
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)	$ (4)	$ (32)

Quantitative Information about

Quantitative Information about Level 3 Fair Value Measurements (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017USD ($)
Natural gas contracts [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (22)
Natural gas contracts [Member] | Options Held [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (10)
Natural gas contracts [Member] | Options Held [Member] | Minimum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Fair Value Assumptions Expected Volatility Curves	24.33%
Credit Risk	0.01%
Natural gas contracts [Member] | Options Held [Member] | Maximum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Fair Value Assumptions Expected Volatility Curves	41.31%
Credit Risk	1.25%
Oil contracts [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 30
Oil contracts [Member] | Options Held [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (53)
Oil contracts [Member] | Options Held [Member] | Minimum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Fair Value Assumptions Expected Volatility Curves	22.57%
Credit Risk	0.01%
Oil contracts [Member] | Options Held [Member] | Maximum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Fair Value Assumptions Expected Volatility Curves	118.40%
Credit Risk	1.25%

Oil and Gas Assets (Details)

Oil and Gas Assets (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017USD ($)$ / bbl$ / MMBTU	Mar. 31, 2016USD ($)	Dec. 31, 2016USD ($)
Oil and gas properties:
Capitalized Costs, Proved Properties	$ 22,253		$ 21,998
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	1,240		1,238
Capitalized Costs, Oil and Gas Producing Activities, Gross	23,493		23,236
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance Relating to Oil and Gas Producing Activities	(9,690)		(9,587)
Capitalized Costs, Accumulated Impairment Relating to Oil and Gas Producing Activities	(10,509)		(10,509)
Capitalized Costs, Oil and Gas Producing Activities, Net	3,294		$ 3,140
Cost of oil and gas properties not subject to amortization
Acquisition costs	1,107
Exploration costs	2
Capitalized interest	131
Oil and Gas Assets (Textuals) [Abstract]
Capitalization of internal costs per full cost method of accounting	$ 33	$ 26
Document Period End Date	Mar. 31, 2017
Unweighted average commodity price of oil based on first-day-of-the-month prices for the prior 12 months (per barrel) | $ / bbl	47.65
Unweighted average commodity price of natural gas based on first-day-of-the-month prices for the prior 12 months (per MMBtu) | $ / MMBTU	2.73
Proceeds from Sale of Oil and Gas Property and Equipment	$ (5)	3
Payments to Acquire Oil and Gas Property and Equipment	4	$ 1
CHINA
Oil and Gas Assets (Textuals) [Abstract]
Disposal Group, Including Discontinued Operation, Consideration	39
Costs incurred in 2017 not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	56
Cost of oil and gas properties not subject to amortization
Acquisition costs	40
Exploration costs	0
Capitalized interest	16
Costs incurred in 2016 not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	585
Cost of oil and gas properties not subject to amortization
Acquisition costs	532
Exploration costs	2
Capitalized interest	51
Costs incurred in 2015 not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	372
Cost of oil and gas properties not subject to amortization
Acquisition costs	339
Exploration costs	0
Capitalized interest	33
Costs incurred in 2014 and Prior not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	227
Cost of oil and gas properties not subject to amortization
Acquisition costs	196
Exploration costs	0
Capitalized interest	$ 31

Other Property and Equipment 48

Other Property and Equipment Other Property and Equipment (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Accumulated depreciation and amortization	$ (103)	$ (98)
Net other property and equipment	166	167
Furniture and Fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Other, Gross	153	150
Gas Gathering and Processing Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Other, Gross	$ 116	$ 115

Income Taxes (Details)

Income Taxes (Details)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Income Tax Disclosure [Abstract]
Effective income tax rate	4.50%	0.30%

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Accrued Liabilities [Line Items]
Accrued liabilities	$ 434	$ 498
Revenue payable
Accrued Liabilities [Line Items]
Accrued liabilities	210	196
Accrued capital costs
Accrued Liabilities [Line Items]
Accrued liabilities	96	92
Accrued lease operating expenses
Accrued Liabilities [Line Items]
Accrued liabilities	31	37
Employee incentive expense
Accrued Liabilities [Line Items]
Accrued liabilities	16	48
Accrued interest on debt
Accrued Liabilities [Line Items]
Accrued liabilities	32	67
Taxes payable
Accrued Liabilities [Line Items]
Accrued liabilities	13	15
Other
Accrued Liabilities [Line Items]
Accrued liabilities	$ 36	$ 43

Debt (Details)

Debt (Details) - USD ($)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Debt Instrument [Line Items]
Payments of Financing Costs		$ 3,000,000
Long-term debt	$ (2,432,000,000)		$ (2,431,000,000)
Debt issuance costs	(18,000,000)		(19,000,000)
Debt (Textuals)
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,800,000,000
Largest individual loan commitment by any lender of total commitments	12.00%
Commitment fees incurred	$ 2,000,000	$ 2,000,000
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
Line of Credit Facility, Current Borrowing Capacity	$ 125,000,000
Percent added to prime rate based on grid of our debt rating	1.00%
Percentage Added To Adjusted Eurodollar Rate	2.00%
Commitment fee percentage on unused capacity of line of credit	0.375%
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%
Letters of Credit Outstanding, Amount	$ 0
5¾% Senior Notes due 2022
Debt Instrument [Line Items]
Long-term debt	$ (750,000,000)		$ (750,000,000)
Debt Instrument, Interest Rate, Stated Percentage	5.75%		5.75%
5⅝% Senior Notes due 2024
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%
5⅜% Senior Notes due 2026
Debt Instrument [Line Items]
Long-term debt	$ (700,000,000)		$ (700,000,000)
Debt Instrument, Interest Rate, Stated Percentage	5.375%		5.375%
Total senior unsecured debt
Debt Instrument [Line Items]
Long-term debt	$ (2,450,000,000)		$ (2,450,000,000)

Stockholders' Equity Activity52

Stockholders' Equity Activity (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Equity [Abstract]
Stock Issued During Period, Shares, New Issues		34.5
Proceeds from Issuance of Common Stock	$ 0	$ 776

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Income (numerator):
Net income (loss)	$ 147	$ (624)
Weighted average shares (denominator):
Weighted-average shares — basic	199	177
Dilution effect of stock options and unvested restricted stock awards and restricted stock units outstanding at end of period	1	0
Weighted-average shares — diluted	200	177
Basic --
Basic	$ 0.74	$ (3.52)
Diluted --
Diluted	$ 0.73	$ (3.52)
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	1	1

Stock-Based Compensation (Detai

Stock-Based Compensation (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Gross	$ 18	$ 12
Capitalized in oil and gas properties	5	4
Net stock-based compensation expense	13	8
Nonvested Awards, Total Compensation Cost Not yet Recognized	76
Obligations, Fair Value Disclosure	$ (12)		$ (11)
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	$ 36.91
Equity [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Gross	$ 16	9
Liability [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Gross	$ 2	$ 3
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Additional shares available for issuance	4
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Additional shares available for issuance	2.1
Fair Value, Inputs, Level 1 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Obligations, Fair Value Disclosure	$ (12)		$ (11)

Stock-Based Compensation- Restr

Stock-Based Compensation- Restricted Stock and Restricted Stock Units Activity (Details) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended
	Mar. 31, 2017USD ($)$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	2,433
Granted	591
Forfeited	(19)
Vested	(37)
Non-vested shares outstanding, Ending balance	2,968
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized | $	$ 76
Service - Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	1,574
Granted	268
Forfeited	(19)
Vested	(37)
Non-vested shares outstanding, Ending balance	1,786
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Beginning balance | $ / shares	$ 35.56
Granted, Weighted Average Grant Date Fair Value per Share | $ / shares	39.56
Forfeited, Weighted Average Grant Date Fair Value per Share | $ / shares	18.70
Vested, Weighted Average Grant Date Fair Value per Share | $ / shares	25.38
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Ending balance | $ / shares	$ 36.41
Performance Market Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	859
Granted	323
Forfeited	0
Vested	0
Non-vested shares outstanding, Ending balance	1,182
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Beginning balance | $ / shares	$ 26.28
Granted, Weighted Average Grant Date Fair Value per Share | $ / shares	50.22
Forfeited, Weighted Average Grant Date Fair Value per Share | $ / shares	0
Vested, Weighted Average Grant Date Fair Value per Share | $ / shares	0
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Ending balance | $ / shares	$ 32.81
Cash-Settled Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	460
Granted	235
Forfeited	(12)
Vested	(26)
Non-vested shares outstanding, Ending balance	657
Minimum [Member] | 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, Award Vesting Rights, Percentage	0.00%
Maximum [Member] | 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, Award Vesting Rights, Percentage	200.00%
Retirement Eligible [Member] [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	50.00%
Retirement Eligible [Member] [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	100.00%

Stock-Based Compensation- Emplo

Stock-Based Compensation- Employee Stock Purchase Plan (Details) - Employee Stock Purchase Plan [Member]	3 Months Ended
	Mar. 31, 2017USD ($)$ / sharesshares
Employee Stock Purchase Plan ESPP Disclosures [Line Items]
Options To Purchase Common Stock Shares | shares	54,000
Weighted average fair value of each option | $ / shares	$ 10.73
Expected volatility	40.20%
Risk-free weighted average interest rate	0.61%
Vesting Period	6 months
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Payments | $	$ 0

Stock-Based Compensation- Stock

Stock-Based Compensation- Stock Option Summary (Details)	3 Months Ended
	Mar. 31, 2017shares
Share-based Compensation [Abstract]
Options Outstanding, Number of Shares Underlying Options	177,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Net of Forfeitures	0

Restructuring Costs Restructu58

Restructuring Costs Restructuring Costs (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017USD ($)
Restructuring Reserve [Roll Forward]
Restructuring Reserve Beg	$ 15
Restructuring Additions	1
Restructuring Settlements	(3)
Restructuring Revisions	(1)
Restructuring Reserve End	12
Restructuring and Related Cost, Cost Incurred to Date	55
Restructuring and Related Cost, Expected Cost	55
Employee Severance [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve Beg	1
Restructuring Additions	0
Restructuring Settlements	(1)
Restructuring Revisions	0
Restructuring Reserve End	0
Restructuring and Related Cost, Cost Incurred to Date	24
Restructuring and Related Cost, Expected Cost	24
Contract Termination [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve Beg	14
Restructuring Additions	0
Restructuring Settlements	(1)
Restructuring Revisions	(1)
Restructuring Reserve End	12
Restructuring and Related Cost, Cost Incurred to Date	19
Restructuring and Related Cost, Expected Cost	19
Employee Relocation [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve Beg	0
Restructuring Additions	1
Restructuring Settlements	(1)
Restructuring Revisions	0
Restructuring Reserve End	0
Restructuring and Related Cost, Cost Incurred to Date	11
Restructuring and Related Cost, Expected Cost	11
Other Restructuring [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve Beg	0
Restructuring Additions	0
Restructuring Reserve, Settled without Cash	0
Restructuring Revisions	0
Restructuring Reserve End	0
Restructuring and Related Cost, Cost Incurred to Date	1
Restructuring and Related Cost, Expected Cost	$ 1

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Segment Information [Line Items]
Schedule of Revenue from External Customers and Long-Lived Assets, by Geographical Areas [Table Text Block]	Domestic China Total (In millions) Three Months Ended March 31, 2017: Oil, gas and NGL revenues $ 383 $ 34 $ 417 Operating expenses: Lease operating 48 8 56 Transportation and processing 72 — 72 Production and other taxes 14 — 14 Depreciation, depletion and amortization 96 10 106 General and administrative 46 1 47 Other 1 — 1 Allocated income tax (benefit) 39 9 Net income (loss) from oil and gas properties $ 67 $ 6 Total operating expenses 296 Income (loss) from operations 121 Interest expense, net of interest income, capitalized interest and other (20 ) Commodity derivative income (expense) 53 Income (loss) from operations before income taxes $ 154 Total assets $ 4,248 $ 140 $ 4,388 Additions to long-lived assets $ 257 $ — $ 257	Domestic China Total (In millions) Three Months Ended March 31, 2016: Oil, gas and NGL revenues $ 235 $ 49 $ 284 Operating expenses: Lease operating 47 14 61 Transportation and processing 63 — 63 Production and other taxes 10 — 10 Depreciation, depletion and amortization 133 44 177 General and administrative 43 1 44 Ceiling test and other impairments 461 45 506 Other 1 — 1 Allocated income tax (benefit) (194 ) (33 ) Net income (loss) from oil and gas properties $ (329 ) $ (22 ) Total operating expenses 862 Income (loss) from operations (578 ) Interest expense, net of interest income, capitalized interest and other (31 ) Commodity derivative income (expense) (17 ) Income (loss) from operations before income taxes $ (626 ) Total assets $ 4,540 $ 237 $ 4,777 Additions to long-lived assets $ 261 $ — $ 261
Oil, gas and NGL revenues	$ 417	$ 284
Operating expenses:
Lease operating	56	61
Transportation and processing	72	63
Production and other taxes	14	10
Depreciation, depletion and amortization	106	177
General and administrative	47	44
Ceiling test and other impairments	0	506
Other	1	1
Allocated income tax (benefit)	7	(2)
Total operating expenses	296	862
Income (loss) from operations	121	(578)
Interest expenses, net of interest income, capitalized interest and other	(20)	(31)
Commodity derivative income (expense)	53	(17)
Income (loss) before income taxes	154	(626)
Total assets	4,388	4,777	$ 4,312
Additions to long-lived assets	257	261
UNITED STATES
Segment Information [Line Items]
Oil, gas and NGL revenues	383	235
Operating expenses:
Lease operating	48	47
Transportation and processing	72	63
Production and other taxes	14	10
Depreciation, depletion and amortization	96	133
General and administrative	46	43
Ceiling test and other impairments		461
Other	1	1
Allocated income tax (benefit)	39	(194)
Net income (loss) from oil and gas properties	67	(329)
Total assets	4,248	4,540
Additions to long-lived assets	257	261
CHINA
Segment Information [Line Items]
Oil, gas and NGL revenues	34	49
Operating expenses:
Lease operating	8	14
Transportation and processing	0	0
Production and other taxes	0	0
Depreciation, depletion and amortization	10	44
General and administrative	1	1
Ceiling test and other impairments		45
Other	0	0
Allocated income tax (benefit)	9	(33)
Net income (loss) from oil and gas properties	6	(22)
Total assets	140	237
Additions to long-lived assets	$ 0	$ 0

Supplemental Cash Flows Infor60

Supplemental Cash Flows Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Supplemental Cash Flow Information [Abstract]
(Increase) decrease in receivables for property sales	$ 0	$ 2
(Increase) decrease in accrued capital expenditures	(4)	20
(Increase) decrease in asset retirement costs	$ (4)	$ 0