Newfield Exploration (NFX) 10-Q 1 Aug 17 2017 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	6 Months Ended
	Jun. 30, 2017	Jul. 27, 2017
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	Jun. 30, 2017
Amendment Flag	false
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q2
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	$ 5,596,079,497
Entity Common Stock, Shares Outstanding		199,319,211

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 522	$ 555
Short-term investments	25	25
Accounts receivable, net	224	232
Inventories	19	16
Derivative assets	33	75
Other current assets	60	46
Total current assets	883	949
Oil and gas properties, net — full cost method ($1,246 and $1,238 were excluded from amortization at June 30, 2017 and December 31, 2016, respectively)	3,479	3,140
Other property and equipment, net	166	167
Derivative assets	1	0
Long-term investments	23	19
Restricted cash	32	25
Other assets	11	12
Total assets	4,595	4,312
Current liabilities:
Accounts payable	44	33
Accrued liabilities	546	498
Advances from joint owners	73	54
Asset retirement obligations	2	2
Derivative liabilities	(13)	(97)
Total current liabilities	678	684
Other liabilities	67	63
Derivative liabilities	0	(3)
Long-term debt	2,432	2,431
Asset retirement obligations	156	154
Deferred taxes	55	39
Total long-term liabilities	2,710	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 June 30, 2017 and December 31, 2016; 200,728,889 and 200,150,392 shares issued at June 30, 2017 and December 31, 2016, respectively)	2	2
Additional paid-in capital	3,278	3,247
Treasury stock (at cost, 1,397,293 and 1,195,809 shares at June 30, 2017 and December 31, 2016, respectively)	(52)	(44)
Accumulated other comprehensive income (loss)	(1)	(2)
Retained earnings (deficit)	(2,020)	(2,265)
Total stockholders' equity	1,207	938
Total liabilities and stockholders' equity	$ 4,595	$ 4,312

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
ASSETS
Property and equipment, at cost, based on the full cost method of accounting for oil and gas properties	$ 1,246	$ 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	200,728,889	200,150,392
Treasury stock, shares	1,397,293	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		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Income Statement [Abstract]
Oil, gas and NGL revenues	$ 402	$ 381	$ 819	$ 665
Operating expenses:
Lease operating	58	62	114	123
Transportation and processing	71	66	143	129
Production and other taxes	13	11	27	21
Depreciation, depletion and amortization	110	160	216	337
General and administrative	51	58	98	102
Ceiling test and other impairments	0	522	0	1,028
Other	0	0	1	1
Total operating expenses	303	879	599	1,741
Income (loss) from operations	99	(498)	220	(1,076)
Other income (expense):
Interest expense	(37)	(38)	(75)	(79)
Capitalized interest	15	11	31	20
Commodity derivative income (expense)	(28)	133	(81)	150
Other, net	2	0	4	1
Total other income (expense)	8	(160)	41	(208)
Income (loss) before income taxes	107	(658)	261	(1,284)
Income tax provision (benefit):
Current	2	6	0	4
Deferred	7	3	16	3
Total income tax provision (benefit)	9	9	16	7
Net income (loss)	$ 98	$ (667)	$ 245	$ (1,291)
Earnings Per Share [Abstract]
Basic	$ 0.49	$ (3.36)	$ 1.23	$ (6.87)
Diluted	$ 0.49	$ (3.36)	$ 1.22	$ (6.87)
Weighted-average number of shares outstanding for basic earnings (loss) per share	199	198	199	188
Weighted-average number of shares outstanding for diluted earnings (loss) per share	200	198	200	188
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	$ 1	$ 0	$ 1	$ 0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$ 99	$ (667)	$ 246	$ (1,291)

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Cash flows from operating activities:
Net income (loss)	$ 245	$ (1,291)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	216	337
Deferred	16	3
Stock-based compensation	20	19
Unrealized (gain) loss on derivative contracts	(46)	296
Ceiling test and other impairments	0	1,028
Other, net	7	6
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	8	(1)
Increase (decrease) in accounts payable and accrued liabilities	5	(41)
Other items, net	(4)	22
Net cash provided by (used in) operating activities	467	378
Cash flows from investing activities:
Additions to oil and gas properties	(507)	(471)
Acquisitions of oil and gas properties	(6)	(495)
Proceeds from sales of oil and gas properties	28	29
Additions to other property and equipment	(8)	(8)
Redemptions of investments	25	0
Purchases of investments	(25)	0
Net cash provided by (used in) investing activities	(493)	(945)
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	2	777
Purchases of treasury stock, net	(8)	(11)
Other	(1)	0
Net cash provided by (used in) financing activities	(7)	727
Increase (decrease) in cash and cash equivalents	(33)	160
Cash and cash equivalents, beginning of period	555	5
Cash and cash equivalents, end of period	$ 522	$ 165

Consolidated Statement of Stock

Consolidated Statement of Stockholders' Equity - USD ($) $ in Millions	Total	Common Stock [Member]	Treasury Stock	Additional Paid-in Capital	Retained Earnings	AOCI Attributable to Parent [Member]
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)
Stock Issued During Period, Shares, New Issues		500,000
Stock Issued During Period, Value, New Issues	0
Stock Issued During Period, Value, Restricted Stock Award, Net of Forfeitures	2			$ 2
BOP Stockholders' Equity Balance at Dec. 31, 2016	938
EOP Stockholders' Equity Balance at Jun. 30, 2017	1,207
Stock-based compensation	29			29
Treasury stock, net, shares			(200,000)
Treasury stock, net, value	(8)		$ (8)	$ 0
Net income (loss)	245				$ 245
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	$ 1					$ 1
Common Stock, Shares, Issued	200,728,889
Common Stock, Value, Issued	$ 2
Treasury Stock, Shares	(1,397,293)
Treasury Stock, Value	$ (52)
Additional Paid in Capital	3,278
Retained Earnings (Accumulated Deficit)	(2,020)
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ (1)

Organization and Summary of Sig

Organization and Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 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 a volatile 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 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 expect to apply the guidance in the first quarter of 2018 using the modified retrospective approach to adjust retained earnings (deficit). We are in the process of comparing our current revenue recognition policies to the new requirements for each of our revenue categories. While we have not identified any material differences in the amount and timing of revenue recognition for the categories we have reviewed to date, our evaluation is not complete, and we have not concluded on the overall impacts of adopting the new requirements. 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 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.

Accounts Receivable

Accounts Receivable	6 Months Ended
	Jun. 30, 2017
Accounts Receivable, Net, Current [Abstract]
Accounts Receivable Text Block	Accounts Receivable Accounts receivable consisted of the following: June 30, December 31, (In millions) Revenue $ 144 $ 163 Joint interest 65 53 Other 31 32 Reserve for doubtful accounts (16 ) (16 ) Total accounts receivable, net $ 224 $ 232

Inventories (Notes)

Inventories (Notes)	6 Months Ended
	Jun. 30, 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. Inventories are carried at the lower of cost or net realizable value. At June 30, 2017 and December 31, 2016 , the crude oil inventory from our China operations consisted of approximately 105,400 and 11,500 barrels of crude oil, respectively.

Derivative Financial Instrument

Derivative Financial Instruments	6 Months Ended
	Jun. 30, 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 June 30, 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 3,128 $ 45.43 $ — $ — $ — $ — $ (4 ) Fixed-price swaps with sold puts: 2,208 Fixed-price swaps 87.95 — — — — 91 Sold puts — — 73.08 — — (61 ) Purchased calls 2,208 — 73.08 — — — — Total $ 26 _________________ (1) For the fixed-price swaps with sold puts, if the market price remains below our sold puts at contract settlement, we will receive the market price plus the difference between our swaps and our sold puts. (2) As a result of our purchased calls, we have effectively locked in the spread between our fixed-price swaps and sold puts (less the deferred call premium). We deferred the premiums related to the purchased calls until contract settlement. At June 30, 2017 , the deferred premiums totaled $5 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 13,800 $ 2.73 $ — $ — $ (4 ) Collars 28,520 — 2.84 3.25 (2 ) 2018: Fixed-price swaps 10,950 3.01 — — — Collars 18,150 — 3.00 3.55 1 Total $ (5 ) 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) June 30, 2017 Oil positions $ 95 $ (62 ) $ 33 $ — $ (69 ) $ 62 $ (7 ) $ — Natural gas positions 9 (8 ) — 1 (14 ) 8 (6 ) — Total $ 104 $ (70 ) $ 33 $ 1 $ (83 ) $ 70 $ (13 ) $ — 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 Six Months Ended 2017 2016 2017 2016 (In millions) Derivatives not designated as hedging instruments: Realized gain (loss) on oil positions $ 19 $ 58 $ 45 $ 129 Realized gain (loss) on natural gas positions (4 ) 6 (10 ) 17 Total realized gain (loss) 15 64 35 146 Unrealized gain (loss) on oil positions (4 ) (149 ) (3 ) (232 ) Unrealized gain (loss) on natural gas positions 17 (48 ) 49 (64 ) Total unrealized gain (loss) 13 (197 ) 46 (296 ) Total $ 28 $ (133 ) $ 81 $ (150 ) 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 June 30, 2017 , 10 of our 15 counterparties accounted for approximately 84% of our contracted volumes, with the largest counterparty accounting for approximately 13% . At June 30, 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	6 Months Ended
	Jun. 30, 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 June 30, 2017: Money market fund investments $ 289 $ — $ — $ 289 Deferred compensation plan assets 7 — — 7 Equity securities available-for-sale 11 — — 11 Oil and gas derivative swap contracts — 83 — 83 Oil and gas derivative option contracts — — (62 ) (62 ) Stock-based compensation liability awards (12 ) — — (12 ) Total $ 295 $ 83 $ (62 ) $ 316 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 (4 ) Purchases, issuances, sales and settlements: Settlements 131 Transfers into Level 3 — Transfers out of Level 3 (1) 46 Balance at June 30, 2016 $ (135 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at June 30, 2016 $ 43 Balance at January 1, 2017 $ (75 ) Unrealized gains (losses) included in earnings (17 ) Purchases, issuances, sales and settlements: Settlements 30 Transfers into Level 3 — Transfers out of Level 3 — Balance at June 30, 2017 $ (62 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at June 30, 2017 $ (10 ) _________________ (1) During the second quarter of 2016, we transferred $46 million of derivative option contracts out of the Level 3 hierarchy. The transfer was the result of our Level 3 swaptions being exercised by the counterparties as swaps in June 2016. 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 $ (61 ) Modified Black-Scholes Oil price volatility 24.27 % — 99.30% Credit risk 0.01 % — 1.39% Natural gas option contracts $ (1 ) Modified Black-Scholes Natural gas price volatility 24.42 % — 46.56% Credit risk 0.01 % — 1.39% 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: June 30, December 31, (In millions) 5¾% Senior Notes due 2022 $ 793 $ 789 5⅝% Senior Notes due 2024 1,041 1,044 5⅜% Senior Notes due 2026 726 714 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 Properties _Text Bl

Oil and Gas Properties [Text Blocks]	6 Months Ended
	Jun. 30, 2017
Oil and Gas Property [Abstract]
Oil and Gas Properties [Text Block]	Oil and Gas Properties Oil and gas properties consisted of the following: June 30, December 31, (In millions) Proved $ 22,536 $ 21,998 Unproved 1,246 1,238 Gross oil and gas properties 23,782 23,236 Accumulated depreciation, depletion and amortization (9,794 ) (9,587 ) Accumulated impairment (10,509 ) (10,509 ) Net oil and gas properties $ 3,479 $ 3,140 Costs withheld from amortization as of June 30, 2017 consisted of the following: Costs Incurred In 2017 2016 2015 2014 & Prior Total (In millions) Acquisition costs $ 77 $ 532 $ 339 $ 156 $ 1,104 Exploration costs — — — — — Capitalized interest 31 51 33 27 142 Total costs withheld from amortization $ 108 $ 583 $ 372 $ 183 $ 1,246 We capitalized approximately $31 million and $30 million of interest and direct internal costs during the three months ended June 30, 2017 and 2016 , respectively, and $64 million and $56 million during the six months ended June 30, 2017 and 2016 , respectively. At June 30, 2017 , the ceiling value of our reserves was calculated based upon SEC pricing of $48.95 per barrel for oil and $3.01 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 June 30, 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 June 30, 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 May 22, 2017, we closed our previously disclosed sale transaction with certain of our joint venture partners to divest our non-operated interest in the Bohai Bay field in China for approximately $32 million , including customary post-close adjustments. Upon completion of our assessment, the sale of our Bohai Bay assets did not significantly alter the relationship between capitalized costs and proved reserves for our China full cost pool and, as such, all proceeds were recorded as adjustments to our China full cost pool with no gain or loss recognized.

Other Property and Equipment Ot

Other Property and Equipment Other Property and Equipment	6 Months Ended
	Jun. 30, 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: June 30, December 31, (In millions) Furniture, fixtures and equipment $ 157 $ 150 Gathering systems and equipment 116 115 Accumulated depreciation and amortization (107 ) (98 ) Net other property and equipment $ 166 $ 167

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2017
Income Tax Disclosure [Abstract]
Income Taxes Text Block	Income Taxes The effective tax rates for the three months ended June 30, 2017 and 2016 were 8.8% and (1.4)% , respectively. The effective tax rates for the six months ended June 30, 2017 and 2016 were 6.3% and (0.6)% , 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 June 30, 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 2011 and 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	6 Months Ended
	Jun. 30, 2017
Accrued Liabilities, Current [Abstract]
Accrued Liabilities Text Block	Accrued Liabilities Accrued liabilities consisted of the following: June 30, December 31, (In millions) Revenue payable $ 220 $ 196 Accrued capital costs 149 92 Accrued lease operating expenses 31 37 Employee incentive expense 24 48 Accrued interest on debt 67 67 Taxes payable 15 15 Other 40 43 Total accrued liabilities $ 546 $ 498

Debt

Debt	6 Months Ended
	Jun. 30, 2017
Debt Disclosure [Abstract]
Debt Text Block	Debt Our debt consisted of the following: June 30, 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 June 30, 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 June 30, 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 June 30, 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 June 30, 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 June 30, 2017 ). We incurred aggregate commitment fees under our credit facility of approximately $1 million and $3 million for the three and six months ended June 30, 2017 , respectively, which were recorded in “Interest expense” on our consolidated statement of operations and comprehensive income. For the three and six months ended June 30, 2016 , we incurred commitment fees under our credit facility of approximately $2 million and $4 million , respectively. 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 June 30, 2017 , we were in compliance with all of our debt covenants. As of June 30, 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 June 30, 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	6 Months Ended
	Jun. 30, 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 June 30, 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)	6 Months Ended
	Jun. 30, 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	6 Months Ended
	Jun. 30, 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 Six Months Ended 2017 2016 2017 2016 (In millions, except per share data) Net income (loss) $ 98 $ (667 ) $ 245 $ (1,291 ) Weighted-average shares (denominator): Weighted-average shares — basic 199 198 199 188 Dilution effect of stock options and unvested restricted stock awards and restricted stock units outstanding at end of period 1 — 1 — Weighted-average shares — diluted 200 198 200 188 Excluded due to anti-dilutive effect 1 2 1 2 Earnings (loss) per share: Basic $ 0.49 $ (3.36 ) $ 1.23 $ (6.87 ) Diluted $ 0.49 $ (3.36 ) $ 1.22 $ (6.87 )

Stock-Based Compensation

Stock-Based Compensation	6 Months Ended
	Jun. 30, 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 Six Months Ended 2017 2016 2017 2016 (In millions) Equity awards $ 13 $ 9 $ 29 $ 18 Liability awards — cash-settled restricted stock units — 7 2 10 Total stock-based compensation 13 16 31 28 Capitalized in oil and gas properties (5 ) (5 ) (10 ) (9 ) Net stock-based compensation expense $ 8 $ 11 $ 21 $ 19 As of June 30, 2017 , we had approximately $59 million of total unrecognized stock-based compensation expense related to unvested stock-based compensation awards that vest within four years . On June 30, 2017 , the last reported sales price of our common stock on the New York Stock Exchange was $28.46 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. Under the revised requirements, 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 unvested market-based restricted stock units previously issued to eligible employees and all new equity and liability 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). In May 2017, Newfield adopted the 2017 Omnibus Incentive Plan, as amended (2017 Plan), which replaced the 2011 Omnibus Stock Plan as the vehicle for granting equity-based compensation awards. At June 30, 2017 , we had approximately (1) 10.4 million shares available for issuance under our 2017 Plan if all future awards are stock options, or (2) 6.2 million shares available for issuance under our 2017 Plan if all future awards are restricted stock awards or restricted stock units. Restricted Stock and Restricted Stock Units. The following table provides information about restricted stock awards and restricted stock unit activity (excluding cash-settled restricted stock units, which are discussed below). Service-Based Shares Weighted- Average Grant Date Fair Value per Share Market-Based Shares 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 341 38.40 323 (1 ) 50.22 664 Forfeited (40 ) 22.79 (48 ) 30.27 (88 ) Vested (128 ) 34.19 (386 ) 22.85 (514 ) Non-vested shares outstanding at June 30, 2017 1,747 $ 36.28 748 $ 38.13 2,495 ________ (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 six months of 2017 , options to purchase approximately 61,000 shares of our common stock were issued 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 June 30, 2017 , we had approximately 160,000 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 June 30, 2017 , we had a liability of $12 million related to these 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 241 Forfeited (22 ) Vested (31 ) Non-vested units outstanding at June 30, 2017 648

Segment Information

Segment Information	6 Months Ended
	Jun. 30, 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 and six-month periods ended June 30, 2017 and 2016 . Income tax allocations have been determined based on statutory rates in the applicable geographic segment. Our income tax allocation for our China operations is based on the combined statutory rates for China and the United States. Domestic China Total (In millions) Three Months Ended June 30, 2017: Oil, gas and NGL revenues $ 361 $ 41 $ 402 Operating expenses: Lease operating 45 13 58 Transportation and processing 71 — 71 Production and other taxes 13 — 13 Depreciation, depletion and amortization 100 10 110 General and administrative 49 2 51 Allocated income tax (benefit) 30 10 Net income (loss) from oil and gas properties $ 53 $ 6 Total operating expenses 303 Income (loss) from operations 99 Interest expense, net of interest income, capitalized interest and other (20 ) Commodity derivative income (expense) 28 Income (loss) from operations before income taxes $ 107 Total assets $ 4,504 $ 91 $ 4,595 Additions to long-lived assets $ 334 $ 1 $ 335 Domestic China Total (In millions) Three Months Ended June 30, 2016: Oil, gas and NGL revenues $ 309 $ 72 $ 381 Operating expenses: Lease operating 46 16 62 Transportation and processing 66 — 66 Production and other taxes 11 — 11 Depreciation, depletion and amortization 126 34 160 General and administrative 56 2 58 Ceiling test and other impairments 501 21 522 Allocated income tax (benefit) (183 ) (1 ) Net income (loss) from oil and gas properties $ (314 ) $ — Total operating expenses 879 Income (loss) from operations (498 ) Interest expense, net of interest income, capitalized interest and other (27 ) Commodity derivative income (expense) (133 ) Income (loss) from operations before income taxes $ (658 ) Total assets $ 4,095 $ 190 $ 4,285 Additions to long-lived assets $ 699 $ — $ 699 Domestic China Total (In millions) Six Months Ended June 30, 2017: Oil, gas and NGL revenues $ 744 $ 75 $ 819 Operating expenses: Lease operating 93 21 114 Transportation and processing 143 — 143 Production and other taxes 27 — 27 Depreciation, depletion and amortization 196 20 216 General and administrative 95 3 98 Other 1 — 1 Allocated income tax (benefit) 69 19 Net income (loss) from oil and gas properties $ 120 $ 12 Total operating expenses 599 Income (loss) from operations 220 Interest expense, net of interest income, capitalized interest and other (40 ) Commodity derivative income (expense) 81 Income (loss) from operations before income taxes $ 261 Total assets $ 4,504 $ 91 $ 4,595 Additions to long-lived assets $ 591 $ 1 $ 592 Domestic China Total (In millions) Six Months Ended June 30, 2016: Oil, gas and NGL revenues $ 544 $ 121 $ 665 Operating expenses: Lease operating 93 30 123 Transportation and processing 129 — 129 Production and other taxes 21 — 21 Depreciation, depletion and amortization 259 78 337 General and administrative 99 3 102 Ceiling test and other impairments 962 66 1,028 Other 1 — 1 Allocated income tax (benefit) (377 ) (34 ) Net income (loss) from oil and gas properties $ (643 ) $ (22 ) Total operating expenses 1,741 Income (loss) from operations (1,076 ) Interest expense, net of interest income, capitalized interest and other (58 ) Commodity derivative income (expense) (150 ) Income (loss) from operations before income taxes $ (1,284 ) Total assets $ 4,095 $ 190 $ 4,285 Additions to long-lived assets $ 960 $ — $ 960

Supplemental Cash Flows Informa

Supplemental Cash Flows Information	6 Months Ended
	Jun. 30, 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. Six 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 $ — $ 6 (Increase) decrease in accrued capital expenditures (57 ) 33 (Increase) decrease in asset retirement costs 2 (8 )

Organization and Summary of S23

Organization and Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 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 a volatile 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 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 expect to apply the guidance in the first quarter of 2018 using the modified retrospective approach to adjust retained earnings (deficit). We are in the process of comparing our current revenue recognition policies to the new requirements for each of our revenue categories. While we have not identified any material differences in the amount and timing of revenue recognition for the categories we have reviewed to date, our evaluation is not complete, and we have not concluded on the overall impacts of adopting the new requirements. 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 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.

Accounts Receivable (Tables)

Accounts Receivable (Tables)	6 Months Ended
	Jun. 30, 2017
Accounts Receivable, Net, Current [Abstract]
Accounts Receivable	Accounts receivable consisted of the following: June 30, December 31, (In millions) Revenue $ 144 $ 163 Joint interest 65 53 Other 31 32 Reserve for doubtful accounts (16 ) (16 ) Total accounts receivable, net $ 224 $ 232

Derivative Financial Instrume25

Derivative Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2017
Derivative Instruments and Hedges, Assets [Abstract]
Outstanding contracts that are not designated for hedge accounting	At June 30, 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 3,128 $ 45.43 $ — $ — $ — $ — $ (4 ) Fixed-price swaps with sold puts: 2,208 Fixed-price swaps 87.95 — — — — 91 Sold puts — — 73.08 — — (61 ) Purchased calls 2,208 — 73.08 — — — — Total $ 26 _________________ (1) For the fixed-price swaps with sold puts, if the market price remains below our sold puts at contract settlement, we will receive the market price plus the difference between our swaps and our sold puts. (2) As a result of our purchased calls, we have effectively locked in the spread between our fixed-price swaps and sold puts (less the deferred call premium). We deferred the premiums related to the purchased calls until contract settlement. At June 30, 2017 , the deferred premiums totaled $5 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 13,800 $ 2.73 $ — $ — $ (4 ) Collars 28,520 — 2.84 3.25 (2 ) 2018: Fixed-price swaps 10,950 3.01 — — — Collars 18,150 — 3.00 3.55 1 Total $ (5 )
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) June 30, 2017 Oil positions $ 95 $ (62 ) $ 33 $ — $ (69 ) $ 62 $ (7 ) $ — Natural gas positions 9 (8 ) — 1 (14 ) 8 (6 ) — Total $ 104 $ (70 ) $ 33 $ 1 $ (83 ) $ 70 $ (13 ) $ — 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 June 30, 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 3,128 $ 45.43 $ — $ — $ — $ — $ (4 ) Fixed-price swaps with sold puts: 2,208 Fixed-price swaps 87.95 — — — — 91 Sold puts — — 73.08 — — (61 ) Purchased calls 2,208 — 73.08 — — — — Total $ 26 _________________ (1) For the fixed-price swaps with sold puts, if the market price remains below our sold puts at contract settlement, we will receive the market price plus the difference between our swaps and our sold puts. (2) As a result of our purchased calls, we have effectively locked in the spread between our fixed-price swaps and sold puts (less the deferred call premium). We deferred the premiums related to the purchased calls until contract settlement. At June 30, 2017 , the deferred premiums totaled $5 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 13,800 $ 2.73 $ — $ — $ (4 ) Collars 28,520 — 2.84 3.25 (2 ) 2018: Fixed-price swaps 10,950 3.01 — — — Collars 18,150 — 3.00 3.55 1 Total $ (5 ) 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) June 30, 2017 Oil positions $ 95 $ (62 ) $ 33 $ — $ (69 ) $ 62 $ (7 ) $ — Natural gas positions 9 (8 ) — 1 (14 ) 8 (6 ) — Total $ 104 $ (70 ) $ 33 $ 1 $ (83 ) $ 70 $ (13 ) $ — 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 Six Months Ended 2017 2016 2017 2016 (In millions) Derivatives not designated as hedging instruments: Realized gain (loss) on oil positions $ 19 $ 58 $ 45 $ 129 Realized gain (loss) on natural gas positions (4 ) 6 (10 ) 17 Total realized gain (loss) 15 64 35 146 Unrealized gain (loss) on oil positions (4 ) (149 ) (3 ) (232 ) Unrealized gain (loss) on natural gas positions 17 (48 ) 49 (64 ) Total unrealized gain (loss) 13 (197 ) 46 (296 ) Total $ 28 $ (133 ) $ 81 $ (150 ) 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 June 30, 2017 , 10 of our 15 counterparties accounted for approximately 84% of our contracted volumes, with the largest counterparty accounting for approximately 13% . At June 30, 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 Six Months Ended 2017 2016 2017 2016 (In millions) Derivatives not designated as hedging instruments: Realized gain (loss) on oil positions $ 19 $ 58 $ 45 $ 129 Realized gain (loss) on natural gas positions (4 ) 6 (10 ) 17 Total realized gain (loss) 15 64 35 146 Unrealized gain (loss) on oil positions (4 ) (149 ) (3 ) (232 ) Unrealized gain (loss) on natural gas positions 17 (48 ) 49 (64 ) Total unrealized gain (loss) 13 (197 ) 46 (296 ) Total $ 28 $ (133 ) $ 81 $ (150 )

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2017
Fair Value Disclosures [Abstract]
Fair Value Measurement Classification [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 June 30, 2017: Money market fund investments $ 289 $ — $ — $ 289 Deferred compensation plan assets 7 — — 7 Equity securities available-for-sale 11 — — 11 Oil and gas derivative swap contracts — 83 — 83 Oil and gas derivative option contracts — — (62 ) (62 ) Stock-based compensation liability awards (12 ) — — (12 ) Total $ 295 $ 83 $ (62 ) $ 316
Level 3 Fair Value Measurements [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 (4 ) Purchases, issuances, sales and settlements: Settlements 131 Transfers into Level 3 — Transfers out of Level 3 (1) 46 Balance at June 30, 2016 $ (135 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at June 30, 2016 $ 43 Balance at January 1, 2017 $ (75 ) Unrealized gains (losses) included in earnings (17 ) Purchases, issuances, sales and settlements: Settlements 30 Transfers into Level 3 — Transfers out of Level 3 — Balance at June 30, 2017 $ (62 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at June 30, 2017 $ (10 ) _________________ (1) During the second quarter of 2016, we transferred $46 million of derivative option contracts out of the Level 3 hierarchy. The transfer was the result of our Level 3 swaptions being exercised by the counterparties as swaps in June 2016.
Quantitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements [Table]	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 $ (61 ) Modified Black-Scholes Oil price volatility 24.27 % — 99.30% Credit risk 0.01 % — 1.39% Natural gas option contracts $ (1 ) Modified Black-Scholes Natural gas price volatility 24.42 % — 46.56% Credit risk 0.01 % — 1.39%
Fair Value of Debt [Table]	The estimated fair value of our notes, based on quoted prices in active markets (Level 1) as of the indicated dates, was as follows: June 30, December 31, (In millions) 5¾% Senior Notes due 2022 $ 793 $ 789 5⅝% Senior Notes due 2024 1,041 1,044 5⅜% Senior Notes due 2026 726 714

Oil and Gas Properties _Tables_

Oil and Gas Properties [Tables]	6 Months Ended
	Jun. 30, 2017
Oil and Gas Property [Abstract]
Oil and Gas Properties [Table Text Block]	Oil and gas properties consisted of the following: June 30, December 31, (In millions) Proved $ 22,536 $ 21,998 Unproved 1,246 1,238 Gross oil and gas properties 23,782 23,236 Accumulated depreciation, depletion and amortization (9,794 ) (9,587 ) Accumulated impairment (10,509 ) (10,509 ) Net oil and gas properties $ 3,479 $ 3,140
Costs withheld from amortization [Table Text Block]	Costs withheld from amortization as of June 30, 2017 consisted of the following: Costs Incurred In 2017 2016 2015 2014 & Prior Total (In millions) Acquisition costs $ 77 $ 532 $ 339 $ 156 $ 1,104 Exploration costs — — — — — Capitalized interest 31 51 33 27 142 Total costs withheld from amortization $ 108 $ 583 $ 372 $ 183 $ 1,246

Other Property and Equipment 28

Other Property and Equipment Other Property and Equipment (Tables)	6 Months Ended
	Jun. 30, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment [Table Text Block]	Other property and equipment consisted of the following: June 30, December 31, (In millions) Furniture, fixtures and equipment $ 157 $ 150 Gathering systems and equipment 116 115 Accumulated depreciation and amortization (107 ) (98 ) Net other property and equipment $ 166 $ 167

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	6 Months Ended
	Jun. 30, 2017
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	Accrued liabilities consisted of the following: June 30, December 31, (In millions) Revenue payable $ 220 $ 196 Accrued capital costs 149 92 Accrued lease operating expenses 31 37 Employee incentive expense 24 48 Accrued interest on debt 67 67 Taxes payable 15 15 Other 40 43 Total accrued liabilities $ 546 $ 498

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2017
Debt Disclosure [Abstract]
Debt	Our debt consisted of the following: June 30, 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)	6 Months Ended
	Jun. 30, 2017
Commitments and Contingencies Disclosure [Abstract]
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 June 30, 2017 . Total 2017 2018 2019 2020 2021 Thereafter (In millions) Firm transportation $ 186 $ — $ 9 $ 18 $ 18 $ 18 $ 123

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 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 Six Months Ended 2017 2016 2017 2016 (In millions, except per share data) Net income (loss) $ 98 $ (667 ) $ 245 $ (1,291 ) Weighted-average shares (denominator): Weighted-average shares — basic 199 198 199 188 Dilution effect of stock options and unvested restricted stock awards and restricted stock units outstanding at end of period 1 — 1 — Weighted-average shares — diluted 200 198 200 188 Excluded due to anti-dilutive effect 1 2 1 2 Earnings (loss) per share: Basic $ 0.49 $ (3.36 ) $ 1.23 $ (6.87 ) Diluted $ 0.49 $ (3.36 ) $ 1.22 $ (6.87 )

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2017
Share-based Compensation [Abstract]
Schedule of Stock Based Compensation Expense Table	Our stock-based compensation expense consisted of the following: Three Months Ended Six Months Ended 2017 2016 2017 2016 (In millions) Equity awards $ 13 $ 9 $ 29 $ 18 Liability awards — cash-settled restricted stock units — 7 2 10 Total stock-based compensation 13 16 31 28 Capitalized in oil and gas properties (5 ) (5 ) (10 ) (9 ) Net stock-based compensation expense $ 8 $ 11 $ 21 $ 19
Restricted Stock and Restricted Stock Unit Activity Table	The following table provides information about restricted stock awards and restricted stock unit activity (excluding cash-settled restricted stock units, which are discussed below). Service-Based Shares Weighted- Average Grant Date Fair Value per Share Market-Based Shares 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 341 38.40 323 (1 ) 50.22 664 Forfeited (40 ) 22.79 (48 ) 30.27 (88 ) Vested (128 ) 34.19 (386 ) 22.85 (514 ) Non-vested shares outstanding at June 30, 2017 1,747 $ 36.28 748 $ 38.13 2,495 ________ (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. 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 241 Forfeited (22 ) Vested (31 ) Non-vested units outstanding at June 30, 2017 648

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Segment Reporting [Abstract]
Segment Information Table	Domestic China Total (In millions) Six Months Ended June 30, 2017: Oil, gas and NGL revenues $ 744 $ 75 $ 819 Operating expenses: Lease operating 93 21 114 Transportation and processing 143 — 143 Production and other taxes 27 — 27 Depreciation, depletion and amortization 196 20 216 General and administrative 95 3 98 Other 1 — 1 Allocated income tax (benefit) 69 19 Net income (loss) from oil and gas properties $ 120 $ 12 Total operating expenses 599 Income (loss) from operations 220 Interest expense, net of interest income, capitalized interest and other (40 ) Commodity derivative income (expense) 81 Income (loss) from operations before income taxes $ 261 Total assets $ 4,504 $ 91 $ 4,595 Additions to long-lived assets $ 591 $ 1 $ 592 Domestic China Total (In millions) Three Months Ended June 30, 2017: Oil, gas and NGL revenues $ 361 $ 41 $ 402 Operating expenses: Lease operating 45 13 58 Transportation and processing 71 — 71 Production and other taxes 13 — 13 Depreciation, depletion and amortization 100 10 110 General and administrative 49 2 51 Allocated income tax (benefit) 30 10 Net income (loss) from oil and gas properties $ 53 $ 6 Total operating expenses 303 Income (loss) from operations 99 Interest expense, net of interest income, capitalized interest and other (20 ) Commodity derivative income (expense) 28 Income (loss) from operations before income taxes $ 107 Total assets $ 4,504 $ 91 $ 4,595 Additions to long-lived assets $ 334 $ 1 $ 335	Domestic China Total (In millions) Three Months Ended June 30, 2016: Oil, gas and NGL revenues $ 309 $ 72 $ 381 Operating expenses: Lease operating 46 16 62 Transportation and processing 66 — 66 Production and other taxes 11 — 11 Depreciation, depletion and amortization 126 34 160 General and administrative 56 2 58 Ceiling test and other impairments 501 21 522 Allocated income tax (benefit) (183 ) (1 ) Net income (loss) from oil and gas properties $ (314 ) $ — Total operating expenses 879 Income (loss) from operations (498 ) Interest expense, net of interest income, capitalized interest and other (27 ) Commodity derivative income (expense) (133 ) Income (loss) from operations before income taxes $ (658 ) Total assets $ 4,095 $ 190 $ 4,285 Additions to long-lived assets $ 699 $ — $ 699 Domestic China Total (In millions) Six Months Ended June 30, 2016: Oil, gas and NGL revenues $ 544 $ 121 $ 665 Operating expenses: Lease operating 93 30 123 Transportation and processing 129 — 129 Production and other taxes 21 — 21 Depreciation, depletion and amortization 259 78 337 General and administrative 99 3 102 Ceiling test and other impairments 962 66 1,028 Other 1 — 1 Allocated income tax (benefit) (377 ) (34 ) Net income (loss) from oil and gas properties $ (643 ) $ (22 ) Total operating expenses 1,741 Income (loss) from operations (1,076 ) Interest expense, net of interest income, capitalized interest and other (58 ) Commodity derivative income (expense) (150 ) Income (loss) from operations before income taxes $ (1,284 ) Total assets $ 4,095 $ 190 $ 4,285 Additions to long-lived assets $ 960 $ — $ 960

Supplemental Cash Flows Infor35

Supplemental Cash Flows Information (Tables)	6 Months Ended
	Jun. 30, 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. Six 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 $ — $ 6 (Increase) decrease in accrued capital expenditures (57 ) 33 (Increase) decrease in asset retirement costs 2 (8 )

Accounts Receivable (Details)

Accounts Receivable (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	$ 224	$ 232
Allowance for Doubtful Accounts Receivable, Current	(16)	(16)
Revenue
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	144	163
Joint interest
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	65	53
Other
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	$ 31	$ 32

Inventories (Details)

Inventories (Details) - bbl	Jun. 30, 2017	Dec. 31, 2016
Inventory Disclosure [Abstract]
Crude oil inventory in barrels	105,400	11,500

Derivative Financial Instrume38

Derivative Financial Instruments (Textuals) (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017USD ($)MMBTU$ / MMBTU$ / bblMBbls	Jun. 30, 2016USD ($)	Jun. 30, 2017USD ($)MMBTU$ / MMBTU$ / bblMBbls	Jun. 30, 2016USD ($)
Derivative [Line Items]
Schedule of Derivative Instruments [Table Text Block]			At June 30, 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 3,128 $ 45.43 $ — $ — $ — $ — $ (4 ) Fixed-price swaps with sold puts: 2,208 Fixed-price swaps 87.95 — — — — 91 Sold puts — — 73.08 — — (61 ) Purchased calls 2,208 — 73.08 — — — — Total $ 26 _________________ (1) For the fixed-price swaps with sold puts, if the market price remains below our sold puts at contract settlement, we will receive the market price plus the difference between our swaps and our sold puts. (2) As a result of our purchased calls, we have effectively locked in the spread between our fixed-price swaps and sold puts (less the deferred call premium). We deferred the premiums related to the purchased calls until contract settlement. At June 30, 2017 , the deferred premiums totaled $5 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 13,800 $ 2.73 $ — $ — $ (4 ) Collars 28,520 — 2.84 3.25 (2 ) 2018: Fixed-price swaps 10,950 3.01 — — — Collars 18,150 — 3.00 3.55 1 Total $ (5 )
Realized Gain Loss On Derivatives	$ 15	$ 64	$ 35	$ 146
Unrealized Gain (Loss) on Derivatives	13	(197)	46	(296)
Deferred Premium	5		5
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ 28	(133)	$ 81	(150)
ConcentrationOfCounterpartiesUnderCreditFacility	83.00%		83.00%
Total Derivative Counterparties	15		15
Primary Derivative Counterparties	10		10
Percent of future hedged production with primary counterparties	84.00%		84.00%
Percentage of contracted volumes held by the largest counterparty.	13.00%		13.00%
Natural gas contracts [Member]
Derivative [Line Items]
Realized Gain Loss On Derivatives	$ (4)	6	$ (10)	17
Unrealized Gain (Loss) on Derivatives	17	(48)	49	(64)
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	(5)		(5)
Oil contracts [Member]
Derivative [Line Items]
Realized Gain Loss On Derivatives	19	58	45	129
Unrealized Gain (Loss) on Derivatives	(4)	$ (149)	(3)	$ (232)
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 26		$ 26
Year 2017 [Member] | Natural gas contracts [Member] | Swap [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / MMBTU	2.73		2.73
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (4)		$ (4)
Volume In Mmbtus | MMBTU	13,800,000		13,800,000
Year 2017 [Member] | Natural gas contracts [Member] | Collars [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price | $ / MMBTU	2.84		2.84
Derivative, Weighted Average Ceiling Price | $ / MMBTU	3.25		3.25
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (2)		$ (2)
Volume In Mmbtus | MMBTU	28,520,000		28,520,000
Year 2017 [Member] | Oil contracts [Member] | Swap [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	3,128		3,128
Derivative, Swap Type, Average Fixed Price | $ / bbl	45.43		45.43
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (4)		$ (4)
Year 2017 [Member] | Oil contracts [Member] | Fixed Price Swaps With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	2,208		2,208
Year 2017 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price | $ / bbl	73.08		73.08
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ (61)		$ (61)
Year 2017 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Swap [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / bbl	87.95		87.95
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 91		$ 91
Year 2017 [Member] | Oil contracts [Member] | Call Option [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	2,208		2,208
Derivative, Weighted Average Ceiling Price | $ / bbl	73.08		73.08
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 0		$ 0
Year 2018 [Member] | Natural gas contracts [Member] | Swap [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / MMBTU	3.01		3.01
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$ 0		$ 0
Volume In Mmbtus | MMBTU	10,950,000		10,950,000
Year 2018 [Member] | Natural gas contracts [Member] | Collars [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price | $ / MMBTU	3		3
Derivative, Weighted Average Ceiling Price | $ / MMBTU	3.55		3.55
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 1		$ 1
Volume In Mmbtus | MMBTU	18,150,000		18,150,000

Derivative Financial Instrume39

Derivative Financial Instruments Derivative Financial Instruments Recorded in Balance Sheet(Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Derivative, Fair Value, Net [Abstract]
Derivative Liability Not Designated as Hedging Instrument Fair Value	$ (83)	$ (261)
Derivative Liability, Fair Value, Gross Asset	70	161
Derivative Asset, Fair Value, Gross Liability	(70)	(161)
Derivative Asset Not Designated As Hedging Instrument, Fair Value	104	236
Derivative Asset, Current	33	75
Derivative Asset, Noncurrent	1	0
Derivative Liability, Current	13	97
Derivative Liability, Noncurrent	0	3
Natural gas contracts [Member]
Derivative, Fair Value, Net [Abstract]
Derivative Liability Not Designated as Hedging Instrument Fair Value	(14)	(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	9	10
Derivative Asset, Current	0	0
Derivative Asset, Noncurrent	1	0
Derivative Liability, Current	6	51
Derivative Liability, Noncurrent	0	3
Oil contracts [Member]
Derivative, Fair Value, Net [Abstract]
Derivative Liability Not Designated as Hedging Instrument Fair Value	(69)	(197)
Derivative Liability, Fair Value, Gross Asset	62	151
Derivative Asset, Fair Value, Gross Liability	(62)	(151)
Derivative Asset Not Designated As Hedging Instrument, Fair Value	95	226
Derivative Asset, Current	33	75
Derivative Asset, Noncurrent	0	0
Derivative Liability, Current	7	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		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	$ 15	$ 64	$ 35	$ 146
Unrealized Gain (Loss) on Derivatives	13	(197)	46	(296)
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	28	(133)	81	(150)
Natural gas contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	(4)	6	(10)	17
Unrealized Gain (Loss) on Derivatives	17	(48)	49	(64)
Oil contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	19	58	45	129
Unrealized Gain (Loss) on Derivatives	$ (4)	$ (149)	$ (3)	$ (232)

Fair Value Measurement Classifi

Fair Value Measurement Classification [Details] - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Money market fund investments	$ 289	$ 320
Deferred Compensation Plan Assets	7	6
Equity securities available-for-sale	11	9
Stock-based compensation liability awards	12	11
Total (Assets)	316	299
Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts (asset)	83	50
Commodity Option [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contract (liability)	(62)	(75)
Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Money market fund investments	289	320
Deferred Compensation Plan Assets	7	6
Equity securities available-for-sale	11	9
Stock-based compensation liability awards	12	11
Total (Assets)	295	324
Fair Value, Inputs, Level 1 [Member] | Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts (asset)		0
Oil and gas derivative contract (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 (asset)	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
Equity securities available-for-sale	0	0
Stock-based compensation liability awards	0	0
Total (Assets)	83	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 (asset)	83	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 (asset)	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
Equity securities available-for-sale	0	0
Stock-based compensation liability awards	0	0
Total (Liabilities)	(62)	(75)
Fair Value, Inputs, Level 3 [Member] | Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts (asset)		0
Oil and gas derivative contract (liability)	0
Fair Value, Inputs, Level 3 [Member] | Commodity Option [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contract (liability)	$ (62)	$ (75)

Level 3 Fair Value Measurements

Level 3 Fair Value Measurements [Details] - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract]
Balance, Beginning of Period		$ (75)	$ (308)
Unrealized gains (losses) included in earnings		(17)	(4)
Settlements		30	131
Transfers into Level 3		0	0
Transfers out of Level 3(1)	$ 46	0	46
Balance, End of Period	$ (135)	(62)	(135)
Change in unrealized gains or losses related to Level 3 instruments		$ (10)	$ 43

Quantitative Information about

Quantitative Information about Unobservable Inputs for Level 3 Fair Value Measurements [Details] - Options Held [Member] $ in Millions	3 Months Ended
	Jun. 30, 2017USD ($)
Natural gas [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Derivative Liability	$ (1)
Natural gas [Member] | Minimum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Volatility	24.42%
Credit risk	0.01%
Natural gas [Member] | Maximum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Volatility	46.56%
Credit risk	1.39%
Oil [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Derivative Liability	$ (61)
Oil [Member] | Minimum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Volatility	24.27%
Credit risk	0.01%
Oil [Member] | Maximum [Member]
Fair Value Inputs, Liabilities, Quantitative Information [Line Items]
Volatility	99.30%
Credit risk	1.39%

Fair Value of Debt _Details_

Fair Value of Debt [Details] - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
5¾% Senior Notes due 2022
Senior Notes	$ 793	$ 789
5⅝% Senior Notes due 2024
Senior Notes	1,041	1,044
5⅜% Senior Notes due 2026
Senior Notes	$ 726	$ 714

Oil and Gas Properties _Details

Oil and Gas Properties [Details] $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017USD ($)$ / MMBTU$ / bbl	Jun. 30, 2016USD ($)	Jun. 30, 2017USD ($)$ / MMBTU$ / bbl	Jun. 30, 2016USD ($)	Dec. 31, 2016USD ($)
Costs withheld from amortization
Acquisition costs	$ 1,104		$ 1,104
Exploration costs	0		0
Capitalized interest	142		142
Total costs withheld from amortization	1,246		1,246		$ 1,238
Oil and Gas Properties (Textuals) [Abstract]
Capitalization of internal costs per full cost method of accounting	$ 31	$ 30	$ 64	$ 56
Unweighted average commodity price of oil based on first-day-of-the-month prices for the prior 12 months (per barrel) | $ / bbl	48.95		48.95
Unweighted average commodity price of natural gas based on first-day-of-the-month prices for the prior 12 months (per MMBtu) | $ / MMBTU	3.01		3.01
Proceeds from Sale of Oil and Gas Property and Equipment			$ 28	29
Payments to Acquire Oil and Gas Property and Equipment			6	$ 495
Oil and gas properties
Proved	$ 22,536		22,536		21,998
Unproved	1,246		1,246		1,238
Gross oil and gas properties	23,782		23,782		23,236
Accumulated depreciation, depletion and amortization	(9,794)		(9,794)		(9,587)
Accumulated impairment	(10,509)		(10,509)		(10,509)
Net oil and gas properties	3,479		3,479		$ 3,140
CHINA
Oil and Gas Properties (Textuals) [Abstract]
Proceeds from Sale of Oil and Gas Property and Equipment			32
Costs incurred in 2017 not subject to amortization [Member]
Costs withheld from amortization
Acquisition costs	77		77
Exploration costs	0		0
Capitalized interest	31		31
Total costs withheld from amortization	108		108
Oil and gas properties
Unproved	108		108
Costs incurred in 2016 not subject to amortization [Member]
Costs withheld from amortization
Acquisition costs	532		532
Exploration costs	0		0
Capitalized interest	51		51
Total costs withheld from amortization	583		583
Oil and gas properties
Unproved	583		583
Costs incurred in 2015 not subject to amortization [Member]
Costs withheld from amortization
Acquisition costs	339		339
Exploration costs	0		0
Capitalized interest	33		33
Total costs withheld from amortization	372		372
Oil and gas properties
Unproved	372		372
Costs incurred in 2014 & Prior [Member]
Costs withheld from amortization
Acquisition costs	156		156
Exploration costs	0		0
Capitalized interest	27		27
Total costs withheld from amortization	183		183
Oil and gas properties
Unproved	$ 183		$ 183

Other Property and Equipment 46

Other Property and Equipment Other Property and Equipment (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Accumulated depreciation and amortization	$ (107)	$ (98)
Net other property and equipment	166	167
Furniture and Fixtures [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Other, Gross	157	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		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Income Tax Disclosure [Abstract]
Effective income tax rate	8.80%	(1.40%)	6.30%	(0.60%)

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Accrued Liabilities [Line Items]
Accrued liabilities	$ 546	$ 498
Revenue payable
Accrued Liabilities [Line Items]
Accrued liabilities	220	196
Accrued capital costs
Accrued Liabilities [Line Items]
Accrued liabilities	149	92
Accrued lease operating expenses
Accrued Liabilities [Line Items]
Accrued liabilities	31	37
Employee incentive expense
Accrued Liabilities [Line Items]
Accrued liabilities	24	48
Accrued interest on debt
Accrued Liabilities [Line Items]
Accrued liabilities	67	67
Taxes payable
Accrued Liabilities [Line Items]
Accrued liabilities	15	15
Other
Accrued Liabilities [Line Items]
Accrued liabilities	$ 40	$ 43

Debt (Details)

Debt (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
Debt Instrument [Line Items]
Payments of Financing Costs		$ 3,000,000
Long-term debt	$ (2,432,000,000)		$ (2,432,000,000)		$ (2,431,000,000)
Debt issuance costs	(18,000,000)		(18,000,000)		(19,000,000)
Debt (Textuals)
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,800,000,000		$ 1,800,000,000
Largest individual loan commitment by any lender of total commitments	12.00%		12.00%
Commitment fees incurred	$ 1,000,000	$ 2,000,000	$ 3,000,000	$ 4,000,000
Ratio of Indebtedness to Net Capital 1	0.6		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		2.5
Line of Credit Facility, Current Borrowing Capacity	$ 125,000,000		$ 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		$ 0
5¾% Senior Notes due 2022
Debt Instrument [Line Items]
Long-term debt	$ (750,000,000)		$ (750,000,000)		$ (750,000,000)
Debt Instrument, Interest Rate, Stated Percentage	5.75%		5.75%		5.75%
5⅝% Senior Notes due 2024
Debt Instrument [Line Items]
Long-term debt	$ (1,000,000,000)		$ (1,000,000,000)		$ (1,000,000,000)
Debt Instrument, Interest Rate, Stated Percentage	5.625%		5.625%		5.625%
5⅜% Senior Notes due 2026
Debt Instrument [Line Items]
Long-term debt	$ (700,000,000)		$ (700,000,000)		$ (700,000,000)
Debt Instrument, Interest Rate, Stated Percentage	5.375%		5.375%		5.375%
Total senior unsecured debt
Debt Instrument [Line Items]
Long-term debt	$ (2,450,000,000)		$ (2,450,000,000)		$ (2,450,000,000)

Commitments and Contingencies50

Commitments and Contingencies (Details) - Firm Transportation [Member] $ in Millions	Jun. 30, 2017USD ($)
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

Stockholders' Equity Activity51

Stockholders' Equity Activity (Details) - USD ($) shares in Millions, $ in Millions	3 Months Ended	6 Months Ended
	Mar. 31, 2016	Jun. 30, 2017	Jun. 30, 2016
Equity [Abstract]
Stock Issued During Period, Shares, New Issues	34.5
Proceeds from Issuance of Common Stock	$ 776	$ 2	$ 777

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Income (numerator):
Net income (loss)	$ 98	$ (667)	$ 245	$ (1,291)
Weighted average shares (denominator):
Weighted-average shares — basic	199	198	199	188
Dilution effect of stock options and unvested restricted stock awards and restricted stock units outstanding at end of period	1	0	1	0
Weighted-average shares — diluted	200	198	200	188
Basic --
Basic	$ 0.49	$ (3.36)	$ 1.23	$ (6.87)
Diluted --
Diluted	$ 0.49	$ (3.36)	$ 1.22	$ (6.87)
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	2	1	2

Stock-Based Compensation (Detai

Stock-Based Compensation (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Gross	$ 13	$ 16	$ 31	$ 28
Capitalized in oil and gas properties	5	5	10	9
Net stock-based compensation expense	8	11	21	19
Nonvested Awards, Total Compensation Cost Not yet Recognized	59		59
Obligations, Fair Value Disclosure	$ (12)		$ (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	$ 28.46		$ 28.46
Equity [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Gross	$ 13	9	$ 29	18
Liability [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Gross	$ 0	$ 7	$ 2	$ 10
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Additional shares available for issuance	10.4		10.4
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Additional shares available for issuance	6.2		6.2
Fair Value, Inputs, Level 1 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Obligations, Fair Value Disclosure	$ (12)		$ (12)		$ (11)

Stock-Based Compensation- Restr

Stock-Based Compensation- Restricted Stock and Restricted Stock Units Activity (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance		2,433	2,433
Granted			664
Forfeited			(88)
Vested			(514)
Non-vested shares outstanding, Ending balance	2,495		2,495
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$ 59		$ 59
Service - Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance		1,574	1,574
Granted			341
Forfeited			(40)
Vested			(128)
Non-vested shares outstanding, Ending balance	1,747		1,747
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Beginning balance		$ 35.56	$ 35.56
Granted, Weighted Average Grant Date Fair Value per Share			38.40
Forfeited, Weighted Average Grant Date Fair Value per Share			22.79
Vested, Weighted Average Grant Date Fair Value per Share			34.19
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Ending balance	$ 36.28		$ 36.28
Cash-Settled Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance		460	460
Granted			241
Forfeited			(22)
Vested			(31)
Non-vested shares outstanding, Ending balance	648		648
MarketBasedShares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance		859	859
Granted		323	323
Forfeited			(48)
Vested			(386)
Non-vested shares outstanding, Ending balance	748		748
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Beginning balance		$ 26.28	$ 26.28
Granted, Weighted Average Grant Date Fair Value per Share			50.22
Forfeited, Weighted Average Grant Date Fair Value per Share			30.27
Vested, Weighted Average Grant Date Fair Value per Share			22.85
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Ending balance	$ 38.13		$ 38.13
Minimum [Member] | MarketBasedShares [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] | MarketBasedShares [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) - USD ($)	3 Months Ended	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2017
Employee Stock Purchase Plan ESPP Disclosures [Line Items]
Options To Purchase Common Stock Shares		0
Employee Stock Purchase Plan [Member]
Employee Stock Purchase Plan ESPP Disclosures [Line Items]
Options To Purchase Common Stock Shares		61,000
Weighted average fair value of each option		$ 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	6 Months Ended
	Jun. 30, 2017shares	Jun. 30, 2017shares
Share-based Compensation [Abstract]
Options Outstanding, Number of Shares Underlying Options	160,000	160,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Net of Forfeitures	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross		0

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 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) Six Months Ended June 30, 2017: Oil, gas and NGL revenues $ 744 $ 75 $ 819 Operating expenses: Lease operating 93 21 114 Transportation and processing 143 — 143 Production and other taxes 27 — 27 Depreciation, depletion and amortization 196 20 216 General and administrative 95 3 98 Other 1 — 1 Allocated income tax (benefit) 69 19 Net income (loss) from oil and gas properties $ 120 $ 12 Total operating expenses 599 Income (loss) from operations 220 Interest expense, net of interest income, capitalized interest and other (40 ) Commodity derivative income (expense) 81 Income (loss) from operations before income taxes $ 261 Total assets $ 4,504 $ 91 $ 4,595 Additions to long-lived assets $ 591 $ 1 $ 592 Domestic China Total (In millions) Three Months Ended June 30, 2017: Oil, gas and NGL revenues $ 361 $ 41 $ 402 Operating expenses: Lease operating 45 13 58 Transportation and processing 71 — 71 Production and other taxes 13 — 13 Depreciation, depletion and amortization 100 10 110 General and administrative 49 2 51 Allocated income tax (benefit) 30 10 Net income (loss) from oil and gas properties $ 53 $ 6 Total operating expenses 303 Income (loss) from operations 99 Interest expense, net of interest income, capitalized interest and other (20 ) Commodity derivative income (expense) 28 Income (loss) from operations before income taxes $ 107 Total assets $ 4,504 $ 91 $ 4,595 Additions to long-lived assets $ 334 $ 1 $ 335	Domestic China Total (In millions) Three Months Ended June 30, 2016: Oil, gas and NGL revenues $ 309 $ 72 $ 381 Operating expenses: Lease operating 46 16 62 Transportation and processing 66 — 66 Production and other taxes 11 — 11 Depreciation, depletion and amortization 126 34 160 General and administrative 56 2 58 Ceiling test and other impairments 501 21 522 Allocated income tax (benefit) (183 ) (1 ) Net income (loss) from oil and gas properties $ (314 ) $ — Total operating expenses 879 Income (loss) from operations (498 ) Interest expense, net of interest income, capitalized interest and other (27 ) Commodity derivative income (expense) (133 ) Income (loss) from operations before income taxes $ (658 ) Total assets $ 4,095 $ 190 $ 4,285 Additions to long-lived assets $ 699 $ — $ 699 Domestic China Total (In millions) Six Months Ended June 30, 2016: Oil, gas and NGL revenues $ 544 $ 121 $ 665 Operating expenses: Lease operating 93 30 123 Transportation and processing 129 — 129 Production and other taxes 21 — 21 Depreciation, depletion and amortization 259 78 337 General and administrative 99 3 102 Ceiling test and other impairments 962 66 1,028 Other 1 — 1 Allocated income tax (benefit) (377 ) (34 ) Net income (loss) from oil and gas properties $ (643 ) $ (22 ) Total operating expenses 1,741 Income (loss) from operations (1,076 ) Interest expense, net of interest income, capitalized interest and other (58 ) Commodity derivative income (expense) (150 ) Income (loss) from operations before income taxes $ (1,284 ) Total assets $ 4,095 $ 190 $ 4,285 Additions to long-lived assets $ 960 $ — $ 960
Oil, gas and NGL revenues	$ 402	$ 381	$ 819	$ 665
Operating expenses:
Lease operating	58	62	114	123
Transportation and processing	71	66	143	129
Production and other taxes	13	11	27	21
Depreciation, depletion and amortization	110	160	216	337
General and administrative	51	58	98	102
Ceiling test and other impairments	0	522	0	1,028
Other	0	0	1	1
Allocated income tax (benefit)	9	9	16	7
Total operating expenses	303	879	599	1,741
Income (loss) from operations	99	(498)	220	(1,076)
Interest expenses, net of interest income, capitalized interest and other	(20)	(27)	(40)	(58)
Commodity derivative income (expense)	28	(133)	81	(150)
Income (loss) before income taxes	107	(658)	261	(1,284)
Total assets	4,595	4,285	4,595	4,285	$ 4,312
Additions to long-lived assets	335	699	592	960
UNITED STATES
Segment Information [Line Items]
Oil, gas and NGL revenues	361	309	744	544
Operating expenses:
Lease operating	45	46	93	93
Transportation and processing	71	66	143	129
Production and other taxes	13	11	27	21
Depreciation, depletion and amortization	100	126	196	259
General and administrative	49	56	95	99
Ceiling test and other impairments		501		962
Other			1	1
Allocated income tax (benefit)	30	(183)	69	(377)
Net income (loss) from oil and gas properties	53	(314)	120	(643)
Total assets	4,504	4,095	4,504	4,095
Additions to long-lived assets	334	699	591	960
CHINA
Segment Information [Line Items]
Oil, gas and NGL revenues	41	72	75	121
Operating expenses:
Lease operating	13	16	21	30
Transportation and processing	0	0	0	0
Production and other taxes	0	0	0	0
Depreciation, depletion and amortization	10	34	20	78
General and administrative	2	2	3	3
Ceiling test and other impairments		21		66
Other			0	0
Allocated income tax (benefit)	10	(1)	19	(34)
Net income (loss) from oil and gas properties	6	0	12	(22)
Total assets	91	190	91	190
Additions to long-lived assets	$ 1	$ 0	$ 1	$ 0

Supplemental Cash Flows Infor58

Supplemental Cash Flows Information (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Supplemental Cash Flow Information [Abstract]
(Increase) decrease in receivables for property sales	$ 0	$ 6
(Increase) decrease in accrued capital expenditures	(57)	33
(Increase) decrease in asset retirement costs	$ 2	$ (8)