Newfield Exploration (NFX) 10-Q 4 Nov 15 2015 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	9 Months Ended
	Sep. 30, 2015	Oct. 30, 2015	Jun. 30, 2015
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	Sep. 30, 2015
Amendment Flag	false
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q3
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			$ 5,900,000,000
Entity Common Stock, Shares Outstanding		163,412,341

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 7	$ 14
Accounts receivable	263	439
Inventories	31	33
Derivative assets	334	431
Other current assets	28	23
Total current assets	663	940
Capitalized Costs, Oil and Gas Producing Activities, Net	4,418	8,232
Other property and equipment, net	168	182
Long-term investments	20	26
Deferred taxes	49	0
Other assets	47	28
Total assets	5,513	9,598
Derivative assets	148	190
Current liabilities:
Accounts payable	62	32
Accrued liabilities	480	880
Advances from joint owners	53	34
Asset retirement obligations	3	3
Derivative liabilities	8	8
Deferred taxes	112	144
Total current liabilities	718	1,101
Other liabilities	47	45
Derivative liabilities	6	0
Long-term debt	2,498	2,892
Asset retirement obligations	192	183
Deferred taxes	21	1,484
Total long-term liabilities	2,764	4,604
Commitments and contingencies	0	0
Stockholders' equity:
Preferred stock ($0.01 par value, 5,000,000 shares authorized; no shares issued)	0	0
Common stock ($0.01 par value)	2	1
Additional paid-in capital	2,424	1,576
Treasury stock (at cost)	(21)	(10)
Accumulated other comprehensive gain (loss)	(2)	(1)
Retained earnings	(372)	2,327
Total stockholders' equity	2,031	3,893
Total liabilities and stockholders' equity	$ 5,513	$ 9,598

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
ASSETS
Property and equipment, at cost, based on the full cost method of accounting for oil and gas properties	$ 985	$ 677
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	200,000,000
Common stock, shares issued	163,989,826	137,603,643
Treasury stock, shares	587,135	275,069
Commitments and Contingencies	$ 0	$ 0

Consolidated Statement of Opera

Consolidated Statement of Operations - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Operating expenses:
Depreciation, depletion and amortization			$ 721	$ 665
Ceiling test impairment			4,202	0
Other income (expenses):
Interest expense	$ (37)	$ (51)	(127)	(153)
Interest Costs Capitalized Adjustment	8	13	23	39
Commodity derivative income (expense)	87	303	230	33
Other	1	1	(13)	4
Total other income (expenses)	59	266	113	(77)
Income (loss) before income taxes	(1,892)	433	(4,218)	453
Income tax provision (benefit):
Current	7	1	25	3
Deferred Income Tax Expense (Benefit)	(672)	154	(1,544)	167
Total income tax provision (benefit)	(665)	155	(1,519)	170
Income (Loss) from Continuing Operations Attributable to Parent	(1,227)	278	(2,699)	283
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	0	0	0	257
Net income (loss)	$ (1,227)	$ 278	$ (2,699)	$ 540
Earnings Per Share [Abstract]
Income (Loss) from Continuing Operations, Per Basic Share	$ (7.52)	$ 2.04	$ (17.17)	$ 2.07
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share	0	0	0	1.89
Earnings (Loss) Per Share, Basic	(7.52)	2.04	(17.17)	3.96
Income (Loss) from Continuing Operations, Per Diluted Share	(7.52)	2.02	(17.17)	2.05
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share	0	0	0	1.87
Earnings (Loss) Per Share, Diluted	$ (7.52)	$ 2.02	$ (17.17)	$ 3.92
Weighted-average number of shares outstanding for basic earnings (loss) per share	163	137	157	137
Weighted average number of shares outstanding for diluted earnings (loss) per share	163	138	157	138
Continuing Operations [Member]
Oil, gas and NGL revenues	$ 377	$ 610	$ 1,195	$ 1,793
Operating expenses:
Lease operating	71	74	219	228
Gas Gathering, Transportation, Marketing and Processing Costs	52	51	153	125
Production and other taxes	13	32	43	90
Depreciation, depletion and amortization	236	228	721	633
General and administrative	66	48	180	172
Ceiling test impairment	1,889	0	4,202	0
Other	1	10	8	15
Total operating expenses	2,328	443	5,526	1,263
Income (loss) from operations	$ (1,951)	$ 167	$ (4,331)	$ 530

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Net Income (Loss) Attributable to Parent [Abstract]
Net income (loss)	$ (1,227)	$ 278	$ (2,699)	$ 540
Other comprehensive income (loss):
Unrealized gain (loss) on investments, net of tax	(1)	0	(1)	0
Other Comprehensive Income (Loss), Net of Tax	(1)	0	(1)	0
Comprehensive income (loss)	$ (1,228)	$ 278	$ (2,700)	$ 540

Consolidated Statement of Stock

Consolidated Statement of Stockholders' Equity - USD ($) $ in Millions	Total	Common Stock	Treasury Stock	Additional Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Income (Loss)
Common Stock, Shares, Issued	137,603,643
Common Stock, Value, Issued	$ 1
Treasury Stock, Shares	(275,069)
Treasury Stock, Value	$ (10)
Additional Paid in Capital	1,576
Retained Earnings (Accumulated Deficit)	2,327
Accumulated Other Comprehensive Income (Loss), Net of Tax	(1)
Issuances of common stock, shares		26,386,183
Issuances of common stock, value	817	$ 1		$ 816
Stock-based compensation	32			32
Treasury stock, net, shares			(312,066)
Treasury stock, net, value	(11)		$ (11)	$ 0
BOP Stockholders' Equity Balance at Dec. 31, 2014	3,893
Net income (loss)	(2,699)				$ (2,699)
Other Comprehensive Income (Loss), Net of Tax	(1)					$ (1)
EOP Stockholders' Equity Balance at Sep. 30, 2015	$ 2,031
Common Stock, Shares, Issued	163,989,826
Common Stock, Value, Issued	$ 2
Treasury Stock, Shares	(587,135)
Treasury Stock, Value	$ (21)
Additional Paid in Capital	2,424
Retained Earnings (Accumulated Deficit)	(372)
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ (2)

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Cash flows from operating activities:
Net income (loss)	$ (2,699)	$ 540
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	721	665
Deferred Income Tax Expense (Benefit), Continuing and Discontinuing Operations	(1,544)	308
Stock-based compensation	19	15
Unrealized Gain (Loss) on Derivatives	145	(139)
Ceiling test impairment	4,202	0
Gain on sale of malaysia	0	(388)
Other non-cash charges	38	1
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	80	89
(Increase) decrease in inventories	0	(1)
(Increase) decrease in other current assets	(5)	(2)
(Increase) decrease in other assets	(5)	1
Increase (decrease) in accounts payable and accrued liabilities	(82)	(20)
Increase (decrease) in advances from joint owners	19	(1)
Increase (decrease) in other liabilities	0	2
Net cash provided by operating activities	889	1,070
Cash flows from investing activities:
Additions to oil and gas properties	(1,294)	(1,535)
Acquisitions of oil and gas properties	(125)	(21)
Proceeds from sales of oil and gas properties	86	616
Proceeds from Divestiture of Businesses	0	809
Additions to furniture, fixtures and equipment	(9)	(22)
Redemptions of investments	0	39
Proceeds from Insurance Settlement, Investing Activities	57	0
Net cash used in investing activities	(1,285)	(114)
Cash flows from financing activities:
Proceeds from borrowings under credit arrangements	1,442	2,076
Repayments of borrowings under credit arrangements	(1,840)	(2,725)
Proceeds from issuance of senior notes	691	0
Debt issue costs	(8)	0
Repayment of senior subordinated notes	(700)	0
Proceeds from issuances of common stock	817	4
Purchases of treasury stock, net	(11)	(10)
Proceeds from (Payments for) Other Financing Activities	(2)	0
Net cash provided by (used in) financing activities	389	(655)
Increase (decrease) in cash and cash equivalents	(7)	301
Cash and cash equivalents, beginning of period	14	95
Cash and cash equivalents, end of period	$ 7	$ 396

Organization and Summary of Sig

Organization and Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2015
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). We focus on U.S. resource plays, and our primary areas of operation include the Mid-Continent, the Rocky Mountains and onshore Texas. We also have offshore oil developments in 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. 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, 2014 . 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. Use of Estimates The preparation of financial statements in accordance with accounting principles generally accepted in the United States of America 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 and the fair value of both our derivative positions and our stock-based compensation liability awards. Restructuring Costs Restructuring costs include severance and related benefit costs, costs associated with abandoned office space, employee relocation costs and other associated costs. Employee severance and related benefit costs are recognized on a straight-line basis over the required service period, if any. Employee relocation costs are expensed as incurred. On the date the leased property ceases to be used, a liability for noncancellable office-lease costs associated with restructuring is recognized and measured at fair value on our consolidated balance sheet. Fair value estimates include assumptions regarding estimated future sublease payments. These estimates could materially differ from actual results and may require revision to initial estimates of the liability. See Note 15, "Restructuring Costs," for additional disclosures. Reclassifications Certain reclassifications have been made to prior years' reported amounts in order to conform to the current year presentation. These reclassifications did not impact our net income (loss), stockholders' equity or cash flows. Restricted Cash We have restricted cash of $10 million included in "Other assets" on our consolidated balance sheet at September 30, 2015 that represents amounts held in escrow accounts to satisfy future plug and abandonment obligations for our China operations. These amounts are restricted as to their current use and will be released as we plug and abandon wells and facilities in our China field. Consistent with our other plug and abandonment activities, changes in restricted cash are included in cash flows from operating activities in our consolidated statement of cash flows. Discontinued Operations The results of our Malaysia operations are reflected separately as discontinued operations in the consolidated statement of operations on a line immediately after "Income (loss) from continuing operations." See Note 17 , "Discontinued Operations," for additional disclosures, as well as information regarding the sale of our Malaysia business, which closed in February 2014. New Accounting Requirements In April 2015, the Financial Accounting Standards Board (FASB) issued guidance regarding the presentation of debt issuance costs in the financial statements and requires that debt issuance costs be presented as a reduction of the carrying value of the financial liability and not as a separate asset. The guidance requires retrospective adjustment to the balance sheet presentation and disclosures applicable for a change in an accounting principle. The guidance is effective for interim and annual periods beginning after December 15, 2015. We expect to adopt this guidance in our 2015 annual report. In May 2014, the FASB issued guidance regarding the accounting for revenue from contracts with customers. The guidance may be applied retrospectively or using a modified retrospective approach to adjust retained earnings (deficit). In July 2015, the FASB approved a deferral of the effective date by one year. As a result, the guidance is effective for interim and annual periods beginning on or after December 15, 2017. We are currently evaluating the impact of this guidance on our financial statements.

Earnings Per Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2015
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 Nine Months Ended 2015 2014 2015 2014 (In millions, except per share data) Income (numerator): Income (loss) from continuing operations $ (1,227 ) $ 278 $ (2,699 ) $ 283 Income (loss) from discontinued operations — — — 257 Net income (loss) $ (1,227 ) $ 278 $ (2,699 ) $ 540 Weighted-average shares (denominator): Weighted-average shares — basic 163 137 157 137 Dilution effect of stock options and unvested restricted stock and restricted stock units outstanding at end of period (1)(2) — 1 — 1 Weighted-average shares — diluted 163 138 157 138 Earnings (loss) per share: Basic: Income (loss) from continuing operations $ (7.52 ) $ 2.04 $ (17.17 ) $ 2.07 Income (loss) from discontinued operations — — — 1.89 Basic earnings (loss) per share $ (7.52 ) $ 2.04 $ (17.17 ) $ 3.96 Diluted: Income (loss) from continuing operations $ (7.52 ) $ 2.02 $ (17.17 ) $ 2.05 Income (loss) from discontinued operations — — — 1.87 Diluted earnings (loss) per share $ (7.52 ) $ 2.02 $ (17.17 ) $ 3.92 _______ (1) The effect of 2.3 million and 2.8 million unvested restricted stock or restricted stock units and stock options for the three and nine months ended September 30, 2015 , respectively, have not been included in the calculation of shares outstanding for diluted EPS as their effect would have been anti-dilutive. (2) Excludes 0.3 million and 1.1 million shares of unvested restricted stock or restricted stock units and stock options for the three and nine months ended September 30, 2014 , respectively, because including the effect would have been anti-dilutive.

Inventories (Notes)

Inventories (Notes)	9 Months Ended
	Sep. 30, 2015
Inventory Disclosure [Abstract]
Inventory Disclosure [Text Block]	Inventories Inventories primarily consist of tubular goods and well equipment held for use in our oil and natural gas operations and oil produced but not sold in our China operations. At September 30, 2015 , the crude oil inventory from our China operations consisted of approximately 188,000 barrels of crude oil valued at cost of approximately $9 million . At December 31, 2014, the crude oil inventory from our China operations consisted of approximately 240,000 barrels of crude oil valued at cost of approximately $8 million and is included under the caption "Inventories" on our consolidated balance sheet. Cost for purposes of the carrying value of oil inventory is the sum of related production costs and depletion expense.

Oil and Gas Assets

Oil and Gas Assets	9 Months Ended
	Sep. 30, 2015
Oil and Gas Property [Abstract]
Oil and Gas Assets Text Block	. Oil and Gas Assets Property and Equipment Property and equipment consisted of the following: September 30, December 31, (In millions) Oil and gas properties: Proved $ 21,305 $ 20,402 Unproved 747 563 Gross oil and gas properties 22,052 20,965 Accumulated depreciation, depletion and amortization (8,855 ) (8,152 ) Accumulated impairment (8,779 ) (4,581 ) Net oil and gas properties $ 4,418 $ 8,232 Other property and equipment: Furniture, fixtures and equipment $ 143 $ 144 Gathering systems and equipment 116 114 Accumulated depreciation and amortization (91 ) (76 ) Net other property and equipment $ 168 $ 182 Oil and gas properties not subject to amortization as of September 30, 2015 , consisted of the following: Costs Incurred In 2015 2014 2013 2012 and Prior Total (In millions) Acquisition costs $ 272 $ 165 $ 158 $ 46 $ 641 Exploration costs 236 2 — — 238 Fee mineral interests — — 1 23 24 Capitalized interest 23 52 7 — 82 Total oil and gas properties not subject to amortization $ 531 $ 219 $ 166 $ 69 $ 985 We capitalized approximately $23 million and $38 million of interest and direct internal costs during the three months ended September 30, 2015 and 2014 , respectively, and $81 million and $158 million during the nine months ended September 30, 2015 and 2014 , respectively. During the second quarter of 2015, we finalized a settlement agreement with our insurance carriers related to an August 2013 LF-7 topside incident in China and recorded a $57 million receivable (the Company's share) and associated reduction to capital expenditures. The settlement proceeds were collected in July 2015. At September 30, 2015 , the ceiling value of our reserves was calculated based upon SEC pricing of $3.06 per MMBtu for natural gas and $59.09 per barrel for oil. Using these prices, our ceiling for the U.S. did not exceed the net capitalized costs of oil and gas properties resulting in a ceiling test writedown. Our domestic ceiling test writedown was approximately $1.8 billion ( $1.2 billion after tax) for the three months ended September 30, 2015 . For the nine months ended September 30, 2015, we recorded U.S. ceiling test writedowns of approximately $4.1 billion ( $2.6 billion after tax). Using SEC pricing, our ceiling for China at September 30, 2015 did not exceed the net capitalized costs of oil and gas properties, resulting in a ceiling test writedown for the three and nine months of approximately $72 million ( $29 million after tax). The continued decline of SEC pricing for oil and natural gas reserves since September 30, 2015 will likely result in additional U.S. and China ceiling test writedowns in the fourth quarter of 2015. Granite Wash Asset Sale In September 2014, we closed on the sale of our Granite Wash assets, located primarily in Texas, for approximately $588 million , subject to customary post-closing purchase price adjustments. The sale of our Granite Wash assets did not significantly alter the relationship between capitalized costs and proved reserves, and as such, all proceeds were recorded as adjustments to our domestic full cost pool with no gain or loss recognized. These consolidated financial statements include the results of our Granite Wash operations through the date of sale. Other Asset Acquisitions and Sales During the nine months ended September 30, 2015 and 2014, we acquired various other oil and gas properties for approximately $125 million and $21 million , respectively, and sold certain other oil and gas properties for proceeds of approximately $86 million and $56 million , respectively. The cash flows and results of operations for the assets sold were included in our consolidated financial statements up to the date of sale. Proceeds associated with our asset sales were recorded as adjustments to our domestic full cost pool.

Derivative Financial Instrument

Derivative Financial Instruments	9 Months Ended
	Sep. 30, 2015
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. In addition to the derivative strategies outlined in our Annual Report on Form 10-K for the year ended December 31, 2014, we purchased call options in 2015 that effectively lock in the value for a portion of our corresponding oil swaps with short puts as well as collars with short puts. We elected to defer the premiums related to these calls until contract settlement. At September 30, 2015 , the deferred premiums totaled $14 million . Excluding the effect of the deferred premium, if the settlement price is above the call strike price, the counterparty is required to make a payment to us. 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 credit default swaps and time to maturity. The calculation of the fair value of options requires the use of an option-pricing model. See Note 9 , “Fair Value Measurements.” At September 30, 2015 , 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) Sold Puts (1) Floors Ceilings (In millions) 2015: Fixed-price swaps 92 $ 90.00 $ — $ — $ — $ — $ 4 Fixed-price swaps with sold puts: 4,278 Fixed-price swaps 90.08 — — — — 189 Sold puts — — 71.12 — — (109 ) Collars with sold puts: 184 Collars — — — 90.00 104.00 8 Sold puts — — 75.00 — — (5 ) 2016: Fixed-price swaps with sold puts: 10,060 Fixed-price swaps 89.98 — — — — 408 Sold puts — — 74.14 — — (258 ) Collars with sold puts: 6,220 Collars — — — 90.00 96.15 252 Sold puts — — 75.00 — — (164 ) Purchased calls 4,954 — 71.60 — — — 6 2017: Fixed-price swaps with sold puts: 4,468 Fixed-price swaps 88.37 — — — — 155 Sold puts — — 73.28 — — (99 ) Collars with sold puts: 2,080 Collars — — — 90.00 95.59 78 Sold puts — — 75.00 — — (50 ) Purchased calls 1,997 — 73.73 — — — 3 Total $ 418 _________________ (1) If the market prices remain below our sold puts at contract settlement, we will receive the market price plus the following associated with our production: • the difference between our floors and our sold puts for collars with sold puts; or • the difference between our swaps and our sold puts for fixed-price swaps with sold puts. For the volumes with purchased calls, we have effectively locked in a portion of the spreads noted above (less the call premium). Natural Gas NYMEX Contract Price Per MMBtu Collars Estimated Fair Value Asset (Liability) Period and Type of Instrument Volume in MMMBtus Swaps (Weighted Average) Sold Puts (Weighted Average) Floors (Weighted Average) Ceilings (Weighted Average) (In millions) 2015: Fixed-price swaps 13,970 $ 4.14 $ — $ — $ — $ 21 Swaptions (1) — 3.50 — — — — Collars 9,660 — — 3.93 4.74 13 2016: Fixed-price swaps 4,550 3.39 — — — 3 Swaptions (1) — 3.50 — — — — Collars 10,980 — — 4.00 4.54 13 Total $ 50 ________ (1) During the second quarter of 2015, we sold natural gas swaption contracts that expired unexercised in October 2015. During the third quarter of 2015, we sold natural gas swaption contracts that, if exercised on their expiration date in December 2015, would protect 9,100 MMMBtus of January 2016 through June 2016 production with $3.50 per MMBtu fixed price swaps. 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) September 30, 2015 Oil positions $ 1,044 $ (612 ) $ 287 $ 145 $ (626 ) $ 612 $ (8 ) $ (6 ) Natural gas positions 50 — 47 3 — — — — Total $ 1,094 $ (612 ) $ 334 $ 148 $ (626 ) $ 612 $ (8 ) $ (6 ) December 31, 2014 Oil positions $ 1,115 $ (597 ) $ 332 $ 186 $ (605 ) $ 597 $ (8 ) $ — Natural gas positions 105 (2 ) 99 4 (2 ) 2 — — Total $ 1,220 $ (599 ) $ 431 $ 190 $ (607 ) $ 599 $ (8 ) $ — The amount of gain (loss) recognized in “Commodity derivative income (expense)” in our consolidated statement of operations related to our derivative financial instruments follows: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Derivatives not designated as hedging instruments: Realized gain (loss) on oil positions $ 100 $ (18 ) $ 287 $ (70 ) Realized gain (loss) on natural gas positions 31 (2 ) 88 (36 ) Total realized gain (loss) 131 (20 ) 375 (106 ) Unrealized gain (loss) on oil positions (30 ) 285 (92 ) 109 Unrealized gain (loss) on natural gas positions (14 ) 38 (53 ) 30 Total unrealized gain (loss) (44 ) 323 (145 ) 139 Total $ 87 $ 303 $ 230 $ 33 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 separate derivative instruments with that counterparty. At September 30, 2015 , ten of our 17 counterparties accounted for approximately 85% of our contracted volumes, with the largest counterparty accounting for approximately 15% . At September 30, 2015, approximately 72% 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.

Accounts Receivable

Accounts Receivable	9 Months Ended
	Sep. 30, 2015
Accounts Receivable, Net, Current [Abstract]
Accounts Receivable Text Block	Accounts Receivable Accounts receivable consisted of the following: September 30, December 31, (In millions) Revenue $ 102 $ 155 Joint interest 122 230 Other 55 70 Reserve for doubtful accounts (16 ) (16 ) Total accounts receivable, net $ 263 $ 439 Reserve for doubtful accounts includes an allowance of $15 million related to discontinued operations. See Note 17 , "Discontinued Operations."

Accrued Liabilities

Accrued Liabilities	9 Months Ended
	Sep. 30, 2015
Accrued Liabilities, Current [Abstract]
Accrued Liabilities Text Block	Accrued Liabilities Accrued liabilities consisted of the following: September 30, December 31, (In millions) Revenue payable $ 151 $ 197 Accrued capital costs 141 441 Accrued lease operating expenses 40 47 Employee incentive expense 31 62 Accrued interest on debt 32 67 Taxes payable 40 32 Other 45 34 Total accrued liabilities $ 480 $ 880

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2015
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 and certain investments. 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) and other financial investments. • Our valuation models for derivative contracts are primarily industry-standard models (i.e., Black-Scholes) that consider various inputs including: (a) forward prices for commodities, (b) time value, (c) volatility factors, (d) counterparty credit risk and (e) current market and contractual prices for the underlying instruments. • Our valuation model for the Stockholder Value Appreciation Program (SVAP) is a Monte Carlo simulation that is based on a probability model and considers various inputs including: (a) the measurement date stock price, (b) time value and (c) historical and implied volatility. See Note 12 , “Stock-Based Compensation,” for a description of the SVAP. 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. 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, 2014: Money market fund investments $ 1 $ — $ — $ 1 Deferred compensation plan assets 9 — — 9 Equity securities available-for-sale 10 — — 10 Oil and gas derivative swap contracts — 994 — 994 Oil and gas derivative option and swaption contracts — — (381 ) (381 ) Stock-based compensation liability awards (12 ) — (3 ) (15 ) Total $ 8 $ 994 $ (384 ) $ 618 As of September 30, 2015: Money market fund investments $ 2 $ — $ — $ 2 Deferred compensation plan assets 5 — — 5 Equity securities available-for-sale 15 — — 15 Oil and gas derivative swap contracts — 780 — 780 Oil and gas derivative option and swaption contracts — — (312 ) (312 ) Stock-based compensation liability awards (11 ) — — (11 ) Total $ 11 $ 780 $ (312 ) $ 479 The determination of the fair values of our derivative contracts above 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 and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests), if any. We utilize credit default swap values to assess the impact of non-performance risk when evaluating both our liabilities to, and receivables from, counterparties. Level 3 Fair Value Measurements The following table sets forth a reconciliation of changes in the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy for the indicated periods. Investments Derivatives Stock-Based Compensation Total (In millions) Balance at January 1, 2014 $ 39 $ (8 ) $ (5 ) $ 26 Realized or unrealized gains (losses) included in earnings — — (42 ) (42 ) Purchases, issuances, sales and settlements: Sales (39 ) — — (39 ) Settlements — 4 40 44 Transfers in to Level 3 — — — — Transfers out of Level 3 — 3 — 3 Balance at September 30, 2014 $ — $ (1 ) $ (7 ) $ (8 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at September 30, 2014 $ — $ 20 $ (3 ) $ 17 Balance at January 1, 2015 $ — $ (381 ) $ (3 ) $ (384 ) Realized or unrealized gains (losses) included in earnings — (116 ) 3 (113 ) Purchases, issuances, sales and settlements: Settlements — 185 — 185 Transfers in to Level 3 — — — — Transfers out of Level 3 — — — — Balance at September 30, 2015 $ — $ (312 ) $ — $ (312 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at September 30, 2015 $ — $ (88 ) $ 3 $ (85 ) Qualitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements Investments. During the first quarter of 2014, all auction rate securities that we held as of January 1, 2014, were sold for $39 million . Derivatives. Our valuation models for Level 3 derivative contracts are primarily industry-standard models that consider various factors, including certain significant unobservable inputs such as volatility factors and counterparty credit risk. 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, regional price differences 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. See Note 6 , "Derivative Financial Instruments," for additional discussion of our derivative instruments. The determination of the fair values of derivative instruments incorporates various factors that include not only the impact of our non-performance risk on our liabilities but also the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). 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. Stock-Based Compensation. The calculation of the fair value of the SVAP liability requires the use of a probability-based Monte Carlo simulation, which includes unobservable inputs. The simulation predicts multiple scenarios of future stock returns over the performance period, which are discounted to calculate the fair value. The fair value is recognized over a service period derived from the simulation. Future stock returns and discounting variables are sensitive to market volatility. Significant increases (decreases) in the volatility factors utilized in our option-pricing model can cause significant increases (decreases) in the fair value measurement of the SVAP liability. 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 $ (338 ) Black-Scholes Oil price volatility 23.88 % — 60.75 % Credit risk 0.01 % — 2.89 % Natural gas option and swaption contracts $ 26 Black-Scholes Natural gas price volatility 27.63 % — 56.05 % Credit risk 0.01 % — 2.19 % SVAP $ — (1) Monte Carlo Implied volatility 53.2 % _______ (1) Rounds to 0 . 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: September 30, December 31, (In millions) 5¾% Senior Notes due 2022 $ 734 $ 772 5⅝% Senior Notes due 2024 953 989 5⅜% Senior Notes due 2026 646 — 6⅞% Senior Subordinated Notes due 2020 — 721 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. Please see Note 10 , “Debt.”

Debt

Debt	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Debt Text Block	Debt Our debt consisted of the following: September 30, December 31, (In millions) Senior unsecured debt: Revolving credit facility — LIBOR based loans (matures in 2020) $ — $ 345 Money market lines of credit (1) 48 101 Total credit arrangements 48 446 5¾% Senior Notes due 2022 750 750 5⅝% Senior Notes due 2024 1,000 1,000 5⅜% Senior Notes due 2026 700 — Total senior unsecured debt 2,498 2,196 6⅞% Senior Subordinated Notes due 2020 — 700 Discount on notes — (4 ) Total long-term debt $ 2,498 $ 2,892 ________ (1) Because we have the ability and intent to use our available credit facility to repay borrowings under our money market lines of credit as of the indicated dates, amounts outstanding under these obligations, if any, are classified as long-term. Credit Arrangements In March 2015, we entered into the fourth amendment to our Credit Agreement. This amendment extended the maturity date of the revolving credit facility from June 2018 to June 2020 and increased the borrowing capacity from $1.4 billion to $1.8 billion . We incurred $7 million of deferred financing costs related to this amendment, which will be amortized through June 2020. As of September 30, 2015 , the largest individual loan commitment by any lender was 12% of total commitments. Loans under the credit facility bear interest, at our option, equal to (a) a rate per annum equal to the higher of the prime rate announced from time to time by JPMorgan Chase Bank, N.A. or the weighted average of the rates on overnight federal funds transactions with members of the Federal Reserve System during the last preceding business day plus 50 basis points, plus a margin that is based on a grid of our debt rating ( 75 basis points per annum at September 30, 2015 ) or (b) the London Interbank Offered Rate, plus a margin that is based on a grid of our debt rating ( 175 basis points per annum at September 30, 2015 ). Under our credit facility, we pay commitment fees on available but undrawn amounts based on a grid of our debt rating ( 30 basis points per annum at September 30, 2015 ). We incurred aggregate commitment fees under our current credit facility of approximately $2 million and $4 million for the three and nine-month periods ended September 30, 2015 , respectively, which are recorded in “Interest expense” on our consolidated statement of operations. For the three- and nine-month periods ended September 30, 2014 , we incurred commitment fees under our credit facility of approximately $1 million and $3 million , respectively. 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 maintenance of a ratio of earnings before gain or loss on the disposition of assets, interest expense, income taxes and noncash items (such as depreciation, depletion and amortization expense, unrealized gains and losses on commodity derivatives, ceiling test writedowns and goodwill impairments) to interest expense of at least 3.0 to 1.0. At September 30, 2015 , we were in compliance with all of our debt covenants. As of September 30, 2015 , 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 ( 175 basis points at September 30, 2015 ). Subject to compliance with the restrictive covenants in our credit facility, at September 30, 2015 , we also had a total of $147 million of available borrowing capacity under our money market lines of credit with various financial institutions, the availability of which is at the discretion of the financial institutions. 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; 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. Senior Notes and Senior Subordinated Notes In March 2015, we issued $700 million of 5⅜% Senior Notes due 2026 and received net proceeds of $691 million (net of offering costs of approximately $9 million ). These notes were issued at par to yield 5⅜%. In April 2015 we used the net proceeds to redeem our $700 million aggregate principal amount of 6 ⅞% Senior Subordinated Notes due 2020. In connection with the redemption, we paid a premium of $24 million . The premium was recorded under the caption "Other income (expense) — Other, net" on our consolidated statement of income. In addition, associated unamortized offering costs and discounts of approximately $8 million were charged to interest expense during the second quarter of 2015 as a result of the redemption.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2015
Income Tax Disclosure [Abstract]
Income Taxes Text Block	Income Taxes The following table presents a reconciliation of the United States statutory income tax rate to our effective income tax rate. Three Months Ended Nine Months Ended 2015 2014 2015 2014 U.S. statutory income tax rate 35.0 % 35.0 % 35.0 % 35.0 % State and local income taxes, net of federal effect (0.6 ) 1.1 0.9 2.0 Foreign tax on foreign earnings 1.1 (0.1 ) 0.2 0.5 Other (0.3 ) (0.4 ) (0.1 ) — Effective income tax rate 35.2 % 35.6 % 36.0 % 37.5 % Unrealized derivative gains and losses are treated differently for income tax purposes in the various state taxing jurisdictions to which we are subject. As a result, our effective tax rate fluctuates in periods with significant commodity price volatility. These effective tax rate fluctuations are magnified when income before taxes approaches zero. As of September 30, 2015 , we did not have a liability for uncertain tax positions, and as such, we had not accrued related interest or penalties. The tax years 2011 through 2014 remain open to examination for federal income tax purposes and by the other major taxing jurisdictions to which we are subject.

Stock-Based Compensation

Stock-Based Compensation	9 Months Ended
	Sep. 30, 2015
Share-based Compensation [Abstract]
Stock-Based Compensation Text Block	Stock-Based Compensation Our stock-based compensation consisted of the following: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Equity awards $ 9 $ 15 $ 31 $ 37 Liability awards: Cash-settled restricted stock units 3 5 15 21 Stockholder Value Appreciation Program (3 ) (12 ) (3 ) 42 Total liability awards — (7 ) 12 63 Total stock-based compensation 9 8 43 100 Capitalized in oil and gas properties (2 ) 2 (11 ) (38 ) Net stock-based compensation expense $ 7 $ 10 $ 32 $ 62 As of September 30, 2015 , we had approximately $63 million of total unrecognized stock-based compensation expense related to unvested stock-based compensation awards that vest within four years . Equity Awards Equity awards consist of service-based and performance- or market-based restricted stock units, stock options and stock purchase options under the Employee Stock Purchase Plan (ESPP). Stock-based compensation classified as equity awards are currently granted under the 2011 Omnibus Stock Plan, as amended (2011 Plan), to employees and non-employee directors. The fair value of grants is determined utilizing the Black-Scholes option-pricing model for stock options and a Monte Carlo lattice-based model for our performance- and market-based restricted stock and restricted stock units. Compensation expense for equity awards is expected to be recognized on a straight-line basis over the applicable remaining vesting periods. Shares available for grant under our 2011 Plan are reduced by 1.87 times the number of shares of restricted stock or restricted stock units awarded under the plan and are reduced by 1 times the number of shares subject to stock options awarded under the plan. In May 2015, our stockholders approved an additional 7.0 million shares available for issuance under our 2011 Plan. As a result, at September 30, 2015, we had approximately (1) 7.2 million shares available for issuance under our 2011 Plan if all future awards are stock options, or (2) 3.9 million shares available for issuance under our 2011 Plan if all future awards are restricted stock or restricted stock units. Thus far, all awards under our 2011 Plan have been granted as restricted stock or restricted stock unit awards. Restricted Stock. The following table provides information about restricted stock and restricted stock unit activity. Service-Based Shares Performance/ Market-Based Shares Total Shares Weighted- Average Grant Date Fair Value per Share (In thousands, except per share data) Non-vested shares outstanding at January 1, 2015 1,902 945 2,847 $ 30.05 Granted 1,008 414 1,422 28.63 Forfeited (328 ) (97 ) (425 ) 24.51 Vested (815 ) (183 ) (998 ) 33.32 Non-vested shares outstanding at September 30, 2015 1,767 1,079 2,846 $ 27.93 On September 30, 2015 , the last reported sales price of our common stock on the New York Stock Exchange was $32.90 per share. Employee Stock Purchase Plan. During the first six months of 2015 , options to purchase approximately 85,000 shares of our common stock were issued under our ESPP. The fair value of each option was $7.93 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 0.12% , an expected life of six months and weighted-average volatility of 52% . On July 1, 2015, options to purchase approximately 49,000 shares of our common stock were granted under our employee stock purchase plan. The fair value of each option was $9.99 per share as determined using the Black-Scholes option valuation method assuming no dividends, a risk-free interest rate of 0.11% , an expected life of six months and weighted-average volatility of 46% . Stock Options. As of September 30, 2015 , we had approximately 200,000 stock options outstanding and exercisable. No stock options have been granted since 2008, except for ESPP options as discussed above. Liability Awards Liability awards consist of performance awards that are settled in cash instead of shares, as discussed below. Cash-Settled Restricted Stock Units. We periodically grant cash-settled restricted stock units to employees that vest over three years . As of September 30, 2015 , we accrued $11 million for future cash settlement upon vesting of awards. The value of the awards, and the associated stock-based compensation expense, is based on the Company’s stock price at the end of each period. As of September 30, 2015 , we had unrecognized stock-based compensation expense related to cash-settled restricted stock units of approximately $10 million . 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, 2015 1,216 Granted 211 Forfeited (218 ) Vested (462 ) Non-vested units outstanding at September 30, 2015 747 Stockholder Value Appreciation Program. In September 2013, the Compensation and Management Development Committee of the Board approved the SVAP to be administered under the 2011 Plan. The SVAP pays substantially all full-time domestic, nonexecutive employees a cash payment based on a percentage of salary upon each incremental $ 5 increase in our 30-calendar day average share price. Each price threshold can be reached only once during the term of the program. The SVAP's performance period lasts through December 31, 2015. Each price trigger, if any, that is reached during the fourth quarter of 2015 would result in an approximately $11 million payment. The first price threshold that triggered a payment under the SVAP was $27.50 during the fourth quarter of 2013. The second and third price thresholds for the SVAP were $32.50 and $37.50 , respectively, which were reached during the second quarter of 2014. The fourth price threshold for the SVAP of $42.50 was reached in July 2014. Each of the first four SVAP payments was approximately $13 million . Based on the valuation of the SVAP as of September 30, 2015 , $0.2 million has been accrued. The total expected cost was determined using a Monte Carlo simulation assuming no dividends, a risk-free weighted-average interest rate of 0.03% , a remaining plan term of three months and an average of implied and historical stock price volatility of 47% . Future changes in our stock price could cause the total cost of the program to be different than our estimates as of September 30, 2015 . In the event we do not achieve the next price threshold of $47.50 before December 31, 2015, the remaining accrued expense will be reversed.

Voluntary Severance Program

Voluntary Severance Program	9 Months Ended
	Sep. 30, 2015
Restructuring and Related Activities [Abstract]
Restructuring and Related Activities Disclosure [Text Block]	15 . Restructuring Costs In April 2015, we announced plans to combine our onshore Gulf Coast and Rocky Mountain business units into our newly-created Western Region which is managed from The Woodlands, Texas. Our decision to restructure our organization, which only affects our domestic business, was primarily in response to the current oil and gas commodity price environment. These changes are expected to result in better utilization of our resources and improve cost efficiencies in operations. We expect substantially all one-time restructuring-related costs to be incurred by December 31, 2015 and do not expect these costs to materially affect our cash flows or results of operations. We abandoned our Denver, Colorado office space during the third quarter of 2015 and recorded a loss for the remaining contracted payments net of expected sublease income. We will close our North Houston (Greenspoint area) office on or before April 2016, consistent with the terms of our lease. Restructuring costs recorded in our consolidated statement of operations are set forth below. Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Type of Restructuring Cost Location in the Consolidated Statement of Operations Severance and related benefit costs Operating expenses - General and administrative $ 3 $ — $ 6 $ — Relocation costs Operating expenses - General and administrative 2 — 3 — Office-lease abandonment costs Operating expenses - General and administrative 13 — 13 — Other associated costs Operating expenses - Depreciation, depletion and amortization — — 1 — Total $ 18 $ — $ 23 $ — The following table summarizes our restructuring costs and related accruals. Severance and Related Benefit Costs Office-lease Abandonment Costs Relocation Costs Other Associated Costs Total (In millions) Restructuring liability at January 1, 2015 $ — $ — $ — $ — $ — Additions 6 13 3 1 23 Settlements (4 ) — (3 ) (1 ) (8 ) Revisions — — — — — Restructuring liability at September 30, 2015 $ 2 $ 13 $ — $ — $ 15 Cumulative costs as of September 30, 2015 $ 6 $ 13 $ 3 $ 1 $ 23 Expected total costs $ 7 $ 19 $ 5 $ 1 $ 32

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies Text Block	Commitments and Contingencies On May 22, 2015, a lawsuit was filed against the Company alleging certain plugging and abandonment predecessor-in-interest liabilities related to offshore assets sold by the Company in 2010. The lawsuit alleges damages of approximately $23 million . The Company has responded to the petition, denied the allegations and is vigorously defending the case. The action is in the early stages and no discovery has been conducted. Therefore, an estimate of reasonably possible losses, if any, cannot be made at this time. 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.

Supplemental Cash Flows Informa

Supplemental Cash Flows Information	9 Months Ended
	Sep. 30, 2015
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. Nine Months Ended September 30, 2015 2014 (In millions) Non-cash investing and financing activities excluded from the statement of cash flows: (Increase) decrease in receivables for property sales $ 8 $ (17 ) (Increase) decrease in accrued capital expenditures 212 2 (Increase) decrease in asset retirement costs (4 ) 18

Segment Information

Segment Information	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Segment Reporting [Abstract]
Schedule of Revenue from External Customers and Long-Lived Assets, by Geographical Areas [Table Text Block]	Domestic China Total (In millions) Three Months Ended September 30, 2015: Oil, gas and NGL revenues $ 316 $ 61 $ 377 Operating expenses: Lease operating 57 14 71 Transportation and processing 52 — 52 Production and other taxes 13 — 13 Depreciation, depletion and amortization 184 52 236 General and administrative 64 2 66 Ceiling test and other impairments 1,817 72 1,889 Other 1 — 1 Allocated income tax (benefit) (693 ) (47 ) Net income (loss) from oil and gas properties $ (1,179 ) $ (32 ) Total operating expenses 2,328 Income (loss) from continuing operations (1,951 ) Interest expense, net of interest income, capitalized interest and other (28 ) Commodity derivative income (expense) 87 Income (loss) from continuing operations before income taxes $ (1,892 ) Total assets $ 5,114 $ 399 $ 5,513 Additions to long-lived assets $ 474 $ (12 ) $ 462 Domestic China Total (In millions) Nine Months Ended September 30, 2015: Oil, gas and NGL revenues $ 989 $ 206 $ 1,195 Operating expenses: Lease operating 178 41 219 Transportation and processing 153 — 153 Production and other taxes 43 — 43 Depreciation, depletion and amortization 603 118 721 General and administrative 174 6 180 Ceiling test and other impairments 4,130 72 4,202 Other 7 1 8 Allocated income tax (benefit) (1,591 ) (19 ) Net income (loss) from oil and gas properties $ (2,708 ) $ (13 ) Total operating expenses 5,526 Income (loss) from continuing operations (4,331 ) Interest expense, net of interest income, capitalized interest and other (117 ) Commodity derivative income (expense) 230 Income (loss) from continuing operations before income taxes $ (4,218 ) Total assets $ 5,114 $ 399 $ 5,513 Additions to long-lived assets $ 1,210 $ 15 $ 1,225	Domestic China Total (In millions) Three Months Ended September 30, 2014: Oil, gas and NGL revenues $ 610 $ — $ 610 Operating expenses: Lease operating 73 1 74 Transportation and processing 51 — 51 Production and other taxes 31 1 32 Depreciation, depletion and amortization 228 — 228 General and administrative 48 — 48 Other 10 — 10 Allocated income tax (benefit) 63 (1 ) Net income (loss) from oil and gas properties $ 106 $ (1 ) Total operating expenses 443 Income (loss) from continuing operations 167 Interest expense, net of interest income, capitalized interest and other (37 ) Commodity derivative income (expense) 303 Income (loss) from continuing operations before income taxes $ 433 Total assets $ 8,392 $ 676 $ 9,068 Additions to long-lived assets $ 485 $ 38 $ 523 Domestic China Total (In millions) Nine Months Ended September 30, 2014: Oil, gas and NGL revenues $ 1,771 $ 22 $ 1,793 Operating expenses: Lease operating 224 4 228 Transportation and processing 125 — 125 Production and other taxes 85 5 90 Depreciation, depletion and amortization 628 5 633 General and administrative 172 — 172 Other 15 — 15 Allocated income tax (benefit) 193 5 Net income (loss) from oil and gas properties $ 329 $ 3 Total operating expenses 1,263 Income (loss) from continuing operations 530 Interest expense, net of interest income, capitalized interest and other (110 ) Commodity derivative income (expense) 33 Income (loss) from continuing operations before income taxes $ 453 Total assets $ 8,392 $ 676 $ 9,068 Additions to long-lived assets $ 1,473 $ 104 $ 1,577
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 each 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, 2014. The following tables provide the geographic operating segment information for our continuing operations for the three- and nine- month periods ended September 30, 2015 and 2014 . Income tax allocations have been determined based on statutory rates in the applicable geographic segment. Our earnings and profits in China are taxed at the combined statutory rates for China and the U.S. for our income tax allocation of our China operations in the following tables. Domestic China Total (In millions) Three Months Ended September 30, 2015: Oil, gas and NGL revenues $ 316 $ 61 $ 377 Operating expenses: Lease operating 57 14 71 Transportation and processing 52 — 52 Production and other taxes 13 — 13 Depreciation, depletion and amortization 184 52 236 General and administrative 64 2 66 Ceiling test and other impairments 1,817 72 1,889 Other 1 — 1 Allocated income tax (benefit) (693 ) (47 ) Net income (loss) from oil and gas properties $ (1,179 ) $ (32 ) Total operating expenses 2,328 Income (loss) from continuing operations (1,951 ) Interest expense, net of interest income, capitalized interest and other (28 ) Commodity derivative income (expense) 87 Income (loss) from continuing operations before income taxes $ (1,892 ) Total assets $ 5,114 $ 399 $ 5,513 Additions to long-lived assets $ 474 $ (12 ) $ 462 Domestic China Total (In millions) Three Months Ended September 30, 2014: Oil, gas and NGL revenues $ 610 $ — $ 610 Operating expenses: Lease operating 73 1 74 Transportation and processing 51 — 51 Production and other taxes 31 1 32 Depreciation, depletion and amortization 228 — 228 General and administrative 48 — 48 Other 10 — 10 Allocated income tax (benefit) 63 (1 ) Net income (loss) from oil and gas properties $ 106 $ (1 ) Total operating expenses 443 Income (loss) from continuing operations 167 Interest expense, net of interest income, capitalized interest and other (37 ) Commodity derivative income (expense) 303 Income (loss) from continuing operations before income taxes $ 433 Total assets $ 8,392 $ 676 $ 9,068 Additions to long-lived assets $ 485 $ 38 $ 523 Domestic China Total (In millions) Nine Months Ended September 30, 2015: Oil, gas and NGL revenues $ 989 $ 206 $ 1,195 Operating expenses: Lease operating 178 41 219 Transportation and processing 153 — 153 Production and other taxes 43 — 43 Depreciation, depletion and amortization 603 118 721 General and administrative 174 6 180 Ceiling test and other impairments 4,130 72 4,202 Other 7 1 8 Allocated income tax (benefit) (1,591 ) (19 ) Net income (loss) from oil and gas properties $ (2,708 ) $ (13 ) Total operating expenses 5,526 Income (loss) from continuing operations (4,331 ) Interest expense, net of interest income, capitalized interest and other (117 ) Commodity derivative income (expense) 230 Income (loss) from continuing operations before income taxes $ (4,218 ) Total assets $ 5,114 $ 399 $ 5,513 Additions to long-lived assets $ 1,210 $ 15 $ 1,225 Domestic China Total (In millions) Nine Months Ended September 30, 2014: Oil, gas and NGL revenues $ 1,771 $ 22 $ 1,793 Operating expenses: Lease operating 224 4 228 Transportation and processing 125 — 125 Production and other taxes 85 5 90 Depreciation, depletion and amortization 628 5 633 General and administrative 172 — 172 Other 15 — 15 Allocated income tax (benefit) 193 5 Net income (loss) from oil and gas properties $ 329 $ 3 Total operating expenses 1,263 Income (loss) from continuing operations 530 Interest expense, net of interest income, capitalized interest and other (110 ) Commodity derivative income (expense) 33 Income (loss) from continuing operations before income taxes $ 453 Total assets $ 8,392 $ 676 $ 9,068 Additions to long-lived assets $ 1,473 $ 104 $ 1,577

Stockholders' Equity Activity (

Stockholders' Equity Activity (Notes)	9 Months Ended
	Sep. 30, 2015
Equity [Abstract]
CommonStock [Text Block]	3. Stockholders' Equity Activity During the first quarter of 2015, we issued 25.3 million additional shares of common stock through a public equity offering. We received net proceeds of approximately $815 million , which were used primarily to repay all borrowings under our credit facility and money market lines of credit. In May 2015, our stockholders approved an amendment to the Company's Certificate of Incorporation that increases the total authorized shares of common stock from 200 million to 300 million shares.

Discontinued Operations

Discontinued Operations	9 Months Ended
	Sep. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	Discontinued Operations In 2013, we met the criteria to classify our Malaysia business as held for sale and discontinued operations. In February 2014, we closed the sale of our Malaysia business to SapuraKencana Petroleum Berhad (SapuraKencana), a Malaysian public company, for $898 million . As a result of the sale, we recorded a gain in the first quarter of 2014 of approximately $388 million ( $252 million , after tax). In the fourth quarter of 2014, we recorded an allowance against a receivable from SapuraKencana and reduced the previously recognized gain by $15 million ( $10 million , after tax) due to uncertainty associated with collectability. In April 2015, we initiated a notice of dispute related to the final post-close settlement, which was countered by SapuraKencana. We believe the dispute may result in arbitration proceedings. There are no other assets and liabilities in the consolidated balance sheet attributable to discontinued operations as of September 30, 2015 or December 31, 2014. Results of Discontinued Operations Nine Months Ended September 30, 2014 (In millions) Oil and gas revenues $ 90 Operating expenses 69 Income (loss) from discontinued operations 21 Gain on sale of Malaysia business 388 Income from discontinued operations before income taxes 409 Income tax provision (benefit): Current 12 Deferred 140 Total income tax provision (benefit) 152 Income (loss) from discontinued operations, net of tax $ 257

Restructuring Costs Restructuri

Restructuring Costs Restructuring Costs	9 Months Ended
	Sep. 30, 2015
Restructuring and Related Activities [Abstract]
Restructuring and Related Activities Disclosure [Text Block]	15 . Restructuring Costs In April 2015, we announced plans to combine our onshore Gulf Coast and Rocky Mountain business units into our newly-created Western Region which is managed from The Woodlands, Texas. Our decision to restructure our organization, which only affects our domestic business, was primarily in response to the current oil and gas commodity price environment. These changes are expected to result in better utilization of our resources and improve cost efficiencies in operations. We expect substantially all one-time restructuring-related costs to be incurred by December 31, 2015 and do not expect these costs to materially affect our cash flows or results of operations. We abandoned our Denver, Colorado office space during the third quarter of 2015 and recorded a loss for the remaining contracted payments net of expected sublease income. We will close our North Houston (Greenspoint area) office on or before April 2016, consistent with the terms of our lease. Restructuring costs recorded in our consolidated statement of operations are set forth below. Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Type of Restructuring Cost Location in the Consolidated Statement of Operations Severance and related benefit costs Operating expenses - General and administrative $ 3 $ — $ 6 $ — Relocation costs Operating expenses - General and administrative 2 — 3 — Office-lease abandonment costs Operating expenses - General and administrative 13 — 13 — Other associated costs Operating expenses - Depreciation, depletion and amortization — — 1 — Total $ 18 $ — $ 23 $ — The following table summarizes our restructuring costs and related accruals. Severance and Related Benefit Costs Office-lease Abandonment Costs Relocation Costs Other Associated Costs Total (In millions) Restructuring liability at January 1, 2015 $ — $ — $ — $ — $ — Additions 6 13 3 1 23 Settlements (4 ) — (3 ) (1 ) (8 ) Revisions — — — — — Restructuring liability at September 30, 2015 $ 2 $ 13 $ — $ — $ 15 Cumulative costs as of September 30, 2015 $ 6 $ 13 $ 3 $ 1 $ 23 Expected total costs $ 7 $ 19 $ 5 $ 1 $ 32

Organization and Summary of S26

Organization and Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2015
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). We focus on U.S. resource plays, and our primary areas of operation include the Mid-Continent, the Rocky Mountains and onshore Texas. We also have offshore oil developments in 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. 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, 2014 .
Discontinued Operations, Policy [Policy Text Block]	Discontinued Operations The results of our Malaysia operations are reflected separately as discontinued operations in the consolidated statement of operations on a line immediately after "Income (loss) from continuing operations." See Note 17 , "Discontinued Operations," for additional disclosures, as well as information regarding the sale of our Malaysia business, which closed in February 2014.
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.
Use of Estimates	Use of Estimates The preparation of financial statements in accordance with accounting principles generally accepted in the United States of America 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 and the fair value of both our derivative positions and our stock-based compensation liability awards.
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.
Cash and Cash Equivalents, Restricted Cash and Cash Equivalents, Policy [Policy Text Block]	Restricted Cash We have restricted cash of $10 million included in "Other assets" on our consolidated balance sheet at September 30, 2015 that represents amounts held in escrow accounts to satisfy future plug and abandonment obligations for our China operations. These amounts are restricted as to their current use and will be released as we plug and abandon wells and facilities in our China field. Consistent with our other plug and abandonment activities, changes in restricted cash are included in cash flows from operating activities in our consolidated statement of cash flows.
New Accounting Requirements	New Accounting Requirements In April 2015, the Financial Accounting Standards Board (FASB) issued guidance regarding the presentation of debt issuance costs in the financial statements and requires that debt issuance costs be presented as a reduction of the carrying value of the financial liability and not as a separate asset. The guidance requires retrospective adjustment to the balance sheet presentation and disclosures applicable for a change in an accounting principle. The guidance is effective for interim and annual periods beginning after December 15, 2015. We expect to adopt this guidance in our 2015 annual report. In May 2014, the FASB issued guidance regarding the accounting for revenue from contracts with customers. The guidance may be applied retrospectively or using a modified retrospective approach to adjust retained earnings (deficit). In July 2015, the FASB approved a deferral of the effective date by one year. As a result, the guidance is effective for interim and annual periods beginning on or after December 15, 2017. We are currently evaluating the impact of this guidance on our financial statements.
Restructuring Policy	Restructuring Costs Restructuring costs include severance and related benefit costs, costs associated with abandoned office space, employee relocation costs and other associated costs. Employee severance and related benefit costs are recognized on a straight-line basis over the required service period, if any. Employee relocation costs are expensed as incurred. On the date the leased property ceases to be used, a liability for noncancellable office-lease costs associated with restructuring is recognized and measured at fair value on our consolidated balance sheet. Fair value estimates include assumptions regarding estimated future sublease payments. These estimates could materially differ from actual results and may require revision to initial estimates of the liability. See Note 15, "Restructuring Costs," for additional disclosures.

Earnings Per Share (Tables)

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2015
Earnings Per Share [Abstract]
Earnings Per Share Table	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 Nine Months Ended 2015 2014 2015 2014 (In millions, except per share data) Income (numerator): Income (loss) from continuing operations $ (1,227 ) $ 278 $ (2,699 ) $ 283 Income (loss) from discontinued operations — — — 257 Net income (loss) $ (1,227 ) $ 278 $ (2,699 ) $ 540 Weighted-average shares (denominator): Weighted-average shares — basic 163 137 157 137 Dilution effect of stock options and unvested restricted stock and restricted stock units outstanding at end of period (1)(2) — 1 — 1 Weighted-average shares — diluted 163 138 157 138 Earnings (loss) per share: Basic: Income (loss) from continuing operations $ (7.52 ) $ 2.04 $ (17.17 ) $ 2.07 Income (loss) from discontinued operations — — — 1.89 Basic earnings (loss) per share $ (7.52 ) $ 2.04 $ (17.17 ) $ 3.96 Diluted: Income (loss) from continuing operations $ (7.52 ) $ 2.02 $ (17.17 ) $ 2.05 Income (loss) from discontinued operations — — — 1.87 Diluted earnings (loss) per share $ (7.52 ) $ 2.02 $ (17.17 ) $ 3.92 _______ (1) The effect of 2.3 million and 2.8 million unvested restricted stock or restricted stock units and stock options for the three and nine months ended September 30, 2015 , respectively, have not been included in the calculation of shares outstanding for diluted EPS as their effect would have been anti-dilutive. (2) Excludes 0.3 million and 1.1 million shares of unvested restricted stock or restricted stock units and stock options for the three and nine months ended September 30, 2014 , respectively, because including the effect would have been anti-dilutive.

Oil and Gas Assets (Tables)

Oil and Gas Assets (Tables)	9 Months Ended
	Sep. 30, 2015
Oil and Gas Property [Abstract]
Costs incurred by year for oil and gas properties not subject to amortization	Oil and gas properties not subject to amortization as of September 30, 2015 , consisted of the following: Costs Incurred In 2015 2014 2013 2012 and Prior Total (In millions) Acquisition costs $ 272 $ 165 $ 158 $ 46 $ 641 Exploration costs 236 2 — — 238 Fee mineral interests — — 1 23 24 Capitalized interest 23 52 7 — 82 Total oil and gas properties not subject to amortization $ 531 $ 219 $ 166 $ 69 $ 985
Capitalized Costs Relating to Oil and Gas Producing Activities and Other PPE [Table Text Block]	Property and equipment consisted of the following: September 30, December 31, (In millions) Oil and gas properties: Proved $ 21,305 $ 20,402 Unproved 747 563 Gross oil and gas properties 22,052 20,965 Accumulated depreciation, depletion and amortization (8,855 ) (8,152 ) Accumulated impairment (8,779 ) (4,581 ) Net oil and gas properties $ 4,418 $ 8,232 Other property and equipment: Furniture, fixtures and equipment $ 143 $ 144 Gathering systems and equipment 116 114 Accumulated depreciation and amortization (91 ) (76 ) Net other property and equipment $ 168 $ 182

Derivative Financial Instrume29

Derivative Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedges, Assets [Abstract]
Outstanding contracts that are not designated for hedge accounting	At September 30, 2015 , 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) Sold Puts (1) Floors Ceilings (In millions) 2015: Fixed-price swaps 92 $ 90.00 $ — $ — $ — $ — $ 4 Fixed-price swaps with sold puts: 4,278 Fixed-price swaps 90.08 — — — — 189 Sold puts — — 71.12 — — (109 ) Collars with sold puts: 184 Collars — — — 90.00 104.00 8 Sold puts — — 75.00 — — (5 ) 2016: Fixed-price swaps with sold puts: 10,060 Fixed-price swaps 89.98 — — — — 408 Sold puts — — 74.14 — — (258 ) Collars with sold puts: 6,220 Collars — — — 90.00 96.15 252 Sold puts — — 75.00 — — (164 ) Purchased calls 4,954 — 71.60 — — — 6 2017: Fixed-price swaps with sold puts: 4,468 Fixed-price swaps 88.37 — — — — 155 Sold puts — — 73.28 — — (99 ) Collars with sold puts: 2,080 Collars — — — 90.00 95.59 78 Sold puts — — 75.00 — — (50 ) Purchased calls 1,997 — 73.73 — — — 3 Total $ 418 _________________ (1) If the market prices remain below our sold puts at contract settlement, we will receive the market price plus the following associated with our production: • the difference between our floors and our sold puts for collars with sold puts; or • the difference between our swaps and our sold puts for fixed-price swaps with sold puts. For the volumes with purchased calls, we have effectively locked in a portion of the spreads noted above (less the call premium). Natural Gas NYMEX Contract Price Per MMBtu Collars Estimated Fair Value Asset (Liability) Period and Type of Instrument Volume in MMMBtus Swaps (Weighted Average) Sold Puts (Weighted Average) Floors (Weighted Average) Ceilings (Weighted Average) (In millions) 2015: Fixed-price swaps 13,970 $ 4.14 $ — $ — $ — $ 21 Swaptions (1) — 3.50 — — — — Collars 9,660 — — 3.93 4.74 13 2016: Fixed-price swaps 4,550 3.39 — — — 3 Swaptions (1) — 3.50 — — — — Collars 10,980 — — 4.00 4.54 13 Total $ 50 ________ (1) During the second quarter of 2015, we sold natural gas swaption contracts that expired unexercised in October 2015. During the third quarter of 2015, we sold natural gas swaption contracts that, if exercised on their expiration date in December 2015, would protect 9,100 MMMBtus of January 2016 through June 2016 production with $3.50 per MMBtu fixed price swaps.
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) September 30, 2015 Oil positions $ 1,044 $ (612 ) $ 287 $ 145 $ (626 ) $ 612 $ (8 ) $ (6 ) Natural gas positions 50 — 47 3 — — — — Total $ 1,094 $ (612 ) $ 334 $ 148 $ (626 ) $ 612 $ (8 ) $ (6 ) December 31, 2014 Oil positions $ 1,115 $ (597 ) $ 332 $ 186 $ (605 ) $ 597 $ (8 ) $ — Natural gas positions 105 (2 ) 99 4 (2 ) 2 — — Total $ 1,220 $ (599 ) $ 431 $ 190 $ (607 ) $ 599 $ (8 ) $ —
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. In addition to the derivative strategies outlined in our Annual Report on Form 10-K for the year ended December 31, 2014, we purchased call options in 2015 that effectively lock in the value for a portion of our corresponding oil swaps with short puts as well as collars with short puts. We elected to defer the premiums related to these calls until contract settlement. At September 30, 2015 , the deferred premiums totaled $14 million . Excluding the effect of the deferred premium, if the settlement price is above the call strike price, the counterparty is required to make a payment to us. 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 credit default swaps and time to maturity. The calculation of the fair value of options requires the use of an option-pricing model. See Note 9 , “Fair Value Measurements.” At September 30, 2015 , 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) Sold Puts (1) Floors Ceilings (In millions) 2015: Fixed-price swaps 92 $ 90.00 $ — $ — $ — $ — $ 4 Fixed-price swaps with sold puts: 4,278 Fixed-price swaps 90.08 — — — — 189 Sold puts — — 71.12 — — (109 ) Collars with sold puts: 184 Collars — — — 90.00 104.00 8 Sold puts — — 75.00 — — (5 ) 2016: Fixed-price swaps with sold puts: 10,060 Fixed-price swaps 89.98 — — — — 408 Sold puts — — 74.14 — — (258 ) Collars with sold puts: 6,220 Collars — — — 90.00 96.15 252 Sold puts — — 75.00 — — (164 ) Purchased calls 4,954 — 71.60 — — — 6 2017: Fixed-price swaps with sold puts: 4,468 Fixed-price swaps 88.37 — — — — 155 Sold puts — — 73.28 — — (99 ) Collars with sold puts: 2,080 Collars — — — 90.00 95.59 78 Sold puts — — 75.00 — — (50 ) Purchased calls 1,997 — 73.73 — — — 3 Total $ 418 _________________ (1) If the market prices remain below our sold puts at contract settlement, we will receive the market price plus the following associated with our production: • the difference between our floors and our sold puts for collars with sold puts; or • the difference between our swaps and our sold puts for fixed-price swaps with sold puts. For the volumes with purchased calls, we have effectively locked in a portion of the spreads noted above (less the call premium). Natural Gas NYMEX Contract Price Per MMBtu Collars Estimated Fair Value Asset (Liability) Period and Type of Instrument Volume in MMMBtus Swaps (Weighted Average) Sold Puts (Weighted Average) Floors (Weighted Average) Ceilings (Weighted Average) (In millions) 2015: Fixed-price swaps 13,970 $ 4.14 $ — $ — $ — $ 21 Swaptions (1) — 3.50 — — — — Collars 9,660 — — 3.93 4.74 13 2016: Fixed-price swaps 4,550 3.39 — — — 3 Swaptions (1) — 3.50 — — — — Collars 10,980 — — 4.00 4.54 13 Total $ 50 ________ (1) During the second quarter of 2015, we sold natural gas swaption contracts that expired unexercised in October 2015. During the third quarter of 2015, we sold natural gas swaption contracts that, if exercised on their expiration date in December 2015, would protect 9,100 MMMBtus of January 2016 through June 2016 production with $3.50 per MMBtu fixed price swaps. 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) September 30, 2015 Oil positions $ 1,044 $ (612 ) $ 287 $ 145 $ (626 ) $ 612 $ (8 ) $ (6 ) Natural gas positions 50 — 47 3 — — — — Total $ 1,094 $ (612 ) $ 334 $ 148 $ (626 ) $ 612 $ (8 ) $ (6 ) December 31, 2014 Oil positions $ 1,115 $ (597 ) $ 332 $ 186 $ (605 ) $ 597 $ (8 ) $ — Natural gas positions 105 (2 ) 99 4 (2 ) 2 — — Total $ 1,220 $ (599 ) $ 431 $ 190 $ (607 ) $ 599 $ (8 ) $ — The amount of gain (loss) recognized in “Commodity derivative income (expense)” in our consolidated statement of operations related to our derivative financial instruments follows: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Derivatives not designated as hedging instruments: Realized gain (loss) on oil positions $ 100 $ (18 ) $ 287 $ (70 ) Realized gain (loss) on natural gas positions 31 (2 ) 88 (36 ) Total realized gain (loss) 131 (20 ) 375 (106 ) Unrealized gain (loss) on oil positions (30 ) 285 (92 ) 109 Unrealized gain (loss) on natural gas positions (14 ) 38 (53 ) 30 Total unrealized gain (loss) (44 ) 323 (145 ) 139 Total $ 87 $ 303 $ 230 $ 33 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 separate derivative instruments with that counterparty. At September 30, 2015 , ten of our 17 counterparties accounted for approximately 85% of our contracted volumes, with the largest counterparty accounting for approximately 15% . At September 30, 2015, approximately 72% 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 related to our derivative financial instruments follows: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Derivatives not designated as hedging instruments: Realized gain (loss) on oil positions $ 100 $ (18 ) $ 287 $ (70 ) Realized gain (loss) on natural gas positions 31 (2 ) 88 (36 ) Total realized gain (loss) 131 (20 ) 375 (106 ) Unrealized gain (loss) on oil positions (30 ) 285 (92 ) 109 Unrealized gain (loss) on natural gas positions (14 ) 38 (53 ) 30 Total unrealized gain (loss) (44 ) 323 (145 ) 139 Total $ 87 $ 303 $ 230 $ 33

Accounts Receivable (Tables)

Accounts Receivable (Tables) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	$ 263	$ 439
Accounts Receivable	Accounts receivable consisted of the following: September 30, December 31, (In millions) Revenue $ 102 $ 155 Joint interest 122 230 Other 55 70 Reserve for doubtful accounts (16 ) (16 ) Total accounts receivable, net $ 263 $ 439 Reserve for doubtful accounts includes an allowance of $15 million related to discontinued operations. See Note 17 , "Discontinued Operations."
Revenue [Member]
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	$ 102	155
Oil and Gas Joint Interest Billing [Member]
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	122	230
Other accounts receivable [Member]
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	55	70
Allowance For Doubtful Accounts [Member]
Accounts Notes And Loans Receivable [Line Items]
Accounts Receivable, Net, Current	$ (16)	$ (16)

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	9 Months Ended
	Sep. 30, 2015
Accrued Liabilities, Current [Abstract]
Accrued Liabilities	Accrued liabilities consisted of the following: September 30, December 31, (In millions) Revenue payable $ 151 $ 197 Accrued capital costs 141 441 Accrued lease operating expenses 40 47 Employee incentive expense 31 62 Accrued interest on debt 32 67 Taxes payable 40 32 Other 45 34 Total accrued liabilities $ 480 $ 880

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2015
Fair Value Disclosures [Abstract]
Fair value by measurement classification and type Table	The following table summarizes the valuation of our assets and liabilities that are measured at fair value on a recurring basis. Fair Value Measurement Classification Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total (In millions) As of December 31, 2014: Money market fund investments $ 1 $ — $ — $ 1 Deferred compensation plan assets 9 — — 9 Equity securities available-for-sale 10 — — 10 Oil and gas derivative swap contracts — 994 — 994 Oil and gas derivative option and swaption contracts — — (381 ) (381 ) Stock-based compensation liability awards (12 ) — (3 ) (15 ) Total $ 8 $ 994 $ (384 ) $ 618 As of September 30, 2015: Money market fund investments $ 2 $ — $ — $ 2 Deferred compensation plan assets 5 — — 5 Equity securities available-for-sale 15 — — 15 Oil and gas derivative swap contracts — 780 — 780 Oil and gas derivative option and swaption contracts — — (312 ) (312 ) Stock-based compensation liability awards (11 ) — — (11 ) Total $ 11 $ 780 $ (312 ) $ 479
Fair value changes level 3 Table	The following table sets forth a reconciliation of changes in the fair value of financial assets and liabilities classified as Level 3 in the fair value hierarchy for the indicated periods. Investments Derivatives Stock-Based Compensation Total (In millions) Balance at January 1, 2014 $ 39 $ (8 ) $ (5 ) $ 26 Realized or unrealized gains (losses) included in earnings — — (42 ) (42 ) Purchases, issuances, sales and settlements: Sales (39 ) — — (39 ) Settlements — 4 40 44 Transfers in to Level 3 — — — — Transfers out of Level 3 — 3 — 3 Balance at September 30, 2014 $ — $ (1 ) $ (7 ) $ (8 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at September 30, 2014 $ — $ 20 $ (3 ) $ 17 Balance at January 1, 2015 $ — $ (381 ) $ (3 ) $ (384 ) Realized or unrealized gains (losses) included in earnings — (116 ) 3 (113 ) Purchases, issuances, sales and settlements: Settlements — 185 — 185 Transfers in to Level 3 — — — — Transfers out of Level 3 — — — — Balance at September 30, 2015 $ — $ (312 ) $ — $ (312 ) Change in unrealized gains or losses included in earnings relating to Level 3 instruments still held at September 30, 2015 $ — $ (88 ) $ 3 $ (85 )
Quantitative disclosures about unobservable inputs	Estimated Fair Value Asset (Liability) Quantitative Information about Level 3 Fair Value Measurements Instrument Type Valuation Technique Unobservable Input Range (In millions) Oil option contracts $ (338 ) Black-Scholes Oil price volatility 23.88 % — 60.75 % Credit risk 0.01 % — 2.89 % Natural gas option and swaption contracts $ 26 Black-Scholes Natural gas price volatility 27.63 % — 56.05 % Credit risk 0.01 % — 2.19 % SVAP $ — (1) Monte Carlo Implied volatility 53.2 % _______ (1) Rounds to 0 .
Estimated fair value of the debt instrument at the balance sheet date	The estimated fair value of our notes, based on quoted prices in active markets (Level 1) as of the indicated dates, was as follows: September 30, December 31, (In millions) 5¾% Senior Notes due 2022 $ 734 $ 772 5⅝% Senior Notes due 2024 953 989 5⅜% Senior Notes due 2026 646 — 6⅞% Senior Subordinated Notes due 2020 — 721

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Debt	Our debt consisted of the following: September 30, December 31, (In millions) Senior unsecured debt: Revolving credit facility — LIBOR based loans (matures in 2020) $ — $ 345 Money market lines of credit (1) 48 101 Total credit arrangements 48 446 5¾% Senior Notes due 2022 750 750 5⅝% Senior Notes due 2024 1,000 1,000 5⅜% Senior Notes due 2026 700 — Total senior unsecured debt 2,498 2,196 6⅞% Senior Subordinated Notes due 2020 — 700 Discount on notes — (4 ) Total long-term debt $ 2,498 $ 2,892 ________ (1) Because we have the ability and intent to use our available credit facility to repay borrowings under our money market lines of credit as of the indicated dates, amounts outstanding under these obligations, if any, are classified as long-term.

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2015
Income Tax Disclosure [Abstract]
Provision for income taxes using federal statutory rate	The following table presents a reconciliation of the United States statutory income tax rate to our effective income tax rate. Three Months Ended Nine Months Ended 2015 2014 2015 2014 U.S. statutory income tax rate 35.0 % 35.0 % 35.0 % 35.0 % State and local income taxes, net of federal effect (0.6 ) 1.1 0.9 2.0 Foreign tax on foreign earnings 1.1 (0.1 ) 0.2 0.5 Other (0.3 ) (0.4 ) (0.1 ) — Effective income tax rate 35.2 % 35.6 % 36.0 % 37.5 %

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2015
Share-based Compensation [Abstract]
Schedule of Stock Based Compensation Expense Table	Our stock-based compensation consisted of the following: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Equity awards $ 9 $ 15 $ 31 $ 37 Liability awards: Cash-settled restricted stock units 3 5 15 21 Stockholder Value Appreciation Program (3 ) (12 ) (3 ) 42 Total liability awards — (7 ) 12 63 Total stock-based compensation 9 8 43 100 Capitalized in oil and gas properties (2 ) 2 (11 ) (38 ) Net stock-based compensation expense $ 7 $ 10 $ 32 $ 62
Restricted Stock and Restricted Stock Unit Activity Table	The following table provides information about restricted stock and restricted stock unit activity. Service-Based Shares Performance/ Market-Based Shares Total Shares Weighted- Average Grant Date Fair Value per Share (In thousands, except per share data) Non-vested shares outstanding at January 1, 2015 1,902 945 2,847 $ 30.05 Granted 1,008 414 1,422 28.63 Forfeited (328 ) (97 ) (425 ) 24.51 Vested (815 ) (183 ) (998 ) 33.32 Non-vested shares outstanding at September 30, 2015 1,767 1,079 2,846 $ 27.93

Supplemental Cash Flows Infor36

Supplemental Cash Flows Information (Tables)	9 Months Ended
	Sep. 30, 2015
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. Nine Months Ended September 30, 2015 2014 (In millions) Non-cash investing and financing activities excluded from the statement of cash flows: (Increase) decrease in receivables for property sales $ 8 $ (17 ) (Increase) decrease in accrued capital expenditures 212 2 (Increase) decrease in asset retirement costs (4 ) 18

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Segment Reporting [Abstract]
Segment Information Table	Domestic China Total (In millions) Three Months Ended September 30, 2015: Oil, gas and NGL revenues $ 316 $ 61 $ 377 Operating expenses: Lease operating 57 14 71 Transportation and processing 52 — 52 Production and other taxes 13 — 13 Depreciation, depletion and amortization 184 52 236 General and administrative 64 2 66 Ceiling test and other impairments 1,817 72 1,889 Other 1 — 1 Allocated income tax (benefit) (693 ) (47 ) Net income (loss) from oil and gas properties $ (1,179 ) $ (32 ) Total operating expenses 2,328 Income (loss) from continuing operations (1,951 ) Interest expense, net of interest income, capitalized interest and other (28 ) Commodity derivative income (expense) 87 Income (loss) from continuing operations before income taxes $ (1,892 ) Total assets $ 5,114 $ 399 $ 5,513 Additions to long-lived assets $ 474 $ (12 ) $ 462 Domestic China Total (In millions) Nine Months Ended September 30, 2015: Oil, gas and NGL revenues $ 989 $ 206 $ 1,195 Operating expenses: Lease operating 178 41 219 Transportation and processing 153 — 153 Production and other taxes 43 — 43 Depreciation, depletion and amortization 603 118 721 General and administrative 174 6 180 Ceiling test and other impairments 4,130 72 4,202 Other 7 1 8 Allocated income tax (benefit) (1,591 ) (19 ) Net income (loss) from oil and gas properties $ (2,708 ) $ (13 ) Total operating expenses 5,526 Income (loss) from continuing operations (4,331 ) Interest expense, net of interest income, capitalized interest and other (117 ) Commodity derivative income (expense) 230 Income (loss) from continuing operations before income taxes $ (4,218 ) Total assets $ 5,114 $ 399 $ 5,513 Additions to long-lived assets $ 1,210 $ 15 $ 1,225	Domestic China Total (In millions) Three Months Ended September 30, 2014: Oil, gas and NGL revenues $ 610 $ — $ 610 Operating expenses: Lease operating 73 1 74 Transportation and processing 51 — 51 Production and other taxes 31 1 32 Depreciation, depletion and amortization 228 — 228 General and administrative 48 — 48 Other 10 — 10 Allocated income tax (benefit) 63 (1 ) Net income (loss) from oil and gas properties $ 106 $ (1 ) Total operating expenses 443 Income (loss) from continuing operations 167 Interest expense, net of interest income, capitalized interest and other (37 ) Commodity derivative income (expense) 303 Income (loss) from continuing operations before income taxes $ 433 Total assets $ 8,392 $ 676 $ 9,068 Additions to long-lived assets $ 485 $ 38 $ 523 Domestic China Total (In millions) Nine Months Ended September 30, 2014: Oil, gas and NGL revenues $ 1,771 $ 22 $ 1,793 Operating expenses: Lease operating 224 4 228 Transportation and processing 125 — 125 Production and other taxes 85 5 90 Depreciation, depletion and amortization 628 5 633 General and administrative 172 — 172 Other 15 — 15 Allocated income tax (benefit) 193 5 Net income (loss) from oil and gas properties $ 329 $ 3 Total operating expenses 1,263 Income (loss) from continuing operations 530 Interest expense, net of interest income, capitalized interest and other (110 ) Commodity derivative income (expense) 33 Income (loss) from continuing operations before income taxes $ 453 Total assets $ 8,392 $ 676 $ 9,068 Additions to long-lived assets $ 1,473 $ 104 $ 1,577
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 each 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, 2014. The following tables provide the geographic operating segment information for our continuing operations for the three- and nine- month periods ended September 30, 2015 and 2014 . Income tax allocations have been determined based on statutory rates in the applicable geographic segment. Our earnings and profits in China are taxed at the combined statutory rates for China and the U.S. for our income tax allocation of our China operations in the following tables. Domestic China Total (In millions) Three Months Ended September 30, 2015: Oil, gas and NGL revenues $ 316 $ 61 $ 377 Operating expenses: Lease operating 57 14 71 Transportation and processing 52 — 52 Production and other taxes 13 — 13 Depreciation, depletion and amortization 184 52 236 General and administrative 64 2 66 Ceiling test and other impairments 1,817 72 1,889 Other 1 — 1 Allocated income tax (benefit) (693 ) (47 ) Net income (loss) from oil and gas properties $ (1,179 ) $ (32 ) Total operating expenses 2,328 Income (loss) from continuing operations (1,951 ) Interest expense, net of interest income, capitalized interest and other (28 ) Commodity derivative income (expense) 87 Income (loss) from continuing operations before income taxes $ (1,892 ) Total assets $ 5,114 $ 399 $ 5,513 Additions to long-lived assets $ 474 $ (12 ) $ 462 Domestic China Total (In millions) Three Months Ended September 30, 2014: Oil, gas and NGL revenues $ 610 $ — $ 610 Operating expenses: Lease operating 73 1 74 Transportation and processing 51 — 51 Production and other taxes 31 1 32 Depreciation, depletion and amortization 228 — 228 General and administrative 48 — 48 Other 10 — 10 Allocated income tax (benefit) 63 (1 ) Net income (loss) from oil and gas properties $ 106 $ (1 ) Total operating expenses 443 Income (loss) from continuing operations 167 Interest expense, net of interest income, capitalized interest and other (37 ) Commodity derivative income (expense) 303 Income (loss) from continuing operations before income taxes $ 433 Total assets $ 8,392 $ 676 $ 9,068 Additions to long-lived assets $ 485 $ 38 $ 523 Domestic China Total (In millions) Nine Months Ended September 30, 2015: Oil, gas and NGL revenues $ 989 $ 206 $ 1,195 Operating expenses: Lease operating 178 41 219 Transportation and processing 153 — 153 Production and other taxes 43 — 43 Depreciation, depletion and amortization 603 118 721 General and administrative 174 6 180 Ceiling test and other impairments 4,130 72 4,202 Other 7 1 8 Allocated income tax (benefit) (1,591 ) (19 ) Net income (loss) from oil and gas properties $ (2,708 ) $ (13 ) Total operating expenses 5,526 Income (loss) from continuing operations (4,331 ) Interest expense, net of interest income, capitalized interest and other (117 ) Commodity derivative income (expense) 230 Income (loss) from continuing operations before income taxes $ (4,218 ) Total assets $ 5,114 $ 399 $ 5,513 Additions to long-lived assets $ 1,210 $ 15 $ 1,225 Domestic China Total (In millions) Nine Months Ended September 30, 2014: Oil, gas and NGL revenues $ 1,771 $ 22 $ 1,793 Operating expenses: Lease operating 224 4 228 Transportation and processing 125 — 125 Production and other taxes 85 5 90 Depreciation, depletion and amortization 628 5 633 General and administrative 172 — 172 Other 15 — 15 Allocated income tax (benefit) 193 5 Net income (loss) from oil and gas properties $ 329 $ 3 Total operating expenses 1,263 Income (loss) from continuing operations 530 Interest expense, net of interest income, capitalized interest and other (110 ) Commodity derivative income (expense) 33 Income (loss) from continuing operations before income taxes $ 453 Total assets $ 8,392 $ 676 $ 9,068 Additions to long-lived assets $ 1,473 $ 104 $ 1,577

Discontinued Operations (Tables

Discontinued Operations (Tables)	9 Months Ended
	Sep. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	Nine Months Ended September 30, 2014 (In millions) Oil and gas revenues $ 90 Operating expenses 69 Income (loss) from discontinued operations 21 Gain on sale of Malaysia business 388 Income from discontinued operations before income taxes 409 Income tax provision (benefit): Current 12 Deferred 140 Total income tax provision (benefit) 152 Income (loss) from discontinued operations, net of tax $ 257

Restructuring Costs Restructu39

Restructuring Costs Restructuring Costs (Tables)	9 Months Ended
	Sep. 30, 2015
Restructuring and Related Activities [Abstract]
Restructuring and Related Costs [Table Text Block]	Three Months Ended Nine Months Ended 2015 2014 2015 2014 (In millions) Type of Restructuring Cost Location in the Consolidated Statement of Operations Severance and related benefit costs Operating expenses - General and administrative $ 3 $ — $ 6 $ — Relocation costs Operating expenses - General and administrative 2 — 3 — Office-lease abandonment costs Operating expenses - General and administrative 13 — 13 — Other associated costs Operating expenses - Depreciation, depletion and amortization — — 1 — Total $ 18 $ — $ 23 $ —
Schedule of Restructuring Reserve Rollforward [Table Text Block]	Severance and Related Benefit Costs Office-lease Abandonment Costs Relocation Costs Other Associated Costs Total (In millions) Restructuring liability at January 1, 2015 $ — $ — $ — $ — $ — Additions 6 13 3 1 23 Settlements (4 ) — (3 ) (1 ) (8 ) Revisions — — — — — Restructuring liability at September 30, 2015 $ 2 $ 13 $ — $ — $ 15 Cumulative costs as of September 30, 2015 $ 6 $ 13 $ 3 $ 1 $ 23 Expected total costs $ 7 $ 19 $ 5 $ 1 $ 32

Organization and Summary of S40

Organization and Summary of Significant Accounting Policies (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Restricted Cash and Cash Equivalents	$ 10
Change in ARO (asset retirement obligation)
Less: Current portion of ARO	(3)	$ (3)
Total long-term ARO	$ 192	$ 183

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Income (numerator):
Income (Loss) from Continuing Operations Attributable to Parent	$ (1,227)	$ 278	$ (2,699)	$ 283
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	0	0	0	257
Net income (loss)	$ (1,227)	$ 278	$ (2,699)	$ 540
Weighted average shares (denominator):
Weighted average shares - basic	163	137	157	137
Dilution effect of stock options and unvested restricted stock and restricted stock units outstanding at end of period	0	1	0	1
Weighted average shares - diluted	163	138	157	138
Basic --
Income (Loss) from Continuing Operations, Per Basic Share	$ (7.52)	$ 2.04	$ (17.17)	$ 2.07
Discontinued Operation, Income (Loss) from Discontinued Operation, Net of Tax, Per Basic Share	0	0	0	1.89
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share	0	0	0	1.89
Earnings (Loss) Per Share, Basic	(7.52)	2.04	(17.17)	3.96
Diluted --
Income (Loss) from Continuing Operations, Per Diluted Share	(7.52)	2.02	(17.17)	2.05
Discontinued Operation, Income (Loss) from Discontinued Operation, Net of Tax, Per Diluted Share	0	0	0	1.87
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share	0	0	0	1.87
Earnings (Loss) Per Share, Diluted	$ (7.52)	$ 2.02	$ (17.17)	$ 3.92
Earnings Per Share (Textuals) [Abstract]
Incremental shares attributable to the assumed exercise of outstanding stock options and the assumed vesting of unvested restricted stock and restricted stock units	2.3	0.3	2.8	1.1

Inventories (Details)

Inventories (Details) $ in Millions	Sep. 30, 2015USD ($)MBbls	Dec. 31, 2014USD ($)MBbls
Inventory Disclosure [Abstract]
Crude oil inventory in barrels | MBbls	188,000	240,000
Energy Related Inventory, Petroleum	$ 9	$ 8

Oil and Gas Assets (Details)

Oil and Gas Assets (Details)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2015USD ($)$ / bbl$ / MMBTU	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)$ / bbl$ / MMBTU	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)
Oil and gas properties:
Capitalized Costs, Proved Properties	$ 21,305,000,000		$ 21,305,000,000		$ 20,402,000,000
Capitalized Costs, Unproved Properties	747,000,000		747,000,000		563,000,000
Capitalized Costs, Oil and Gas Producing Activities, Gross	22,052,000,000		22,052,000,000		20,965,000,000
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance Relating to Oil and Gas Producing Activities	8,855,000,000		8,855,000,000		8,152,000,000
Capitalized Costs, Accumulated Impairment Relating to Oil and Gas Producing Activities	(8,779,000,000)		(8,779,000,000)		(4,581,000,000)
Capitalized Costs, Oil and Gas Producing Activities, Net	4,418,000,000		4,418,000,000		8,232,000,000
Accumulated depreciation and amortization	(91,000,000)		(91,000,000)		(76,000,000)
Net other property and equipment	168,000,000		168,000,000		182,000,000
Cost of oil and gas properties not subject to amortization
Acquisition costs	641,000,000		641,000,000
Exploration costs	238,000,000		238,000,000
Fee mineral interests	24,000,000		24,000,000
Capitalized interest	82,000,000		82,000,000
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	985,000,000		985,000,000		677,000,000
Oil and Gas Assets (Textuals) [Abstract]
Capitalization of internal costs per full cost method of accounting	23,000,000	$ 38,000,000	81,000,000	$ 158,000,000
Insurance Recoveries decrease to capital	$ 57,000,000		$ 57,000,000
Unweighted average commodity price of natural gas based on first-day-of-the-month prices for the prior 12 months (per MMBtu) | $ / MMBTU	3.06		3.06
Unweighted average commodity price of oil based on first-day-of-the-month prices for the prior 12 months (per barrel) | $ / bbl	59.09		59.09
Proceeds from Sale of Oil and Gas Property and Equipment			$ 86,000,000	616,000,000
Furniture and Fixtures [Member]
Oil and gas properties:
Other property and equipment	$ 143,000,000		143,000,000		144,000,000
Gas Gathering and Processing Equipment [Member]
Oil and gas properties:
Other property and equipment	116,000,000		116,000,000		114,000,000
ERROR in label resolution.
Oil and Gas Assets (Textuals) [Abstract]
Sales of Oil and Gas Prospects					$ 588,000,000
Other Property [Member]
Oil and Gas Assets (Textuals) [Abstract]
Payments for Previous Acquisition			125,000,000	21,000,000
Proceeds from Sale of Oil and Gas Property and Equipment			86,000,000	56,000,000
UNITED STATES
Oil and Gas Assets (Textuals) [Abstract]
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitation Expense Gross	1,800,000,000		4,100,000,000
Capitalized Costs Exceeding Ceiling, Net	1,200,000,000			$ 2,600,000,000
CHINA
Oil and Gas Assets (Textuals) [Abstract]
Unamortized Costs Capitalized Less Related Deferred Income Taxes Exceed Ceiling Limitation Expense Gross			72,000,000
Capitalized Costs Exceeding Ceiling, Net			29,000,000
Costs incurred in 2015 not subject to amortization [Member]
Cost of oil and gas properties not subject to amortization
Acquisition costs	272,000,000		272,000,000
Exploration costs	236,000,000		236,000,000
Fee mineral interests	0		0
Capitalized interest	23,000,000		23,000,000
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	531,000,000		531,000,000
Costs incurred in 2014 not subject to amortization [Member]
Cost of oil and gas properties not subject to amortization
Acquisition costs	165,000,000		165,000,000
Exploration costs	2,000,000		2,000,000
Fee mineral interests	0		0
Capitalized interest	52,000,000		52,000,000
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	219,000,000		219,000,000
Costs incurred in 2013 not subject to amortization [Member]
Cost of oil and gas properties not subject to amortization
Acquisition costs	158,000,000		158,000,000
Exploration costs	0		0
Fee mineral interests	1,000,000		1,000,000
Capitalized interest	7,000,000		7,000,000
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	166,000,000		166,000,000
Costs incurred in 2012 and prior not subject to amortization [Member] [Domain]
Cost of oil and gas properties not subject to amortization
Acquisition costs	46,000,000		46,000,000
Exploration costs	0		0
Fee mineral interests	23,000,000		23,000,000
Capitalized interest	0		0
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	$ 69,000,000		$ 69,000,000

Derivative Financial Instrume44

Derivative Financial Instruments (Textuals) (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015USD ($)MMBTU$ / bbl$ / MMBTUMBbls	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)MMBTU$ / bbl$ / MMBTUMBbls	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 1,094		$ 1,094		$ 1,220
Realized Gain Loss On Derivatives	131	$ (20)	375	$ (106)
Deferred Premium	14		14
Unrealized Gain (Loss) on Derivatives	(44)	323	(145)	139
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	87	303	230	33
Derivative Asset, Fair Value, Gross Liability	612		612		599
Derivative Asset, Current	334		334		431
Derivative Asset, Noncurrent	148		148		190
Derivative Liability, Fair Value, Gross Liability	626		626		607
Derivative Liability, Fair Value, Gross Asset	612		612		599
Derivative Liability, Current	8		8		8
Derivative Liability, Noncurrent	$ 6		$ 6		0
ConcentrationOfCounterpartiesUnderCreditFacility	72.00%		72.00%
Total Derivative Counterparties	17		17
Primary Derivative Counterparties	10		10
Percent of future hedged production with primary counterparties	85.00%		85.00%
Number of counterparties holding approximately 15 percent of future hedge position	1		1
Concentraction Of Future Hedged Production	15.00%		15.00%
Natural gas contracts [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 50		$ 50		105
Realized Gain Loss On Derivatives	31	(2)	88	(36)
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	50		50
Unrealized Gain (Loss) on Derivatives	(14)	38	(53)	30
Derivative Asset, Fair Value, Gross Liability	0		0		2
Derivative Asset, Current	47		47		99
Derivative Asset, Noncurrent	3		3		4
Derivative Liability, Fair Value, Gross Liability	0		0		2
Derivative Liability, Fair Value, Gross Asset	0		0		2
Derivative Liability, Current	0		0		0
Derivative Liability, Noncurrent	0		0		0
Oil contracts [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	1,044		1,044		1,115
Realized Gain Loss On Derivatives	100	(18)	287	(70)
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	418		418
Unrealized Gain (Loss) on Derivatives	(30)	$ 285	(92)	$ 109
Derivative Asset, Fair Value, Gross Liability	612		612		597
Derivative Asset, Current	287		287		332
Derivative Asset, Noncurrent	145		145		186
Derivative Liability, Fair Value, Gross Liability	626		626		605
Derivative Liability, Fair Value, Gross Asset	612		612		597
Derivative Liability, Current	8		8		8
Derivative Liability, Noncurrent	$ 6		$ 6		$ 0
Year2015 [Member] | Natural gas contracts [Member] | Swaption [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / MMBTU	3.5		3.5
Derivative Liability, Fair Value, Total	$ 0		$ 0
Year2015 [Member] | Natural gas contracts [Member] | Swap [Member]
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 21		$ 21
Derivative, Swap Type, Average Fixed Price | $ / MMBTU	4.14		4.14
Volume In Mmbtus | MMBTU	13,970,000		13,970,000
Year2015 [Member] | Natural gas contracts [Member] | Collars [Member]
Derivative [Line Items]
Derivative, Weighted Average Ceiling Price | $ / MMBTU	4.74		4.74
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 13		$ 13
Volume In Mmbtus | MMBTU	9,660,000		9,660,000
Derivative, Weighted Average Floor Price | $ / MMBTU	3.93		3.93
Year2015 [Member] | Oil contracts [Member] | Collars with Sold Puts - Collar [Member]
Derivative [Line Items]
Derivative, Weighted Average Ceiling Price | $ / bbl	104		104
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 8		$ 8
Derivative, Weighted Average Floor Price | $ / bbl	90		90
Year2015 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Swap [Member]
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 189		$ 189
Derivative, Swap Type, Average Fixed Price | $ / bbl	90.08		90.08
Year2015 [Member] | Oil contracts [Member] | Swap [Member]
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 4		$ 4
Volume in MBbls | MBbls	92		92
Derivative, Swap Type, Average Fixed Price | $ / bbl	90		90
Year2015 [Member] | Oil contracts [Member] | Fixed Price Swaps With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	4,278		4,278
Year2015 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price | $ / bbl	71.12		71.12
Derivative Liability, Fair Value, Total	$ (109)		$ (109)
Year2015 [Member] | Oil contracts [Member] | Collars with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price | $ / bbl	75		75
Derivative Liability, Fair Value, Total	$ (5)		$ (5)
Year2015 [Member] | Oil contracts [Member] | Collars With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	184		184
Year 2016 [Member] | Natural gas contracts [Member] | Swaption [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / MMBTU	3.5		3.5
Derivative Liability, Fair Value, Total	$ 0		$ 0
Volume In Mmbtus | MMBTU	9,100,000		9,100,000
Year 2016 [Member] | Natural gas contracts [Member] | Swap [Member]
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 3		$ 3
Derivative, Swap Type, Average Fixed Price | $ / MMBTU	3.39		3.39
Volume In Mmbtus | MMBTU	4,550,000		4,550,000
Year 2016 [Member] | Natural gas contracts [Member] | Collars [Member]
Derivative [Line Items]
Derivative, Weighted Average Ceiling Price | $ / MMBTU	4.54		4.54
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 13		$ 13
Volume In Mmbtus | MMBTU	10,980,000		10,980,000
Derivative, Weighted Average Floor Price | $ / MMBTU	4		4
Year 2016 [Member] | Oil contracts [Member] | Collars with Sold Puts - Collar [Member]
Derivative [Line Items]
Derivative, Weighted Average Ceiling Price | $ / bbl	96.15		96.15
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 252		$ 252
Derivative, Weighted Average Floor Price | $ / bbl	90		90
Year 2016 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Swap [Member]
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 408		$ 408
Derivative, Swap Type, Average Fixed Price | $ / bbl	89.98		89.98
Year 2016 [Member] | Oil contracts [Member] | Fixed Price Swaps With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	10,060		10,060
Year 2016 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price | $ / bbl	74.14		74.14
Derivative Liability, Fair Value, Total	$ (258)		$ (258)
Year 2016 [Member] | Oil contracts [Member] | Collars with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price | $ / bbl	75		75
Derivative Liability, Fair Value, Total	$ (164)		$ (164)
Year 2016 [Member] | Oil contracts [Member] | Call Option [Member]
Derivative [Line Items]
Derivative, Weighted Average Ceiling Price | $ / bbl	71.60		71.60
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 6		$ 6
Volume in MBbls | MBbls	4,954		4,954
Year 2016 [Member] | Oil contracts [Member] | Collars With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	6,220		6,220
Year2017 [Member] | Oil contracts [Member] | Collars with Sold Puts - Collar [Member]
Derivative [Line Items]
Derivative, Weighted Average Ceiling Price | $ / bbl	95.59		95.59
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 78		$ 78
Derivative, Weighted Average Floor Price | $ / bbl	90		90
Year2017 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Swap [Member]
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 155		$ 155
Derivative, Swap Type, Average Fixed Price | $ / bbl	88.37		88.37
Year2017 [Member] | Oil contracts [Member] | Fixed Price Swaps With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	4,468		4,468
Year2017 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price | $ / bbl	73.28		73.28
Derivative Liability, Fair Value, Total	$ (99)		$ (99)
Year2017 [Member] | Oil contracts [Member] | Collars with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price | $ / bbl	75		75
Derivative Liability, Fair Value, Total	$ (50)		$ (50)
Year2017 [Member] | Oil contracts [Member] | Call Option [Member]
Derivative [Line Items]
Derivative, Weighted Average Ceiling Price | $ / bbl	73.73		73.73
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ 3		$ 3
Volume in MBbls | MBbls	1,997		1,997
Year2017 [Member] | Oil contracts [Member] | Collars With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls | MBbls	2,080		2,080

Outstanding Natural Gas Contrac

Outstanding Natural Gas Contracts That Are Not Designated for Hedge Accounting (Details) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)MMBTU$ / MMBTU
Derivative [Line Items]
Schedule of Derivative Instruments [Table Text Block]	At September 30, 2015 , 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) Sold Puts (1) Floors Ceilings (In millions) 2015: Fixed-price swaps 92 $ 90.00 $ — $ — $ — $ — $ 4 Fixed-price swaps with sold puts: 4,278 Fixed-price swaps 90.08 — — — — 189 Sold puts — — 71.12 — — (109 ) Collars with sold puts: 184 Collars — — — 90.00 104.00 8 Sold puts — — 75.00 — — (5 ) 2016: Fixed-price swaps with sold puts: 10,060 Fixed-price swaps 89.98 — — — — 408 Sold puts — — 74.14 — — (258 ) Collars with sold puts: 6,220 Collars — — — 90.00 96.15 252 Sold puts — — 75.00 — — (164 ) Purchased calls 4,954 — 71.60 — — — 6 2017: Fixed-price swaps with sold puts: 4,468 Fixed-price swaps 88.37 — — — — 155 Sold puts — — 73.28 — — (99 ) Collars with sold puts: 2,080 Collars — — — 90.00 95.59 78 Sold puts — — 75.00 — — (50 ) Purchased calls 1,997 — 73.73 — — — 3 Total $ 418 _________________ (1) If the market prices remain below our sold puts at contract settlement, we will receive the market price plus the following associated with our production: • the difference between our floors and our sold puts for collars with sold puts; or • the difference between our swaps and our sold puts for fixed-price swaps with sold puts. For the volumes with purchased calls, we have effectively locked in a portion of the spreads noted above (less the call premium). Natural Gas NYMEX Contract Price Per MMBtu Collars Estimated Fair Value Asset (Liability) Period and Type of Instrument Volume in MMMBtus Swaps (Weighted Average) Sold Puts (Weighted Average) Floors (Weighted Average) Ceilings (Weighted Average) (In millions) 2015: Fixed-price swaps 13,970 $ 4.14 $ — $ — $ — $ 21 Swaptions (1) — 3.50 — — — — Collars 9,660 — — 3.93 4.74 13 2016: Fixed-price swaps 4,550 3.39 — — — 3 Swaptions (1) — 3.50 — — — — Collars 10,980 — — 4.00 4.54 13 Total $ 50 ________ (1) During the second quarter of 2015, we sold natural gas swaption contracts that expired unexercised in October 2015. During the third quarter of 2015, we sold natural gas swaption contracts that, if exercised on their expiration date in December 2015, would protect 9,100 MMMBtus of January 2016 through June 2016 production with $3.50 per MMBtu fixed price swaps.
Natural gas contracts [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Total | $	$ 50
Collars [Member] | Natural gas contracts [Member] | Year2015 [Member]
Derivative [Line Items]
Natural Gas Volumes | MMBTU	9,660,000
Derivative, Weighted Average Floor Price	3.93
Derivative, Weighted Average Ceiling Price	4.74
Derivative Asset, Fair Value, Total | $	$ 13
Collars [Member] | Natural gas contracts [Member] | Year 2016 [Member]
Derivative [Line Items]
Natural Gas Volumes | MMBTU	10,980,000
Derivative, Weighted Average Floor Price	4
Derivative, Weighted Average Ceiling Price	4.54
Derivative Asset, Fair Value, Total | $	$ 13
Swaption [Member] | Natural gas contracts [Member] | Year2015 [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Total | $	$ 0
Derivative, Swap Type, Average Fixed Price	3.5
Swaption [Member] | Natural gas contracts [Member] | Year 2016 [Member]
Derivative [Line Items]
Natural Gas Volumes | MMBTU	9,100,000
Derivative Liability, Fair Value, Total | $	$ 0
Derivative, Swap Type, Average Fixed Price	3.5
Fixed-price swaps | Natural gas contracts [Member] | Year2015 [Member]
Derivative [Line Items]
Natural Gas Volumes | MMBTU	13,970,000
Derivative, Swap Type, Average Fixed Price	4.14
Derivative Asset, Fair Value, Total | $	$ 21
Fixed-price swaps | Natural gas contracts [Member] | Year 2016 [Member]
Derivative [Line Items]
Natural Gas Volumes | MMBTU	4,550,000
Derivative, Swap Type, Average Fixed Price	3.39
Derivative Asset, Fair Value, Total | $	$ 3

Derivative Financial Instrume46

Derivative Financial Instruments Recorded in Balance Sheet (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Derivative, Fair Value, Net [Abstract]
Derivative Asset Not Designated As Hedging Instrument, Fair Value	$ 1,094	$ 1,220
Derivative Asset, Fair Value, Gross Liability	(612)	(599)
Derivative Liability Not Designated as Hedging Instrument Fair Value	(626)	(607)
Derivative Liability, Fair Value, Gross Asset	612	599
Derivative Asset, Current	334	431
Derivative Asset, Noncurrent	148	190
Derivative Liability, Current	8	8
Derivative Liability, Noncurrent	6	0
Natural gas contracts [Member]
Derivative, Fair Value, Net [Abstract]
Derivative Asset Not Designated As Hedging Instrument, Fair Value	50	105
Derivative Asset, Fair Value, Gross Liability	0	(2)
Derivative Liability Not Designated as Hedging Instrument Fair Value	0	(2)
Derivative Liability, Fair Value, Gross Asset	0	2
Derivative Asset, Current	47	99
Derivative Asset, Noncurrent	3	4
Derivative Liability, Current	0	0
Derivative Liability, Noncurrent	0	0
Oil contracts [Member]
Derivative, Fair Value, Net [Abstract]
Derivative Asset Not Designated As Hedging Instrument, Fair Value	1,044	1,115
Derivative Asset, Fair Value, Gross Liability	(612)	(597)
Derivative Liability Not Designated as Hedging Instrument Fair Value	(626)	(605)
Derivative Liability, Fair Value, Gross Asset	612	597
Derivative Asset, Current	287	332
Derivative Asset, Noncurrent	145	186
Derivative Liability, Current	8	8
Derivative Liability, Noncurrent	$ 6	$ 0

Outstanding Oil Contracts That

Outstanding Oil Contracts That Are Not Designated For Hedge Accounting (Details) - Oil contracts [Member] $ in Millions	Sep. 30, 2015USD ($)$ / bblMBbls
Derivative [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value | $	$ 418
Fixed Price Swaps With Sold Puts [Member] | Year2015 [Member]
Derivative [Line Items]
Volume in MBbls	4,278
Fixed Price Swaps With Sold Puts [Member] | Year 2016 [Member]
Derivative [Line Items]
Volume in MBbls	10,060
Fixed Price Swaps With Sold Puts [Member] | Year2017 [Member]
Derivative [Line Items]
Volume in MBbls	4,468
Collars With Sold Puts [Member] | Year2015 [Member]
Derivative [Line Items]
Volume in MBbls	184
Collars With Sold Puts [Member] | Year 2016 [Member]
Derivative [Line Items]
Volume in MBbls	6,220
Collars With Sold Puts [Member] | Year2017 [Member]
Derivative [Line Items]
Volume in MBbls	2,080
Fixed-price swaps | Year2015 [Member]
Derivative [Line Items]
Volume in MBbls	92
Derivative, Swap Type, Average Fixed Price | $ / bbl	90
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value | $	$ 4

Amount of Gain Loss Recognized

Amount of Gain Loss Recognized in Income Related to Derivative Financial Instruments (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	$ 131	$ (20)	$ 375	$ (106)
Unrealized Gain (Loss) on Derivatives	(44)	323	(145)	139
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	87	303	230	33
Natural gas contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	31	(2)	88	(36)
Unrealized Gain (Loss) on Derivatives	(14)	38	(53)	30
Oil contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	100	(18)	287	(70)
Unrealized Gain (Loss) on Derivatives	$ (30)	$ 285	$ (92)	$ 109

Accounts Receivable (Details)

Accounts Receivable (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Reserve for Doubtful Accounts [Abstract]
Accounts Receivable, Net, Current	$ 263	$ 439
Malaysia Reserve for Doubtful Accounts Allowance	$ 15

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Accrued Liabilities [Line Items]
Accrued liabilities	$ 480	$ 880
Revenue payable [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	151	197
Accrued capital costs [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	141	441
Accrued lease operating expenses [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	40	47
Employee incentive expense [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	31	62
Accrued interest on debt [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	32	67
Taxes payable [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	40	32
Other accrued liabilities [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	$ 45	$ 34

Fair Value Measurements (Textua

Fair Value Measurements (Textuals) (Details) - USD ($)	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value				$ (26,000,000)
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value	$ 312,000,000	$ 8,000,000	$ 384,000,000
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) Included in Investment Income		17,000,000
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)	(85,000,000)
Money Market Funds, at Carrying Value	2,000,000		1,000,000
Deferred Compensation Plan Assets	5,000,000		9,000,000
Assets, Fair Value Disclosure	479,000,000		618,000,000
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	(113,000,000)	(42,000,000)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales		(39,000,000)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	185,000,000	44,000,000
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	0	3,000,000
Obligations, Fair Value Disclosure	(11,000,000)		(15,000,000)
Oil contracts [Member]
Derivative Asset, Fair Value, Total	418,000,000
Oil contracts [Member] | Options Held [Member]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	$ (338,000,000)
Oil contracts [Member] | Maximum [Member] | Options Held [Member]
Fair Value Assumptions Expected Volatility Curves	60.75%
Fair Value Inputs, Entity Credit Risk	2.89%
Oil contracts [Member] | Minimum [Member] | Options Held [Member]
Fair Value Assumptions Expected Volatility Curves	23.88%
Fair Value Inputs, Entity Credit Risk	0.01%
Natural gas contracts [Member]
Derivative Asset, Fair Value, Total	$ 50,000,000
Natural gas contracts [Member] | Options Held [Member]
Derivative Asset, Fair Value, Total	$ 26,000,000
Natural gas contracts [Member] | Maximum [Member] | Options Held [Member]
Fair Value Assumptions Expected Volatility Curves	56.05%
Fair Value Inputs, Entity Credit Risk	2.19%
Natural gas contracts [Member] | Minimum [Member] | Options Held [Member]
Fair Value Assumptions Expected Volatility Curves	27.63%
Fair Value Inputs, Entity Credit Risk	0.01%
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member]
Money Market Funds, at Carrying Value	$ 2,000,000		1,000,000
Deferred Compensation Plan Assets	5,000,000		9,000,000
Assets, Fair Value Disclosure	11,000,000		8,000,000
Obligations, Fair Value Disclosure	(11,000,000)		(12,000,000)
Significant Other Observable Fair Value Inputs (Level 2) [Member]
Money Market Funds, at Carrying Value	0		0
Deferred Compensation Plan Assets	0		0
Assets, Fair Value Disclosure	780,000,000		994,000,000
Obligations, Fair Value Disclosure	0		0
Fair Value, Inputs, Level 3 [Member]
Money Market Funds, at Carrying Value	0		0
Deferred Compensation Plan Assets	0		0
Financial and Nonfinancial Liabilities, Fair Value Disclosure	312,000,000		384,000,000
Obligations, Fair Value Disclosure	0		(3,000,000)
Investments [Member]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0	0	0	(39,000,000)
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) Included in Investment Income	0	0
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales		(39,000,000)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	0	0
Derivatives [Member]
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value	312,000,000	1,000,000	381,000,000	8,000,000
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)	(88,000,000)	20,000,000
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	(116,000,000)	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales		0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	185,000,000	4,000,000
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	0	3,000,000
Auction Rate Securities [Member]
Proceeds from Sale of Available-for-sale Securities		39,000,000
Equity Securities [Member]
Available-for-sale Securities, Fair Value Disclosure	15,000,000		10,000,000
Equity Securities [Member] | Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member]
Available-for-sale Securities, Fair Value Disclosure	15,000,000		10,000,000
Equity Securities [Member] | Significant Other Observable Fair Value Inputs (Level 2) [Member]
Available-for-sale Securities, Fair Value Disclosure	0		0
Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]
Available-for-sale Securities, Fair Value Disclosure	0		0
Swap [Member]
Derivative Assets	780,000,000		994,000,000
Swap [Member] | Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member]
Derivative Assets			0
Derivative Liability	0
Swap [Member] | Significant Other Observable Fair Value Inputs (Level 2) [Member]
Derivative Assets	780,000,000		994,000,000
Swap [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative Assets			0
Derivative Liability	0
Commodity Option [Member]
Derivative Liability	(312,000,000)		(381,000,000)
Commodity Option [Member] | Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member]
Derivative Assets	0		0
Commodity Option [Member] | Significant Other Observable Fair Value Inputs (Level 2) [Member]
Derivative Assets	0		0
Commodity Option [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative Liability	(312,000,000)		(381,000,000)
Stockholder Value Appreciation Program [Member]
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value	200,000
Stock Compensation Plan [Member]
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value	200,000	7,000,000	3,000,000	$ 5,000,000
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)	3,000,000	(3,000,000)
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	3,000,000	(42,000,000)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales		0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	0	40,000,000
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	0	$ 0
5.75% Senior Notes Due 2022 [Member]
Debt Instrument, Fair Value Disclosure	734,000,000		772,000,000
5.625% Senior Notes Due 2024 [Member]
Debt Instrument, Fair Value Disclosure	953,000,000		989,000,000
5.375% Senior Notes Due 2026 [Member]
Debt Instrument, Fair Value Disclosure	646,000,000		0
6.875% Senior Subordinated Notes due 2020 [Member]
Debt Instrument, Fair Value Disclosure	$ 0		$ 721,000,000
Historical [Member] | Stockholder Value Appreciation Program [Member]
SBC Expected Volatility Rate, Maximum	53.20%

Valuation of Investments and Fi

Valuation of Investments and Financial Instrument Assets Liabilities By Pricing Levels (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Obligations, Fair Value Disclosure	$ 11	$ 15
Money market fund investments	2	1
Deferred Compensation Plan Assets	5	9
Total	479	618
Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Available-for-sale Securities	15	10
Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts	780	994
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Obligations, Fair Value Disclosure	11	12
Money market fund investments	2	1
Deferred Compensation Plan Assets	5	9
Total	11	8
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member] | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Available-for-sale Securities	15	10
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member] | Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts		0
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member] | Commodity Option [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts	0	0
Significant Other Observable Fair Value Inputs (Level 2) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Obligations, Fair Value Disclosure	0	0
Money market fund investments	0	0
Deferred Compensation Plan Assets	0	0
Total	780	994
Significant Other Observable Fair Value Inputs (Level 2) [Member] | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Available-for-sale Securities	0	0
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	780	994
Significant Other Observable Fair Value Inputs (Level 2) [Member] | Commodity Option [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts	0	0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Obligations, Fair Value Disclosure	0	3
Money market fund investments	0	0
Deferred Compensation Plan Assets	0	0
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Available-for-sale Securities	$ 0	0
Fair Value, Inputs, Level 3 [Member] | Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts		$ 0

Reconciliation of Changes in Fa

Reconciliation of Changes in Fair Value of Financial Assets and Liabilities Classified as Level Three In Fair Value Hierarchy (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	$ 0	$ 3
Beginning Balance		26
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	113	42
Change in unrealized gains (losses) relating to investments and derivatives still held		(17)
Derivatives [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	0	3
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	116	0
Investments [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	0	0
Beginning Balance	0	39
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	0	0
Settlements	0	0
Ending Balance	0	0
Change in unrealized gains (losses) relating to investments and derivatives still held	$ 0	$ 0

Quantitative Information about

Quantitative Information about Level 3 Fair Value Measurements (Details) - USD ($)	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014	Sep. 30, 2014
Fair Value, Option, Quantitative Disclosures [Line Items]
Liability Value	$ (312,000,000)	$ (384,000,000)	$ (8,000,000)
Stockholder Value Appreciation Program [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Liability Value	$ (200,000)
Stockholder Value Appreciation Program [Member] | Historical [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
SBC Expected Volatility Rate, Maximum	53.20%
Natural gas contracts [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Derivative Asset, Fair Value, Total	$ 50,000,000
Oil contracts [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Derivative Asset, Fair Value, Total	418,000,000
Options Held [Member] | Natural gas contracts [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Derivative Asset, Fair Value, Total	$ 26,000,000
Options Held [Member] | Natural gas contracts [Member] | Maximum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value Assumptions Expected Volatility Curves	56.05%
Credit Risk	2.19%
Options Held [Member] | Natural gas contracts [Member] | Minimum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value Assumptions Expected Volatility Curves	27.63%
Credit Risk	0.01%
Options Held [Member] | Oil contracts [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Derivative Liability, Fair Value, Total	$ (338,000,000)
Options Held [Member] | Oil contracts [Member] | Maximum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value Assumptions Expected Volatility Curves	60.75%
Credit Risk	2.89%
Options Held [Member] | Oil contracts [Member] | Minimum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value Assumptions Expected Volatility Curves	23.88%
Credit Risk	0.01%

Estimated Fair Value of Notes B

Estimated Fair Value of Notes Based on Quoted Market Prices (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
5.75% Senior Notes Due 2022 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of debt	$ 734	$ 772
5.625% Senior Notes Due 2024 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of debt	953	989
6.875% Senior Subordinated Notes due 2020 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of debt	$ 0	$ 721

Debt (Details)

Debt (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Debt Instrument [Line Items]
Debt Issuance Cost			$ 7,000,000
Line of Credit Facility, Amount Outstanding	$ 48,000,000		48,000,000		$ 446,000,000
Long-term debt	(2,498,000,000)		(2,498,000,000)		(2,892,000,000)
Payments Of Debt Extinguishment Costs			24,000,000
Net Proceeds Sr Notes Due 2026			691,000,000
Payments of Debt Issuance Costs			8,000,000	$ 0
Write off of Deferred Debt Issuance Cost			8,000,000
Debt (Textuals)
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,800,000,000		$ 1,800,000,000		1,400,000,000
Largest individual loan commitment by any lender of total commitments	12.00%		12.00%
Commitment fees incurred	$ 2,000,000	$ 1,000,000	$ 4,000,000	$ 3,000,000
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	3		3
Line of Credit Facility, Current Borrowing Capacity	$ 147,000,000		$ 147,000,000
Percentage of basis points to be added for calculation of interest rate			0.50%
Percent added to prime rate based on grid of our debt rating			0.75%
Percentage added to LIBOR based on grid of our debt rating			1.75%
Commitment fee percentage on unused capacity of line of credit			0.30%
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.			1.75%
Letters of Credit Outstanding, Amount	0		$ 0
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding	0		0		345,000,000
Money market lines of credit(1)
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding	48,000,000		48,000,000		101,000,000
5.75% Senior Notes Due 2022 [Member]
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%
5.625% Senior Notes Due 2024 [Member]
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%
5.375% Senior Notes Due 2026 [Member]
Debt Instrument [Line Items]
Long-term debt	$ (700,000,000)		$ (700,000,000)		$ 0
Debt Instrument, Interest Rate, Stated Percentage	5.375%		5.375%
Payments of Debt Issuance Costs			$ 9,000,000
Total senior unsecured debt
Debt Instrument [Line Items]
Long-term debt	$ (2,498,000,000)		(2,498,000,000)		(2,196,000,000)
6.875% Senior Subordinated Notes due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt	$ 0		$ 0		$ (700,000,000)
Debt Instrument, Interest Rate, Stated Percentage	6.875%		6.875%		6.875%
Discount on notes [Member]
Debt Instrument [Line Items]
Long-term debt	$ 0		$ 0		$ 4,000,000

Income Taxes (Details)

Income Taxes (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Income tax reconciliation to US federal statutory rate
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	35.00%	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	(0.60%)	1.10%	0.90%	2.00%
Effective Income Tax Rate Reconciliation, Foreign Income Tax Rate Differential, Percent	1.10%	(0.10%)	0.20%	0.50%
Effective Income Tax Rate Reconciliation, Other Adjustments, Percent	(0.30%)	(0.40%)	(0.10%)	0.00%
Effective Income Tax Rate Reconciliation, Percent	35.20%	35.60%	36.00%	37.50%
Income Taxes (Textuals) [Abstract]
Federal statutory tax rate	35.00%	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, Percent	35.20%	35.60%	36.00%	37.50%

Stock-Based Compensation (Detai

Stock-Based Compensation (Details)	3 Months Ended			9 Months Ended		12 Months Ended
	Sep. 30, 2015USD ($)$ / sharesshares	Sep. 30, 2014USD ($)$ / shares	Dec. 31, 2013$ / shares	Sep. 30, 2015USD ($)$ / sharesshares	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Gross	$ 9,000,000	$ 8,000,000		$ 43,000,000	$ 100,000,000
Capitalized in oil and gas properties	2,000,000	(2,000,000)		11,000,000	38,000,000
Net stock-based compensation expense	7,000,000	10,000,000		32,000,000	62,000,000
Obligations, Fair Value Disclosure	$ 11,000,000			$ 11,000,000		$ 15,000,000
Number of restricted stock shares vested | shares				(998,000)
Number of Restricted Stock Shares Granted | shares				1,422,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period | shares				(425,000)
Number of restricted stock shares outstanding | shares	2,846,000			2,846,000		2,847,000
Nonvested Awards, Total Compensation Cost Not yet Recognized	$ 63,000,000			$ 63,000,000
Liability Value	$ 312,000,000	8,000,000		312,000,000	8,000,000	$ 384,000,000
Liability Settlements				$ 185,000,000	44,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Net of Forfeitures | shares				0
Stock-Based Compensation (Textuals) [Abstract]
Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition				4 years
Last reported sales price of our common stock on the New York Stock Exchange per share | $ / shares	$ 32.90			$ 32.90
Employee Stock Purchase Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Payments	$ 0
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Reduction factor multiplied by number of shares awarded				1.87
Additional shares available for issuance | shares	3,900,000			3,900,000
Equity [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Gross	$ 9,000,000	15,000,000		$ 31,000,000	37,000,000
Cash-Settled Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Gross	3,000,000	5,000,000		15,000,000	21,000,000
Obligations, Fair Value Disclosure	$ 11,000,000			$ 11,000,000
Service Period				3 years
Number of restricted stock shares vested | shares				(462,000)
Number of Restricted Stock Shares Granted | shares				211,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period | shares				(218,000)
Number of restricted stock shares outstanding | shares	747,000			747,000		1,216,000
Nonvested Awards, Total Compensation Cost Not yet Recognized	$ 10,000,000			$ 10,000,000
Liability [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Gross	$ 0	(7,000,000)		$ 12,000,000	63,000,000
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Additional shares available for issuance | shares	7,200,000			7,200,000
Share Based Compensation Arrangement By Share Based Payment Award Options Factor Multiplied By Awards Used To Determine Shares Available For Grant				1
Stockholder Value Appreciation Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Payments				$ 0
SVAP Incremental Price Threshold | $ / shares				$ 5
Share-based Compensation Gross	$ (3,000,000)	$ (12,000,000)		$ (3,000,000)	$ 42,000,000
Service Period				3 months
Weighted Average Volatility Rate				47.00%
Liability Settlements				$ 11,000,000		$ 13,000,000
Fair Value Assumptions, Risk Free Interest Rate				0.03%
Stockholder Value Appreciation Program [Member] | $27.50 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SVAP Price Threshold | $ / shares			$ 27.50
Stockholder Value Appreciation Program [Member] | $32.50 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SVAP Price Threshold | $ / shares		$ 32.50
Stockholder Value Appreciation Program [Member] | $37.50 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SVAP Price Threshold | $ / shares		37.50
Stockholder Value Appreciation Program [Member] | $42.50 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SVAP Price Threshold | $ / shares		$ 42.50
Stockholder Value Appreciation Program [Member] | $47.50 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SVAP Price Threshold | $ / shares				$ 47.50
Stockholder Value Appreciation Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Liability Value	$ 200,000			$ 200,000

Stock-Based Compensation- Stock

Stock-Based Compensation- Stock Option Activity (Details)	9 Months Ended
	Sep. 30, 2015shares
Share-based Compensation [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Additional Shares Authorized	7,000,000
Stock option activity
Outstanding, Ending Balance, Number of Shares Underlying Options	200,000
Exercisable, Number of Shares Underlying Options	200,000

Stock-Based Compensation- Sto60

Stock-Based Compensation- Stock Option Summary (Details)	Sep. 30, 2015shares
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Options Outstanding, Number of Shares Underlying Options	200,000
Options Exercisable, Number of Shares Underlying Options	200,000

Stock-Based Compensation- Restr

Stock-Based Compensation- Restricted Stock and Restricted Stock Units Activity (Details) shares in Thousands	9 Months Ended
	Sep. 30, 2015$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	2,847
Granted	1,422
Forfeited	(425)
Vested	(998)
Non-vested shares outstanding, Ending balance	2,846
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Beginning balance | $ / shares	$ 30.05
Granted, Weighted Average Grant Date Fair Value per Share | $ / shares	28.63
Forfeited, Weighted Average Grant Date Fair Value per Share | $ / shares	24.51
Vested, Weighted Average Grant Date Fair Value per Share | $ / shares	33.32
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Ending balance | $ / shares	$ 27.93
Service - Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	1,902
Granted	1,008
Forfeited	(328)
Vested	(815)
Non-vested shares outstanding, Ending balance	1,767
Performance Market Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	945
Granted	414
Forfeited	(97)
Vested	(183)
Non-vested shares outstanding, Ending balance	1,079

Stock-Based Compensation- Emplo

Stock-Based Compensation- Employee Stock Purchase Plan (Details) - Employee Stock Purchase Plan [Member] - $ / shares	3 Months Ended	6 Months Ended
	Sep. 30, 2015	Jun. 30, 2015
Employee Stock Purchase Plan ESPP Disclosures [Line Items]
Options To Purchase Common Stock Shares	49,000	85,000
Weighted average fair value of each option	$ 9.99	$ 7.93
Expected volatility	46.00%	52.00%
Risk-free weighted average interest rate	0.11%	0.12%
Vesting Period	6 months	6 months

Commitments and Contingencies (

Commitments and Contingencies (Details) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)
Commitments and Contingencies (Textuals) [Abstract]
Loss Contingency, Damages Sought, Value	$ 23

Supplemental Cash Flows Infor64

Supplemental Cash Flows Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Supplemental Cash Flow Information [Abstract]
Increase (Decrease) in Other Receivables	$ 8	$ (17)
Non Cash Items Excluded From Statement of Cash Flows [Abstract]
(Increase) decrease in accrued capital expenditures	212	2
Increase in asset retirement costs	$ (4)	$ 18

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Subsequent Event [Line Items]
Long-term Debt, Excluding Current Maturities	$ 2,498	$ 2,892
6.875% Senior Subordinated Notes due 2020 [Member]
Subsequent Event [Line Items]
Long-term Debt, Excluding Current Maturities	$ 0	$ 700
Debt Instrument, Interest Rate, Stated Percentage	6.875%	6.875%

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Operating expenses:
Depreciation, depletion and amortization			$ 721	$ 665
Ceiling test impairment			4,202	0
Allocated income tax (benefit)	$ (665)	$ 155	(1,519)	170
Commodity derivative income (expense)	87	303	230	33
Income (loss) before income taxes	(1,892)	433	(4,218)	453
Total assets	5,513	9,068	5,513	9,068	$ 9,598
Additions to long-lived assets	462	523	1,225	1,577
Domestic [Member]
Segment Information [Line Items]
Oil, gas and NGL revenues	316	610	989	1,771
Operating expenses:
Lease operating	57	73	178	224
Production and other taxes	13	31	43	85
Depreciation, depletion and amortization	184	228	603	628
General and administrative	64	48	174	172
Ceiling test impairment	1,817		4,130
Other	1	10	7	15
Allocated income tax (benefit)	(693)	63	(1,591)	193
Net income (loss) from oil and gas properties	(1,179)	106	(2,708)	329
Total assets	5,114	8,392	5,114	8,392
Additions to long-lived assets	474	485	1,210	1,473
Gas Gathering, Transportation, Marketing and Processing Costs	52	51	153	125
CHINA
Segment Information [Line Items]
Oil, gas and NGL revenues	61	0	206	22
Operating expenses:
Lease operating	14	1	41	4
Production and other taxes	0	1	0	5
Depreciation, depletion and amortization	52	0	118	5
General and administrative	2	0	6	0
Ceiling test impairment	72		72
Other	0	0	1	0
Allocated income tax (benefit)	(47)	(1)	(19)	5
Net income (loss) from oil and gas properties	(32)	(1)	(13)	3
Total assets	399	676	399	676
Additions to long-lived assets	(12)	38	15	104
Gas Gathering, Transportation, Marketing and Processing Costs	0	0	0	0
Continuing Operations [Member]
Segment Information [Line Items]
Oil, gas and NGL revenues	377	610	1,195	1,793
Operating expenses:
Lease operating	71	74	219	228
Production and other taxes	13	32	43	90
Depreciation, depletion and amortization	236	228	721	633
General and administrative	66	48	180	172
Ceiling test impairment	1,889		4,202
Other	1	10	8	15
Total operating expenses	2,328	443	5,526	1,263
Income (loss) from operations	(1,951)	167	(4,331)	530
Interest expenses, net of interest income, capitalized interest and other	(28)	(37)	(117)	(110)
Commodity derivative income (expense)	87	303	230	33
Income (loss) before income taxes	(1,892)	433	(4,218)	453
Gas Gathering, Transportation, Marketing and Processing Costs	$ 52	$ 51	$ 153	$ 125

Stockholders' Equity Activity67

Stockholders' Equity Activity (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Equity [Abstract]
Stock Issued During Period, Shares, New Issues	25,300,000
Stock Issued During Period, Value, New Issues	$ 815
Common Stock, Shares Authorized	300,000,000	200,000,000

Discontinued Operations (Detail

Discontinued Operations (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal Group, Including Discontinued Operation, Consideration		$ 898
Gain on Sale of Malaysia, before Income Tax		(15)		$ 0	$ 388
Gain on Sale of Malaysia, Net of Tax		10			(252)
Disposal Group, Including Discontinued Operation, Operating Income (Loss)					(21)
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	$ 0		$ 0	0	(257)
Discontinued Operation, Tax Effect of Discontinued Operation					152
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	985	677		985
Disposal Group, Including Discontinued Operation, Revenue					90
Disposal Group, Including Discontinued Operation, Operating Expense					69
Disposal Group, Including Discontinued Operation, Operating Income (Loss)					(21)
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax		$ (15)		0	388
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax					(409)
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	$ 0		$ 0	$ 0	(257)
Current [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operation, Tax Effect of Discontinued Operation					12
Deferred [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operation, Tax Effect of Discontinued Operation					$ 140

Restructuring Costs Restructu69

Restructuring Costs Restructuring Costs (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Restructuring Reserve [Roll Forward]
Restructuring Reserve Beg			$ 0
Restructuring Charges	$ 18	$ 0	23	$ 0
Restructuring Reserve, Settled without Cash			8
Restructuring Revisions			0
Restructuring Reserve End	15		15
Restructuring and Related Cost, Cost Incurred to Date	23		23
Restructuring and Related Cost, Expected Cost	32		32
Employee Severance [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve Beg			0
Restructuring Charges			6
Restructuring Settlements			(4)
Restructuring Revisions			0
Restructuring Reserve End	2		2
Restructuring and Related Cost, Cost Incurred to Date	6		6
Restructuring and Related Cost, Expected Cost	7		7
Contract Termination [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve Beg			0
Restructuring Charges			13
Restructuring Settlements			0
Restructuring Revisions			0
Restructuring Reserve End	13		13
Restructuring and Related Cost, Cost Incurred to Date	13		13
Restructuring and Related Cost, Expected Cost	19		19
Employee Relocation [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve Beg			0
Restructuring Charges			3
Restructuring Settlements			(3)
Restructuring Revisions			0
Restructuring Reserve End	0		0
Restructuring and Related Cost, Cost Incurred to Date	3		3
Restructuring and Related Cost, Expected Cost	5		5
Other Restructuring [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve Beg			0
Restructuring Charges			1
Restructuring Reserve, Settled without Cash			1
Restructuring Revisions			0
Restructuring Reserve End	0		0
Restructuring and Related Cost, Cost Incurred to Date	1		1
Restructuring and Related Cost, Expected Cost	1		1
General and Administrative Expense [Member] | Employee Severance [Member]
Restructuring Reserve [Roll Forward]
Restructuring Charges	3	0	6	0
General and Administrative Expense [Member] | Contract Termination [Member]
Restructuring Reserve [Roll Forward]
Restructuring Charges	13	0	13	0
General and Administrative Expense [Member] | Employee Relocation [Member]
Restructuring Reserve [Roll Forward]
Restructuring Charges	2	0	3	0
Depreciation Depletion and Amortization [Member] | Other Restructuring [Member]
Restructuring Reserve [Roll Forward]
Restructuring Charges	$ 0	$ 0	$ 1	$ 0