Newfield Exploration (NFX) 10-K 24 Feb 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Feb. 20, 2015	Jun. 30, 2014
Document and Entity Information [Abstract]
Entity Registrant Name	NEWFIELD EXPLORATION CO /DE/
Entity Central Index Key	912750
Document Type	10-K
Document Period End Date	31-Dec-14
Amendment Flag	FALSE
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	-19
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		137,387,180

Consolidated_Balance_Sheet

Consolidated Balance Sheet (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current assets:
Cash and cash equivalents	$14	$95
Restricted Cash and Cash Equivalents, Current	0	90
Accounts receivable	405	474
Inventories	33	163
Derivative assets	431	0
Deferred Tax Assets, Net, Current	0	22
Other current assets	57	57
Total current assets	940	901
Oil and Gas Property, Full Cost Method, Gross	16,384	16,407
Oil and Gas Property, Full Cost Method, Depletion	8,152	8,306
Oil and Gas Property, Full Cost Method, Net	8,232	8,101
Property, Plant and Equipment, Other, Net	182	174
Derivative assets	190	26
Long-term investments	26	63
Deferred taxes	0	19
Other assets	28	37
Total assets	9,598	9,321
Current liabilities:
Accounts payable	32	76
Accrued liabilities	880	978
Deposit Liability, Current	0	90
Advances from joint owners	34	30
Asset retirement obligations	3	54
Derivative liabilities	8	62
Deferred taxes	144	0
Total current liabilities	1,101	1,290
Other liabilities	45	38
Derivative liabilities	0	0
Long-term debt	2,892	3,694
Deferred taxes	1,484	1,142
Asset retirement obligations	183	201
Total long-term liabilities	4,604	5,075
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)	1	1
Additional Paid in Capital	1,576	1,539
Treasury stock (at cost)	-10	-13
Accumulated other comprehensive loss	-1	2
Retained earnings	2,327	1,427
Total stockholders' equity	3,893	2,956
Total liabilities and stockholders' equity	$9,598	$9,321

Consolidated_Balance_Sheet_Par

Consolidated Balance Sheet (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, except Share data, unless otherwise specified
ASSETS
Property and equipment, at cost, based on the full cost method of accounting for oil and gas properties	$677	$1,300
Stockholders' equity:
Preferred stock ($0.01 par value)	$0.01	$0.01
Preferred stock (5,000,000 shares authorized)	5,000,000	5,000,000
Preferred stock (no shares issued)	0	0
Common stock ($0.01 par value)	$0.01	$0.01
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	137,603,643	136,682,631
Treasury Stock, shares	275,069	460,914
Commitments and Contingencies	$0	$0

Consolidated_Statement_of_Oper

Consolidated Statement of Operations (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Earnings Per Share [Abstract]
Income (Loss) from Continuing Operations, Per Basic Share	$4.76	$0.39	($6.85)
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share	$1.83	$0.55	($1.95)
Earnings (Loss) Per Share, Basic	$6.59	$0.94	($8.80)
Income (Loss) from Continuing Operations, Per Diluted Share	$4.71	$0.39	($6.85)
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share	$1.81	$0.55	($1.95)
Earnings (Loss) Per Share, Diluted	$6.52	$0.94	($8.80)
Operating expenses:
Depreciation, depletion and amortization	$903	$930	$955
Ceiling test impairment	0	0	1,488
Other income (expenses):
Commodity derivative income (expense)	610	-97	120
Income (loss) before income taxes	1,032	201	-1,374
Income tax provision (benefit):
Total income tax provision (benefit)	382	128	-452
Income (Loss) from Continuing Operations Attributable to Parent	650	73	-922
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	250	74	-262
Net income (loss)	900	147	-1,184
Weighted-average number of shares outstanding for basic earnings (loss) per share	137	135	135
Weighted average number of shares outstanding for diluted earnings (loss) per share	138	136	135
Continuing Operations [Member]
Statement [Line Items]
Oil, gas and NGL revenues	2,288	1,857	1,562
Operating expenses:
Lease operating	321	284	306
Gas Gathering, Transportation, Marketing and Processing Costs	174	137	107
Production and other taxes	111	79	85
Depreciation, depletion and amortization	870	685	704
General and administrative	222	219	211
Ceiling test impairment	0	0	1,488
Other	15	3	15
Total operating expenses	1,713	1,407	2,916
Income (loss) from operations	575	450	-1,354
Other income (expenses):
Interest expense	-200	-205	-205
Interest Costs Capitalized Adjustment	53	53	68
Commodity derivative income (expense)	610	-97	120
Other	-6	0	-3
Total other income (expenses)	457	-249	-20
Income (loss) before income taxes	1,032	201	-1,374
Income tax provision (benefit):
Current	5	-2	16
Deferred	377	130	-468
Total income tax provision (benefit)	$382	$128	($452)

Consolidated_Statement_of_Comp

Consolidated Statement of Comprehensive Income (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Net Income (Loss) Attributable to Parent [Abstract]
Net income (loss)	$900	$147	($1,184)
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	0		3
Other Comprehensive Income (Loss), Available-for-sale Securities, Tax, Including OTTI		7
Other comprehensive income (loss):
Other Comprehensive Income (Loss), Net of Tax	-3	9	3
Unrealized gain (loss) on post-retirement benefits, net of tax	-3	2	0
Comprehensive income (loss)	$897	$156	($1,181)

Consolidated_Statement_of_Comp1

Consolidated Statement of Comprehensive Income (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Other Comprehensive Income (Loss), Tax, Portion Attributable to Parent, Parenthetical Disclosures [Abstract]
Other Comprehensive Income (Loss), Available-for-sale Securities, Tax, Including OTTI		$3
Other Comprehensive Income (Loss), Available-for-sale Securities, Tax	0		1
Unrealized gain (loss) on post-retirement benefits tax	($2)	($1)	$0

Consolidated_Statement_of_Stoc

Consolidated Statement of Stockholders' Equity (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Common Stock, shares	137,603,643	136,682,631	136,500,000
Common Stock Value	$1	$1	$1
Treasury Stock, Shares	-275,069	-460,914	-1,200,000
Treasury Stock	-10	-13	-36
Additional Paid in Capital	1,576	1,539	1,522
Retained Earnings (Accumulated Deficit)	2,327	1,427	1,300
Accumulated Other Comprehensive Income (Loss), Net of Tax	-1	2	-7
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	3,893	2,956	2,780
Issuances of common stock, value	6	1	2
Stock-based compensation	45	45	46
Stock Issued During Period, Value, Treasury Stock Reissued	-11	-6	-7
Net income (loss)	900	147	-1,184
Other Comprehensive Income (Loss), Net of Tax	-3	9	3
Payments for Repurchase of Preferred Stock and Preference Stock	0	-20	0
Common Stock
Issuances of common stock, shares	900,000	200,000	100,000
Issuances of common stock, value	0	0	0
Treasury Stock
Stock Issued During Period, Shares, Treasury Stock Reissued	200,000	700,000	500,000
Stock Issued During Period, Value, Treasury Stock Reissued	3	23	14
Additional Paid-in Capital
Issuances of common stock, value	6	1	2
Stock-based compensation	45	45	46
Stock Issued During Period, Value, Treasury Stock Reissued	-14	-29	-21
Retained Earnings
Net income (loss)	900	147	-1,184
Payments for Repurchase of Preferred Stock and Preference Stock		-20
Accumulated Other Comprehensive Income (Loss)
Other Comprehensive Income (Loss), Net of Tax	($3)	$9	$3

Consolidated_Statement_of_Cash

Consolidated Statement of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash flows from operating activities:
Net income (loss)	$900	$147	($1,184)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	903	930	955
Deferred Income Tax Expense (Benefit), Continuing and Discontinuing Operations	509	143	1
Stock-based compensation	28	43	35
Commodity derivative income (expense)	-610	97	-120
Cash receipts on derivative settlements, net	-39	60	135
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax	-373	0	0
Ceiling test impairment	0	0	1,488
Other non-cash charges	21	14	19
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	47	-62	-70
(Increase) decrease in inventories	0	-11	-35
(Increase) decrease in other current assets	-30	12	5
(Increase) decrease in other assets	2	6	7
Increase (decrease) in accounts payable and accrued liabilities	21	74	-77
Increase (decrease) in advances from joint owners	5	-1	-14
Increase (decrease) in other liabilities	3	-7	2
Net cash provided by operating activities	1,387	1,445	1,147
Cash flows from investing activities:
Additions to oil and gas properties	-2,064	-1,987	-1,758
Acquisitions of oil and gas properties	-33	-72	-9
Proceeds from sales of oil and gas properties	620	36	630
Proceeds from Divestiture of Businesses, Net of Cash Divested	809	0	0
Additions to furniture, fixtures and equipment	-31	-36	-22
Redemptions of investments	39	1	0
Net cash used in investing activities	-660	-2,058	-1,159
Cash flows from financing activities:
Proceeds from borrowings under credit arrangements	2,949	3,263	2,844
Repayments of borrowings under credit arrangements	-3,152	-2,614	-2,930
Proceeds from issuance of senior notes	0	0	1,000
Debt issue costs	0	-4	-10
Repayment of senior subordinated notes	-600	0	-875
Proceeds from issuances of common stock	6	1	2
Payments for Repurchase of Preferred Stock and Preference Stock	0	-20	0
Purchases of treasury stock, net	-11	-6	-7
Net cash provided by (used in) financing activities	-808	620	24
Increase (decrease) in cash and cash equivalents	-81	7	12
Cash and cash equivalents, beginning of period	95	88	76
Cash and cash equivalents, end of period	$14	$95	$88

Organization_and_Summary_of_Si

Organization and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Organization and Summary of Significant Accounting Policies	Organization and Summary of Significant Accounting Policies:
	Organization and Principles of Consolidation
	We are an independent energy company engaged in the exploration, development and production of crude oil, natural gas and natural gas liquids (NGLs). Our principal domestic areas of operation include the Mid-Continent, the Rocky Mountains and the onshore Gulf Coast regions of the United States. In addition, we 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.
	Discontinued Operations
	Our businesses in Malaysia and China were classified as held for sale in the second quarter of 2013. As of December 31, 2014, our China business is no longer held for sale, as we concluded the marketing process and were unable to sell at an acceptable price given the significant decrease in oil prices in the fourth quarter of 2014. Therefore, our China business is included in continuing operations for all periods in these financial statements. 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 3, "Discontinued Operations," for additional disclosures, as well as information regarding the sale of our Malaysia business, which closed in February 2014. These financial statements and notes are inclusive of our Malaysia operations unless otherwise noted.
	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. It is possible for any of these effects to occur in the near term, given the recent decline in commodity pricing.
	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
	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.
	Revenue Recognition
	Substantially all of our oil, natural gas and NGLs are sold at market-based prices to a variety of purchasers under short-term contracts (less than 12 months). We also have long-term contracts in the Uinta Basin at market-based prices, less a variable differential that becomes fixed below certain market price thresholds. We record revenue when we deliver our production to the customer and collectability is reasonably assured. Revenues from the production of oil, natural gas and NGLs on properties in which we have joint ownership are recorded under the sales method. Under the sales method, the Company and other joint owners may sell more or less than their entitled share of production. Should the Company’s excess sales exceed our share of estimated remaining recoverable reserves, a liability is recorded. Differences between sales and our entitled share of production are not significant.
	Foreign Currency
	The functional currency for our foreign operations is the U.S. dollar. Gains and losses incurred on transactions in a currency other than a country’s functional currency are recorded under the caption “Other income (expense) — Other, net” on our consolidated statement of operations.
	Cash and Cash Equivalents
	Cash and cash equivalents include highly liquid investments with a maturity of three months or less when acquired and are stated at cost, which approximates fair value. We invest cash in excess of near-term capital and operating requirements in U.S. Treasury Notes, Eurodollar time deposits and money market funds, which are classified as cash and cash equivalents on our consolidated balance sheet.
	Restricted Cash and Deferred Liabilities
	Restricted cash and the associated deferred liability on our consolidated balance sheet at December 31, 2013 represent a deposit received in the fourth quarter of 2013 related to the sale of our Malaysia business. Amounts were contractually restricted until the transaction closed in February 2014. See Note 3, "Discontinued Operations," for further discussion about the close of the sale of the Malaysia business.
	Investments
	Investments consist of debt and equity securities, a majority of which are classified as “available-for-sale” and stated at fair value. Accordingly, unrealized gains and losses and the related deferred income tax effects are excluded from earnings and reported in other comprehensive income within our consolidated statement of stockholders' equity. Realized gains or losses are computed based on specific identification of the securities sold. We regularly assess our investments for impairment and consider any impairment to be other than temporary if we intend to sell the security, it is more likely than not that we will be required to sell the security or we do not expect to recover our cost of the security.
	Allowance for Doubtful Accounts
	We routinely assess material trade and other receivables to determine their collectability. Many of our receivables are from joint interest owners of properties we operate. Thus, we may have the ability to withhold future revenue disbursements to recover any non-payment of joint interest billings. Generally, our oil and gas receivables are collected within 45 to 60 days of production. We accrue a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of the reserve may be reasonably estimated.
	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 international operations. Tubular goods and well equipment inventories are carried at the lower of cost or market. During 2014, we wrote down obsolete inventory across all three of our domestic regions. At December 31, 2012, we wrote down subsea wellhead inventory that was not included in the sale of our Gulf of Mexico assets. The writedowns of $9 million in 2014 and $8 million in 2012 are included in “Operating expenses — Other” on our consolidated statement of operations.
	Substantially all of the crude oil from our offshore operations in China is produced into floating storage facilities and “lifted” and sold periodically as barge quantities are accumulated. At December 31, 2014 and 2013, the crude oil inventory from our China operations consisted of approximately 240,000 and 23,000 barrels of crude oil valued at cost of approximately $8 million and $1 million, respectively, 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. See Note 3, "Discontinued Operations" for details on our Malaysia crude oil inventory.
	Oil and Gas Properties
	We use the full cost method of accounting for our oil and gas producing activities. Under this method, all costs incurred in the acquisition, exploration and development of oil and gas properties, including salaries, benefits, interest and other internal costs directly attributable to these activities, are capitalized into cost centers that are established on a country-by-country basis. We capitalized approximately $199 million, $198 million and $191 million of interest and direct internal costs in 2014, 2013 and 2012, respectively.
	Proceeds from the sale of oil and gas properties are applied to reduce the costs in the applicable cost center unless the reduction would significantly alter the relationship between capitalized costs and proved reserves, in which case a gain or loss is recognized. During the first quarter of 2014, we sold our Malaysia business, which constituted the entire full cost pool for Malaysia. See Note 3, "Discontinued Operations," for further discussion.
	Capitalized costs and estimated future development costs are amortized using a unit-of-production method based on proved reserves associated with the applicable cost center. For each cost center, the net capitalized costs of oil and gas properties are limited to the lower of the unamortized cost or the cost center ceiling. A particular cost center ceiling is equal to the sum of:
	•	the present value (10% per annum discount rate) of estimated future net revenues from proved reserves using oil, natural gas and NGL reserve estimation requirements, which require use of the unweighted average first-day-of-the-month commodity prices for the prior 12 months (SEC pricing), adjusted for market differentials, applicable to our reserves (including the effects of derivative contracts that are designated for hedge accounting, if any); plus
	•	the costs of properties not included in the costs being amortized, if any; less
	•	related income tax effects.
	If net capitalized costs of oil and gas properties exceed the cost center ceiling, we are subject to a ceiling test writedown to the extent of such excess. If required, a ceiling test writedown reduces earnings and stockholders’ equity in the period of occurrence and, holding other factors constant, results in lower depreciation, depletion and amortization expense in future periods.
	The risk that we will be required to writedown the carrying value of our oil and gas properties increases when oil, natural gas and NGL prices decrease significantly for a prolonged period of time or if we have substantial downward revisions in our estimated proved reserves. At December 31, 2014, the ceiling value of our reserves was calculated based upon SEC pricing of $4.35 per MMBtu for natural gas and $94.98 per barrel for oil. Using these prices, our ceilings for the U.S. and China exceeded the net capitalized costs of oil and gas properties by approximately $400 million and $150 million, respectively, net of tax, and as such, no ceiling test writedown was required.
	The continued decline of SEC pricing for oil and natural gas reserves since December 31, 2014 will likely result in a ceiling test writedown in the first quarter of 2015.
	At December 31, 2013, the ceiling value of our reserves was calculated based upon SEC pricing of $3.67 per MMBtu for natural gas and $96.82 per barrel for oil. Using these prices, the cost center ceilings with respect to our domestic and China full cost pools exceeded the net capitalized costs. As such, no ceiling test writedowns were required at December 31, 2013.
	At December 31, 2012, the ceiling value of our reserves was calculated based upon SEC pricing of $2.76 per MMBtu for natural gas and $94.84 per barrel for oil. Using these prices, the unamortized net capitalized costs of our domestic oil and gas properties exceeded the ceiling amount by approximately $1.5 billion ($948 million, after tax). No ceiling test writedown was required for the China full cost pool at December 31, 2012.
	See Note 4, “Oil and Gas Assets,” for a detailed discussion regarding our oil and gas asset acquisitions and sales transactions during 2014, 2013 and 2012.
	Other Property and Equipment
	Furniture, fixtures and equipment are recorded at cost and are depreciated using the straight-line method over their estimated useful lives, which range from three to seven years. Gathering systems and equipment are recorded at cost and depreciated using the straight-line method over their estimated useful lives of 25 years.
	Accounting for Asset Retirement Obligations
	If a reasonable estimate of the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon wells can be made, we record a liability (an asset retirement obligation or ARO) on our consolidated balance sheet and capitalize the present value of the asset retirement cost in oil and gas properties in the period in which the ARO is incurred. Settlements include payments made to satisfy the AROs, as well as transfer of the AROs to purchasers of our divested properties.
	In general, the amount of an ARO and the costs capitalized will equal the estimated future costs to satisfy the abandonment obligation assuming normal operation of the asset, using current prices that are escalated by an assumed inflation factor up to the estimated settlement date, which is then discounted back to the date that the abandonment obligation was incurred using an assumed cost of funds for our Company. After recording these amounts, the ARO is accreted to its future estimated value using the same assumed cost of funds, and the original capitalized costs are depreciated on a unit-of-production basis within the related full cost pool. Both the accretion and the depreciation are included in depreciation, depletion and amortization expense on our consolidated statement of operations.
	The change in our ARO for continuing operations for each of the three years ended December 31, is set forth below:
			2014			2013			2012
			(In millions)
	Balance at January 1		$	122		$	102		$	108
	Accretion expense		8			8			8
	Additions(1)		58			12			20
	Revisions		16			8			12
	Settlements(2)		(18		)	(8		)	(46		)
	Balance at December 31		186			122			102
	Less: Current portion of ARO at December 31		(3		)	(5		)	(5		)
	Total long-term ARO at December 31		$	183		$	117		$	97
	_________________
	-1	For the year ended December 31, 2014, additions include $28 million for our Pearl development in offshore China and $30 million for abandonment obligations in our domestic business.
	-2	For the year ended December 31, 2014, settlements include $10 million related to the sale of our Granite Wash assets. For the year ended December 31, 2012, settlements include $28 million related to the sale of our Gulf of Mexico assets. See Note 4, “Oil and Gas Assets.”
	Contingencies
	We are subject to legal proceedings, claims, liabilities and environmental matters that arise in the ordinary course of business. We accrue for losses when such losses are considered probable and the amounts can be reasonably estimated. See Note 13, “Commitments and Contingencies,” for a more detailed discussion regarding our contingencies.
	Environmental Matters
	Environmental costs that relate to current operations are expensed as incurred. Remediation costs that relate to an existing condition caused by past operations are accrued when it is probable that those costs will be incurred and can be reasonably estimated based upon evaluations of currently available facts related to each site.
	Income Taxes
We use the liability method of accounting for income taxes. Under this method, deferred tax assets and liabilities are determined by applying tax regulations existing at the end of a reporting period to the cumulative temporary differences between the tax bases of assets and liabilities and their reported amounts in our financial statements. A valuation allowance is established to reduce deferred tax assets if it is more likely than not that the related tax benefits will not be realized.
As of December 31, 2014, we did not have a liability for uncertain tax positions, and as such, we did not accrue related interest or penalties. The tax years 2011-2014 remain open to examination for federal income tax purposes and by the other major taxing jurisdictions to which we are subject.
Stock-Based Compensation
We apply a fair value-based method of accounting for stock-based compensation which requires recognition in the financial statements of the cost of services received in exchange for awards of equity instruments based on the grant date fair value of those awards. For equity awards, compensation expense is based on the fair value on the grant or modification date and is recognized in our financial statements over the vesting period. We utilize the Black-Scholes option-pricing model to measure the fair value of stock options and a Monte Carlo lattice-based model for our performance and market-based restricted stock and restricted stock units. We also have cash-settled restricted stock units as well as a Stockholder Value Appreciation Program that are accounted for under the liability method which requires us to recognize the fair value of each award based on the underlying share price at the end of each period. See Note 11, “Stock-Based Compensation,” for a full discussion of our stock-based compensation.
Concentration of Credit Risk
We operate a substantial portion of our oil and gas properties. As the operator of a property, we make full payment for costs associated with the property and seek reimbursement from the other working interest owners in the property for their share of those costs. Our joint interest owners consist primarily of independent oil and gas producers. If the oil and gas exploration and production industry in general was adversely affected, the ability of our joint interest partners to reimburse us could be adversely affected.
The purchasers of our oil, gas and NGL production consist primarily of independent marketers, major oil and gas companies, refiners and gas pipeline companies. We perform credit evaluations of the purchasers of our production and monitor their financial condition on an ongoing basis. Based on our evaluations and monitoring, we obtain cash escrows, letters of credit or parental guarantees from some purchasers.
All of our derivative transactions have been carried out in the over-the-counter market and are not typically subject to margin-deposit requirements. The use of derivative transactions involves the risk that the counterparties will be unable to meet the financial terms of such transactions. The counterparties for all of our derivative transactions have an “investment grade” credit rating. We monitor the credit ratings of our hedging counterparties on an ongoing basis. Although we have entered into derivative contracts with multiple counterparties to mitigate our exposure to any individual counterparty, if any of our counterparties were to default on its obligations to us under the derivative contracts or seek bankruptcy protection, it could have a material adverse effect on our ability to fund our planned activities and could result in a larger percentage of our future production being subject to commodity price changes. In addition, in poor economic environments and tight financial markets, the risk of a counterparty default is heightened and fewer counterparties may participate in hedging transactions, which could result in greater concentration of our exposure to any one counterparty or a larger percentage of our future production being subject to commodity price changes. At December 31, 2014, ten of our 16 counterparties accounted for approximately 85% of our contracted volumes, with no single counterparty accounting for more than 15%. Approximately 40% of our volumes subject to derivative instruments are with lenders under our credit facility. Our credit facility, senior notes, senior subordinated 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.
Major Customers
Tesoro Corporation and Sunoco Logistics Partners Operations GP LLC accounted for 12% and 10%, respectively, of our total revenues in 2014. During 2013, Sunoco Logistics Partners Operations GP LLC, Royal Dutch Shell plc and Tesoro Corporation accounted for 13%, 12%, and 11%, respectively, of our total revenues. During 2012, sales of our oil and gas production to Royal Dutch Shell plc, Tesoro Corporation and Big West Oil LLC accounted for 14%, 14% and 10%, respectively, of our total revenues. We believe that the loss of any of our major customers would not have a material adverse effect on us because alternative purchasers are available.
Derivative Financial Instruments
Our derivative instruments are recorded on the consolidated balance sheet at fair value as either an asset or a liability with changes in fair value recognized currently in earnings. While we utilize our derivative instruments to manage the price risk attributable to our expected oil and gas production, we have elected not to designate our derivative instruments as accounting hedges under the accounting guidance.
The related cash flow impact of our derivative activities are reflected as cash flows from operating activities unless they are determined to have a significant financing element at inception, in which case they are classified within financing activities. See Note 5, “Derivative Financial Instruments,” for a more detailed discussion of our derivative activities.
Offsetting Assets and Liabilities
Our derivative financial instruments are subject to master netting arrangements and are reflected on our consolidated balance sheet accordingly. See Note 5, "Derivative Financial Instruments," for details regarding the gross amounts, as well as the impact of our netting arrangements on our net derivative position. We only offset assets and liabilities in relation to our derivative financial instruments.
Accumulated Other Comprehensive Income
At December 31, 2012, accumulated other comprehensive income (“AOCI”) included unrealized losses related to auction rate securities that were deemed to be temporary as the Company had the intent and ability to hold the securities to maturity. As of December 31, 2013, the Company changed its intention and considered plans to sell the securities. As a result, the losses previously accumulated in AOCI related to these securities were transferred and recognized in the consolidated statement of operations for the year ended December 31, 2013. During the first quarter of 2014, all auction rate securities were sold for $39 million. The change in AOCI for the indicated periods is set forth below:
		Unrealized Gains / (Losses) in
		Accumulated Other Comprehensive Income
		Available-for-Sale Securities			Post-Retirement Benefits			Total
		(In millions, net of tax)
Balance at January 1, 2012		$	(9	)	$	(1	)	$	(10	)
Current period other comprehensive income (loss)		3			—			3
Balance at December 31, 2012		(6		)	(1		)	(7		)
Other comprehensive income before reclassifications		3			2			5
Amounts reclassified from accumulated other comprehensive income		4			—			4
Net current period other comprehensive income (loss)		7			2			9
Balance at December 31, 2013		1			1			2
Current period other comprehensive income (loss)		—			(3		)	(3		)
Balance at December 31, 2014		$	1		$	(2	)	$	(1	)
New Accounting Requirements
In August 2014, the FASB issued guidance regarding disclosures of uncertainties about an entity's ability to continue as a going concern. The guidance applies prospectively to all entities, requiring management to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity's ability to continue as a going concern and disclose certain information when substantial doubt is raised. The guidance is effective for interim and annual periods beginning on or after December 15, 2016. We do not expect this guidance to impact our Company.
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. The guidance is effective for interim and annual periods beginning on or after December 15, 2016. We are currently evaluating the impact of this guidance on our financial statements.
In April 2014, the FASB issued guidance regarding the reporting of discontinued operations. The guidance applies prospectively to new disposals and new classifications of disposal groups as held for sale after the effective date. The guidance is effective for interim and annual periods beginning on or after December 15, 2014. We do not expect this guidance to impact our Company.

Earnings_Per_Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Earnings Per Share Text Block	Earnings Per Share:
	Basic earnings per share (EPS) is calculated by dividing net income, less any applicable adjustments, (the numerator) by the weighted-average number of shares of common stock (excluding unvested restricted stock and restricted stock units) outstanding during the period (the denominator). Diluted EPS incorporates the dilutive impact of outstanding stock options and unvested restricted stock and restricted stock units (using the treasury stock method). Under the treasury stock method, the amount the employee must pay for exercising stock options, the amount of unrecognized compensation expense related to unvested stock-based compensation grants and the amount of excess tax benefits that would be recorded when the award becomes deductible are assumed to be used to repurchase shares. See Note 11, “Stock-Based Compensation.”
	The following is the calculation of basic and diluted weighted-average shares outstanding and EPS for the indicated years:
			2014		2013			2012
			(In millions, except per share data)
	Income (numerator):
	Income (loss) from continuing operations		$	650	$	73		$	(922	)
	Income (loss) from discontinued operations, net of tax		250		74			(262		)
	Net income (loss)		900		147			(1,184		)
	Repurchase of preferred shares of subsidiary(3)		—		(20		)	—
	Net income (loss) attributable to common stockholders		$	900	$	127		$	(1,184	)
	Weighted-average shares (denominator):
	Weighted-average shares — basic		137		135			135
	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		138		136			135
	Earnings (loss) per share:
	Basic:
	Income (loss) from continuing operations before preferred share repurchase		$	4.76	$	0.54		$	(6.85	)
	Repurchase of preferred shares of subsidiary(3)		—		(0.15		)	—
	Income (loss) from continuing operations		4.76		0.39			(6.85		)
	Income (loss) from discontinued operations		1.83		0.55			(1.95		)
	Basic earnings (loss) per share		$	6.59	$	0.94		$	(8.80	)
	Diluted:
	Income (loss) from continuing operations before preferred share repurchase		$	4.71	$	0.54		$	(6.85	)
	Repurchase of preferred shares of subsidiary(3)		—		(0.15		)	—
	Income (loss) from continuing operations		4.71		0.39			(6.85		)
	Income (loss) from discontinued operations		1.81		0.55			(1.95		)
	Diluted earnings (loss) per share		$	6.52	$	0.94		$	(8.80	)
	_________________
	-1	Excludes 1.1 million and 4.0 million shares of unvested restricted stock or restricted stock units and stock options for the years ended December 31, 2014 and 2013, respectively, because including the effect would have been anti-dilutive.
	-2	The effect of unvested restricted stock or restricted stock units and stock options has not been included in the calculation of shares outstanding for diluted EPS for the year ended December 31, 2012, as their effect would have been anti-dilutive. Had we recognized income from continuing operations for that year, incremental shares attributable to the assumed vesting of unvested restricted stock and restricted stock units and the assumed exercise of outstanding stock options would have increased diluted weighted-averages shares outstanding by 0.7 million shares for the year ended December 31, 2012.
	-3	The numerator includes an adjustment of $20 million related to the repurchase of preferred shares of a now wholly-owned subsidiary, which reduces net income (loss) for purposes of earnings per share for the year ended December 31, 2013. The subsidiary is part of our continuing operations. See Note 16, "Related Party Transaction," for additional information.

Discontinued_Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2014
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, Newfield International Holdings Inc., a wholly-owned subsidiary of the Company, 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). As of the date of this report, the final post-close settlement is pending due to a dispute with the purchaser that arose subsequent to closing and could possibly go to arbitration. 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.
	Results of Discontinued Operations
		Year Ended December 31,
		2014			2013			2012
		(In millions)
	Oil and gas revenues (1)	$	90		$	823		$	1,005
	Operating expenses	69			652			618
	Income from discontinued operations	21			171			387
	Other income (expense)	—			4			(1		)
	Gain on sale of Malaysia business	373			—			—
	Income from discontinued operations before income taxes	394			175			386
	Income tax provision (benefit):
	Current	12			88			179
	Deferred	132			13			469
	Total income tax provision (benefit)	144			101			648
	Income (loss) from discontinued operations, net of tax	$	250		$	74		$	(262	)
	________________
	(1) Certain payments to foreign governments made on our behalf that are part of the revenue process are recorded as a reduction of the related oil and gas revenues.
	Income Taxes
	Historically, our effective tax rate in Malaysia was approximately 38%. As a result of our December 2012 decision to repatriate earnings from our international operations, we experienced higher international effective tax rates due to these earnings being taxed both in the U.S. and the local country. For the year ended 2014, our effective tax rate in Malaysia was 37% as the majority of our income from discontinued operations resulted from the gain on the sale of our Malaysia business, which was only taxable in the U.S. The effective tax rate for our discontinued operations for the years ended 2013 and 2012 was 58% and 168%, respectively, due to our international earnings being taxed both in the U.S and the local country.
	Assets and Liabilities in the Consolidated Balance Sheet Attributable to Discontinued Operations
		December 31,
		2013
		(In millions)
	Current assets:
	Cash and cash equivalents	$	55
	Accounts receivable	142
	Inventories	121
	Other current assets	29
	Total current assets	347
	Noncurrent assets:
	Oil and gas properties, net of accumulated depreciation, depletion and amortization of $1,009 as of December 31, 2013	547
	Deferred taxes	19
	Other assets	3
	Total noncurrent assets	569
	Total assets	$	916
	Current liabilities:
	Accounts payable	$	34
	Accrued liabilities	185
	Asset retirement obligations	49
	Other current liabilities	18
	Total current liabilities	286
	Noncurrent liabilities:
	Asset retirement obligations	84
	Deferred taxes	29
	Other liabilities	11
	Total noncurrent liabilities	124
	Total liabilities	$	410
	Inventories
	At December 31, 2013, the crude oil inventory from our Malaysia operations consisted of approximately 1.1 million barrels of crude oil valued at cost of $89 million and is included in the "Inventories" line item in the preceding table and in our consolidated balance sheet. Cost for purposes of the carrying value of oil inventory is the sum of production costs and depletion expense.
	Oil and Gas Properties
	At December 31, 2013, we performed a fair value assessment of our discontinued operations, noting no indication of impairment based on the carrying value.
	During 2012, when our Malaysia business was reported as continuing operations, we performed a ceiling test for the full cost pool. The ceiling value of our reserves was calculated based upon SEC pricing of $2.76 per MMBtu for natural gas and $94.84 per barrel for oil. Using these prices, the cost center ceiling with respect to our Malaysia full cost pool exceeded the net capitalized costs of the respective cost center at December 31, 2012 and as such, no ceiling test writedown was required.
	The change in our ARO for our discontinued operations for each of the three years ended December 31, is set forth below:
		2014			2013			2012
		(In millions)
	Balance at January 1	$	133		$	40		$	37
	Accretion expense	1			3			3
	Additions	—			4			4
	Revisions	—			101			—
	Settlements (1)	(134		)	(15		)	(4		)
	Balance at December 31	—			133			40
	Less: Current portion of ARO at December 31	—			(49		)	(5		)
Total long-term ARO at December 31	$	—		$	84		$	35
________________
(1) Obligations reduced as a result of the sale of our Malaysia business in February 2014.

Oil_and_Gas_Assets

Oil and Gas Assets	12 Months Ended
	Dec. 31, 2014
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 at December 31:
		2014			2013
		(In millions)
	Oil and gas properties:
	Subject to amortization	$	15,707		$	15,107
	Not subject to amortization	677			1,300
	Gross oil and gas properties	16,384			16,407
	Accumulated depreciation, depletion and amortization	(8,152		)	(8,306		)
	Net oil and gas properties	$	8,232		$	8,101
	Other property and equipment:
	Furniture, fixtures and equipment	$	144		$	139
	Gathering systems and equipment	114			104
	Accumulated depreciation and amortization	(76		)	(69		)
	Net other property and equipment	$	182		$	174
	Oil and gas properties not subject to amortization represent investments in unproved properties and major development projects in which we own an interest. These unproved property costs include unevaluated leasehold acreage, geological and geophysical data costs associated with leasehold or drilling interests, costs associated with wells in progress at year-end and capitalized internal costs. We exclude these costs on a country-by-country basis until proved reserves are found or until it is determined that the costs are impaired. Unproved property costs are grouped by major prospect area where individual property costs are not significant and are assessed individually when individual costs are significant. Costs associated with wells in progress are transferred to the amortization base upon the determination of whether proved reserves can be assigned to the properties, which is generally based on drilling results. All other costs excluded from the amortization base are reviewed quarterly to determine if impairment has occurred. The amount of any impairment is transferred to the amortization base or a charge is made against earnings for international operations if a reserve base has not yet been established.
	During the fourth quarter of 2014, crude oil and natural gas prices declined to price levels that are likely to change our future development plans in certain operating areas of our domestic business. Accordingly, we transferred approximately $760 million of costs that were previously withheld from the full cost pool into the full cost pool amortization base.
	Oil and gas properties not subject to amortization as of December 31, 2014, consisted of the following:
		Costs Incurred In
		2014			2013			2012		2011 and Prior		Total
		(In millions)
	Acquisition costs	$	185		$	159		$	41	$	84	$	469
	Exploration costs	111			—			—		3		114
	Fee mineral interests	—			1			—		23		24
	Capitalized interest	53			17			—		—		70
	Total oil and gas properties not subject to amortization	$	349		$	177		$	41	$	110	$	677
	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.
	Gulf of Mexico Asset Sale
	In October 2012, we closed the sale of our remaining assets in the Gulf of Mexico to W&T Offshore, Inc. for approximately $208 million, subject to customary post-closing adjustments. The sale of our remaining assets in the Gulf of Mexico 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 Gulf of Mexico operations through the date of sale.
	Other Asset Acquisitions and Sales
	During 2014, 2013 and 2012, we acquired various other oil and gas properties for approximately $33 million, $72 million and $9 million, respectively, and sold certain other oil and gas properties for proceeds of approximately $69 million, $36 million and $422 million, respectively. The cash flows and results of operations for the assets included in a sale are included in our consolidated financial statements up to the date of sale. All of the proceeds associated with our asset sales were recorded as adjustments to our domestic full cost pool.

Derivative_Financial_Instrumen

Derivative Financial Instruments	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedges, Assets [Abstract]
Derivative Financial Instruments Text Block	Derivative Financial Instruments:
	Commodity Derivative Instruments
	We utilize the following derivative strategies, which 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 domestic oil and natural gas production.
	•	Fixed-price swaps. With respect to a swap position, the counterparty is required to make a payment to us if the settlement price for any settlement period is less than the swap strike price, and we are required to make a payment to the counterparty if the settlement price for any settlement period is greater than the swap strike price.
	•	Collars (combination of purchased put options (floor) and sold call options (ceiling)). For a collar position, the counterparty is required to make a payment to us if the settlement price for any settlement period is below the floor strike price while we are required to make payment to the counterparty if the settlement price for any settlement period is above the ceiling strike price. Neither party is required to make a payment to the other party if the settlement price for any settlement period is equal to or greater than the floor strike price and equal to or less than the ceiling strike price.
	•	Fixed-price swaps with sold puts. A swap with a sold put position consists of a standard swap position plus a put sold by us with a strike price below the associated fixed-price swap. This structure enables us to increase the fixed-price swap with the value received through the sale of the put. If the settlement price for any settlement period falls equal to or below the put strike price, then we will only receive the difference between the swap price and the put strike price. If the settlement price is greater than the put strike price, the result is the same as it would have been with a standard swap only.
	•	Collars with sold puts. A collar with a sold put position consists of a standard collar position plus a put sold by us with a strike price below the floor strike price of the collar. This structure enables us to improve the collar strike prices with the value received through the sale of the additional put. If the settlement price for any settlement period falls equal to or below the additional put strike price, then we will receive the difference between the floor strike price and the additional put strike price. If the settlement price is greater than the additional put strike price, the result is the same as it would have been with a standard collar only.
	•	Swaptions. A swaption is an option to exercise a swap where the buyer (counterparty) of the swaption purchases the right from the seller (Newfield), but not the obligation, to enter into a fixed-price swap with the seller on a predetermined date (expiration date). The swap price is a fixed price determined at the time of the swaption contract. If the swaption is exercised, the contract will become a swap treated consistent with our other fixed-price swaps.
	While the use of these 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. For discussion of the accounting policies associated with our derivative financial instruments (including the offsetting of derivative assets and liabilities), see Note 1, "Organization and Summary of Significant Accounting Policies."
	Our oil and gas derivative contracts are settled based upon reported prices on the NYMEX. The estimated fair value of these contracts is based upon various factors, including closing exchange prices on the NYMEX, over-the-counter quotations, estimated volatility, non-performance risk adjustments using credit default swaps, interest rates and time to maturity. The calculation of the fair value of options requires the use of an option-pricing model. See Note 8, “Fair Value Measurements.”
	At December 31, 2014, we had outstanding derivative positions as set forth in the tables below.
	Natural Gas
		Period and Type of Instrument					NYMEX Contract Price Per MMBtu
															Collars
				Volume in			Swaps				Sold Puts(Weighted				Floors(Weighted			Ceilings(Weighted				Estimated
				MMMBtus			(Weighted				Average)				Average)			Average)				Fair Value
							Average)															Asset
																						(Liability)
																						(In millions)
		2015:00:00
		Fixed-price swaps		49,275			$	4.28			$	—			$	—		$	—			$	62
		Collars		38,325			—				—				3.93			4.74				36
		2016:00:00
		Swaptions (1)		—			4.1				—				—			—				(2		)
		Collars		10,980			—				—				4			4.54				7
		Total																				$	103
	_________________
	-1	During the fourth quarter of 2014, we sold natural gas swaption contracts that, if exercised on their expiration date in the second quarter of 2015, would protect 14,640 MMMBtus of calendar-year 2016 production from future commodity price volatility. These contracts give the counterparties the option to enter into swap contracts with us at $4.10/MMBtu for calendar-year 2016.
	Crude Oil
						NYMEX Contract Price Per Bbl
														Collars							Estimated Fair Value
	Period and Type of Instrument		Volume in MBbls			Swaps				Sold Puts				Floors			Ceilings				Asset (Liability)
						(Weighted Average)				(Weighted Average) (1)				(Weighted Average)			(Weighted Average)
																					(In millions)
	2015:00:00
	Fixed-price swaps		2,275			$	90.2			$	—			$	—		$	—			$	78
	Fixed-price swaps with sold puts:		15,019
	Fixed-price swaps					90.02				—				—			—				495
	Sold puts					—				71.67				—			—				(258		)
	Collars with sold puts:		730
	Collars					—				—				90			104				25
	Sold puts					—				75				—			—				(15		)
	2016:00:00
	Fixed-price swaps with sold puts:		10,060
	Fixed-price swaps					89.98				—				—			—				266
	Sold puts					—				74.14				—			—				(174		)
	Collars with sold puts:		6,220
	Collars					—				—				90			96.15				170
	Sold puts					—				75				—			—				(112		)
	Swaptions (2)		—			91				—				—			—				—
	2017:00:00
	Fixed-price swaps with sold puts:		4,468
	Fixed-price swaps					88.37				—				—			—				93
	Sold puts					—				73.28				—			—				(72		)
	Collars with sold puts:		2,080
	Collars					—				—				90			95.59				50
	Sold puts					—				75				—			—				(36		)
	Total																				$	510
	_________________
	-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.
	-2	During the third quarter of 2014, we sold crude oil swaption contracts that, if exercised on their expiration date in the first quarter of 2015, would protect 732 MBbls of calendar-year 2016 production from future commodity price volatility. These contracts give the counterparties the option to enter into swap contracts with us at $91.00/Bbl for calendar-year 2016.
	Additional Disclosures about Derivative 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
31-Dec-14		(In millions)															(In millions)
Natural gas positions		$	105			$	(2	)		$	99			$	4		$	(2	)		$	2		$	—		$	—
Oil positions		1,115				(597		)		332				186			(605		)		597			(8		)	—
Total		$	1,220			$	(599	)		$	431			$	190		$	(607	)		$	599		$	(8	)	$	—
31-Dec-13
Natural gas positions		$	11			$	(2	)		$	—			$	9		$	(22	)		$	2		$	(20	)	$	—
Oil positions		26				(9		)		—				17			(51		)		9			(42		)	—
Total		$	37			$	(11	)		$	—			$	26		$	(73	)		$	11		$	(62	)	$	—
The amount of gain (loss) recognized in “Commodity derivative income (expense)” in our consolidated statement of operations related to our derivative financial instruments follows:
		Year Ended December 31,
		2014				2013				2012
		(In millions)
Derivatives not designated as hedging instruments:
Realized gain (loss) on natural gas positions		$	(36	)		$	66			$	144
Realized gain (loss) on oil positions		(3		)		(6		)		1
Realized gain (loss) on basis positions		—				—				(10		)
Total realized gain (loss)		(39		)		60				135
Unrealized gain (loss) on natural gas positions		114				(81		)		(124		)
Unrealized gain (loss) on oil positions		535				(76		)		99
Unrealized gain (loss) on basis positions		—				—				10
Total unrealized gain (loss)		649				(157		)		(15		)
Total gain (loss)		$	610			$	(97	)		$	120

Accounts_Receivable

Accounts Receivable	12 Months Ended
	Dec. 31, 2014
Accounts Receivable, Net, Current [Abstract]
Loans, Notes, Trade and Other Receivables Disclosure [Text Block]	Accounts Receivable:
	Accounts receivable consisted of the following at December 31:
		2014			2013
		(In millions)
	Revenue	$	155		$	294
	Joint interest	230			156
	Other	36			25
	Reserve for doubtful accounts	(16		)	(1		)
	Total accounts receivable, net	$	405		$	474
	Reserve for doubtful accounts at December 31, 2014 includes an allowance for $15 million related to discontinued operations. See Note 3, "Discontinued Operations."

Accrued_Liabilities

Accrued Liabilities	12 Months Ended
	Dec. 31, 2014
Accrued Liabilities, Current [Abstract]
Accounts Payable and Accrued Liabilities Disclosure [Text Block]	Accrued Liabilities:
	Accrued liabilities consisted of the following at December 31:
		2014		2013
		(In millions)
	Revenue payable	$	197	$	175
	Accrued capital costs	441		458
	Accrued lease operating expenses	47		71
	Employee incentive expense	62		64
	Accrued interest on debt	67		72
	Taxes payable	32		93
	Other	34		45
	Total accrued liabilities	$	880	$	978

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2014
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 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 11, “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			Significant			Significant				Total
			in Active			Other			Unobservable
			Markets for			Observable			Inputs
			Identical Assets			Inputs			(Level 3)
			or Liabilities			(Level 2)
			(Level 1)
			(In millions)
	As of December 31, 2013:
	Money market fund investments		$	2		$	—		$	—			$	2
	Deferred compensation plan assets		8			—			—				8
	Investments available-for-sale:
	Equity securities		8			—			—				8
	Auction rate securities		—			—			39				39
	Oil and gas derivative swap contracts		—			(28		)	—				(28		)
	Oil and gas derivative option and swaption contracts		—			—			(8		)		(8		)
	Stock-based compensation liability awards		(11		)	—			(5		)		(16		)
	Total		$	7		$	(28	)	$	26			$	5
	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
	The determination of the fair values 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.
	As of December 31, 2013, we held $39 million of auction rate securities, which were classified as a Level 3 fair value measurement. During the first quarter of 2014, all auction rate securities were sold for $39 million.
	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, 2012		$	32		$	71		$	—			$	103
	Realized or unrealized gains (losses):
	Included in earnings		—			135			—				135
	Included in other comprehensive income (loss)		4			—			—				4
	Purchases, issuances, sales and settlements:
	Settlements		—			(91		)	—				(91		)
	Transfers in to Level 3		—			—			—				—
	Transfers out of Level 3		—			—			—				—
	Balance at December 31, 2012		$	36		$	115		$	—			$	151
	Change in unrealized gains or losses included in earnings relating to		$	—		$	82		$	—			$	82
	Level 3 instruments still held at December 31, 2012
	Balance at January 1, 2013		$	36		$	115		$	—			$	151
	Realized or unrealized gains (losses):
	Included in earnings		(6		)	(66		)	(18		)		(90		)
	Included in other comprehensive income (loss)		10			—			—				10
	Purchases, issuances, sales and settlements:
	Settlements		(1		)	(57		)	13				(45		)
	Transfers in to Level 3		—			—			—				—
	Transfers out of Level 3		—			—			—				—
	Balance at December 31, 2013		$	39		$	(8	)	$	(5	)		$	26
	Change in unrealized gains or losses included in earnings relating to		$	(6	)	$	(10	)	$	—			$	(16	)
	Level 3 instruments still held at December 31, 2013
Balance at January 1, 2014		$	39		$	(8	)	$	(5	)		$	26
Realized or unrealized gains (losses):
Included in earnings		—			(381		)	(38		)		(419		)
Included in other comprehensive income (loss)		—			—			—				—
Purchases, issuances, sales and settlements:
Sales		(39		)	—			—				(39		)
Settlements		—			5			40				45
Transfers in to Level 3		—			—			—				—
Transfers out of Level 3(1)		—			3			—				3
Balance at December 31, 2014		$	—		$	(381	)	$	(3	)		$	(384	)
Change in unrealized gains or losses included in earnings relating to		$	—		$	(375	)	$	2			$	(373	)
Level 3 instruments still held at December 31, 2014
________
-1	During the second quarter of 2014, we transferred $3 million of derivative option contracts out of the Level 3 hierarchy. The transfer was a result of our Level 3 swaptions being exercised by the counterparties as swaps on May 30, 2014.
Qualitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements
Investments.   As of December 31, 2013, we held $39 million of auction rate securities maturing beginning in 2033 that were classified as a Level 3 fair value measurement. This amount reflected an other than temporary decrease in the fair value of these investments since the time of purchase of $6 million ($4 million net of tax) recorded in 2013 under the caption "Other income (expense) — Other, net" on our consolidated statement of operations as a result of our 2013 decision to liquidate our auction rate investments. During the first quarter of 2014, all auction rate securities were sold for $39 million.
Derivatives.   Our valuation models for Level 3 derivative option contracts are primarily industry-standard models that consider various factors, including certain significant unobservable inputs such as (a) volatility factors and (b) 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 5, "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		Unobservable Input	Range
					Technique
		(In millions)
Oil option and swaption contracts		$	(422	)	Black-Scholes		Oil price volatility	28.03	%	—	63.41%
							Credit risk	0.01	%	—	1.76%
Natural gas option and swaption contracts		$	41		Black-Scholes		Natural gas price volatility	23.11	%	—	60.53%
							Credit risk	0.01	%	—	1.12%
SVAP		$	(3	)	Monte Carlo		Implied volatility				50.20%
Fair Value of Debt
The estimated fair value of our notes, based on quoted prices in active markets (Level 1) as of December 31, was as follows:
		2014			2013
		(In millions)
5¾% Senior Notes due 2022		$	772		$	767
5⅝% Senior Notes due 2024		989			1,025
7⅛% Senior Subordinated Notes due 2018		—			624
6⅞% Senior Subordinated Notes due 2020		721			755
Any amounts outstanding under our revolving credit facility and money market lines of credit are at variable rates as of the indicated dates and are stated at cost, which approximates fair value. Please see Note 9, "Debt."

Debt

Debt	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt Text Block	Debt:
	At December 31, our debt consisted of the following:
			2014			2013
			(In millions)
	Senior unsecured debt:
	Revolving credit facility — LIBOR based loans		$	345		$	585
	Money market lines of credit(1)		101			64
	Total credit arrangements		446			649
	5¾% Senior Notes due 2022		750			750
	5⅝% Senior Notes due 2024		1,000			1,000
	Total senior unsecured debt		2,196			2,399
	7⅛% Senior Subordinated Notes due 2018		—			600
	6⅞% Senior Subordinated Notes due 2020		700			700
	Discount on notes		(4		)	(5		)
	Total long-term debt		$	2,892		$	3,694
	_________________
	-1	Because we have the ability and intent to use our available credit facility capacity 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
	We have a revolving credit facility that matures in June 2018 and provides borrowing capacity of $1.4 billion. As of December 31, 2014, the largest individual loan commitment by any lender was 14% 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 December 31, 2014) 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 December 31, 2014).
	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 December 31, 2014). We incurred aggregate commitment fees under our credit facility of approximately $4 million, $3 million and $3 million for each of the years ended December 31, 2014, 2013 and 2012, respectively, which are recorded in “Interest expense” on our consolidated statement of operations.
	Our credit facility has restrictive financial covenants that include the maintenance of a ratio of total debt to book capitalization not to exceed 0.6 to 1.0 and 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 December 31, 2014, we were in compliance with all of our debt covenants.
	As of December 31, 2014, 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 December 31, 2014).
	Subject to compliance with the restrictive covenants in our credit facility, at December 31, 2014, we also had a total of $94 million of additional, available borrowing capacity under 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 and senior subordinated 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, senior subordinated notes and substantially all of our derivative arrangements contain provisions that provide for cross defaults and acceleration of those debt and derivative instruments in certain situations. See Note 1, " Organization and Principles of Consolidation – Concentration of Credit Risk," for additional details.
	Senior Notes
	In June 2012, we issued $1 billion of 5⅝% Senior Notes due 2024 and received proceeds of $990 million (net of offering costs). These notes were issued at par to yield 5⅝%. We used a portion of the net proceeds to repay borrowings outstanding under our credit facility and money market lines of credit as well as redeem our 6⅝% Senior Subordinated Notes due 2016.
	Interest on our senior notes is payable semi-annually. The notes are unsecured and unsubordinated obligations and rank equally with all of our other existing and future unsecured and unsubordinated obligations. We may redeem some or all of our senior notes at any time before their maturity at a redemption price based on a make-whole amount plus accrued and unpaid interest to the date of redemption. The indentures governing our senior notes contain covenants that may limit our ability to, among other things, incur debt secured by liens; enter into sale/leaseback transactions; and enter into merger or consolidation transactions.
	The indentures also provide that if any of our subsidiaries guarantee any of our indebtedness at any time in the future, then we will cause our senior notes to be equally and ratably guaranteed by that subsidiary. At December 31, 2014, we were in compliance with all of our debt covenants.
	Senior Subordinated Notes
	In October 2014, we redeemed our $600 million aggregate principal amount of 7⅛% Senior Subordinated Notes due 2018. In connection with the redemption, we paid a premium of $14 million. The premium was recorded under the caption "Other income (expense) — Other, net" on our consolidated statement of operations. In addition, unamortized offering costs of approximately $3 million were charged to interest expense as a result of the repayment.
	We may redeem some or all of our 6⅞% Senior Subordinated Notes due 2020 at any time on or after February 1, 2015 at a redemption price stated in the indenture governing the notes. Interest on our senior subordinated notes is payable semi-annually. The notes are unsecured senior subordinated obligations that rank junior in right of payment to all of our present and future senior indebtedness.
	The indenture governing our senior subordinated notes may limit our ability under certain circumstances to, among other things:
	•	incur additional debt;
	•	make restricted payments; and
	•	engage in mergers; consolidations; and sales and other dispositions of assets.
	At December 31, 2014, we were in compliance with all of our debt covenants.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Taxes Text Block	Income Taxes:
	For the years ended December 31, income (loss) from continuing operations before income taxes consisted of the following:
		2014			2013			2012
		(In millions)
	U.S.	$	1,022		$	170		$	(1,414	)
	International	10			31			40
	Total income (loss) before income taxes	$	1,032		$	201		$	(1,374	)
	For the years ended December 31, the total provision (benefit) for income taxes for continuing operations consisted of the following:
		2014			2013			2012
		(In millions)
	Current taxes:
	U.S. federal	$	—		$	(4	)	$	1
	U.S. state	2			—			1
	International	3			2			14
	Deferred taxes:
	U.S. federal	350			53			(479		)
	U.S. state	25			13			(34		)
	International	2			64			45
	Total provision (benefit) for income taxes	$	382		$	128		$	(452	)
	The provision (benefit) for income taxes for continuing operations for the indicated years was different than the amount computed using the federal statutory rate (35%) for the following reasons:
		2014			2013			2012
		(In millions)
	Amount computed using the statutory rate	$	361		$	70		$	(481	)
	Increase (decrease) in taxes resulting from:
	State and local income taxes, net of federal effect	17			8			(18		)
	Valuation allowance, state net of federal	—			(2		)	—
	Foreign tax on foreign earnings	1			53			47
	Other	3			(1		)	—
	Total provision (benefit) for income taxes	$	382		$	128		$	(452	)
	In fourth quarter 2012, we made a decision to repatriate earnings from our international operations. By doing so we made an election to have our China business be treated as a disregarded entity for U.S. federal income tax purposes, which resulted in earnings and profits of our international business in China being taxed both in the United States and China. Due to our NOL carryforward position, we do not expect to be able to utilize related foreign tax credits (FTC) before they expire and accordingly recorded a full valuation allowance against these credits. These FTCs are utilized in the alternative minimum tax (AMT) system to reduce current cash taxes. The result is a high effective tax rate in periods where our book income in China is high relative to our domestic book income. These effective tax rate fluctuations are magnified when net income approaches zero.
	At December 31, the components of our deferred tax asset (liability) were as follows:
		2014			2013
		(In millions)
	Deferred tax asset:
	Net operating loss carryforwards	$	173		$	335
	Alternative minimum tax credit	99			99
	Stock-based compensation	26			25
	Marketable securities	—			3
	Oil and gas properties	—			59
	Foreign tax credit	547			535
	Commodity derivatives	—			13
	Other	8			6
	Total deferred tax asset	853			1,075
	Deferred tax asset valuation allowances	(549		)	(584		)
	Net deferred tax asset	304			491
	Deferred tax liability:
	Commodity derivatives	(217		)	—
	Oil and gas properties	(1,715		)	(1,592		)
	Total deferred tax liability	(1,932		)	(1,592		)
	Net deferred tax liability	(1,628		)	(1,101		)
	Less: Net current deferred tax asset (liability)	(144		)	22
	Net noncurrent deferred tax liability	$	(1,484	)	$	(1,123	)
	As of December 31, 2014 and 2013, we had gross net operating loss (NOL) carryforwards of approximately $0.5 billion and $1.0 billion for federal income tax and $1.6 billion and $1.7 billion for state income tax purposes, respectively, which may be used in future years to offset taxable income. NOL carryforwards of $155 million are subject to annual limitations due to stock ownership changes. We currently estimate that we will not be able to utilize $64 million of our various gross state NOLs because we do not have sufficient estimated future taxable income in the appropriate jurisdictions. To the extent not utilized, the federal NOL carryforwards will begin to expire during the years 2019 through 2033.
	As of December 31, 2013, we had gross NOL carryforwards for international income tax purposes of approximately $17 million. In the fourth quarter of 2014, we wrote off the deferred tax asset and related valuation allowance since we have ceased operating in these jurisdictions and it is remote that the NOL carryforwards will be realized in the future.
	As of December 31, 2014 and 2013, we had foreign tax credits of approximately $547 million and $535 million, respectively, which will expire during the years 2022 through 2024.
	Utilization of deferred tax assets is dependent upon generating sufficient future taxable income in the appropriate jurisdictions within the carryforward period. Estimates of future taxable income can be significantly affected by changes in oil, gas and NGL prices; estimates of the timing and amount of future production; and estimates of future operating and capital costs. Therefore, no certainty exists that we will be able to fully utilize our existing deferred tax assets.
	The change in our deferred tax asset valuation allowance is as follows at December 31:
		2014			2013			2012
		(In millions)
	Balance at the beginning of the year	$	(584	)	$	(457	)	$	(11	)
	Charged to provision for income taxes:
	Malaysia valuation allowance	40			(15		)	(25		)
	Foreign tax credit valuation allowance	(12		)	(114		)	(421		)
	Brazil and other international valuation allowance	6			—			—
U.S. state net operating loss carryforwards	1			2			—
Balance at the end of the year	$	(549	)	$	(584	)	$	(457	)
As the result of the divestiture of the Malaysia operations in 2014, all of the deferred tax asset and related valuation allowance were transferred to the buyer. In the fourth quarter of 2014, we wrote off the other international deferred tax assets and related valuation allowances since we have ceased operating in these jurisdictions and it is remote that the NOL carryforwards will be realized in the future. In fourth quarter of 2014, 2013 and 2012, we recorded valuation allowances related to insufficient estimated future domestic taxable income to fully utilize foreign tax credits before they expire of $12 million, $114 million, and $421 million, respectively. The foreign tax credit deferred tax asset is fully offset by a valuation allowance. In 2014, we released $1 million of state valuation allowances due to utilization of the related state NOLs.

StockBased_Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2014
Share-based Compensation [Abstract]
Stock-Based Compensation Text Block	Stock-Based Compensation:
	For the years ended December 31, our stock-based compensation expense consisted of the following:
			2014				2013				2012
			(In millions)
	Equity awards		$	47			$	48			$	46
	Liability awards:
	Stockholder Value Appreciation Program		38				18				—
	Cash-settled restricted stock units		20				9				1
	Total liability awards		58				27				1
	Total stock-based compensation		105				75				47
	Capitalized in oil and gas properties		(40		)		(20		)		(12		)
	Net stock-based compensation expense		$	65			$	55			$	35
	As of December 31, 2014, we had approximately $70 million of total unrecognized stock-based compensation expense related to unvested stock-based compensation awards. The full amount is expected to be recognized 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.
	Stock-based compensation classified as equity awards to employees and non-employee directors are currently granted under the 2011 Omnibus Stock Plan (2011 Plan). 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. At December 31, 2014, we had approximately (1) 2.3 million additional shares available for issuance pursuant to our existing plan if all future awards under our 2011 Plan are stock options, or (2) 1.2 million additional shares available for issuance pursuant to our existing plan if all future awards under our 2011 Plan are restricted stock or restricted stock units. Thus far, the majority of the awards under our 2011 Plan have been granted as restricted stock unit awards.
	Restricted Stock.    At December 31, 2014, our employees held approximately 1.9 million shares of non-vested restricted stock and restricted stock units. These shares primarily vest over three to five years and vesting is dependent upon the employee’s continued service with our Company. In addition, at December 31, 2014, our employees held approximately 0.9 million shares of restricted stock subject to performance-based vesting criteria (all of which are currently considered market-based restricted stock under authoritative accounting guidance). To the extent we have treasury shares available, we utilize treasury shares when restricted stock is issued or restricted stock units vest.
	The following table provides information about restricted stock and restricted stock unit activity.
			Service-Based			Performance/			Total			Weighted-
			Shares			Market-Based			Shares			Average
						Shares						Grant Date
												Fair Value
												per Share
			(In thousands, except per share data)
	Non-vested shares outstanding at January 1, 2012		2,123			357			2,480			$	49.52
	Granted		1,589			184			1,773			35.29
	Forfeited		(364	)		(14	)		(378	)		47.34
	Vested		(977	)		(89	)		(1,066	)		41.7
	Non-vested shares outstanding at December 31, 2012		2,371			438			2,809			43.31
	Granted		2,428			300			2,728			27.24
	Forfeited		(605	)		(32	)		(637	)		39.47
	Vested		(1,195	)		—			(1,195	)		39.64
	Non-vested shares outstanding at December 31, 2013		2,999			706			3,705			33.31
	Granted		465			338			803			25.42
	Forfeited		(416	)		(69	)		(485	)		25.14
	Vested		(1,146	)		(30	)		(1,176	)		36.64
	Non-vested shares outstanding at December 31, 2014		1,902			945			2,847			$	30.05
	The total fair value of restricted stock and restricted stock units that vested during the years ended December 31, 2014, 2013 and 2012 was $43 million, $47 million and $44 million, respectively.
	Stock Options.    Options generally expire ten years from the date of grant and become exercisable at the rate of 20% per year. The exercise price of options cannot be less than the fair market value per share of our common stock on the date of grant. We issue new shares of stock when stock options are exercised.
	The excess tax benefit realized from stock options exercised is recognized as a credit to additional paid-in capital and is calculated as the amount by which the tax deduction we receive exceeds the deferred tax asset associated with recorded stock-based compensation expense. We did not realize an excess tax benefit from stock-based compensation for 2014, 2013 or 2012 because we did not have sufficient taxable income to fully realize the deduction. At December 31, 2014, we had unrecognized net operating losses of $99 million related to stock-based compensation.
	The following table below provides information about stock option activity.
			Number of			Weighted-				Weighted-				Weighted-		Aggregate
			Shares			Average				Average				Average Remaining		Intrinsic
			Underlying			Exercise				Grant Date				Contractual Life		Value(1)
			Options			Price				Fair Value
						per Share				per Share
			(In thousands)											(In years)		(In millions)
	Outstanding at January 1, 2012		1,059			$	36.31							4		$	7
	Granted		—			—				$	—
	Exercised		(94	)		19.52										1
	Forfeited		(64	)		36.19
	Outstanding at December 31, 2012		901			38.06								3.3		1
	Granted		—			—				—
	Exercised		(53	)		19.68										1
	Forfeited		(161	)		37.26
	Outstanding at December 31, 2013		687			39.68								1.9		—
	Granted		—			—				—
	Exercised		(134	)		29.32										1
	Forfeited		(252	)		40.1
	Outstanding at December 31, 2014		301			$	43.93							2.2		$	—
	Exercisable at December 31, 2014		301			$	43.93							2.2		$	—
	_________________
	-1	The intrinsic value of a stock option is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the option.
On December 31, 2014, the last reported sales price of our common stock on the New York Stock Exchange was $27.12 per share.
The following table summarizes information about stock options outstanding and exercisable at December 31, 2014:
Options Outstanding											Options Exercisable
Range of Exercise Prices		Number of			Weighted-		Weighted-				Number of			Weighted-
		Shares			Average		Average				Shares			Average
		Underlying			Remaining		Exercise Price				Underlying			Exercise Price
		Options			Contractual Life		per Share				Options			per Share
		(In thousands)			(In years)						(In thousands)
$27.51 to $35.00		66			0.1		$	31.94			66			$	31.94
35.01 to 41.72		27			0.3		38.44				27			38.44
41.73 to 48.45		208			3.1		48.45				208			48.45
		301			2.2		$	43.93			301			$	43.93
Employee Stock Purchase Plan.    In May 2010, our stockholders approved the Newfield Exploration Company 2010 Employee Stock Purchase Plan with one million shares of our common stock available for issuance. Pursuant to our employee stock purchase plan, for each six-month period beginning on January 1 or July 1 during the term of the plan, each eligible employee has the opportunity to purchase our common stock for a purchase price equal to 85% of the lesser of the fair market value of our common stock on the first or last day of the period. Each employee may purchase up to $25,000 in common stock per calendar year. Employees of our foreign subsidiaries are not eligible to participate in the plan.
During 2014, options to purchase 168,394 shares of our common stock were issued under our employee stock purchase plan. The weighted-average fair value of each option was $7.91 per share. The fair value of the options granted was determined using the Black-Scholes option valuation method assuming no dividends, a risk-free weighted-average interest rate of 0.07%, an expected life of six months and weighted-average volatility of 32.05%. At December 31, 2014, approximately 356,000 shares of our common stock remained available for issuance under the current plan.
During 2013, options to purchase 178,733 shares of our common stock were issued under our employee stock purchase plan. The weighted-average fair value of each option was $6.59 per share. The fair value of the options granted was determined using the Black-Scholes option valuation method assuming no dividends, a risk-free weighted-average interest rate of 0.10%, an expected life of six months and weighted-average volatility of 39.45%.
During 2012, options to purchase 165,722 shares of our common stock were issued under our employee stock purchase plan. The weighted-average fair value of each option was $9.86 per share. The fair value of the options granted was determined using the Black-Scholes option valuation method assuming no dividends, a risk-free weighted-average interest rate of 0.10%, an expected life of six months and weighted-average volatility of 49.43%.
Liability Awards
Liability awards consist of performance awards that are settled in cash instead of shares as discussed below.
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 that is reached results in an approximately $13 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.
Based on the valuation of the SVAP as of December 31, 2014, the fair value was $4 million, of which $3 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 0.27%, a plan term of one year and an average of implied and historical stock price volatility of 47%. An additional $1 million is expected to be recognized over the remaining service period of the plan. Future changes in our stock price could cause the total cost of the plan to be significantly different than our estimates as of December 31, 2014.
Cash-Settled Restricted Stock Units.    We also have granted cash-settled restricted stock units to employees that vest over three years. As of December 31, 2014, we accrued $12 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. During the year ended December 31, 2014, we granted approximately 759,000 cash-settled restricted stock units to employees. During the year ended December 31, 2014, approximately 587,000 cash-settled restricted stock units vested and settled for approximately $19 million. During the year ended December 31, 2013, approximately 85,000 cash-settled restricted units vested and settled for approximately $2 million. As of December 31, 2014, we had approximately 1.2 million cash-settled restricted stock units outstanding and related unrecognized stock-based compensation expense of approximately $18 million.

Employee_Benefit_Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2014
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Compensation and Employee Benefit Plans [Text Block]	Employee Benefit Plans:
	Post-Retirement Medical Plan
	We sponsor a post-retirement medical plan that covers all retired employees until they reach age 65. At December 31, 2014, both our accumulated benefit obligation and our accrued benefit costs were $16 million. Our net periodic benefit cost was approximately $2 million for each of the years ended December 31, 2014, 2013 and 2012.
	The expected future benefit payments under our post-retirement medical plan for the next ten years include $5 million for the five-year period 2015 through 2019 and $7 million for the five-year period 2020 through 2024.
	Annual Cash Incentive Compensation Plan
	During 2010, our Board of Directors, with the recommendation of the Compensation & Management Development Committee, approved a new annual cash incentive compensation plan for all employees (the 2011 Annual Incentive Plan). Under the 2011 Annual Incentive Plan, the Compensation & Management Development Committee determines the annual award pool for all employees based upon a number of factors including the Company’s performance against stated performance goals and in comparison with peer companies in our industry. All employees are eligible if employed on October 1 and December 31 of the performance period. Beginning with the year ended December 31, 2010, our annual cash incentive compensation is paid in a single payment to employees during the first quarter after the end of the performance period.
	Total incentive compensation expense under the 2011 Annual Incentive Plan for the years ended December 31, 2014, 2013 and 2012 was $45 million, $40 million and $41 million, respectively.
	401(k) and Deferred Compensation Plans
	We sponsor a 401(k) profit sharing plan under Section 401(k) of the Internal Revenue Code. This plan covers all of our employees, excluding those of our foreign subsidiaries. We match $1.00 for each $1.00 of employee deferral, with our contribution not to exceed 8% of an employee’s salary, subject to limitations imposed by the IRS. We also sponsor a highly compensated employee deferred compensation plan. This non-qualified plan allows an eligible employee to defer a portion of his or her salary or bonus on an annual basis. We match $1.00 for each $1.00 of employee deferral, with our contribution not to exceed 8% of an employee’s salary, subject to limitations imposed by the plan. Our contribution with respect to each participant in the deferred compensation plan is reduced by the amount of contribution made by us to our 401(k) plan for that participant. Our combined contributions to these two plans was $10 million for each of the years ended December 31, 2014, 2013 and 2012.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies Text Block	Commitments and Contingencies:
	We have various commitments from continuing operations for firm transportation, operating lease agreements for office space and other agreements. As of December 31, 2014, future minimum payments under these non-cancelable agreements are as follows:
			Firm			Operating		Drilling-Related		Other		Total
			Transportation			Leases
						(Office Space)
			(In millions)
	Year Ending December 31,
	2015		$	72		$	18	$	196	$	26	$	312
	2016		85			15		36		16		152
	2017		82			15		—		13		110
	2018		63			14		—		12		89
	2019		52			12		—		11		75
	Thereafter		35			24		—		35		94
	Total minimum future payments		$	389		$	98	$	232	$	113	$	832
	Firm transportation is comprised of various agreements with third parties for oil and gas gathering and transportation. Rent expense with respect to our lease commitments for office space for the years ended December 31, 2014, 2013 and 2012 was $20 million, $19 million and $17 million, respectively. Our other agreements are primarily other equipment leases. Payments under our drilling-related contracts are accounted for as capital additions to our oil and gas properties.
	We have various oil and gas production volume delivery commitments that are related to our domestic operations. As of December 31, 2014, our delivery commitments through 2025 were as follows:
			Natural		Oil(1)
			Gas
	Year Ending December 31,		(MMMBtus)		(MBbls)
	2015		15,372		6,570
	2016		—		13,908
	2017		—		13,870
	2018		—		13,870
	2019		—		13,870
	Thereafter		—		46,576
	Total delivery commitments		15,372		108,664
	_________________
	-1	Our oil delivery commitments include commitments with Salt Lake City, Utah refiners. Our delivery commitments are for approximately 18,000 barrels of oil per day through 2020 and an additional 20,000 barrels of oil per day expected to start in 2016 and continuing through 2025. The 20,000 barrel per day delivery commitment represents approximately 7,300 MBbls of our committed oil volumes for each of the years 2016 through 2025. The timing may change due to timing of the refinery expansion completion. These commitments relate to our Uinta Basin production.
	Given the recent decline in oil and natural gas prices and the related impact on our 2015 planned capital investments as well as the potential impact on development plans in future years, we could fail to deliver the minimum production required under these commitments. In the event that we are unable to meet our crude oil volume delivery commitments, we would incur deficiency fees ranging from $1.83 to $6.50 per barrel.
	Litigation
	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.
	During the fourth quarter 2012, we settled a lawsuit where the Company was the plaintiff and recorded a gain of $13 million in “Other income (expense) — Other, net” on our consolidated statement of operations.

Segment_Information

Segment Information	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Segment Reporting Disclosure [Text Block]
		Segment Information
	While we only have operations in the oil and gas exploration and production industry, we are organizationally structured along geographic operating segments. Our current operating segments are the United States and China. Prior to classifying our Malaysia business as held for sale and discontinued operations, we reported a business segment for Malaysia. 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.”
	The following tables provide the geographic operating segment information for our continuing operations for the years ended December 31, 2014, 2013 and 2012. Income tax allocations have been determined based on statutory rates in the applicable geographic segment. In order to reflect the double taxation of our earnings and profits in China, we have applied the statutory rates for China and the U.S. to determine our income tax allocation for our China operations in the following three tables.
			Domestic			China		Total
			(In millions)
	Year Ended December 31, 2014:
	Oil, gas and NGL revenues		$	2,249		$	39	$	2,288
	Operating expenses:
	Lease operating		309			12		321
	Transportation and processing		174			—		174
	Production and other taxes		105			6		111
	Depreciation, depletion and amortization		857			13		870
	General and administrative		221			1		222
	Other		15			—		15
	Allocated income tax (benefit)		210			5
	Net income (loss) from oil and gas properties		$	358		$	2
	Total operating expenses							1,713
	Income (loss) from continuing operations							575
	Interest expense, net of interest income, capitalized interest and other							(153		)
	Commodity derivative income (expense)							610
	Income (loss) from continuing operations before income taxes							$	1,032
	Total assets		$	8,870		$	728	$	9,598
	Additions to long-lived assets		$	2,044		$	156	$	2,200
			Domestic			China		Total
			(In millions)
	Year Ended December 31, 2013:
	Oil, gas and NGL revenues		$	1,788		$	69	$	1,857
	Operating expenses:
	Lease operating		276			8		284
	Transportation and processing		137			—		137
	Production and other taxes		67			12		79
	Depreciation, depletion and amortization		668			17		685
	General and administrative		219			—		219
	Other		3			—		3
	Allocated income tax (benefit)		155			19
	Net income (loss) from oil and gas properties		$	263		$	13
	Total operating expenses							1,407
	Income (loss) from continuing operations							450
	Interest expense, net of interest income, capitalized interest and other							(152		)
	Commodity derivative income (expense)							(97		)
	Income (loss) from continuing operations before income taxes							$	201
	Total assets(1)		$	7,863		$	542	$	8,405
	Additions to long-lived assets		$	1,932		$	174	$	2,106
	_________________
	-1	Excludes total assets from our discontinued operations of $916 million.
			Domestic			China		Total
			(In millions)
	Year Ended December 31, 2012:
	Oil, gas and NGL revenues		$	1,476		$	86	$	1,562
	Operating expenses:
	Lease operating		299			7		306
	Transportation and processing		107			—		107
	Production and other taxes		67			18		85
	Depreciation, depletion and amortization		683			21		704
	General and administrative		211			—		211
	Ceiling test impairment		1,488			—		1,488
	Other		15			—		15
	Allocated income tax (benefit)		(516		)	24
	Net income (loss) from oil and gas properties		$	(878	)	$	16
	Total operating expenses							2,916
	Income (loss) from continuing operations							(1,354		)
	Interest expense, net of interest income, capitalized interest and other							(140		)
	Commodity derivative income (expense)							120
Income (loss) from continuing operations before income taxes							$	(1,374	)
Total assets(1)		$	6,699		$	347	$	7,046
Additions to long-lived assets		$	1,655		$	87	$	1,742
_________________
-1	Excludes total assets from our discontinued operations of $866 million.

Supplemental_Cash_Flows_Inform

Supplemental Cash Flows Information	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flows Information Text Block	Supplemental Cash Flows Information:
	The following table presents information about supplemental cash flows for each of the years in the three-year period ended December 31:
		2014			2013			2012
		(In millions)
	Cash Payments:
	Interest payments	$	144		$	148		$	137
	Income tax payments	4			128			206
	Non-cash investing and financing activities excluded from the statement of cash flows:
	(Increase) decrease in receivables for property sales	$	(17	)	$	12		$	25
	(Increase) decrease in accrued capital expenditures	(1		)	(75		)	(124		)
	(Increase) decrease in asset retirement costs	(56		)	(125		)	(8		)

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transaction Text Block	Related Party Transaction:
	Kevin M. Robinson, our former Vice President — Asia through February 10, 2014, and Susan G. Riggs, our current Treasurer, were minority owners of Huffco International L.L.C. (Huffco). In May 1997, before Mr. Robinson and Ms. Riggs joined the Company, we acquired from Huffco an entity now known as Newfield China, LDC, the owner of a 12% interest in a three-field unit located in Bohai Bay, offshore China. Huffco retained preferred shares of Newfield China that provided for dividend payments. During the third quarter of 2013, we purchased the outstanding preferred shares of Newfield China from Huffco for approximately $20 million, which was recorded as a charge against retained earnings.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2014
Subsequent Events [Abstract]
Subsequent Events [Text Block]	Subsequent Events:
	As a result of decreasing commodity pricing and projected lower capital spending for 2015, the Company executed a reduction in force during the first quarter of 2015, which reduced approximately 15% of the total headcount. We incurred severance and related costs as a result of these workforce reductions totaling approximately $10 million, which will be reflected in our first quarter 2015 financial statements.

Quarterly_Results_of_Operation

Quarterly Results of Operations	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information Text Block	Quarterly Results of Operations (Unaudited):
	The results of operations by quarter for the indicated periods are as follows:
			2014 Quarter Ended
			March 31			June 30			September 30			December 31
			(In millions, except per share data)
	Oil, gas and NGL revenues(1)		$	571		$	612		$	610		$	495
	Income (loss) from operations(1)		182			180			167			46
	Income (loss) from continuing operations, net of tax		$	27		$	(23	)	$	279		$	367
	Income (loss) from discontinued operations, net of tax(2)		257			1			(1		)	(7		)
	Net income (loss)		$	284		$	(22	)	$	278		$	360
	Basic earnings (loss) per common share(3)
	Income (loss) from continuing operations		$	0.19		$	(0.16	)	$	2.04		$	2.67
	Income (loss) from discontinued operations		1.89			—			—			(0.05		)
	Basic earnings (loss) per share		$	2.08		$	(0.16	)	$	2.04		$	2.62
	Diluted earnings (loss) per common share(3)
	Income (loss) from continuing operations		$	0.19		$	(0.16	)	$	2.01		$	2.65
	Income (loss) from discontinued operations		1.88			—			—			(0.05		)
	Diluted earnings (loss) per share		$	2.07		$	(0.16	)	$	2.01		$	2.6
			2013 Quarter Ended
			March 31			June 30			September 30			December 31
			(In millions, except per share data)
	Oil, gas and NGL revenues(1)		$	393		$	449		$	505		$	510
	Income (loss) from operations(1)		91			93			140			126
	Income (loss) from continuing operations, net of tax		$	(21	)	$	107		$	3		$	(16	)
	Income (loss) from discontinued operations, net of tax		13			4			24			33
	Net income (loss)		$	(8	)	$	111		$	27		$	17
	Basic earnings (loss) per common share(3)
	Income (loss) from continuing operations(4)		$	(0.15	)	$	0.79		$	(0.13	)	$	(0.12	)
	Income (loss) from discontinued operations		0.09			0.03			0.18			0.25
	Basic earnings (loss) per share		$	(0.06	)	$	0.82		$	0.05		$	0.13
	Diluted earnings (loss) per common share(3)
	Income (loss) from continuing operations(4)		$	(0.15	)	$	0.79		$	(0.13	)	$	(0.12	)
	Income (loss) from discontinued operations		0.09			0.03			0.18			0.25
	Diluted earnings (loss) per share		$	(0.06	)	$	0.82		$	0.05		$	0.13
	_________________
	-1	Oil, gas and NGL revenues and Income (loss) from operations are specific to our continuing operations.
	-2	During the quarter ended March 31, 2014, we sold our Malaysia business and recorded a gain of approximately $388 million ($252 million, after tax). During the fourth quarter, we reduced the previously recognized gain by $15 million ($10 million, after tax) due to recording an allowance against a receivable. See Note 3, "Discontinued Operations," for additional information.
	-3	The sum of the individual quarterly earnings (loss) per share may not agree with year-to-date earnings (loss) per share as each quarterly computation is based on the income or loss for that quarter and the weighted-average number of shares outstanding during that quarter.
	-4	Basic and diluted earnings per share includes an adjustment of $20 million related to the repurchase of preferred shares of a now wholly-owned subsidiary. See Note 2, "Earnings Per Share" for additional detail.

Supplementary_Oil_and_Gas_Disc

Supplementary Oil and Gas Disclosure	12 Months Ended
	Dec. 31, 2014
Supplementary Oil And Gas Disclosures [Abstract]
Oil and Gas Exploration and Production Industries Disclosures [Text Block]	Results of Operations for Oil and Gas Producing Activities
	The following tables present the results of our oil and gas producing activities for the years ending December 31:
			Continuing Operations								Discontinued Operations
			Domestic				China				Malaysia			Total
			(In millions)
	2014:00:00
	Revenues		$	2,240			$	39			$	90		$	2,369
	Production costs		299				12				11			322
	Production taxes and other operating expenses		279				6				25			310
	Depreciation, depletion and amortization		857				13				33			903
	Income taxes		282				2				8			292
	Results of operations for oil and gas producing activities		$	523			$	6			$	13		$	542
	2013:00:00
	Revenues		$	1,777			$	69			$	822		$	2,668
	Production costs		265				8				117			390
	Production taxes and other operating expenses		204				12				272			488
	Depreciation, depletion and amortization		668				18				244			930
	Income taxes		224				8				72			304
	Results of operations for oil and gas producing activities		$	416			$	23			$	117		$	556
	2012:00:00
	Revenues		$	1,469			$	86			$	1,005		$	2,560
	Production costs		292				7				101			400
	Production taxes and other operating expenses		174				18				259			451
	Depreciation, depletion and amortization		683				21				251			955
	Impairment of oil and gas properties		1,488				—				—			1,488
	Income taxes		(410		)		10				150			(250		)
	Results of operations for oil and gas producing activities		$	(758	)		$	30			$	244		$	(484	)
	Costs Incurred
	The following tables present costs incurred for oil and gas property acquisitions, exploration and development for the respective years:
			Continuing Operations								Discontinued Operations
			Domestic				China				Malaysia			Total
			(In millions)
	2014:00:00
	Property acquisitions:
	Unproved		$	146			$	—			$	—		$	146
	Proved		6				—				—			6
	Exploration		1,089				—				—			1,089
	Development(1)		772				156				14			942
	Total costs incurred(2)		$	2,013			$	156			$	14		$	2,183
	2013:00:00
	Property acquisitions:
	Unproved		$	154			$	—			$	—		$	154
	Proved		8				1				—			9
	Exploration		966				33				101			1,100
	Development(1)		691				140				211			1,042
	Total costs incurred(2)		$	1,819			$	174			$	312		$	2,305
	2012:00:00
	Property acquisitions:
	Unproved		$	64			$	—			$	—		$	64
	Proved		3				—				—			3
	Exploration		929				1				63			993
	Development(1)		659				86				108			853
	Total costs incurred(2)		$	1,655			$	87			$	171		$	1,913
	_________________
	-1	Includes $56 million, $121 million and $9 million for 2014, 2013 and 2012, respectively, of asset retirement costs.
	-2	Other items impacting the capitalized costs of our oil and gas properties which are not included in total costs incurred are as follows:
			2014				2013				2012
			(In millions)
	Property sales — Domestic		$	635			$	23			$	606
	Property sales — International		1,571				—				—
	Ceiling test writedown — Domestic		—				—				1,488
			$	2,206			$	23			$	2,094
	Capitalized Costs
	Capitalized costs for our oil and gas producing activities consisted of the following at the end of each of the years in the two-year period ended December 31, 2014:
		Continuing Operations								Discontinued Operations
		Domestic				China				Malaysia			Total
		(In millions)
December 31, 2014:
Proved properties		$	14,998			$	709			$	—		$	15,707
Unproved properties		677				—				—			677
		15,675				709				—			16,384
Accumulated depreciation, depletion and amortization		(8,022		)		(130		)		—			(8,152		)
Net capitalized costs		$	7,653			$	579			$	—		$	8,232
December 31, 2013:
Proved properties		$	13,185			$	550			$	1,441		$	15,176
Unproved properties		1,116				—				115			1,231
		14,301				550				1,556			16,407
Accumulated depreciation, depletion and amortization		(7,185		)		(112		)		(1,009		)	(8,306		)
Net capitalized costs		$	7,116			$	438			$	547		$	8,101
Reserves
Users of this information should be aware that the process of estimating quantities of proved and proved developed oil and gas reserves is very complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir also may change substantially over time as a result of numerous factors, including additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Consequently, material revisions to existing reserve estimates may occur from time to time.
Reserves Estimates.    All reserve information in this report is based on estimates prepared by our petroleum engineering staff and is the responsibility of management. The preparation of our oil and gas reserves estimates is completed in accordance with our prescribed internal control procedures, which include verification of data input into our reserves forecasting and economics evaluation software, as well as multi-discipline management reviews. The technical employee responsible for overseeing the preparation of the reserves estimates has a Bachelor of Science in Petroleum Engineering, with more than 30 years of experience (including over 20 years of experience in reserve estimation).
Our reserves estimates are made using available geological and reservoir data as well as production performance data. These estimates, made by our petroleum engineering staff, are reviewed annually with management and revised, either upward or downward, as warranted by additional data. The data reviewed includes, among other things, seismic data, well logs, production tests, reservoir pressures, and individual well and field performance data. The data incorporated into our interpretations includes structure and isopach maps, individual well and field performance and other engineering and geological work products such as material balance calculations and reservoir simulation to arrive at conclusions about individual well and field projections. Additionally, offset performance data, operating expenses, capital costs and product prices factor into estimating quantities of reserves. Revisions are necessary due to changes in, among other things, reservoir performance, prices, economic conditions and governmental regulations, as well as changes in the expected recovery rates associated with development drilling. Sustained decreases in prices, for example, may cause a reduction in some reserves due to reaching economic limits sooner.
Reserves Activity Overview.    The following is a discussion of our proved reserves and reserve additions and revisions.
		Year Ended December 31,
		2014			2013			2012
		(MMBOE)
Proved Reserves:
Beginning of year		612			566			652
Reserve additions		81			82			86
Reserve revisions		51			14			(91	)
Sales		(49	)		(1	)		(30	)
Production		(50	)		(49	)		(51	)
End of year		645			612			566
Our proved crude oil and condensate reserves at year-end 2014 were 301 million barrels compared to 270 million barrels and 237 million barrels at year-end 2013 and 2012, respectively. Our proved NGL reserves at year-end 2014 were 76 million barrels compared to 68 million barrels and 37 million barrels at year-end 2013 and 2012, respectively. Our proved natural gas reserves at year-end 2014 were 1.6 Tcf compared to 1.6 Tcf and 1.8 Tcf year-end 2013 and 2012, respectively. Liquids comprised about 58%, 55% and 48% of our proved reserves at year-end 2014, 2013 and 2012, respectively.
Reserve Additions and Revisions.    During 2014, our proved reserves increased 132 MMBOE as a result of additions (extensions, discoveries, improved recovery and purchases of reserves in place) and revisions of previous estimates. We expect the majority of future reserve growth to be associated with infill drilling, extensions of current fields and new discoveries, as well as improved recovery operations and purchases of proved properties. The success of these operations will directly impact reserve additions or revisions in the future.
Additions.    We added 72 MMBOE of proved reserves through discoveries, extensions and other additions, and 9 MMBOE through purchases. Drilling additions related to our domestic resource plays constituted 99% of our additions. Of the drilling additions, 52 MMBOE were proved undeveloped additions and 54 million barrels were liquids reserves.
Revisions.    Total proved reserve revisions in 2014 were a positive 51 MMBOE or 8% of the beginning of year proved reserves. They included a positive 3 MMBOE price revision which was primarily related to our onshore natural gas plays. In mature plays, dominated by infill drilling and where reserve growth cannot be classified as an extension or discovery, the change in reserves is captured as a revision. In 2014, our revisions associated with the development of existing fields were a positive 77 MMBOE. The remaining 29 MMBOE negative revisions are associated with development plan changes and well performance.
Sales.    In 2014, 2013 and 2012, we sold proved reserves associated with non-strategic assets and acreage trades.
Estimated Net Quantities of Proved Oil and Gas Reserves
The following table sets forth our total net proved reserves and our total net proved developed and undeveloped reserves as of December 31, 2011, 2012, 2013 and 2014 and the changes in our total net proved reserves during the three-year period ended December 31, 2014:
		Crude Oil											Natural Gas (Bcf)
		and Condensate (MMBbls)
		Continuing Operations						Discontinued Operations					Continuing Operations					Discontinued Operations
		Domestic			China(1)			Malaysia(1)			Total		Domestic			China(1)		Malaysia(1)		Total
Proved developed and undeveloped reserves as of:
31-Dec-11		204			20			23			247		2,329			—		4		2,333
Revisions of previous estimates		(13	)		—			2			(11	)	(525	)		—		(2	)	(527	)
Extensions, discoveries and other additions		38			—			—			38		181			—		—		181
Purchases of properties		—			—			—			—		1			—		—		1
Sales of properties		(15	)		—			—			(15	)	(80	)		—		—		(80	)
Production		(11	)		(1	)		(10	)		(22	)	(151	)		—		(2	)	(153	)
31-Dec-12		203			19			15			237		1,755			—		—		1,755
Revisions of previous estimates		19			7			2			28		(166	)		—		—		(166	)
Extensions, discoveries and other additions		25			—			2			27		187			—		—		187
Purchases of properties		1			—			—			1		1			—		—		1
Sales of properties		—			—			—			—		(5	)		—		—		(5	)
Production		(14	)		(1	)		(8	)		(23	)	(124	)		—		—		(124	)
31-Dec-13		234			25			11			270		1,648			—		—		1,648
Revisions of previous estimates		18			(2	)		—			16		129			—		—		129
Extensions, discoveries and other additions		41			1			—			42		112			—		—		112
Purchases of properties		6			—			—			6		9			—		—		9
Sales of properties		(3	)		—			(10	)		(13	)	(164	)		—		—		(164	)
Production		(18	)		(1	)		(1	)		(20	)	(127	)		—		—		(127	)
31-Dec-14		278			23			—			301		1,607			—		—		1,607
Proved developed reserves as of:
31-Dec-11		88			5			17			110		1,405			—		4		1,409
31-Dec-12		92			4			14			110		1,042			—		—		1,042
31-Dec-13		112			4			11			127		1,055			—		—		1,055
31-Dec-14		135			9			—			144		938			—		—		938
Proved undeveloped reserves as of:
31-Dec-11		116			15			6			137		924			—		—		924
31-Dec-12		111			15			1			127		713			—		—		713
31-Dec-13		122			21			—			143		593			—		—		593
31-Dec-14		143			14			—			157		669			—		—		669
_________________
-1	All of our reserves in China are associated with production sharing contracts and are calculated using the economic interest method. We used the economic interest method in Malaysia until we sold our Malaysia business in 2014.
Estimated Net Quantities of Proved Oil and Gas Reserves — (Continued)
		NGLs (MMBbls)											Total Oil Equivalents (MMBOE)
		Continuing Operations						Discontinued Operations					Continuing Operations					Discontinued Operations
		Domestic			China(1)			Malaysia(1)			Total		Domestic			China(1)		Malaysia(1)		Total
Proved developed and undeveloped reserves as of:
31-Dec-11		16			—			—			16		608			20		24		652
Revisions of previous estimates		9			—			—			9		(92	)		—		1		(91	)
Extensions, discoveries and other additions		17			—			—			17		86			—		—		86
Purchases of properties		—			—			—			—		—			—		—		—
Sales of properties		(2	)		—			—			(2	)	(30	)		—		—		(30	)
Production		(3	)		—			—			(3	)	(40	)		(1	)	(10	)	(51	)
31-Dec-12		37			—			—			37		532			19		15		566
Revisions of previous estimates		14			—			—			14		5			7		2		14
Extensions, discoveries and other additions		22			—			—			22		78			—		2		80
Purchases of properties		—			—			—			—		2			—		—		2
Sales of properties		—			—			—			—		(1	)		—		—		(1	)
Production		(5	)		—			—			(5	)	(40	)		(1	)	(8	)	(49	)
31-Dec-13		68			—			—			68		576			25		11		612
Revisions of previous estimates		13			—			—			13		53			(2	)	—		51
Extensions, discoveries and other additions		12			—			—			12		71			1		—		72
Purchases of properties		1			—			—			1		9			—		—		9
Sales of properties		(9	)		—			—			(9	)	(39	)		—		(10	)	(49	)
Production		(9	)		—			—			(9	)	(48	)		(1	)	(1	)	(50	)
31-Dec-14		76			—			—			76		622			23		—		645
Proved developed reserves as of:
31-Dec-11		10			—			—			10		332			5		18		355
31-Dec-12		15			—			—			15		280			4		14		298
31-Dec-13		35			—			—			35		322			4		11		337
31-Dec-14		38			—			—			38		329			9		—		338
Proved undeveloped reserves as of:
31-Dec-11		6			—			—			6		276			15		6		297
31-Dec-12		22			—			—			22		252			15		1		268
31-Dec-13		33			—			—			33		254			21		—		275
31-Dec-14		38			—			—			38		293			14		—		307
_________________
-1	All of our reserves in China are associated with production sharing contracts and are calculated using the economic interest method. We used the economic interest method in Malaysia until we sold our Malaysia business in 2014.
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves
The standardized measure of discounted future net cash flows from our estimated proved oil and gas reserves is as follows:
		Continuing Operations								Discontinued Operations
		Domestic				China				Malaysia			Total
		(In millions)
2014:00:00
Future cash inflows		$	31,758			$	2,183			$	—		$	33,941
Less related future:
Production costs		(11,508		)		(784		)		—			(12,292		)
Development and abandonment costs		(4,611		)		(73		)		—			(4,684		)
Future net cash flows before income taxes		15,639				1,326				—			16,965
Future income tax expense		(4,449		)		(221		)		—			(4,670		)
Future net cash flows before 10% discount		11,190				1,105				—			12,295
10% annual discount for estimating timing of cash flows		(5,860		)		(223		)		—			(6,083		)
Standardized measure of discounted future net cash flows		$	5,330			$	882			$	—		$	6,212
2013:00:00
Future cash inflows		$	26,600			$	2,640			$	1,245		$	30,485
Less related future:
Production costs		(8,302		)		(959		)		(771		)	(10,032		)
Development and abandonment costs		(4,166		)		(143		)		(148		)	(4,457		)
Future net cash flows before income taxes		14,132				1,538				326			15,996
Future income tax expense		(4,278		)		(316		)		—			(4,594		)
Future net cash flows before 10% discount		9,854				1,222				326			11,402
10% annual discount for estimating timing of cash flows		(5,226		)		(320		)		(23		)	(5,569		)
Standardized measure of discounted future net cash flows		$	4,628			$	902			$	303		$	5,833
2012:00:00
Future cash inflows		$	21,724			$	2,186			$	1,754		$	25,664
Less related future:
Production costs		(7,042		)		(888		)		(1,135		)	(9,065		)
Development and abandonment costs		(3,949		)		(202		)		(82		)	(4,233		)
Future net cash flows before income taxes		10,733				1,096				537			12,366
Future income tax expense		(2,786		)		(239		)		(66		)	(3,091		)
Future net cash flows before 10% discount		7,947				857				471			9,275
10% annual discount for estimating timing of cash flows		(4,539		)		(245		)		(55		)	(4,839		)
Standardized measure of discounted future net cash flows		$	3,408			$	612			$	416		$	4,436
Set forth in the table below is a summary of the changes in the standardized measure of discounted future net cash flows for our proved oil and gas reserves during each of the years in the three-year period ended December 31, 2014:
		Continuing Operations								Discontinued Operations
		Domestic				China				Malaysia			Total
		(In millions)
2014:00:00
Beginning of the period		$	4,628			$	902			$	303		$	5,833
Revisions of previous estimates:
Changes in prices and costs		(492		)		(119		)		(132		)	(743		)
Changes in quantities		784				(104		)		—			680
Changes in future development costs		253				(72		)		129			310
Previously estimated development costs incurred during the period		698				147				12			857
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs		860				—				—			860
Purchases and sales of reserves in place, net		(171		)		—				(279		)	(450		)
Accretion of discount		655				114				19			788
Sales of oil and gas, net of production costs		(1,662		)		(21		)		(54		)	(1,737		)
Net change in income taxes		(383		)		51				—			(332		)
Production timing and other		160				(16		)		2			146
Net increase (decrease)		702				(20		)		(303		)	379
End of period		$	5,330			$	882			$	—		$	6,212
2013:00:00
Beginning of the period		$	3,408			$	612			$	416		$	4,436
Revisions of previous estimates:
Changes in prices and costs		944				2				33			979
Changes in quantities		81				302				76			459
Changes in future development costs		(83		)		(50		)		(126		)	(259		)
Previously estimated development costs incurred during the period		549				130				79			758
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs		1,012				—				49			1,061
Purchases and sales of reserves in place, net		13				—				—			13
Accretion of discount		470				82				33			585
Sales of oil and gas, net of production costs		(973		)		(46		)		(330		)	(1,349		)
Net change in income taxes		(815		)		(63		)		59			(819		)
Production timing and other		22				(67		)		14			(31		)
Net increase (decrease)		1,220				290				(113		)	1,397
End of period		$	4,628			$	902			$	303		$	5,833
2012:00:00
Beginning of the period		$	4,724			$	565			$	692		$	5,981
Revisions of previous estimates:
Changes in prices and costs		(1,490		)		(24		)		(14		)	(1,528		)
Changes in quantities		(427		)		—				23			(404		)
Changes in future development costs		294				(2		)		(19		)	273
Previously estimated development costs incurred during the period		434				67				93			594
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs		791				24				—			815
Purchases and sales of reserves in place, net		(758		)		—				—			(758		)
Accretion of discount		542				77				64			683
Sales of oil and gas, net of production costs		(1,129		)		(63		)		(439		)	(1,631		)
Net change in income taxes		650				4				119			773
Production timing and other		(223		)		(36		)		(103		)	(362		)
Net increase (decrease)		(1,316		)		47				(276		)	(1,545		)
End of period		$	3,408			$	612			$	416		$	4,436

Organization_and_Summary_of_Si1

Organization and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Organization and Principles of Consolidation	Organization and Principles of Consolidation
	We are an independent energy company engaged in the exploration, development and production of crude oil, natural gas and natural gas liquids (NGLs). Our principal domestic areas of operation include the Mid-Continent, the Rocky Mountains and the onshore Gulf Coast regions of the United States. In addition, we 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.
Discontinued Operations, Policy [Policy Text Block]	Discontinued Operations
	Our businesses in Malaysia and China were classified as held for sale in the second quarter of 2013. As of December 31, 2014, our China business is no longer held for sale, as we concluded the marketing process and were unable to sell at an acceptable price given the significant decrease in oil prices in the fourth quarter of 2014. Therefore, our China business is included in continuing operations for all periods in these financial statements. 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 3, "Discontinued Operations," for additional disclosures, as well as information regarding the sale of our Malaysia business, which closed in February 2014. These financial statements and notes are inclusive of our Malaysia operations unless otherwise noted.
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. It is possible for any of these effects to occur in the near term, given the recent decline in commodity pricing.
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.
Revenue Recognition	Revenue Recognition
	Substantially all of our oil, natural gas and NGLs are sold at market-based prices to a variety of purchasers under short-term contracts (less than 12 months). We also have long-term contracts in the Uinta Basin at market-based prices, less a variable differential that becomes fixed below certain market price thresholds. We record revenue when we deliver our production to the customer and collectability is reasonably assured. Revenues from the production of oil, natural gas and NGLs on properties in which we have joint ownership are recorded under the sales method. Under the sales method, the Company and other joint owners may sell more or less than their entitled share of production. Should the Company’s excess sales exceed our share of estimated remaining recoverable reserves, a liability is recorded. Differences between sales and our entitled share of production are not significant.
Foreign Currency	Foreign Currency
	The functional currency for our foreign operations is the U.S. dollar. Gains and losses incurred on transactions in a currency other than a country’s functional currency are recorded under the caption “Other income (expense) — Other, net” on our consolidated statement of operations.
Cash and Cash Equivalents	Cash and Cash Equivalents
	Cash and cash equivalents include highly liquid investments with a maturity of three months or less when acquired and are stated at cost, which approximates fair value. We invest cash in excess of near-term capital and operating requirements in U.S. Treasury Notes, Eurodollar time deposits and money market funds, which are classified as cash and cash equivalents on our consolidated balance sheet.
Cash and Cash Equivalents, Restricted Cash and Cash Equivalents, Policy [Policy Text Block]	Restricted Cash and Deferred Liabilities
	Restricted cash and the associated deferred liability on our consolidated balance sheet at December 31, 2013 represent a deposit received in the fourth quarter of 2013 related to the sale of our Malaysia business. Amounts were contractually restricted until the transaction closed in February 2014. See Note 3, "Discontinued Operations," for further discussion about the close of the sale of the Malaysia business.
Investments	Investments
	Investments consist of debt and equity securities, a majority of which are classified as “available-for-sale” and stated at fair value. Accordingly, unrealized gains and losses and the related deferred income tax effects are excluded from earnings and reported in other comprehensive income within our consolidated statement of stockholders' equity. Realized gains or losses are computed based on specific identification of the securities sold. We regularly assess our investments for impairment and consider any impairment to be other than temporary if we intend to sell the security, it is more likely than not that we will be required to sell the security or we do not expect to recover our cost of the security.
Allowance for Doubtful Accounts	Allowance for Doubtful Accounts
	We routinely assess material trade and other receivables to determine their collectability. Many of our receivables are from joint interest owners of properties we operate. Thus, we may have the ability to withhold future revenue disbursements to recover any non-payment of joint interest billings. Generally, our oil and gas receivables are collected within 45 to 60 days of production. We accrue a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of the reserve may be reasonably estimated.
Inventories	Inventories
	Inventories primarily consist of tubular goods and well equipment held for use in our oil and natural gas operations and oil produced but not sold in our international operations. Tubular goods and well equipment inventories are carried at the lower of cost or market. During 2014, we wrote down obsolete inventory across all three of our domestic regions. At December 31, 2012, we wrote down subsea wellhead inventory that was not included in the sale of our Gulf of Mexico assets. The writedowns of $9 million in 2014 and $8 million in 2012 are included in “Operating expenses — Other” on our consolidated statement of operations.
	Substantially all of the crude oil from our offshore operations in China is produced into floating storage facilities and “lifted” and sold periodically as barge quantities are accumulated. At December 31, 2014 and 2013, the crude oil inventory from our China operations consisted of approximately 240,000 and 23,000 barrels of crude oil valued at cost of approximately $8 million and $1 million, respectively, 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. See Note 3, "Discontinued Operations" for details on our Malaysia crude oil inventory.
Oil and Gas Properties	Oil and Gas Properties
	We use the full cost method of accounting for our oil and gas producing activities. Under this method, all costs incurred in the acquisition, exploration and development of oil and gas properties, including salaries, benefits, interest and other internal costs directly attributable to these activities, are capitalized into cost centers that are established on a country-by-country basis. We capitalized approximately $199 million, $198 million and $191 million of interest and direct internal costs in 2014, 2013 and 2012, respectively.
	Proceeds from the sale of oil and gas properties are applied to reduce the costs in the applicable cost center unless the reduction would significantly alter the relationship between capitalized costs and proved reserves, in which case a gain or loss is recognized. During the first quarter of 2014, we sold our Malaysia business, which constituted the entire full cost pool for Malaysia. See Note 3, "Discontinued Operations," for further discussion.
	Capitalized costs and estimated future development costs are amortized using a unit-of-production method based on proved reserves associated with the applicable cost center. For each cost center, the net capitalized costs of oil and gas properties are limited to the lower of the unamortized cost or the cost center ceiling. A particular cost center ceiling is equal to the sum of:
	•	the present value (10% per annum discount rate) of estimated future net revenues from proved reserves using oil, natural gas and NGL reserve estimation requirements, which require use of the unweighted average first-day-of-the-month commodity prices for the prior 12 months (SEC pricing), adjusted for market differentials, applicable to our reserves (including the effects of derivative contracts that are designated for hedge accounting, if any); plus
	•	the costs of properties not included in the costs being amortized, if any; less
	•	related income tax effects.
	If net capitalized costs of oil and gas properties exceed the cost center ceiling, we are subject to a ceiling test writedown to the extent of such excess. If required, a ceiling test writedown reduces earnings and stockholders’ equity in the period of occurrence and, holding other factors constant, results in lower depreciation, depletion and amortization expense in future periods.
	The risk that we will be required to writedown the carrying value of our oil and gas properties increases when oil, natural gas and NGL prices decrease significantly for a prolonged period of time or if we have substantial downward revisions in our estimated proved reserves. At December 31, 2014, the ceiling value of our reserves was calculated based upon SEC pricing of $4.35 per MMBtu for natural gas and $94.98 per barrel for oil. Using these prices, our ceilings for the U.S. and China exceeded the net capitalized costs of oil and gas properties by approximately $400 million and $150 million, respectively, net of tax, and as such, no ceiling test writedown was required.
	The continued decline of SEC pricing for oil and natural gas reserves since December 31, 2014 will likely result in a ceiling test writedown in the first quarter of 2015.
	At December 31, 2013, the ceiling value of our reserves was calculated based upon SEC pricing of $3.67 per MMBtu for natural gas and $96.82 per barrel for oil. Using these prices, the cost center ceilings with respect to our domestic and China full cost pools exceeded the net capitalized costs. As such, no ceiling test writedowns were required at December 31, 2013.
	At December 31, 2012, the ceiling value of our reserves was calculated based upon SEC pricing of $2.76 per MMBtu for natural gas and $94.84 per barrel for oil. Using these prices, the unamortized net capitalized costs of our domestic oil and gas properties exceeded the ceiling amount by approximately $1.5 billion ($948 million, after tax). No ceiling test writedown was required for the China full cost pool at December 31, 2012.
	See Note 4, “Oil and Gas Assets,” for a detailed discussion regarding our oil and gas asset acquisitions and sales transactions during 2014, 2013 and 2012.
Other Property and Equipment	Other Property and Equipment
	Furniture, fixtures and equipment are recorded at cost and are depreciated using the straight-line method over their estimated useful lives, which range from three to seven years. Gathering systems and equipment are recorded at cost and depreciated using the straight-line method over their estimated useful lives of 25 years.
Accounting for Asset Retirement Obligations	Accounting for Asset Retirement Obligations
	If a reasonable estimate of the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon wells can be made, we record a liability (an asset retirement obligation or ARO) on our consolidated balance sheet and capitalize the present value of the asset retirement cost in oil and gas properties in the period in which the ARO is incurred. Settlements include payments made to satisfy the AROs, as well as transfer of the AROs to purchasers of our divested properties.
	In general, the amount of an ARO and the costs capitalized will equal the estimated future costs to satisfy the abandonment obligation assuming normal operation of the asset, using current prices that are escalated by an assumed inflation factor up to the estimated settlement date, which is then discounted back to the date that the abandonment obligation was incurred using an assumed cost of funds for our Company. After recording these amounts, the ARO is accreted to its future estimated value using the same assumed cost of funds, and the original capitalized costs are depreciated on a unit-of-production basis within the related full cost pool. Both the accretion and the depreciation are included in depreciation, depletion and amortization expense on our consolidated statement of operations.
	The change in our ARO for continuing operations for each of the three years ended December 31, is set forth below:
			2014			2013			2012
			(In millions)
	Balance at January 1		$	122		$	102		$	108
	Accretion expense		8			8			8
	Additions(1)		58			12			20
	Revisions		16			8			12
	Settlements(2)		(18		)	(8		)	(46		)
	Balance at December 31		186			122			102
	Less: Current portion of ARO at December 31		(3		)	(5		)	(5		)
	Total long-term ARO at December 31		$	183		$	117		$	97
	_________________
	-1	For the year ended December 31, 2014, additions include $28 million for our Pearl development in offshore China and $30 million for abandonment obligations in our domestic business.
	-2	For the year ended December 31, 2014, settlements include $10 million related to the sale of our Granite Wash assets. For the year ended December 31, 2012, settlements include $28 million related to the sale of our Gulf of Mexico assets. See Note 4, “Oil and Gas Assets.”
Contingencies	Contingencies
	We are subject to legal proceedings, claims, liabilities and environmental matters that arise in the ordinary course of business. We accrue for losses when such losses are considered probable and the amounts can be reasonably estimated. See Note 13, “Commitments and Contingencies,” for a more detailed discussion regarding our contingencies.
Environmental Matters	Environmental Matters
	Environmental costs that relate to current operations are expensed as incurred. Remediation costs that relate to an existing condition caused by past operations are accrued when it is probable that those costs will be incurred and can be reasonably estimated based upon evaluations of currently available facts related to each site.
Income Taxes	Income Taxes
	We use the liability method of accounting for income taxes. Under this method, deferred tax assets and liabilities are determined by applying tax regulations existing at the end of a reporting period to the cumulative temporary differences between the tax bases of assets and liabilities and their reported amounts in our financial statements. A valuation allowance is established to reduce deferred tax assets if it is more likely than not that the related tax benefits will not be realized.
	As of December 31, 2014, we did not have a liability for uncertain tax positions, and as such, we did not accrue related interest or penalties. The tax years 2011-2014 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
	We apply a fair value-based method of accounting for stock-based compensation which requires recognition in the financial statements of the cost of services received in exchange for awards of equity instruments based on the grant date fair value of those awards. For equity awards, compensation expense is based on the fair value on the grant or modification date and is recognized in our financial statements over the vesting period. We utilize the Black-Scholes option-pricing model to measure the fair value of stock options and a Monte Carlo lattice-based model for our performance and market-based restricted stock and restricted stock units. We also have cash-settled restricted stock units as well as a Stockholder Value Appreciation Program that are accounted for under the liability method which requires us to recognize the fair value of each award based on the underlying share price at the end of each period. See Note 11, “Stock-Based Compensation,” for a full discussion of our stock-based compensation.
Concentration of Credit Risk	Concentration of Credit Risk
	We operate a substantial portion of our oil and gas properties. As the operator of a property, we make full payment for costs associated with the property and seek reimbursement from the other working interest owners in the property for their share of those costs. Our joint interest owners consist primarily of independent oil and gas producers. If the oil and gas exploration and production industry in general was adversely affected, the ability of our joint interest partners to reimburse us could be adversely affected.
	The purchasers of our oil, gas and NGL production consist primarily of independent marketers, major oil and gas companies, refiners and gas pipeline companies. We perform credit evaluations of the purchasers of our production and monitor their financial condition on an ongoing basis. Based on our evaluations and monitoring, we obtain cash escrows, letters of credit or parental guarantees from some purchasers.
	All of our derivative transactions have been carried out in the over-the-counter market and are not typically subject to margin-deposit requirements. The use of derivative transactions involves the risk that the counterparties will be unable to meet the financial terms of such transactions. The counterparties for all of our derivative transactions have an “investment grade” credit rating. We monitor the credit ratings of our hedging counterparties on an ongoing basis. Although we have entered into derivative contracts with multiple counterparties to mitigate our exposure to any individual counterparty, if any of our counterparties were to default on its obligations to us under the derivative contracts or seek bankruptcy protection, it could have a material adverse effect on our ability to fund our planned activities and could result in a larger percentage of our future production being subject to commodity price changes. In addition, in poor economic environments and tight financial markets, the risk of a counterparty default is heightened and fewer counterparties may participate in hedging transactions, which could result in greater concentration of our exposure to any one counterparty or a larger percentage of our future production being subject to commodity price changes. At December 31, 2014, ten of our 16 counterparties accounted for approximately 85% of our contracted volumes, with no single counterparty accounting for more than 15%. Approximately 40% of our volumes subject to derivative instruments are with lenders under our credit facility. Our credit facility, senior notes, senior subordinated 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.
Major Customers	Major Customers
	Tesoro Corporation and Sunoco Logistics Partners Operations GP LLC accounted for 12% and 10%, respectively, of our total revenues in 2014. During 2013, Sunoco Logistics Partners Operations GP LLC, Royal Dutch Shell plc and Tesoro Corporation accounted for 13%, 12%, and 11%, respectively, of our total revenues. During 2012, sales of our oil and gas production to Royal Dutch Shell plc, Tesoro Corporation and Big West Oil LLC accounted for 14%, 14% and 10%, respectively, of our total revenues. We believe that the loss of any of our major customers would not have a material adverse effect on us because alternative purchasers are available.
Derivative Financial Instruments	Derivative Financial Instruments
	Our derivative instruments are recorded on the consolidated balance sheet at fair value as either an asset or a liability with changes in fair value recognized currently in earnings. While we utilize our derivative instruments to manage the price risk attributable to our expected oil and gas production, we have elected not to designate our derivative instruments as accounting hedges under the accounting guidance.
	The related cash flow impact of our derivative activities are reflected as cash flows from operating activities unless they are determined to have a significant financing element at inception, in which case they are classified within financing activities. See Note 5, “Derivative Financial Instruments,” for a more detailed discussion of our derivative activities.
Comprehensive Income (Loss)	Accumulated Other Comprehensive Income
	At December 31, 2012, accumulated other comprehensive income (“AOCI”) included unrealized losses related to auction rate securities that were deemed to be temporary as the Company had the intent and ability to hold the securities to maturity. As of December 31, 2013, the Company changed its intention and considered plans to sell the securities. As a result, the losses previously accumulated in AOCI related to these securities were transferred and recognized in the consolidated statement of operations for the year ended December 31, 2013. During the first quarter of 2014, all auction rate securities were sold for $39 million. The change in AOCI for the indicated periods is set forth below:
			Unrealized Gains / (Losses) in
			Accumulated Other Comprehensive Income
			Available-for-Sale Securities			Post-Retirement Benefits			Total
			(In millions, net of tax)
	Balance at January 1, 2012		$	(9	)	$	(1	)	$	(10	)
	Current period other comprehensive income (loss)		3			—			3
	Balance at December 31, 2012		(6		)	(1		)	(7		)
	Other comprehensive income before reclassifications		3			2			5
	Amounts reclassified from accumulated other comprehensive income		4			—			4
	Net current period other comprehensive income (loss)		7			2			9
	Balance at December 31, 2013		1			1			2
	Current period other comprehensive income (loss)		—			(3		)	(3		)
	Balance at December 31, 2014		$	1		$	(2	)	$	(1	)
Offsetting Fair Value	Offsetting Assets and Liabilities
	Our derivative financial instruments are subject to master netting arrangements and are reflected on our consolidated balance sheet accordingly. See Note 5, "Derivative Financial Instruments," for details regarding the gross amounts, as well as the impact of our netting arrangements on our net derivative position. We only offset assets and liabilities in relation to our derivative financial instruments.
New Accounting Requirements	New Accounting Requirements
	In August 2014, the FASB issued guidance regarding disclosures of uncertainties about an entity's ability to continue as a going concern. The guidance applies prospectively to all entities, requiring management to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity's ability to continue as a going concern and disclose certain information when substantial doubt is raised. The guidance is effective for interim and annual periods beginning on or after December 15, 2016. We do not expect this guidance to impact our Company.
	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. The guidance is effective for interim and annual periods beginning on or after December 15, 2016. We are currently evaluating the impact of this guidance on our financial statements.
	In April 2014, the FASB issued guidance regarding the reporting of discontinued operations. The guidance applies prospectively to new disposals and new classifications of disposal groups as held for sale after the effective date. The guidance is effective for interim and annual periods beginning on or after December 15, 2014. We do not expect this guidance to impact our Company.

Organization_and_Summary_of_Si2

Organization and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Change in ARO (asset retirement obligation)	The change in our ARO for continuing operations for each of the three years ended December 31, is set forth below:
			2014			2013			2012
			(In millions)
	Balance at January 1		$	122		$	102		$	108
	Accretion expense		8			8			8
	Additions(1)		58			12			20
	Revisions		16			8			12
	Settlements(2)		(18		)	(8		)	(46		)
	Balance at December 31		186			122			102
	Less: Current portion of ARO at December 31		(3		)	(5		)	(5		)
	Total long-term ARO at December 31		$	183		$	117		$	97
	_________________
	-1	For the year ended December 31, 2014, additions include $28 million for our Pearl development in offshore China and $30 million for abandonment obligations in our domestic business.
	-2	For the year ended December 31, 2014, settlements include $10 million related to the sale of our Granite Wash assets. For the year ended December 31, 2012, settlements include $28 million related to the sale of our Gulf of Mexico assets. See Note 4, “Oil and Gas Assets.”
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]	The change in AOCI for the indicated periods is set forth below:
			Unrealized Gains / (Losses) in
			Accumulated Other Comprehensive Income
			Available-for-Sale Securities			Post-Retirement Benefits			Total
			(In millions, net of tax)
	Balance at January 1, 2012		$	(9	)	$	(1	)	$	(10	)
	Current period other comprehensive income (loss)		3			—			3
	Balance at December 31, 2012		(6		)	(1		)	(7		)
	Other comprehensive income before reclassifications		3			2			5
	Amounts reclassified from accumulated other comprehensive income		4			—			4
	Net current period other comprehensive income (loss)		7			2			9
	Balance at December 31, 2013		1			1			2
	Current period other comprehensive income (loss)		—			(3		)	(3		)
	Balance at December 31, 2014		$	1		$	(2	)	$	(1	)

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Earnings Per Share Table	The following is the calculation of basic and diluted weighted-average shares outstanding and EPS for the indicated years:
			2014		2013			2012
			(In millions, except per share data)
	Income (numerator):
	Income (loss) from continuing operations		$	650	$	73		$	(922	)
	Income (loss) from discontinued operations, net of tax		250		74			(262		)
	Net income (loss)		900		147			(1,184		)
	Repurchase of preferred shares of subsidiary(3)		—		(20		)	—
	Net income (loss) attributable to common stockholders		$	900	$	127		$	(1,184	)
	Weighted-average shares (denominator):
	Weighted-average shares — basic		137		135			135
	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		138		136			135
	Earnings (loss) per share:
	Basic:
	Income (loss) from continuing operations before preferred share repurchase		$	4.76	$	0.54		$	(6.85	)
	Repurchase of preferred shares of subsidiary(3)		—		(0.15		)	—
	Income (loss) from continuing operations		4.76		0.39			(6.85		)
	Income (loss) from discontinued operations		1.83		0.55			(1.95		)
	Basic earnings (loss) per share		$	6.59	$	0.94		$	(8.80	)
	Diluted:
	Income (loss) from continuing operations before preferred share repurchase		$	4.71	$	0.54		$	(6.85	)
	Repurchase of preferred shares of subsidiary(3)		—		(0.15		)	—
	Income (loss) from continuing operations		4.71		0.39			(6.85		)
	Income (loss) from discontinued operations		1.81		0.55			(1.95		)
	Diluted earnings (loss) per share		$	6.52	$	0.94		$	(8.80	)
	_________________
	-1	Excludes 1.1 million and 4.0 million shares of unvested restricted stock or restricted stock units and stock options for the years ended December 31, 2014 and 2013, respectively, because including the effect would have been anti-dilutive.
	-2	The effect of unvested restricted stock or restricted stock units and stock options has not been included in the calculation of shares outstanding for diluted EPS for the year ended December 31, 2012, as their effect would have been anti-dilutive. Had we recognized income from continuing operations for that year, incremental shares attributable to the assumed vesting of unvested restricted stock and restricted stock units and the assumed exercise of outstanding stock options would have increased diluted weighted-averages shares outstanding by 0.7 million shares for the year ended December 31, 2012.
	-3	The numerator includes an adjustment of $20 million related to the repurchase of preferred shares of a now wholly-owned subsidiary, which reduces net income (loss) for purposes of earnings per share for the year ended December 31, 2013. The subsidiary is part of our continuing operations. See Note 16, "Related Party Transaction," for additional information.

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2014
Discontinued Operations and Disposal Groups [Abstract]
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]
		Year Ended December 31,
		2014			2013			2012
		(In millions)
	Oil and gas revenues (1)	$	90		$	823		$	1,005
	Operating expenses	69			652			618
	Income from discontinued operations	21			171			387
	Other income (expense)	—			4			(1		)
	Gain on sale of Malaysia business	373			—			—
	Income from discontinued operations before income taxes	394			175			386
	Income tax provision (benefit):
	Current	12			88			179
	Deferred	132			13			469
	Total income tax provision (benefit)	144			101			648
	Income (loss) from discontinued operations, net of tax	$	250		$	74		$	(262	)
	________________
	(1) Certain payments to foreign governments made on our behalf that are part of the revenue process are recorded as a reduction of the related oil and gas revenues.
Schedule of Disposal Groups, Including Discontinued Operations, Balance Sheet [Table Text Block]
		December 31,
		2013
		(In millions)
	Current assets:
	Cash and cash equivalents	$	55
	Accounts receivable	142
	Inventories	121
	Other current assets	29
	Total current assets	347
	Noncurrent assets:
	Oil and gas properties, net of accumulated depreciation, depletion and amortization of $1,009 as of December 31, 2013	547
	Deferred taxes	19
	Other assets	3
	Total noncurrent assets	569
	Total assets	$	916
	Current liabilities:
	Accounts payable	$	34
	Accrued liabilities	185
	Asset retirement obligations	49
	Other current liabilities	18
	Total current liabilities	286
	Noncurrent liabilities:
	Asset retirement obligations	84
	Deferred taxes	29
	Other liabilities	11
	Total noncurrent liabilities	124
	Total liabilities	$	410
ScheduleOfChangeInAssetRetirementObligationDiscontinued [Table Text Block]	The change in our ARO for our discontinued operations for each of the three years ended December 31, is set forth below:
		2014			2013			2012
		(In millions)
	Balance at January 1	$	133		$	40		$	37
	Accretion expense	1			3			3
	Additions	—			4			4
	Revisions	—			101			—
	Settlements (1)	(134		)	(15		)	(4		)
	Balance at December 31	—			133			40
	Less: Current portion of ARO at December 31	—			(49		)	(5		)
	Total long-term ARO at December 31	$	—		$	84		$	35
	________________
	(1) Obligations reduced as a result of the sale of our Malaysia business in February 2014.

Oil_and_Gas_Assets_Tables

Oil and Gas Assets (Tables)	12 Months Ended
	Dec. 31, 2014
Oil and Gas Property [Abstract]
Costs incurred by year for oil and gas properties not subject to amortization
		Costs Incurred In
		2014			2013			2012		2011 and Prior		Total
		(In millions)
	Acquisition costs	$	185		$	159		$	41	$	84	$	469
	Exploration costs	111			—			—		3		114
	Fee mineral interests	—			1			—		23		24
	Capitalized interest	53			17			—		—		70
	Total oil and gas properties not subject to amortization	$	349		$	177		$	41	$	110	$	677
Capitalized Costs Relating to Oil and Gas Producing Activities and Other PPE [Table Text Block]	Property and equipment consisted of the following at December 31:
		2014			2013
		(In millions)
	Oil and gas properties:
	Subject to amortization	$	15,707		$	15,107
	Not subject to amortization	677			1,300
	Gross oil and gas properties	16,384			16,407
	Accumulated depreciation, depletion and amortization	(8,152		)	(8,306		)
	Net oil and gas properties	$	8,232		$	8,101
	Other property and equipment:
	Furniture, fixtures and equipment	$	144		$	139
	Gathering systems and equipment	114			104
	Accumulated depreciation and amortization	(76		)	(69		)
	Net other property and equipment	$	182		$	174

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedges, Assets [Abstract]
Outstanding contracts that are not designated for hedge accounting	At December 31, 2014, we had outstanding derivative positions as set forth in the tables below.
	Natural Gas
		Period and Type of Instrument					NYMEX Contract Price Per MMBtu
															Collars
				Volume in			Swaps				Sold Puts(Weighted				Floors(Weighted			Ceilings(Weighted				Estimated
				MMMBtus			(Weighted				Average)				Average)			Average)				Fair Value
							Average)															Asset
																						(Liability)
																						(In millions)
		2015:00:00
		Fixed-price swaps		49,275			$	4.28			$	—			$	—		$	—			$	62
		Collars		38,325			—				—				3.93			4.74				36
		2016:00:00
		Swaptions (1)		—			4.1				—				—			—				(2		)
		Collars		10,980			—				—				4			4.54				7
		Total																				$	103
	_________________
	-1	During the fourth quarter of 2014, we sold natural gas swaption contracts that, if exercised on their expiration date in the second quarter of 2015, would protect 14,640 MMMBtus of calendar-year 2016 production from future commodity price volatility. These contracts give the counterparties the option to enter into swap contracts with us at $4.10/MMBtu for calendar-year 2016.
	Crude Oil
						NYMEX Contract Price Per Bbl
														Collars							Estimated Fair Value
	Period and Type of Instrument		Volume in MBbls			Swaps				Sold Puts				Floors			Ceilings				Asset (Liability)
						(Weighted Average)				(Weighted Average) (1)				(Weighted Average)			(Weighted Average)
																					(In millions)
	2015:00:00
	Fixed-price swaps		2,275			$	90.2			$	—			$	—		$	—			$	78
	Fixed-price swaps with sold puts:		15,019
	Fixed-price swaps					90.02				—				—			—				495
	Sold puts					—				71.67				—			—				(258		)
	Collars with sold puts:		730
	Collars					—				—				90			104				25
	Sold puts					—				75				—			—				(15		)
	2016:00:00
	Fixed-price swaps with sold puts:		10,060
	Fixed-price swaps					89.98				—				—			—				266
	Sold puts					—				74.14				—			—				(174		)
	Collars with sold puts:		6,220
	Collars					—				—				90			96.15				170
	Sold puts					—				75				—			—				(112		)
	Swaptions (2)		—			91				—				—			—				—
	2017:00:00
	Fixed-price swaps with sold puts:		4,468
	Fixed-price swaps					88.37				—				—			—				93
	Sold puts					—				73.28				—			—				(72		)
	Collars with sold puts:		2,080
	Collars					—				—				90			95.59				50
	Sold puts					—				75				—			—				(36		)
	Total																				$	510
	_________________
	-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.
	-2	During the third quarter of 2014, we sold crude oil swaption contracts that, if exercised on their expiration date in the first quarter of 2015, would protect 732 MBbls of calendar-year 2016 production from future commodity price volatility. These contracts give the counterparties the option to enter into swap contracts with us at $91.00/Bbl for calendar-year 2016.
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
	31-Dec-14		(In millions)															(In millions)
	Natural gas positions		$	105			$	(2	)		$	99			$	4		$	(2	)		$	2		$	—		$	—
	Oil positions		1,115				(597		)		332				186			(605		)		597			(8		)	—
	Total		$	1,220			$	(599	)		$	431			$	190		$	(607	)		$	599		$	(8	)	$	—
	31-Dec-13
	Natural gas positions		$	11			$	(2	)		$	—			$	9		$	(22	)		$	2		$	(20	)	$	—
	Oil positions		26				(9		)		—				17			(51		)		9			(42		)	—
	Total		$	37			$	(11	)		$	—			$	26		$	(73	)		$	11		$	(62	)	$	—
Schedule of Derivative Instruments, Gain (Loss) in Statement of Operations [Table Text Block]	The amount of gain (loss) recognized in “Commodity derivative income (expense)” in our consolidated statement of operations related to our derivative financial instruments follows:
			Year Ended December 31,
			2014				2013				2012
			(In millions)
	Derivatives not designated as hedging instruments:
	Realized gain (loss) on natural gas positions		$	(36	)		$	66			$	144
	Realized gain (loss) on oil positions		(3		)		(6		)		1
	Realized gain (loss) on basis positions		—				—				(10		)
	Total realized gain (loss)		(39		)		60				135
	Unrealized gain (loss) on natural gas positions		114				(81		)		(124		)
	Unrealized gain (loss) on oil positions		535				(76		)		99
	Unrealized gain (loss) on basis positions		—				—				10
	Total unrealized gain (loss)		649				(157		)		(15		)
	Total gain (loss)		$	610			$	(97	)		$	120

Accounts_Receivable_Tables

Accounts Receivable (Tables)	12 Months Ended
	Dec. 31, 2014
Accounts Receivable, Net, Current [Abstract]
Schedule of Accounts, Notes, Loans and Financing Receivable [Table Text Block]	Accounts receivable consisted of the following at December 31:
		2014			2013
		(In millions)
	Revenue	$	155		$	294
	Joint interest	230			156
	Other	36			25
	Reserve for doubtful accounts	(16		)	(1		)
	Total accounts receivable, net	$	405		$	474
	Reserve for doubtful accounts at December 31, 2014 includes an allowance for $15 million related to discontinued operations. See Note 3, "Discontinued Operations."

Accrued_Liabilities_Tables

Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2014
Accrued Liabilities, Current [Abstract]
Schedule of Accrued Liabilities [Table Text Block]	Accrued liabilities consisted of the following at December 31:
		2014		2013
		(In millions)
	Revenue payable	$	197	$	175
	Accrued capital costs	441		458
	Accrued lease operating expenses	47		71
	Employee incentive expense	62		64
	Accrued interest on debt	67		72
	Taxes payable	32		93
	Other	34		45
	Total accrued liabilities	$	880	$	978

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
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			Significant			Significant				Total
			in Active			Other			Unobservable
			Markets for			Observable			Inputs
			Identical Assets			Inputs			(Level 3)
			or Liabilities			(Level 2)
			(Level 1)
			(In millions)
	As of December 31, 2013:
	Money market fund investments		$	2		$	—		$	—			$	2
	Deferred compensation plan assets		8			—			—				8
	Investments available-for-sale:
	Equity securities		8			—			—				8
	Auction rate securities		—			—			39				39
	Oil and gas derivative swap contracts		—			(28		)	—				(28		)
	Oil and gas derivative option and swaption contracts		—			—			(8		)		(8		)
	Stock-based compensation liability awards		(11		)	—			(5		)		(16		)
	Total		$	7		$	(28	)	$	26			$	5
	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
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, 2012		$	32		$	71		$	—			$	103
	Realized or unrealized gains (losses):
	Included in earnings		—			135			—				135
	Included in other comprehensive income (loss)		4			—			—				4
	Purchases, issuances, sales and settlements:
	Settlements		—			(91		)	—				(91		)
	Transfers in to Level 3		—			—			—				—
	Transfers out of Level 3		—			—			—				—
	Balance at December 31, 2012		$	36		$	115		$	—			$	151
	Change in unrealized gains or losses included in earnings relating to		$	—		$	82		$	—			$	82
	Level 3 instruments still held at December 31, 2012
	Balance at January 1, 2013		$	36		$	115		$	—			$	151
	Realized or unrealized gains (losses):
	Included in earnings		(6		)	(66		)	(18		)		(90		)
	Included in other comprehensive income (loss)		10			—			—				10
	Purchases, issuances, sales and settlements:
	Settlements		(1		)	(57		)	13				(45		)
	Transfers in to Level 3		—			—			—				—
	Transfers out of Level 3		—			—			—				—
	Balance at December 31, 2013		$	39		$	(8	)	$	(5	)		$	26
	Change in unrealized gains or losses included in earnings relating to		$	(6	)	$	(10	)	$	—			$	(16	)
	Level 3 instruments still held at December 31, 2013
	Balance at January 1, 2014		$	39		$	(8	)	$	(5	)		$	26
	Realized or unrealized gains (losses):
	Included in earnings		—			(381		)	(38		)		(419		)
	Included in other comprehensive income (loss)		—			—			—				—
	Purchases, issuances, sales and settlements:
	Sales		(39		)	—			—				(39		)
	Settlements		—			5			40				45
	Transfers in to Level 3		—			—			—				—
	Transfers out of Level 3(1)		—			3			—				3
	Balance at December 31, 2014		$	—		$	(381	)	$	(3	)		$	(384	)
	Change in unrealized gains or losses included in earnings relating to		$	—		$	(375	)	$	2			$	(373	)
	Level 3 instruments still held at December 31, 2014
	________
	-1	During the second quarter of 2014, we transferred $3 million of derivative option contracts out of the Level 3 hierarchy. The transfer was a result of our Level 3 swaptions being exercised by the counterparties as swaps on May 30, 2014.
Quantitative disclosures about unobservable inputs
			Estimated Fair Value Asset (Liability)			Quantitative Information about Level 3 Fair Value Measurements
	Instrument Type					Valuation		Unobservable Input	Range
						Technique
			(In millions)
	Oil option and swaption contracts		$	(422	)	Black-Scholes		Oil price volatility	28.03	%	—	63.41%
								Credit risk	0.01	%	—	1.76%
	Natural gas option and swaption contracts		$	41		Black-Scholes		Natural gas price volatility	23.11	%	—	60.53%
								Credit risk	0.01	%	—	1.12%
	SVAP		$	(3	)	Monte Carlo		Implied volatility				50.20%
Estimated fair value of the debt instrument at the balance sheet date	The estimated fair value of our notes, based on quoted prices in active markets (Level 1) as of December 31, was as follows:
			2014			2013
			(In millions)
	5¾% Senior Notes due 2022		$	772		$	767
	5⅝% Senior Notes due 2024		989			1,025
	7⅛% Senior Subordinated Notes due 2018		—			624
	6⅞% Senior Subordinated Notes due 2020		721			755

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt	At December 31, our debt consisted of the following:
			2014			2013
			(In millions)
	Senior unsecured debt:
	Revolving credit facility — LIBOR based loans		$	345		$	585
	Money market lines of credit(1)		101			64
	Total credit arrangements		446			649
	5¾% Senior Notes due 2022		750			750
	5⅝% Senior Notes due 2024		1,000			1,000
	Total senior unsecured debt		2,196			2,399
	7⅛% Senior Subordinated Notes due 2018		—			600
	6⅞% Senior Subordinated Notes due 2020		700			700
	Discount on notes		(4		)	(5		)
	Total long-term debt		$	2,892		$	3,694
	_________________
	-1	Because we have the ability and intent to use our available credit facility capacity 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)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income (loss) before income taxes	For the years ended December 31, income (loss) from continuing operations before income taxes consisted of the following:
		2014			2013			2012
		(In millions)
	U.S.	$	1,022		$	170		$	(1,414	)
	International	10			31			40
	Total income (loss) before income taxes	$	1,032		$	201		$	(1,374	)
Total provision (benefit) for income taxes	For the years ended December 31, the total provision (benefit) for income taxes for continuing operations consisted of the following:
		2014			2013			2012
		(In millions)
	Current taxes:
	U.S. federal	$	—		$	(4	)	$	1
	U.S. state	2			—			1
	International	3			2			14
	Deferred taxes:
	U.S. federal	350			53			(479		)
	U.S. state	25			13			(34		)
	International	2			64			45
	Total provision (benefit) for income taxes	$	382		$	128		$	(452	)
Provision for income taxes using federal statutory rate	The provision (benefit) for income taxes for continuing operations for the indicated years was different than the amount computed using the federal statutory rate (35%) for the following reasons:
		2014			2013			2012
		(In millions)
	Amount computed using the statutory rate	$	361		$	70		$	(481	)
	Increase (decrease) in taxes resulting from:
	State and local income taxes, net of federal effect	17			8			(18		)
	Valuation allowance, state net of federal	—			(2		)	—
	Foreign tax on foreign earnings	1			53			47
	Other	3			(1		)	—
	Total provision (benefit) for income taxes	$	382		$	128		$	(452	)
Components of deferred tax asset and deferred tax liability	At December 31, the components of our deferred tax asset (liability) were as follows:
		2014			2013
		(In millions)
	Deferred tax asset:
	Net operating loss carryforwards	$	173		$	335
	Alternative minimum tax credit	99			99
	Stock-based compensation	26			25
	Marketable securities	—			3
	Oil and gas properties	—			59
	Foreign tax credit	547			535
	Commodity derivatives	—			13
	Other	8			6
	Total deferred tax asset	853			1,075
	Deferred tax asset valuation allowances	(549		)	(584		)
	Net deferred tax asset	304			491
	Deferred tax liability:
	Commodity derivatives	(217		)	—
	Oil and gas properties	(1,715		)	(1,592		)
	Total deferred tax liability	(1,932		)	(1,592		)
	Net deferred tax liability	(1,628		)	(1,101		)
	Less: Net current deferred tax asset (liability)	(144		)	22
	Net noncurrent deferred tax liability	$	(1,484	)	$	(1,123	)
Roll forward of deferred tax asset valuation allowance	The change in our deferred tax asset valuation allowance is as follows at December 31:
		2014			2013			2012
		(In millions)
	Balance at the beginning of the year	$	(584	)	$	(457	)	$	(11	)
	Charged to provision for income taxes:
	Malaysia valuation allowance	40			(15		)	(25		)
	Foreign tax credit valuation allowance	(12		)	(114		)	(421		)
	Brazil and other international valuation allowance	6			—			—
	U.S. state net operating loss carryforwards	1			2			—
	Balance at the end of the year	$	(549	)	$	(584	)	$	(457	)

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2014
Share-based Compensation [Abstract]
Schedule of Stock Based Compensation Expense Table	For the years ended December 31, our stock-based compensation expense consisted of the following:
			2014				2013				2012
			(In millions)
	Equity awards		$	47			$	48			$	46
	Liability awards:
	Stockholder Value Appreciation Program		38				18				—
	Cash-settled restricted stock units		20				9				1
	Total liability awards		58				27				1
	Total stock-based compensation		105				75				47
	Capitalized in oil and gas properties		(40		)		(20		)		(12		)
	Net stock-based compensation expense		$	65			$	55			$	35
Stock Option Activity Table	The following table below provides information about stock option activity.
			Number of			Weighted-				Weighted-				Weighted-		Aggregate
			Shares			Average				Average				Average Remaining		Intrinsic
			Underlying			Exercise				Grant Date				Contractual Life		Value(1)
			Options			Price				Fair Value
						per Share				per Share
			(In thousands)											(In years)		(In millions)
	Outstanding at January 1, 2012		1,059			$	36.31							4		$	7
	Granted		—			—				$	—
	Exercised		(94	)		19.52										1
	Forfeited		(64	)		36.19
	Outstanding at December 31, 2012		901			38.06								3.3		1
	Granted		—			—				—
	Exercised		(53	)		19.68										1
	Forfeited		(161	)		37.26
	Outstanding at December 31, 2013		687			39.68								1.9		—
	Granted		—			—				—
	Exercised		(134	)		29.32										1
	Forfeited		(252	)		40.1
	Outstanding at December 31, 2014		301			$	43.93							2.2		$	—
	Exercisable at December 31, 2014		301			$	43.93							2.2		$	—
	_________________
	-1	The intrinsic value of a stock option is the amount by which the market value of our common stock at the indicated date, or at the time of exercise, exceeds the exercise price of the option.
Stock Options Outstanding and Exercisable Table	The following table summarizes information about stock options outstanding and exercisable at December 31, 2014:
	Options Outstanding											Options Exercisable
	Range of Exercise Prices		Number of			Weighted-		Weighted-				Number of			Weighted-
			Shares			Average		Average				Shares			Average
			Underlying			Remaining		Exercise Price				Underlying			Exercise Price
			Options			Contractual Life		per Share				Options			per Share
			(In thousands)			(In years)						(In thousands)
	$27.51 to $35.00		66			0.1		$	31.94			66			$	31.94
	35.01 to 41.72		27			0.3		38.44				27			38.44
	41.73 to 48.45		208			3.1		48.45				208			48.45
			301			2.2		$	43.93			301			$	43.93
Restricted Stock and Restricted Stock Unit Activity Table	The following table provides information about restricted stock and restricted stock unit activity.
			Service-Based			Performance/			Total			Weighted-
			Shares			Market-Based			Shares			Average
						Shares						Grant Date
												Fair Value
												per Share
			(In thousands, except per share data)
	Non-vested shares outstanding at January 1, 2012		2,123			357			2,480			$	49.52
	Granted		1,589			184			1,773			35.29
	Forfeited		(364	)		(14	)		(378	)		47.34
	Vested		(977	)		(89	)		(1,066	)		41.7
	Non-vested shares outstanding at December 31, 2012		2,371			438			2,809			43.31
	Granted		2,428			300			2,728			27.24
	Forfeited		(605	)		(32	)		(637	)		39.47
	Vested		(1,195	)		—			(1,195	)		39.64
	Non-vested shares outstanding at December 31, 2013		2,999			706			3,705			33.31
	Granted		465			338			803			25.42
	Forfeited		(416	)		(69	)		(485	)		25.14
	Vested		(1,146	)		(30	)		(1,176	)		36.64
	Non-vested shares outstanding at December 31, 2014		1,902			945			2,847			$	30.05

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Future minimum payments under non-cancellable agreements	As of December 31, 2014, future minimum payments under these non-cancelable agreements are as follows:
			Firm			Operating		Drilling-Related		Other		Total
			Transportation			Leases
						(Office Space)
			(In millions)
	Year Ending December 31,
	2015		$	72		$	18	$	196	$	26	$	312
	2016		85			15		36		16		152
	2017		82			15		—		13		110
	2018		63			14		—		12		89
	2019		52			12		—		11		75
	Thereafter		35			24		—		35		94
	Total minimum future payments		$	389		$	98	$	232	$	113	$	832
Oil and gas production volume delivery commitments	As of December 31, 2014, our delivery commitments through 2025 were as follows:
			Natural		Oil(1)
			Gas
	Year Ending December 31,		(MMMBtus)		(MBbls)
	2015		15,372		6,570
	2016		—		13,908
	2017		—		13,870
	2018		—		13,870
	2019		—		13,870
	Thereafter		—		46,576
	Total delivery commitments		15,372		108,664
	_________________
	-1	Our oil delivery commitments include commitments with Salt Lake City, Utah refiners. Our delivery commitments are for approximately 18,000 barrels of oil per day through 2020 and an additional 20,000 barrels of oil per day expected to start in 2016 and continuing through 2025. The 20,000 barrel per day delivery commitment represents approximately 7,300 MBbls of our committed oil volumes for each of the years 2016 through 2025. The timing may change due to timing of the refinery expansion completion. These commitments relate to our Uinta Basin production.

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2014								Dec. 31, 2013									Dec. 31, 2012
Segment Reporting [Abstract]
Segment Information Table
		Domestic		China		Total					Domestic		China		Total					Domestic			China		Total
		(In millions)									(In millions)									(In millions)
	Year Ended December 31, 2014:								Year Ended December 31, 2013:									Year Ended December 31, 2012:
	Oil, gas and NGL revenues	$	2,249	$	39	$	2,288		Oil, gas and NGL revenues		$	1,788	$	69	$	1,857		Oil, gas and NGL revenues		$	1,476		$	86	$	1,562
	Operating expenses:								Operating expenses:									Operating expenses:
	Lease operating	309		12		321			Lease operating		276		8		284			Lease operating		299			7		306
	Transportation and processing	174		—		174			Transportation and processing		137		—		137			Transportation and processing		107			—		107
	Production and other taxes	105		6		111			Production and other taxes		67		12		79			Production and other taxes		67			18		85
	Depreciation, depletion and amortization	857		13		870			Depreciation, depletion and amortization		668		17		685			Depreciation, depletion and amortization		683			21		704
	General and administrative	221		1		222			General and administrative		219		—		219			General and administrative		211			—		211
	Other	15		—		15			Other		3		—		3			Ceiling test impairment		1,488			—		1,488
	Allocated income tax (benefit)	210		5					Allocated income tax (benefit)		155		19					Other		15			—		15
	Net income (loss) from oil and gas properties	$	358	$	2				Net income (loss) from oil and gas properties		$	263	$	13				Allocated income tax (benefit)		(516		)	24
	Total operating expenses					1,713			Total operating expenses						1,407			Net income (loss) from oil and gas properties		$	(878	)	$	16
	Income (loss) from continuing operations					575			Income (loss) from continuing operations						450			Total operating expenses							2,916
	Interest expense, net of interest income, capitalized interest and other					(153		)	Interest expense, net of interest income, capitalized interest and other						(152		)	Income (loss) from continuing operations							(1,354		)
	Commodity derivative income (expense)					610			Commodity derivative income (expense)						(97		)	Interest expense, net of interest income, capitalized interest and other							(140		)
	Income (loss) from continuing operations before income taxes					$	1,032		Income (loss) from continuing operations before income taxes						$	201		Commodity derivative income (expense)							120
	Total assets	$	8,870	$	728	$	9,598		Total assets(1)		$	7,863	$	542	$	8,405		Income (loss) from continuing operations before income taxes							$	(1,374	)
	Additions to long-lived assets	$	2,044	$	156	$	2,200		Additions to long-lived assets		$	1,932	$	174	$	2,106		Total assets(1)		$	6,699		$	347	$	7,046
									_________________									Additions to long-lived assets		$	1,655		$	87	$	1,742
									-1	Excludes total assets from our discontinued operations of $916 million.								_________________
																		-1	Excludes total assets from our discontinued operations of $866 million.

Supplemental_Cash_Flows_Inform1

Supplemental Cash Flows Information (Tables)	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flows Information Schedule (Table)	The following table presents information about supplemental cash flows for each of the years in the three-year period ended December 31:
		2014			2013			2012
		(In millions)
	Cash Payments:
	Interest payments	$	144		$	148		$	137
	Income tax payments	4			128			206
	Non-cash investing and financing activities excluded from the statement of cash flows:
	(Increase) decrease in receivables for property sales	$	(17	)	$	12		$	25
	(Increase) decrease in accrued capital expenditures	(1		)	(75		)	(124		)
	(Increase) decrease in asset retirement costs	(56		)	(125		)	(8		)

Quarterly_Results_of_Operation1

Quarterly Results of Operations (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information Table	The results of operations by quarter for the indicated periods are as follows:
			2014 Quarter Ended
			March 31			June 30			September 30			December 31
			(In millions, except per share data)
	Oil, gas and NGL revenues(1)		$	571		$	612		$	610		$	495
	Income (loss) from operations(1)		182			180			167			46
	Income (loss) from continuing operations, net of tax		$	27		$	(23	)	$	279		$	367
	Income (loss) from discontinued operations, net of tax(2)		257			1			(1		)	(7		)
	Net income (loss)		$	284		$	(22	)	$	278		$	360
	Basic earnings (loss) per common share(3)
	Income (loss) from continuing operations		$	0.19		$	(0.16	)	$	2.04		$	2.67
	Income (loss) from discontinued operations		1.89			—			—			(0.05		)
	Basic earnings (loss) per share		$	2.08		$	(0.16	)	$	2.04		$	2.62
	Diluted earnings (loss) per common share(3)
	Income (loss) from continuing operations		$	0.19		$	(0.16	)	$	2.01		$	2.65
	Income (loss) from discontinued operations		1.88			—			—			(0.05		)
	Diluted earnings (loss) per share		$	2.07		$	(0.16	)	$	2.01		$	2.6
			2013 Quarter Ended
			March 31			June 30			September 30			December 31
			(In millions, except per share data)
	Oil, gas and NGL revenues(1)		$	393		$	449		$	505		$	510
	Income (loss) from operations(1)		91			93			140			126
	Income (loss) from continuing operations, net of tax		$	(21	)	$	107		$	3		$	(16	)
	Income (loss) from discontinued operations, net of tax		13			4			24			33
	Net income (loss)		$	(8	)	$	111		$	27		$	17
	Basic earnings (loss) per common share(3)
	Income (loss) from continuing operations(4)		$	(0.15	)	$	0.79		$	(0.13	)	$	(0.12	)
	Income (loss) from discontinued operations		0.09			0.03			0.18			0.25
	Basic earnings (loss) per share		$	(0.06	)	$	0.82		$	0.05		$	0.13
	Diluted earnings (loss) per common share(3)
	Income (loss) from continuing operations(4)		$	(0.15	)	$	0.79		$	(0.13	)	$	(0.12	)
	Income (loss) from discontinued operations		0.09			0.03			0.18			0.25
	Diluted earnings (loss) per share		$	(0.06	)	$	0.82		$	0.05		$	0.13
	_________________
	-1	Oil, gas and NGL revenues and Income (loss) from operations are specific to our continuing operations.
	-2	During the quarter ended March 31, 2014, we sold our Malaysia business and recorded a gain of approximately $388 million ($252 million, after tax). During the fourth quarter, we reduced the previously recognized gain by $15 million ($10 million, after tax) due to recording an allowance against a receivable. See Note 3, "Discontinued Operations," for additional information.
	-3	The sum of the individual quarterly earnings (loss) per share may not agree with year-to-date earnings (loss) per share as each quarterly computation is based on the income or loss for that quarter and the weighted-average number of shares outstanding during that quarter.
	-4	Basic and diluted earnings per share includes an adjustment of $20 million related to the repurchase of preferred shares of a now wholly-owned subsidiary. See Note 2, "Earnings Per Share" for additional detail.

Supplementary_Oil_and_Gas_Disc1

Supplementary Oil and Gas Disclosure (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Supplementary Oil And Gas Disclosures Tables [Abstract]
Total Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities	The following tables present costs incurred for oil and gas property acquisitions, exploration and development for the respective years:
			Continuing Operations								Discontinued Operations
			Domestic				China				Malaysia			Total
			(In millions)
	2014:00:00
	Property acquisitions:
	Unproved		$	146			$	—			$	—		$	146
	Proved		6				—				—			6
	Exploration		1,089				—				—			1,089
	Development(1)		772				156				14			942
	Total costs incurred(2)		$	2,013			$	156			$	14		$	2,183
	2013:00:00
	Property acquisitions:
	Unproved		$	154			$	—			$	—		$	154
	Proved		8				1				—			9
	Exploration		966				33				101			1,100
	Development(1)		691				140				211			1,042
	Total costs incurred(2)		$	1,819			$	174			$	312		$	2,305
	2012:00:00
	Property acquisitions:
	Unproved		$	64			$	—			$	—		$	64
	Proved		3				—				—			3
	Exploration		929				1				63			993
	Development(1)		659				86				108			853
	Total costs incurred(2)		$	1,655			$	87			$	171		$	1,913
	_________________
	-1	Includes $56 million, $121 million and $9 million for 2014, 2013 and 2012, respectively, of asset retirement costs.
	-2	Other items impacting the capitalized costs of our oil and gas properties which are not included in total costs incurred are as follows:
			2014				2013				2012
			(In millions)
	Property sales — Domestic		$	635			$	23			$	606
	Property sales — International		1,571				—				—
	Ceiling test writedown — Domestic		—				—				1,488
			$	2,206			$	23			$	2,094
Estimated Net Quantities of Proved Oil and Gas Reserves	The following table sets forth our total net proved reserves and our total net proved developed and undeveloped reserves as of December 31, 2011, 2012, 2013 and 2014 and the changes in our total net proved reserves during the three-year period ended December 31, 2014:
			Crude Oil											Natural Gas (Bcf)
			and Condensate (MMBbls)
			Continuing Operations						Discontinued Operations					Continuing Operations					Discontinued Operations
			Domestic			China(1)			Malaysia(1)			Total		Domestic			China(1)		Malaysia(1)		Total
	Proved developed and undeveloped reserves as of:
	31-Dec-11		204			20			23			247		2,329			—		4		2,333
	Revisions of previous estimates		(13	)		—			2			(11	)	(525	)		—		(2	)	(527	)
	Extensions, discoveries and other additions		38			—			—			38		181			—		—		181
	Purchases of properties		—			—			—			—		1			—		—		1
	Sales of properties		(15	)		—			—			(15	)	(80	)		—		—		(80	)
	Production		(11	)		(1	)		(10	)		(22	)	(151	)		—		(2	)	(153	)
	31-Dec-12		203			19			15			237		1,755			—		—		1,755
	Revisions of previous estimates		19			7			2			28		(166	)		—		—		(166	)
	Extensions, discoveries and other additions		25			—			2			27		187			—		—		187
	Purchases of properties		1			—			—			1		1			—		—		1
	Sales of properties		—			—			—			—		(5	)		—		—		(5	)
	Production		(14	)		(1	)		(8	)		(23	)	(124	)		—		—		(124	)
	31-Dec-13		234			25			11			270		1,648			—		—		1,648
	Revisions of previous estimates		18			(2	)		—			16		129			—		—		129
	Extensions, discoveries and other additions		41			1			—			42		112			—		—		112
	Purchases of properties		6			—			—			6		9			—		—		9
	Sales of properties		(3	)		—			(10	)		(13	)	(164	)		—		—		(164	)
	Production		(18	)		(1	)		(1	)		(20	)	(127	)		—		—		(127	)
	31-Dec-14		278			23			—			301		1,607			—		—		1,607
	Proved developed reserves as of:
	31-Dec-11		88			5			17			110		1,405			—		4		1,409
	31-Dec-12		92			4			14			110		1,042			—		—		1,042
	31-Dec-13		112			4			11			127		1,055			—		—		1,055
	31-Dec-14		135			9			—			144		938			—		—		938
	Proved undeveloped reserves as of:
	31-Dec-11		116			15			6			137		924			—		—		924
	31-Dec-12		111			15			1			127		713			—		—		713
	31-Dec-13		122			21			—			143		593			—		—		593
	31-Dec-14		143			14			—			157		669			—		—		669
	_________________
	-1	All of our reserves in China are associated with production sharing contracts and are calculated using the economic interest method. We used the economic interest method in Malaysia until we sold our Malaysia business in 2014.
	Estimated Net Quantities of Proved Oil and Gas Reserves — (Continued)
			NGLs (MMBbls)											Total Oil Equivalents (MMBOE)
			Continuing Operations						Discontinued Operations					Continuing Operations					Discontinued Operations
			Domestic			China(1)			Malaysia(1)			Total		Domestic			China(1)		Malaysia(1)		Total
	Proved developed and undeveloped reserves as of:
	31-Dec-11		16			—			—			16		608			20		24		652
	Revisions of previous estimates		9			—			—			9		(92	)		—		1		(91	)
	Extensions, discoveries and other additions		17			—			—			17		86			—		—		86
	Purchases of properties		—			—			—			—		—			—		—		—
	Sales of properties		(2	)		—			—			(2	)	(30	)		—		—		(30	)
	Production		(3	)		—			—			(3	)	(40	)		(1	)	(10	)	(51	)
	31-Dec-12		37			—			—			37		532			19		15		566
	Revisions of previous estimates		14			—			—			14		5			7		2		14
	Extensions, discoveries and other additions		22			—			—			22		78			—		2		80
	Purchases of properties		—			—			—			—		2			—		—		2
	Sales of properties		—			—			—			—		(1	)		—		—		(1	)
	Production		(5	)		—			—			(5	)	(40	)		(1	)	(8	)	(49	)
	31-Dec-13		68			—			—			68		576			25		11		612
	Revisions of previous estimates		13			—			—			13		53			(2	)	—		51
	Extensions, discoveries and other additions		12			—			—			12		71			1		—		72
	Purchases of properties		1			—			—			1		9			—		—		9
	Sales of properties		(9	)		—			—			(9	)	(39	)		—		(10	)	(49	)
	Production		(9	)		—			—			(9	)	(48	)		(1	)	(1	)	(50	)
	31-Dec-14		76			—			—			76		622			23		—		645
	Proved developed reserves as of:
	31-Dec-11		10			—			—			10		332			5		18		355
	31-Dec-12		15			—			—			15		280			4		14		298
31-Dec-13		35			—			—			35		322			4		11		337
31-Dec-14		38			—			—			38		329			9		—		338
Proved undeveloped reserves as of:
31-Dec-11		6			—			—			6		276			15		6		297
31-Dec-12		22			—			—			22		252			15		1		268
31-Dec-13		33			—			—			33		254			21		—		275
31-Dec-14		38			—			—			38		293			14		—		307
_________________
-1	All of our reserves in China are associated with production sharing contracts and are calculated using the economic interest method. We used the economic interest method in Malaysia until we sold our Malaysia business in 2014.
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows	Set forth in the table below is a summary of the changes in the standardized measure of discounted future net cash flows for our proved oil and gas reserves during each of the years in the three-year period ended December 31, 2014:
			Continuing Operations								Discontinued Operations
			Domestic				China				Malaysia			Total
			(In millions)
	2014:00:00
	Beginning of the period		$	4,628			$	902			$	303		$	5,833
	Revisions of previous estimates:
	Changes in prices and costs		(492		)		(119		)		(132		)	(743		)
	Changes in quantities		784				(104		)		—			680
	Changes in future development costs		253				(72		)		129			310
	Previously estimated development costs incurred during the period		698				147				12			857
	Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs		860				—				—			860
	Purchases and sales of reserves in place, net		(171		)		—				(279		)	(450		)
	Accretion of discount		655				114				19			788
	Sales of oil and gas, net of production costs		(1,662		)		(21		)		(54		)	(1,737		)
	Net change in income taxes		(383		)		51				—			(332		)
	Production timing and other		160				(16		)		2			146
	Net increase (decrease)		702				(20		)		(303		)	379
	End of period		$	5,330			$	882			$	—		$	6,212
	2013:00:00
	Beginning of the period		$	3,408			$	612			$	416		$	4,436
	Revisions of previous estimates:
	Changes in prices and costs		944				2				33			979
	Changes in quantities		81				302				76			459
	Changes in future development costs		(83		)		(50		)		(126		)	(259		)
	Previously estimated development costs incurred during the period		549				130				79			758
	Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs		1,012				—				49			1,061
	Purchases and sales of reserves in place, net		13				—				—			13
	Accretion of discount		470				82				33			585
	Sales of oil and gas, net of production costs		(973		)		(46		)		(330		)	(1,349		)
	Net change in income taxes		(815		)		(63		)		59			(819		)
	Production timing and other		22				(67		)		14			(31		)
	Net increase (decrease)		1,220				290				(113		)	1,397
	End of period		$	4,628			$	902			$	303		$	5,833
	2012:00:00
	Beginning of the period		$	4,724			$	565			$	692		$	5,981
	Revisions of previous estimates:
	Changes in prices and costs		(1,490		)		(24		)		(14		)	(1,528		)
	Changes in quantities		(427		)		—				23			(404		)
	Changes in future development costs		294				(2		)		(19		)	273
	Previously estimated development costs incurred during the period		434				67				93			594
	Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs		791				24				—			815
	Purchases and sales of reserves in place, net		(758		)		—				—			(758		)
	Accretion of discount		542				77				64			683
	Sales of oil and gas, net of production costs		(1,129		)		(63		)		(439		)	(1,631		)
	Net change in income taxes		650				4				119			773
	Production timing and other		(223		)		(36		)		(103		)	(362		)
	Net increase (decrease)		(1,316		)		47				(276		)	(1,545		)
	End of period		$	3,408			$	612			$	416		$	4,436
Capitalized Costs of Oil and Gas Properties not Included in Cost Incurred	Other items impacting the capitalized costs of our oil and gas properties which are not included in total costs incurred are as follows:
			2014				2013				2012
			(In millions)
	Property sales — Domestic		$	635			$	23			$	606
	Property sales — International		1,571				—				—
	Ceiling test writedown — Domestic		—				—				1,488
			$	2,206			$	23			$	2,094
Summary Schedule of Estimated Quantities of Proved Oil and Gas Reserves	The following is a discussion of our proved reserves and reserve additions and revisions.
			Year Ended December 31,
			2014			2013			2012
			(MMBOE)
	Proved Reserves:
	Beginning of year		612			566			652
	Reserve additions		81			82			86
	Reserve revisions		51			14			(91	)
	Sales		(49	)		(1	)		(30	)
	Production		(50	)		(49	)		(51	)
	End of year		645			612			566
Standardized Measure Of Discounted Future Net Cash Flows Relating To Proved Oil and Gas Reserves	The standardized measure of discounted future net cash flows from our estimated proved oil and gas reserves is as follows:
			Continuing Operations								Discontinued Operations
			Domestic				China				Malaysia			Total
			(In millions)
	2014:00:00
	Future cash inflows		$	31,758			$	2,183			$	—		$	33,941
	Less related future:
	Production costs		(11,508		)		(784		)		—			(12,292		)
	Development and abandonment costs		(4,611		)		(73		)		—			(4,684		)
	Future net cash flows before income taxes		15,639				1,326				—			16,965
	Future income tax expense		(4,449		)		(221		)		—			(4,670		)
	Future net cash flows before 10% discount		11,190				1,105				—			12,295
	10% annual discount for estimating timing of cash flows		(5,860		)		(223		)		—			(6,083		)
	Standardized measure of discounted future net cash flows		$	5,330			$	882			$	—		$	6,212
	2013:00:00
	Future cash inflows		$	26,600			$	2,640			$	1,245		$	30,485
	Less related future:
	Production costs		(8,302		)		(959		)		(771		)	(10,032		)
	Development and abandonment costs		(4,166		)		(143		)		(148		)	(4,457		)
	Future net cash flows before income taxes		14,132				1,538				326			15,996
	Future income tax expense		(4,278		)		(316		)		—			(4,594		)
	Future net cash flows before 10% discount		9,854				1,222				326			11,402
	10% annual discount for estimating timing of cash flows		(5,226		)		(320		)		(23		)	(5,569		)
	Standardized measure of discounted future net cash flows		$	4,628			$	902			$	303		$	5,833
	2012:00:00
	Future cash inflows		$	21,724			$	2,186			$	1,754		$	25,664
	Less related future:
	Production costs		(7,042		)		(888		)		(1,135		)	(9,065		)
	Development and abandonment costs		(3,949		)		(202		)		(82		)	(4,233		)
	Future net cash flows before income taxes		10,733				1,096				537			12,366
	Future income tax expense		(2,786		)		(239		)		(66		)	(3,091		)
	Future net cash flows before 10% discount		7,947				857				471			9,275
	10% annual discount for estimating timing of cash flows		(4,539		)		(245		)		(55		)	(4,839		)
	Standardized measure of discounted future net cash flows		$	3,408			$	612			$	416		$	4,436
Capitalized Costs Relating to Oil and Gas Producing Activities	Capitalized costs for our oil and gas producing activities consisted of the following at the end of each of the years in the two-year period ended December 31, 2014:
			Continuing Operations								Discontinued Operations
			Domestic				China				Malaysia			Total
			(In millions)
	December 31, 2014:
	Proved properties		$	14,998			$	709			$	—		$	15,707
	Unproved properties		677				—				—			677
			15,675				709				—			16,384
	Accumulated depreciation, depletion and amortization		(8,022		)		(130		)		—			(8,152		)
	Net capitalized costs		$	7,653			$	579			$	—		$	8,232
	December 31, 2013:
	Proved properties		$	13,185			$	550			$	1,441		$	15,176
	Unproved properties		1,116				—				115			1,231
			14,301				550				1,556			16,407
	Accumulated depreciation, depletion and amortization		(7,185		)		(112		)		(1,009		)	(8,306		)
	Net capitalized costs		$	7,116			$	438			$	547		$	8,101
Results of Operations for Oil and Gas Producing Activities	The following tables present the results of our oil and gas producing activities for the years ending December 31:
			Continuing Operations								Discontinued Operations
			Domestic				China				Malaysia			Total
			(In millions)
	2014:00:00
	Revenues		$	2,240			$	39			$	90		$	2,369
	Production costs		299				12				11			322
	Production taxes and other operating expenses		279				6				25			310
	Depreciation, depletion and amortization		857				13				33			903
	Income taxes		282				2				8			292
	Results of operations for oil and gas producing activities		$	523			$	6			$	13		$	542
	2013:00:00
	Revenues		$	1,777			$	69			$	822		$	2,668
	Production costs		265				8				117			390
	Production taxes and other operating expenses		204				12				272			488
	Depreciation, depletion and amortization		668				18				244			930
	Income taxes		224				8				72			304
	Results of operations for oil and gas producing activities		$	416			$	23			$	117		$	556
	2012:00:00
	Revenues		$	1,469			$	86			$	1,005		$	2,560
	Production costs		292				7				101			400
	Production taxes and other operating expenses		174				18				259			451
	Depreciation, depletion and amortization		683				21				251			955
	Impairment of oil and gas properties		1,488				—				—			1,488
	Income taxes		(410		)		10				150			(250		)
	Results of operations for oil and gas producing activities		$	(758	)		$	30			$	244		$	(484	)

Organization_and_Summary_of_Si3

Organization and Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended			3 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2014	Dec. 31, 2011
	MBbls	MBbls
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	$1,000,000	$1,000,000	($6,000,000)		($9,000,000)
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	-2,000,000	1,000,000	-1,000,000		-1,000,000
Accumulated Other Comprehensive Income (Loss), Net of Tax	-1,000,000	2,000,000	-7,000,000		-10,000,000
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	0		3,000,000
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	-3,000,000	2,000,000	0
Other Comprehensive Income (Loss), Net of Tax	-3,000,000	9,000,000	3,000,000
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	-3,000,000	9,000,000	3,000,000
Other Comprehensive Income (Loss), Available-for-sale Securities, Tax, Including OTTI		7,000,000
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI for Write-down of Securities, Net of Tax		4,000,000
Change in asset retirement obligations [Line Items]
Less: Current portion of ARO	-3,000,000	-54,000,000
Asset Retirement Obligations, Noncurrent	183,000,000	201,000,000
Statement [Line Items]
Property, Plant and Equipment, Useful Life	25 years 0 months 0 days
Crude oil inventory in barrels	240,000	23,000
Capitalization of internal costs per full cost method of accounting	199,000,000	198,000,000	191,000,000
Document Fiscal Year Focus	2014
Discount rate	10.00%
Unweighted average commodity price of natural gas based on first-day-of-the-month prices for the prior 12 months (per MMBtu)	4.35	3.67	2.76
Unweighted average commodity price of oil based on first-day-of-the-month prices for the prior 12 months (per barrel)	94.98	96.82	94.84
Capitalized Costs Exceeding Ceiling, Net			948,000,000
Unrealized loss on post-retirement benefits	-2,000,000	1,000,000	-1,000,000		-1,000,000
Inventory Write-down	9,000,000		8,000,000
Asset retirement obligation liabilities settled through property sales	10,000,000		28,000,000
Primary Derivative Counterparties	10
Total Derivative Counterparties	16
Percent of future hedged production with primary counterparties	85.00%
Number of counterparties holding more than 25 percent of future hedge position.	0
Concentraction Of Future Hedged Production	15.00%
ConcentrationOfCounterpartiesUnderCreditFacility	40.00%
China [Member]
Statement [Line Items]
UnamortizedCostCapitalizedLessRelatedDeferredIncomeTaxesCeilingLimitationCushion	150,000,000
Domestic [Member]
Statement [Line Items]
UnamortizedCostCapitalizedLessRelatedDeferredIncomeTaxesCeilingLimitationCushion	400,000,000
Capitalized Cost Exceeding Ceiling, Gross			1,500,000,000
Sunoco Logistics Partners [Member]
Statement [Line Items]
Sales of oil and gas to customer	10.00%	13.00%
Royal Dutch Shell [Member]
Statement [Line Items]
Sales of oil and gas to customer		12.00%	14.00%
Tesoro Corporation [Member]
Statement [Line Items]
Sales of oil and gas to customer	12.00%	11.00%	14.00%
Big West Oil [Member]
Statement [Line Items]
Sales of oil and gas to customer			10.00%
Minimum [Member]
Statement [Line Items]
Property, Plant and Equipment, Useful Life	3 years 0 months 0 days
Maximum [Member]
Statement [Line Items]
Property, Plant and Equipment, Useful Life	7 years 0 months 0 days
Auction Rate Securities [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Proceeds from Sale of Available-for-sale Securities	39,000,000			39,000,000
Continuing Operations [Member]
Change in asset retirement obligations [Line Items]
Beginning Balance	122,000,000	102,000,000	108,000,000	122,000,000
Accretion expense	8,000,000	8,000,000	8,000,000
Additions	58,000,000	12,000,000	20,000,000
Revisions	16,000,000	8,000,000	12,000,000
Settlements	-18,000,000	-8,000,000	-46,000,000
Ending Balance	186,000,000	122,000,000	102,000,000
Less: Current portion of ARO	-3,000,000	-5,000,000	-5,000,000
Asset Retirement Obligations, Noncurrent	183,000,000	117,000,000	97,000,000
China [Member]
Change in asset retirement obligations [Line Items]
Additions	28,000,000
Domestic [Member]
Change in asset retirement obligations [Line Items]
Additions	30,000,000
Reclassification out of Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax		0
Other Comprehensive Income (Loss), Net of Tax		4,000,000
Other Comprehensive Income (Loss), Available-for-sale Securities, Tax, Including OTTI		4,000,000
Other Comprehensive Income (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax		2,000,000
Other Comprehensive Income (Loss), Net of Tax		5,000,000
Other Comprehensive Income (Loss), Available-for-sale Securities, Tax, Including OTTI		$3,000,000

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014										Dec. 31, 2013	Dec. 31, 2012
Income (numerator):
Income (Loss) from Continuing Operations Attributable to Parent	$367	$279	($23)	$27	($16)	$3	$107	($21)	$650										$73	($922)
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	-7	-1	1	257	33	24	4	13	250										74	-262
Net income (loss)	360	278	-22	284	17	27	111	-8	900										147	-1,184
Preferred Stock Dividends and Other Adjustments									0										-20	0
Net Income (Loss) Available to Common Stockholders, Basic									900										127	-1,184
Weighted average shares (denominator):
Weighted average shares - basic									137										135	135
Dilution effect of stock options and unvested restricted stock and restricted stock units outstanding at end of period									1										1	0
Weighted average shares - diluted									138										136	135
Basic --
Income (Loss) from Continuing Operations, Net of Tax, Before Preferred Share Repurchase, Per Basic Share									$4.76										$0.54	($6.85)
Income (Loss) Attributable to Repurchase of Preferred Shares of Wholly-owned Subsidiary, Per Basic Share									$0										($0.15)	$0
Income (Loss) from Continuing Operations, Per Basic Share	$2.67	$2.04	($0.16)	$0.19	($0.12)	($0.13)	$0.79	($0.15)	$4.76										$0.39	($6.85)
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share	($0.05)	$0	$0	$1.89	$0.25	$0.18	$0.03	$0.09	$1.83										$0.55	($1.95)
Earnings (Loss) Per Share, Basic	$2.62	$2.04	($0.16)	$2.08	$0.13	$0.05	$0.82	($0.06)	$6.59										$0.94	($8.80)
Diluted --
Income (Loss) from Continuing Operations, Net of Tax, Before Preferred Share Repurchase, Per Diluted Share									$4.71										$0.54	($6.85)
Income (Loss) Attributable to Repurchase of Preferred Shares of Wholly-owned Subsidiary, Per Diluted Share									$0										($0.15)	$0
Income (Loss) from Continuing Operations, Per Diluted Share	$2.65	$2.01	($0.16)	$0.19	($0.12)	($0.13)	$0.79	($0.15)	$4.71										$0.39	($6.85)
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share	($0.05)	$0	$0	$1.88	$0.25	$0.18	$0.03	$0.09	$1.81										$0.55	($1.95)
Earnings (Loss) Per Share, Diluted	$2.60	$2.01	($0.16)	$2.07	$0.13	$0.05	$0.82	($0.06)	$6.52										$0.94	($8.80)
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]									The following is the calculation of basic and diluted weighted-average shares outstanding and EPS for the indicated years:
											2014		2013			2012
											(In millions, except per share data)
									Income (numerator):
									Income (loss) from continuing operations		$	650	$	73		$	(922	)
									Income (loss) from discontinued operations, net of tax		250		74			(262		)
									Net income (loss)		900		147			(1,184		)
									Repurchase of preferred shares of subsidiary(3)		—		(20		)	—
									Net income (loss) attributable to common stockholders		$	900	$	127		$	(1,184	)
									Weighted-average shares (denominator):
									Weighted-average shares — basic		137		135			135
									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		138		136			135
									Earnings (loss) per share:
									Basic:
									Income (loss) from continuing operations before preferred share repurchase		$	4.76	$	0.54		$	(6.85	)
									Repurchase of preferred shares of subsidiary(3)		—		(0.15		)	—
									Income (loss) from continuing operations		4.76		0.39			(6.85		)
									Income (loss) from discontinued operations		1.83		0.55			(1.95		)
									Basic earnings (loss) per share		$	6.59	$	0.94		$	(8.80	)
									Diluted:
									Income (loss) from continuing operations before preferred share repurchase		$	4.71	$	0.54		$	(6.85	)
									Repurchase of preferred shares of subsidiary(3)		—		(0.15		)	—
									Income (loss) from continuing operations		4.71		0.39			(6.85		)
									Income (loss) from discontinued operations		1.81		0.55			(1.95		)
									Diluted earnings (loss) per share		$	6.52	$	0.94		$	(8.80	)
									_________________
									-1	Excludes 1.1 million and 4.0 million shares of unvested restricted stock or restricted stock units and stock options for the years ended December 31, 2014 and 2013, respectively, because including the effect would have been anti-dilutive.
									-2	The effect of unvested restricted stock or restricted stock units and stock options has not been included in the calculation of shares outstanding for diluted EPS for the year ended December 31, 2012, as their effect would have been anti-dilutive. Had we recognized income from continuing operations for that year, incremental shares attributable to the assumed vesting of unvested restricted stock and restricted stock units and the assumed exercise of outstanding stock options would have increased diluted weighted-averages shares outstanding by 0.7 million shares for the year ended December 31, 2012.
									-3	The numerator includes an adjustment of $20 million related to the repurchase of preferred shares of a now wholly-owned subsidiary, which reduces net income (loss) for purposes of earnings per share for the year ended December 31, 2013. The subsidiary is part of our continuing operations. See Note 16, "Related Party Transaction," for additional information.
Earnings Per Share (Textuals) [Abstract]
Incremental shares attributable to the assumed exercise of outstanding stock options and the assumed vesting of unvested restricted stock and restricted stock units									1.1										4	0.7
Payments for Repurchase of Preferred Stock and Preference Stock									$0										$20	$0

Discontinued_Operations_Detail

Discontinued Operations (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	MBbls				MBbls				MBbls	MBbls
Change in asset retirement obligations [Line Items]
Less: Current portion of ARO	($3)				($54)				($3)	($54)
Asset Retirement Obligations, Noncurrent	183				201				183	201
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal Group, Including Discontinued Operation, Other Expense									0	4	-1
Disposal Group, Including Discontinued Operation, Consideration	898								898
Gain on Sale of Malaysia, Before Income Tax									373	0	0
Disposal Group, Including Discontinued Operation, Operating Income (Loss)									21	171	387
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	-7	-1	1	257	33	24	4	13	250	74	-262
Discontinued Operation, Tax Effect of Discontinued Operation									144	101	648
Historical Effective Tax Rate, Discontinuing Operations									38.00%
Effective Income Tax Rate, Discontinuing Operations									37.00%	58.00%	168.00%
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	677				1,300				677	1,300
Less - accumulated depreciation, depletion and amortization	8,152				8,306				8,152	8,306
Energy Related Inventory, Petroleum	8				1				8	1
Crude oil inventory in barrels	240,000				23,000				240,000	23,000
Disposal Group, Including Discontinued Operation, Revenue									90	823	1,005
Disposal Group, Including Discontinued Operation, Operating Expense									69	652	618
Disposal Group, Including Discontinued Operation, Operating Income (Loss)									21	171	387
Gain on Sale of Malaysia, Before Income Tax									373	0	0
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax									394	175	386
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	-7	-1	1	257	33	24	4	13	250	74	-262
Disposal Group, Including Discontinued Operation, Cash and Cash Equivalents					55					55
Disposal Group, Including Discontinued Operation, Accounts, Notes and Loans Receivable, Net					142					142
Disposal Group, Including Discontinued Operation, Inventory					121					121
Disposal Group, Including Discontinued Operation, Other Current Assets					29					29
Assets of Disposal Group, Including Discontinued Operation, Current					347					347
Disposal Group, including Discontinued Operations, Oil and Gas Properties, Net					547					547
Disposal Group, Including Discontinued Operation, Deferred Tax Assets					19					19
Disposal Group, Including Discontinued Operation, Other Noncurrent Assets					3					3
Disposal Group, Including Discontinued Operation, Long Lived Assets, Noncurrent					569					569
Assets of Disposal Group, Including Discontinued Operation					916					916
Disposal Group, Including Discontinued Operation, Accounts Payable					34					34
Disposal Group, Including Discontinued Operation, Accrued Liabilities					185					185
Disposal Group, Including Discontinued Operations, Asset Retirement Obligation, Current					49					49
Disposal Group, Including Discontinued Operation, Other Current Liabilities					18					18
Liabilities of Disposal Group, Including Discontinued Operation, Current					286					286
Disposal Group, Including Discontinued Operations, Asset Retirement Obligations					84					84
Disposal Group, Including Discontinued Operation, Deferred Tax Liabilities					29					29
Disposal Group, Including Discontinued Operation, Other Noncurrent Liabilities					11					11
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent					124					124
Liabilities of Disposal Group, Including Discontinued Operation					410					410
Unweighted average commodity price of oil based on first day of month prices for prior twelve months	94.98				96.82				94.98	96.82	94.84
Unweighted average commodity price of natural gas based on first day of month prices for prior twelve months	4.35				3.67				4.35	3.67	2.76
Discontinued Operations [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Less - accumulated depreciation, depletion and amortization					1,009					1,009
Energy Related Inventory, Petroleum					89					89
Crude oil inventory in barrels					1,100,000					1,100,000
Costs incurred in 2011 and prior not subject to amortization [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	110								110
Costs incurred in 2012 not subject to amortization [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	41								41
Costs incurred in 2013 not subject to amortization [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	177								177
Costs incurred in 2014 not subject to amortization [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	349								349
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	88	179
Deferred [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Discontinued Operation, Tax Effect of Discontinued Operation									132	13	469
Malaysia [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain on Sale of Malaysia, Before Income Tax	-15			388
Gain on Sale of Malaysia, Net of Tax	-10			252
Gain on Sale of Malaysia, Before Income Tax	-15			388
Discontinued Operations [Member]
Change in asset retirement obligations [Line Items]
Beginning Balance				133				40	133	40	37
Accretion expense									1	3	3
Additions									0	4	4
Revisions									0	101	0
Settlements									-134	-15	-4
Ending Balance	0				133				0	133	40
Less: Current portion of ARO	0				-49				0	-49	-5
Asset Retirement Obligations, Noncurrent	$0				$84				$0	$84	$35

Oil_and_Gas_Assets_Details

Oil and Gas Assets (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Oil and gas properties:
Subject to amortization	$15,707,000,000	$15,107,000,000
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	677,000,000	1,300,000,000
Oil and Gas Property, Full Cost Method, Gross	16,384,000,000	16,407,000,000
Oil and Gas Property, Full Cost Method, Depletion	8,152,000,000	8,306,000,000
Oil and Gas Property, Full Cost Method, Net	8,232,000,000	8,101,000,000
Accumulated depreciation and amortization	-76,000,000	-69,000,000
Net other property and equipment	182,000,000	174,000,000
Cost of oil and gas properties not subject to amortization
Acquisition costs	469,000,000
Exploration costs	114,000,000
Fee mineral interests	24,000,000
Capitalized interest	70,000,000
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	677,000,000	1,300,000,000
Oil and Gas Assets (Textuals) [Abstract]
Increase (Decrease) in Unproved Oil and Gas Property	760,000,000
Proceeds from Sale of Oil and Gas Property and Equipment	620,000,000	36,000,000	630,000,000
Granite Wash [Member]
Oil and Gas Assets (Textuals) [Abstract]
Sales of Oil and Gas Prospects	588,000,000
Gulf of Mexico [Member]
Oil and Gas Assets (Textuals) [Abstract]
Proceeds from Sale of Oil and Gas Property and Equipment			208,000,000
Other Property [Member]
Oil and Gas Assets (Textuals) [Abstract]
Value of Assets acquired	33,000,000	72,000,000	9,000,000
Proceeds from Sale of Oil and Gas Property and Equipment	69,000,000	36,000,000	422,000,000
Furniture and Fixtures [Member]
Oil and gas properties:
Other property and equipment	144,000,000	139,000,000
Gas Gathering and Processing Equipment [Member]
Oil and gas properties:
Other property and equipment	114,000,000	104,000,000
Costs incurred in 2014 not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	349,000,000
Cost of oil and gas properties not subject to amortization
Acquisition costs	185,000,000
Exploration costs	111,000,000
Fee mineral interests	0
Capitalized interest	53,000,000
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	349,000,000
Costs incurred in 2013 not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	177,000,000
Cost of oil and gas properties not subject to amortization
Acquisition costs	159,000,000
Exploration costs	0
Fee mineral interests	1,000,000
Capitalized interest	17,000,000
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	177,000,000
Costs incurred in 2012 not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	41,000,000
Cost of oil and gas properties not subject to amortization
Acquisition costs	41,000,000
Exploration costs	0
Fee mineral interests	0
Capitalized interest	0
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	41,000,000
Costs incurred in 2011 and prior not subject to amortization [Member]
Oil and gas properties:
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	110,000,000
Cost of oil and gas properties not subject to amortization
Acquisition costs	84,000,000
Exploration costs	3,000,000
Fee mineral interests	23,000,000
Capitalized interest	0
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	$110,000,000

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Textuals) (Details) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Natural gas contracts [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Total	$103
Oil contracts [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Total	510
Year2015 [Member] | Natural gas contracts [Member] | Swap [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	4.28
Derivative Asset, Fair Value, Total	62
Volume In Mmbtus	49,275,000
Year2015 [Member] | Natural gas contracts [Member] | Collars [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price	3.93
Derivative, Average Cap Price	4.74
Derivative Asset, Fair Value, Total	36
Volume In Mmbtus	38,325,000
Year2015 [Member] | Oil contracts [Member] | Swap [Member]
Derivative [Line Items]
Volume in MBbls	2,275,000
Derivative, Swap Type, Average Fixed Price	90.2
Derivative Asset, Fair Value, Total	78
Year2015 [Member] | Oil contracts [Member] | Fixed Price Swaps With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls	15,019,000
Year2015 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Swap [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	90.02
Derivative Asset, Fair Value, Total	495
Year2015 [Member] | Oil contracts [Member] | Collars With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls	730,000
Year2015 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price	71.67
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-258
Year2015 [Member] | Oil contracts [Member] | Collars with Sold Puts - Collar [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price	90
Derivative, Average Cap Price	104
Derivative Asset, Fair Value, Total	25
Year2015 [Member] | Oil contracts [Member] | Collars with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price	75
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-15
Year 2016 [Member] | Natural gas contracts [Member] | Swaption [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	4.1
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-2
Volume In Mmbtus	14,640,000
Year 2016 [Member] | Natural gas contracts [Member] | Collars [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price	4
Derivative, Average Cap Price	4.54
Derivative Asset, Fair Value, Total	7
Volume In Mmbtus	10,980,000
Year 2016 [Member] | Oil contracts [Member] | Swaption [Member]
Derivative [Line Items]
Volume in MBbls	732,000
Derivative, Swap Type, Average Fixed Price	91
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	0
Year 2016 [Member] | Oil contracts [Member] | Fixed Price Swaps With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls	10,060,000
Year 2016 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Swap [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	89.98
Derivative Asset, Fair Value, Total	266
Year 2016 [Member] | Oil contracts [Member] | Collars With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls	6,220,000
Year 2016 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price	74.14
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-174
Year 2016 [Member] | Oil contracts [Member] | Collars with Sold Puts - Collar [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price	90
Derivative, Average Cap Price	96.15
Derivative Asset, Fair Value, Total	170
Year 2016 [Member] | Oil contracts [Member] | Collars with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price	75
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-112
Year2017 [Member] | Oil contracts [Member] | Fixed Price Swaps With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls	4,468,000
Year2017 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Swap [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	88.37
Derivative Asset, Fair Value, Total	93
Year2017 [Member] | Oil contracts [Member] | Collars With Sold Puts [Member]
Derivative [Line Items]
Volume in MBbls	2,080,000
Year2017 [Member] | Oil contracts [Member] | Fixed Price Swaps with Sold Puts - Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price	73.28
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-72
Year2017 [Member] | Oil contracts [Member] | Collars with Sold Puts - Collar [Member]
Derivative [Line Items]
Derivative, Weighted Average Floor Price	90
Derivative, Average Cap Price	95.59
Derivative Asset, Fair Value, Total	50
Year2017 [Member] | Oil contracts [Member] | Collars with Sold Puts - Sold Put [Member]
Derivative [Line Items]
Derivative Average Additional Put Price	75
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	($36)

Outstanding_Natural_Gas_Contra

Outstanding Natural Gas Contracts That Are Not Designated for Hedge Accounting (Details) (Natural gas contracts [Member], USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Derivative [Line Items]
Derivative Asset, Fair Value, Total	$103
Collars [Member] | Year2015 [Member]
Derivative [Line Items]
Natural Gas Volumes	38,325,000
Derivative, Weighted Average Floor Price	3.93
Derivative, Weighted Average Ceiling Price	4.74
Derivative Asset, Fair Value, Total	36
Fixed-price swaps | Year2015 [Member]
Derivative [Line Items]
Natural Gas Volumes	49,275,000
Derivative, Swap Type, Average Fixed Price	4.28
Derivative Asset, Fair Value, Total	$62

Outstanding_Oil_Contracts_That

Outstanding Oil Contracts That Are Not Designated For Hedge Accounting (Details) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Oil contracts [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Total	$510
Natural gas contracts [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Total	103
Fixed Price Swaps With Sold Puts [Member] | Oil contracts [Member] | Year2015 [Member]
Derivative [Line Items]
Volume in MBbls	15,019,000
Collars With Sold Puts [Member] | Oil contracts [Member] | Year2015 [Member]
Derivative [Line Items]
Volume in MBbls	730,000
Fixed-price swaps | Oil contracts [Member] | Year2015 [Member]
Derivative [Line Items]
Volume in MBbls	2,275,000
Derivative, Swap Type, Average Fixed Price	90.2
Derivative Asset, Fair Value, Total	78
Fixed-price swaps | Natural gas contracts [Member] | Year2015 [Member]
Derivative [Line Items]
Derivative, Swap Type, Average Fixed Price	4.28
Derivative Asset, Fair Value, Total	$62

Derivative_Financial_Instrumen3

Derivative Financial Instruments Recorded in Balance Sheet (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Asset	$599	$11
Derivative Asset Not Designated As Hedging Instrument, Fair Value	1,220	37
Derivative Asset, Fair Value, Gross Liability	-599	-11
Derivative Asset, Current	431	0
Derivative Asset, Noncurrent	190	26
Derivative Liability, Current	-8	-62
Derivative Liability, Noncurrent	0	0
Derivative Liability, Fair Value, Gross Liability	-607	-73
Derivative Liability Not Designated as Hedging Instrument Fair Value	-607	-73
Natural gas contracts [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Asset	2	2
Derivative Asset, Fair Value, Total	103
Derivative Asset Not Designated As Hedging Instrument, Fair Value	105	11
Derivative Asset, Fair Value, Gross Liability	-2	-2
Derivative Asset, Current	99	0
Derivative Asset, Noncurrent	4	9
Derivative Liability, Current	0	-20
Derivative Liability, Noncurrent	0	0
Derivative Liability, Fair Value, Gross Liability	-2	-22
Derivative Liability Not Designated as Hedging Instrument Fair Value	-2	-22
Oil contracts [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Asset	597	9
Derivative Asset, Fair Value, Total	510
Derivative Asset Not Designated As Hedging Instrument, Fair Value	1,115	26
Derivative Asset, Fair Value, Gross Liability	-597	-9
Derivative Asset, Current	332	0
Derivative Asset, Noncurrent	186	17
Derivative Liability, Current	-8	-42
Derivative Liability, Noncurrent	0	0
Derivative Liability, Fair Value, Gross Liability	-605	-51
Derivative Liability Not Designated as Hedging Instrument Fair Value	($605)	($51)

Amount_of_Gain_Loss_Recognized

Amount of Gain Loss Recognized in Income Related to Derivative Financial Instruments (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	($39)	$60	$135
Unrealized Gain (Loss) on Derivatives	649	-157	-15
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	610	-97	120
Natural gas contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	-36	66	144
Unrealized Gain (Loss) on Derivatives	114	-81	-124
Oil contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	-3	-6	1
Unrealized Gain (Loss) on Derivatives	535	-76	99
Basis contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]
Realized Gain (Loss) on Derivatives	0	0	-10
Unrealized Gain (Loss) on Derivatives	$0	$0	$10

Accounts_Receivable_Details

Accounts Receivable (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Accounts Notes And Loans Receivable [Line Items]
Malaysia Reserve for Doubtful Accounts Allowance	$15
Accounts receivable	405	474
Revenue [Member]
Accounts Notes And Loans Receivable [Line Items]
Accounts receivable	155	294
Other accounts receivable [Member]
Accounts Notes And Loans Receivable [Line Items]
Accounts receivable	36	25
Allowance For Doubtful Accounts [Member]
Accounts Notes And Loans Receivable [Line Items]
Accounts receivable	-16	-1
Oil and Gas Joint Interest Billing [Member]
Accounts Notes And Loans Receivable [Line Items]
Accounts receivable	$230	$156

Accrued_Liabilities_Details

Accrued Liabilities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Accrued Liabilities [Line Items]
Accrued liabilities	$880	$978
Revenue payable [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	197	175
Accrued capital costs [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	441	458
Accrued lease operating expenses [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	47	71
Employee incentive expense [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	62	64
Accrued interest on debt [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	67	72
Taxes payable [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	32	93
Other accrued liabilities [Member]
Accrued Liabilities [Line Items]
Accrued liabilities	$34	$45

Fair_Value_Measurements_Textua

Fair Value Measurements (Textuals) (Details) (USD $)	12 Months Ended			3 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2014	Dec. 31, 2011
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value		($26)	($151)		($103)
Liability Value	-384
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) Included in Investment Income		-16	82
Money Market Funds, at Carrying Value	1	2
Deferred Compensation Plan Assets	9	8
Assets, Fair Value Disclosure	618	5
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	-419	-90	135
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	0	10	4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	39
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	45	45	91
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3	0	0	0
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)	-373
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	3	0	0
Obligations, Fair Value Disclosure	-15	-16
Accumulated Other Comprehensive Income Loss Available For Sale Securities Adjustment Gross Of Tax		6
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI for Write-down of Securities, Net of Tax		4
Swap [Member]
Derivative Assets	994
Derivative Liability		-28
Auction Rate Securities [Member]
Available-for-sale Securities, Fair Value Disclosure		39
Proceeds from Sale of Available-for-sale Securities	39			39
Commodity Option [Member]
Derivative Liability	-381	-8
Equity Securities [Member]
Available-for-sale Securities, Fair Value Disclosure	10	8
Oil contracts [Member]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	510
Oil contracts [Member] | Options Held [Member]
Derivative Liability, Fair Value, Total	-422
Oil contracts [Member] | Maximum [Member] | Options Held [Member]
Fair Value Assumptions Expected Volatility Curves	63.41%
Fair Value Inputs, Entity Credit Risk	1.76%
Oil contracts [Member] | Minimum [Member] | Options Held [Member]
Fair Value Assumptions Expected Volatility Curves	28.03%
Fair Value Inputs, Entity Credit Risk	0.01%
Natural Gas [Member]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	103
Natural Gas [Member] | Options Held [Member]
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	41
Natural Gas [Member] | Maximum [Member] | Options Held [Member]
Fair Value Assumptions Expected Volatility Curves	60.53%
Fair Value Inputs, Entity Credit Risk	1.12%
Natural Gas [Member] | Minimum [Member] | Options Held [Member]
Fair Value Assumptions Expected Volatility Curves	23.11%
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	1	2
Deferred Compensation Plan Assets	9	8
Assets, Fair Value Disclosure	8	7
Obligations, Fair Value Disclosure	-12	-11
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member] | Swap [Member]
Derivative Assets	0	0
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member] | Auction Rate Securities [Member]
Available-for-sale Securities, Fair Value Disclosure		0
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member] | Commodity Option [Member]
Derivative Assets	0	0
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member] | Equity Securities [Member]
Available-for-sale Securities, Fair Value Disclosure	10	8
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	994
Financial and Nonfinancial Liabilities, Fair Value Disclosure		-28
Obligations, Fair Value Disclosure	0	0
Significant Other Observable Fair Value Inputs (Level 2) [Member] | Swap [Member]
Derivative Assets	994
Derivative Liability		-28
Significant Other Observable Fair Value Inputs (Level 2) [Member] | Auction Rate Securities [Member]
Available-for-sale Securities, Fair Value Disclosure		0
Significant Other Observable Fair Value Inputs (Level 2) [Member] | Commodity Option [Member]
Derivative Assets	0	0
Significant Other Observable Fair Value Inputs (Level 2) [Member] | Equity Securities [Member]
Available-for-sale Securities, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member]
Liability Value	-384
Money Market Funds, at Carrying Value	0	0
Deferred Compensation Plan Assets	0	0
Assets, Fair Value Disclosure		26
Obligations, Fair Value Disclosure	-3	-5
Fair Value, Inputs, Level 3 [Member] | Swap [Member]
Derivative Assets	0	0
Fair Value, Inputs, Level 3 [Member] | Auction Rate Securities [Member]
Available-for-sale Securities, Fair Value Disclosure		39
Fair Value, Inputs, Level 3 [Member] | Commodity Option [Member]
Derivative Liability	-381	-8
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member]
Available-for-sale Securities, Fair Value Disclosure	0	0
Derivative Financial Instruments, Assets [Member]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value			-115		-71
Liability Value		-8
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) Included in Investment Income			82
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings		-66	135
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)		0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements		57	91
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3	0	0	0
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)		-10
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	3	0	0
Investments [Member]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0	-39	-36		-32
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) Included in Investment Income	0	-6	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	0	-6	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	0	10	4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	39
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	0	1	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	0	0	0
6.875% Senior Subordinated Notes due 2020 [Member]
Debt Instrument, Fair Value Disclosure	721	755
7.125% Senior Subordinated Notes due 2018 [Member]
Debt Instrument, Fair Value Disclosure	0	624
5.625% Senior Notes Due 2024 [Member]
Debt Instrument, Fair Value Disclosure	989	1,025
5.75 %Senior Notes Due 2022 [Member]
Debt Instrument, Fair Value Disclosure	772	767
Stockholder Value Appreciation Program [Member]
Liability Value	-3
Derivative Financial Instruments, Assets [Member]
Liability Value	-381
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	-381
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	5
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)	-375
Stock Compensation Plan [Member]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value			0		0
Liability Value	-3	-5
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) Included in Investment Income			0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	-38	-18	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements			0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3	0	0	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	40	13
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)	2	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers out of Level 3	$0	$0	$0
Implied [Member] | Stockholder Value Appreciation Program [Member]
SBC Expected Volatility Rate, Maximum	50.20%

Valuation_of_Investments_and_F

Valuation of Investments and Financial Instrument Assets Liabilities By Pricing Levels (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Money market fund investments	$1	$2
Deferred Compensation Plan Assets	9	8
Total	618	5
Equity Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Available-for-sale Securities	10	8
Auction Rate Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Available-for-sale Securities		39
Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts	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]
Money market fund investments	1	2
Deferred Compensation Plan Assets	9	8
Total	8	7
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	10	8
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member] | Auction Rate Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Available-for-sale Securities		0
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	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]
Money market fund investments	0	0
Deferred Compensation Plan Assets	0	0
Total	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] | Auction Rate Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Available-for-sale Securities		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	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]
Money market fund investments	0	0
Deferred Compensation Plan Assets	0	0
Total		26
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] | Auction Rate Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Available-for-sale Securities		39
Fair Value, Inputs, Level 3 [Member] | Swap [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Oil and gas derivative contracts	$0	$0

Reconciliation_of_Changes_in_F

Reconciliation of Changes in Fair Value of Financial Assets and Liabilities Classified as Level Three In Fair Value Hierarchy (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	$26	$151	$103
Included in earnings	-419	-90	135
Included in other comprehensive income (loss)	0	10	4
Settlements	-45	-45	-91
Ending Balance		26	151
Change in unrealized gains (losses) relating to investments and derivatives still held		-16	82
Derivatives [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance		115	71
Included in earnings		-66	135
Included in other comprehensive income (loss)		0	0
Settlements		-57	-91
Ending Balance			115
Change in unrealized gains (losses) relating to investments and derivatives still held			82
Investments [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	39	36	32
Included in earnings	0	-6	0
Included in other comprehensive income (loss)	0	10	4
Settlements	0	-1	0
Ending Balance	0	39	36
Change in unrealized gains (losses) relating to investments and derivatives still held	$0	($6)	$0

Quantitative_Information_about

Quantitative Information about Level 3 Fair Value Measurements (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Fair Value, Option, Quantitative Disclosures [Line Items]
Liability Value	-384
Stockholder Value Appreciation Program [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Liability Value	-3
Stockholder Value Appreciation Program [Member] | Historical [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
SBC Expected Volatility Rate, Maximum	50.20%
Natural gas contracts [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Derivative Asset, Fair Value, Total	103
Oil contracts [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Derivative Asset, Fair Value, Total	510
Options Held [Member] | Natural gas contracts [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Derivative Asset, Fair Value, Total	41
Options Held [Member] | Natural gas contracts [Member] | Maximum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Credit Risk	1.12%
Fair Value Assumptions Expected Volatility Curves	60.53%
Options Held [Member] | Natural gas contracts [Member] | Minimum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Credit Risk	0.01%
Fair Value Assumptions Expected Volatility Curves	23.11%
Options Held [Member] | Oil contracts [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Derivative Liability, Fair Value, Total	422
Options Held [Member] | Oil contracts [Member] | Maximum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Credit Risk	1.76%
Fair Value Assumptions Expected Volatility Curves	63.41%
Options Held [Member] | Oil contracts [Member] | Minimum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Credit Risk	0.01%
Fair Value Assumptions Expected Volatility Curves	28.03%

Debt_Details

Debt (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding	$446,000,000	$649,000,000
Long-term debt	2,892,000,000	3,694,000,000
Net proceeds from issuance of Senior Notes		990,000,000
Early Repayment of Subordinated Debt	600,000,000	0	875,000,000
Payments Of Debt Extinguishment Costs	14,000,000
Write off of Deferred Debt Issuance Cost	3,000,000
Debt (Textuals)
Line of Credit Facility, Maximum Borrowing Capacity	1,400,000,000
Largest individual loan commitment by any lender of total commitments	14.00%
Percentage of basis points to be added for calculation of interest rate	0.50%
Percent added to prime rate based on grid of our debt rating	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%
Commitment fees incurred	4,000,000	3,000,000	3,000,000
Ratio of Indebtedness to Net Capital 1	0.6
Ratio of total debt to earnings before gain or loss on disposition of assets, interest expense, income taxes and noncash items	3
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%
Line of Credit Facility, Current Borrowing Capacity	94,000,000
Discount On Notes [Member]
Debt Instrument [Line Items]
Long-term debt	-4,000,000	-5,000,000
6.875% Senior Subordinated Notes due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt	700,000,000	700,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.88%	6.88%
7.125% Senior Subordinated Notes due 2018 [Member]
Debt Instrument [Line Items]
Long-term debt	0	600,000,000
Debt Instrument, Interest Rate, Stated Percentage	7.13%	7.13%
Early Repayment of Subordinated Debt	600,000,000
Total senior unsecured debt
Debt Instrument [Line Items]
Long-term debt	2,196,000,000	2,399,000,000
5.625% Senior Notes Due 2024 [Member]
Debt Instrument [Line Items]
Long-term debt	1,000,000,000	1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.63%	5.63%
5.75 %Senior Notes Due 2022 [Member]
Debt Instrument [Line Items]
Long-term debt	750,000,000	750,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.75%	5.75%
Money market lines of credit [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding	101,000,000	64,000,000
Revolving Credit Facility Libor Based Loans [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding	$345,000,000	$585,000,000

Income_Taxes_Details

Income Taxes (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Contingency [Line Items]
Total income (loss) before income taxes	$1,032,000,000	$201,000,000	($1,374,000,000)
Components of Deferred Tax Assets and Liabilities [Abstract]
Valuation Allowance, Amount	-549,000,000	-584,000,000	-457,000,000	-11,000,000
Deferred tax asset:
Net operating loss carryforwards	173,000,000	335,000,000
Alternative minimum tax credit	99,000,000	99,000,000
Stock compensation	26,000,000	25,000,000
Marketable securities	0	3,000,000
Oil and gas properties	0	59,000,000
Valuation Allowance	-549,000,000	-584,000,000	-457,000,000	-11,000,000
Foreign tax credit	547,000,000	535,000,000
Other	8,000,000	6,000,000
Deferred tax asset	304,000,000	491,000,000
Commodity derivatives	0	13,000,000
Deferred tax liability:
Commodity derivatives	-217,000,000	0
Oil and gas properties	-1,715,000,000	-1,592,000,000
Deferred tax liability	-1,932,000,000	-1,592,000,000
Deferred Tax Assets (Liabilities), Net, Total	-1,628,000,000	-1,101,000,000
Deferred Tax Liabilities, Net, Current	-144,000,000	0
Less net current deferred tax liability	0	22,000,000
Deferred Tax Assets (Liabilities), Net, Noncurrent	-1,484,000,000	-1,123,000,000
Deferred Tax Assets, Gross	853,000,000	1,075,000,000
Income tax reconciliation to US federal statutory rate
Amount computed using the statutory rate	361,000,000	70,000,000	-481,000,000
Increase (decrease) in taxes resulting from:
State and local income taxes, net of federal effect	17,000,000	8,000,000	-18,000,000
Other	3,000,000	-1,000,000	0
Total income tax provision (benefit)	382,000,000	128,000,000	-452,000,000
Income Taxes (Textuals) [Abstract]
Federal statutory tax rate	35.00%
Net operating loss carryforwards subject to annual limitations	155,000,000
International Nols That We Do Not Anticipate Utilizing		17,000,000
US state NOLs that we do not anticipate utilizing	64,000,000
U.S. [Member]
Income Tax Contingency [Line Items]
Total income (loss) before income taxes	1,022,000,000	170,000,000	-1,414,000,000
Foreign [Member]
Income Tax Contingency [Line Items]
Total income (loss) before income taxes	10,000,000	31,000,000	40,000,000
Increase (decrease) in taxes resulting from:
Valuation allowance, state net of federal	1,000,000	53,000,000	47,000,000
State and Local Jurisdiction [Member]
Components of Deferred Tax Assets and Liabilities [Abstract]
Operating Loss Carryforwards	1,600,000,000	1,700,000,000
Increase (decrease) in taxes resulting from:
Valuation allowance, state net of federal	0	-2,000,000	0
Federal [Member]
Components of Deferred Tax Assets and Liabilities [Abstract]
Operating Loss Carryforwards	500,000,000	1,000,000,000
Valuation Allowance, Tax Credit Carryforward [Member] | Foreign [Member]
Income Tax Contingency [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	12,000,000	114,000,000	421,000,000
Valuation Allowance, Tax Credit Carryforward [Member] | Malaysia [Member]
Income Tax Contingency [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	-40,000,000	15,000,000	25,000,000
Valuation Allowance, Operating Loss Carryforwards [Member] | U.S. [Member]
Income Tax Contingency [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	($1,000,000)	($2,000,000)	$0

Income_Taxes_Breakout_of_Provi

Income Taxes- Breakout of Provision (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current taxes:
U.S. federal	$0	($4)	$1
U.S. state	2	0	1
Foreign	3	2	14
Deferred taxes:
U.S. federal	350	53	-479
U.S. state	25	13	-34
Foreign	2	64	45
Total income tax provision (benefit)	382	128	-452
State and Local Jurisdiction [Member]
Income Tax Provision [Line Items]
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	0	-2	0
Foreign [Member]
Income Tax Provision [Line Items]
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	$1	$53	$47

Income_Taxes_DTA_Valuation_Rol

Income Taxes- DTA Valuation Rollforward (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Valuation Allowance [Line Items]
International Nols That We Do Not Anticipate Utilizing		$17,000,000
Balance at the beginning of the year				-11,000,000
Balance at the end of the year	-549,000,000	-584,000,000	-457,000,000	-11,000,000
Deferred Tax Assets, Tax Credit Carryforwards, Foreign	547,000,000	535,000,000
Internal Revenue Service (IRS) [Member]
Valuation Allowance [Line Items]
Operating Loss Carryforwards	500,000,000	1,000,000,000
Valuation Allowance, Tax Credit Carryforward [Member] | Malaysia [Member]
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	40,000,000	-15,000,000	-25,000,000
Valuation Allowance, Tax Credit Carryforward [Member] | Foreign [Member]
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	-12,000,000	-114,000,000	-421,000,000
Valuation Allowance, Tax Credit Carryforward [Member] | Other International [Member]
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	6,000,000	0	0
Valuation Allowance, Operating Loss Carryforwards [Member] | U.S. [Member]
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Change in Amount	$1,000,000	$2,000,000	$0

Income_Taxes_Breakout_of_Incom

Income Taxes- Breakout of Income (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Total income (loss) before income taxes	$1,032	$201	($1,374)

StockBased_Compensation_Detail

Stock-Based Compensation (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost	$105	$75	$47
Total stock-based compensation expense	65	55	35
Capitalized in oil and gas properties	-40	-20	-12
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	803,000	2,728,000	1,773,000
Number of restricted stock shares vested	1,176,000	1,195,000	1,066,000
Number of restricted stock shares outstanding	2,847,000	3,705,000	2,809,000	2,480,000
Fair value of units vested during the period	43	47	44
Share Based Compensation Arrangement Exercise Rate	20.00%
Nonvested Awards, Total Compensation Cost Not yet Recognized	70
Liability Value	384
Obligations, Fair Value Disclosure	15	16
Stock-Based Compensation (Textuals) [Abstract]
Unrecognized net operating loss related to Stock Based Compensation	99
Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition	4 years 0 months
Last reported sales price of our common stock on the New York Stock Exchange per share	$27.12
$27.50 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SVAP Price Threshold		$27.50
$32.50 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SVAP Price Threshold	$32.50
$37.50 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SVAP Price Threshold	$37.50
$42.50 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SVAP Price Threshold	$42.50
Equity [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost	47	48	46
Liability [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost	58	27	1
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Reduction factor multiplied by number of shares awarded	1
Additional shares available for issuance	2,300,000
Cash-Settled Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost	20	9	1
Service Period	3 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	759,000
Number of restricted stock shares vested	587,000	85,000
Number of restricted stock shares outstanding	1,200,000
Nonvested Awards, Total Compensation Cost Not yet Recognized	18
Liability Settlements	19	2
Obligations, Fair Value Disclosure	12
Stockholder Value Appreciation Program [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost	38	18	0
Service Period	1 year
Nonvested Awards, Total Compensation Cost Not yet Recognized	1
Weighted Average Volatility Rate	47.00%
Liability Value	3
Liability Settlements	13
SVAP Incremental Price Threshold	$5
Fair Value Assumptions, Risk Free Interest Rate	0.27%
FairValueMeasurementWithUnobservableInputsReconciliationsRecurringBasisLiabilityValueTotal	4
Service - Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	465,000	2,428,000	1,589,000
Number of restricted stock shares vested	1,146,000	1,195,000	977,000
Number of restricted stock shares outstanding	1,902,000	2,999,000	2,371,000	2,123,000
Performance Market Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	338,000	300,000	184,000
Number of restricted stock shares vested	30,000	0	89,000
Number of restricted stock shares outstanding	945,000	706,000	438,000	357,000
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Reduction factor multiplied by number of shares awarded	1.87
Additional shares available for issuance	1,200,000
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	$0	$0

StockBased_Compensation_Stock_

Stock-Based Compensation- Stock Option Activity (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Stock option activity
Outstanding, Beginning Balance, Number of Shares Underlying Options	687,000	901,000	1,059,000
Granted, Number of Shares Underlying Options	0	0	0
Exercised, Number of Shares Underlying Options	-134,000	-53,000	-94,000
Forfeited, Number of Shares Underlying Options	-252,000	-161,000	-64,000
Outstanding, Ending Balance, Number of Shares Underlying Options	301,000	687,000	901,000	1,059,000
Exercisable, Number of Shares Underlying Options	301,000
Outstanding, Beginning Balance, Weighted Average Exercise Price per Share	$39.68	$38.06	$36.31
Granted, Weighted Average Exercise Price per Share	$0	$0	$0
Exercised, Weighted Average Exercise Price per Share	$29.32	$19.68	$19.52
Forfeited, Weighted Average Exercise Price per Share	$40.10	$37.26	$36.19
Outstanding, Ending Balance, Weighted Average Exercise Price per Share	$43.93	$39.68	$38.06	$36.31
Exercisable, Weighted Average Exercise Price per Share	$43.93
Weighted average fair value of each option	$0	$0	$0
Outstanding, Beginning Balance, Weighted Average Remaining Contractual Life (In years)	2 years 2 months 12 days	1 year 10 months 24 days	3 years 3 months 18 days	4 years
Outstanding, Ending Balance, Weighted Average Remaining Contractual Life (In years)	2 years 2 months 12 days	1 year 10 months 24 days	3 years 3 months 18 days	4 years
Exercisable, Weighted Average Remaining Contractual Life (In years)	2 years 2 months 12 days
Outstanding, Beginning Balance, Aggregate Intrinsic Value	$0	$1	$7
Exercised, Aggregate Intrinsic Value	1	1	1
Outstanding, Ending Balance, Aggregate Intrinsic Value	0	0	1	7
Exercisable, Aggregate Intrinsic Value	$0

StockBased_Compensation_Stock_1

Stock-Based Compensation- Stock Option Summary (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Options Outstanding, Number of Shares Underlying Options	301,000	687,000	901,000	1,059,000
Options Outstanding, Weighted Average Remaining Contractual Life (In years)	2 years 2 months 12 days	1 year 10 months 24 days	3 years 3 months 18 days	4 years
Options Outstanding, Weighted Average Exercise Price per Share	$43.93	$39.68	$38.06	$36.31
Options Exercisable, Number of Shares Underlying Options	301,000
Options Exercisable, Weighted Average Exercise Price per Share	$43.93
Range Two Twenty-seven Dollars Fifty-one Cents To Thirty-five Dollars [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise Price Lower Range Limit	$27.51
Exercise Price Upper Range Limit	$35
Options Outstanding, Number of Shares Underlying Options	66,000
Options Outstanding, Weighted Average Remaining Contractual Life (In years)	0 years 1 month 6 days
Options Outstanding, Weighted Average Exercise Price per Share	$31.94
Options Exercisable, Number of Shares Underlying Options	66,000
Options Exercisable, Weighted Average Exercise Price per Share	$31.94
Range Three Thirty-five Dollars One Cent To Forty-one Dollars Seventy-two Cents [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise Price Lower Range Limit	$35.01
Exercise Price Upper Range Limit	$41.72
Options Outstanding, Number of Shares Underlying Options	27,000
Options Outstanding, Weighted Average Remaining Contractual Life (In years)	0 years 3 months 18 days
Options Outstanding, Weighted Average Exercise Price per Share	$38.44
Options Exercisable, Number of Shares Underlying Options	27,000
Options Exercisable, Weighted Average Exercise Price per Share	$38.44
Range Four Forty-one Dollars Seventy-three Cents To Forty-eight Dollars Forty-five Cents [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise Price Lower Range Limit	$41.73
Exercise Price Upper Range Limit	$48.45
Options Outstanding, Number of Shares Underlying Options	208,000
Options Outstanding, Weighted Average Remaining Contractual Life (In years)	3 years 1 month 6 days
Options Outstanding, Weighted Average Exercise Price per Share	$48.45
Options Exercisable, Number of Shares Underlying Options	208,000
Options Exercisable, Weighted Average Exercise Price per Share	$48.45

StockBased_Compensation_Restri

Stock-Based Compensation- Restricted Stock and Restricted Stock Units Activity (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	3,705,000	2,809,000	2,480,000
Granted	803,000	2,728,000	1,773,000
Forfeited	-485,000	-637,000	-378,000
Vested	-1,176,000	-1,195,000	-1,066,000
Non-vested shares outstanding, Ending balance	2,847,000	3,705,000	2,809,000
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Beginning balance	$33.31	$43.31	$49.52
Granted, Weighted Average Grant Date Fair Value per Share	$25.42	$27.24	$35.29
Forfeited, Weighted Average Grant Date Fair Value per Share	$25.14	$39.47	$47.34
Vested, Weighted Average Grant Date Fair Value per Share	$36.64	$39.64	$41.70
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Ending balance	$30.05	$33.31	$43.31
Service - Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	2,999,000	2,371,000	2,123,000
Granted	465,000	2,428,000	1,589,000
Forfeited	-416,000	-605,000	-364,000
Vested	-1,146,000	-1,195,000	-977,000
Non-vested shares outstanding, Ending balance	1,902,000	2,999,000	2,371,000
Performance Market Based Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares outstanding, Beginning balance	706,000	438,000	357,000
Granted	338,000	300,000	184,000
Forfeited	-69,000	-32,000	-14,000
Vested	-30,000	0	-89,000
Non-vested shares outstanding, Ending balance	945,000	706,000	438,000

StockBased_Compensation_Employ

Stock-Based Compensation- Employee Stock Purchase Plan (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2010
Employee Stock Purchase Plan ESPP Disclosures [Line Items]
Options To Purchase Common Stock Shares	0	0	0
Weighted average fair value of each option	$0	$0	$0
Employee Stock Purchase Plan [Member]
Employee Stock Purchase Plan ESPP Disclosures [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Percentage of Market Price, Purchase Date	85.00%
Maximum amount of common stock that an employee can purchase under Employee Stock Purchase Plan in any calendar year	$25,000
Additional shares available for issuance	356,000			1,000,000
Options To Purchase Common Stock Shares	168,394	178,733	165,722
Weighted average fair value of each option	$7.91	$6.59	$9.86
Expected volatility	32.05%	39.45%	49.43%
Risk-free weighted average interest rate	0.07%	0.10%	0.10%
Vesting Period	0 years 6 months 0 days	0 years 6 months 0 days	0 years 6 months 0 days

Employee_Benefit_Plans_Details

Employee Benefit Plans (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Expected future benefit payments in years one through five for post-retirement medical plan	$5,000,000
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter	7,000,000
Maximum age for retire employees to be covered under post-retirement medical plan	65
Defined Benefit Plan, Benefit Obligation	16,000,000
Defined Benefit Plan, Net Periodic Benefit Cost	2,000,000	2,000,000	2,000,000
Other Labor-related Expenses	45,000,000	40,000,000	41,000,000
Employer matching contribution for each $1 of employee deferral	1
Employee contribution to be matched by the Company	0.08
Defined Contribution Plan, Employer Discretionary Contribution Amount	$10,000,000	$10,000,000	$10,000,000

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	MBbls
	MMBTU
Future minimum payments under non-cancellable agreements
Natural Gas Commitments Current	15,372,000
2015	$312
2016	152
2017	110
2018	89
2019	75
Thereafter	94
Total minimum future payments	832
Delivery Commitments, Current	6,570,000
Natural Gas Commitments Due In Two Years	0
Delivery Commitments, Due In Two Years	13,908,000
Natural Gas Commitments Due In Three Years	0
Delivery Commitments, Due In Three Years	13,870,000
Natural Gas Delivery Commitments Due In Four Years	0
Delivery Commitments, Due In Four Years	13,870,000
Natural Gas Delivery Commitments Due In Five Years	0
Delivery Commitments, Due In Five Years	13,870,000
Natural Gas Commitments Due Thereafter	0
Delivery Commitments, Due Thereafter	46,576,000
Total Natural Gas Commitments	15,372,000
Total Delivery Commitments	108,664,000
Commitments and Contingencies (Textuals) [Abstract]
Rent expense under lease commitments	20	19	17
Firm Transportation [Member]
Future minimum payments under non-cancellable agreements
2015	72
2016	85
2017	82
2018	63
2019	52
Thereafter	35
Total minimum future payments	389
Operating Leases [Member]
Future minimum payments under non-cancellable agreements
2015	18
2016	15
2017	15
2018	14
2019	12
Thereafter	24
Total minimum future payments	98
Drilling-Related Leases [Member]
Future minimum payments under non-cancellable agreements
2015	196
2016	36
2017	0
2018	0
2019	0
Thereafter	0
Total minimum future payments	232
Other Commitments [Member]
Future minimum payments under non-cancellable agreements
2015	26
2016	16
2017	13
2018	12
2019	11
Thereafter	35
Total minimum future payments	$113

Delivery_Commitments_Details

Delivery Commitments (Details) (USD $)	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2014
		bbls
Delivery Commitments [Line Items]
Delivery Commitments, Current (2015)		6,570,000
Delivery Commitments, Due In Two Years (2016)		13,908,000
Delivery Commitments, Due In Three Years (2017)		13,870,000
Delivery Commitments, Due In Four Years (2018)		13,870,000
Delivery Commitments, Due In Five Years (2019)		13,870,000
Delivery Commitments, Due Thereafter		46,576,000
Total Delivery Commitments		108,664,000
Natural Gas Commitments, Current (2015)		15,372,000
Natural Gas Commitments, Due In Two Years (2016)		0
Natural Gas Commitments, Due In Three Years (2017)		0
Natural Gas Commitments, Due In Four Years (2018)		0
Natural Gas Commitments, Due In Five Years (2019)		0
Natural Gas Commitments, Due Thereafter		0
Total Natural Gas Commitments		15,372,000
Oil and Gas Delivery Commitments and Contracts Additional Information [Abstract]
Gain (Loss) Related to Litigation Settlement	$13
Commitment Volumes 2025		7,300
Minimum [Member]
Delivery Commitments [Line Items]
Deficiency Fees		1.83
Maximum [Member]
Delivery Commitments [Line Items]
Deficiency Fees		6.5
2016 to 2025 [Member]
Delivery Commitments [Line Items]
Oil and Gas Delivery Commitments and Contracts, Daily Production		20,000
2020 [Member]
Delivery Commitments [Line Items]
Oil and Gas Delivery Commitments and Contracts, Daily Production		18,000

Segment_Information_Details

Segment Information (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating expenses:
Depreciation, depletion and amortization	$903	$930	$955
Ceiling test impairment	0	0	1,488
Allocated income tax (benefit)	382	128	-452
Commodity derivative income (expense)	-610	97	-120
Income (loss) before income taxes	1,032	201	-1,374
Total assets	9,598	9,321
Additions to long-lived assets	2,200	2,106	1,742
Domestic [Member]
Segment Information [Line Items]
Oil, gas and NGL revenues	2,249	1,788	1,476
Operating expenses:
Lease operating	309	276	299
Gas Gathering, Transportation, Marketing and Processing Costs	174	137	107
Production and other taxes	105	67	67
Depreciation, depletion and amortization	857	668	683
General and administrative	221	219	211
Ceiling test impairment			1,488
Other	15	3	15
Allocated income tax (benefit)	210	155	-516
Net income (loss) from oil and gas properties	358	263	-878
Total assets	8,870	7,863	6,699
Additions to long-lived assets	2,044	1,932	1,655
Malaysia [Member]
Operating expenses:
Total assets		916	866
China [Member]
Segment Information [Line Items]
Oil, gas and NGL revenues	39	69	86
Operating expenses:
Lease operating	12	8	7
Gas Gathering, Transportation, Marketing and Processing Costs	0	0	0
Production and other taxes	6	12	18
Depreciation, depletion and amortization	13	17	21
General and administrative	1	0	0
Ceiling test impairment			0
Other	0	0	0
Allocated income tax (benefit)	5	19	24
Net income (loss) from oil and gas properties	2	13	16
Total assets	728	542	347
Additions to long-lived assets	156	174	87
Continuing Operations [Member]
Segment Information [Line Items]
Oil, gas and NGL revenues	2,288	1,857	1,562
Operating expenses:
Lease operating	321	284	306
Gas Gathering, Transportation, Marketing and Processing Costs	174	137	107
Production and other taxes	111	79	85
Depreciation, depletion and amortization	870	685	704
General and administrative	222	219	211
Ceiling test impairment			1,488
Other	15	3	15
Total operating expenses	1,713	1,407	2,916
Income (loss) from operations	575	450	-1,354
Interest expenses, net of interest income, capitalized interest and other	-153	-152	-140
Commodity derivative income (expense)	-610	97	-120
Income (loss) before income taxes	1,032	201	-1,374
Total assets		$8,405	$7,046

Supplemental_Cash_Flows_Inform2

Supplemental Cash Flows Information (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash Payments [Abstract]
Interest payments, net of capitalized interest	$144	$148	$137
Income tax payments	4	128	206
Increase (Decrease) in Other Receivables	-17	12	25
Non Cash Items Excluded From Statement of Cash Flows [Abstract]
(Increase) decrease in accrued capital expenditures	-1	-75	-124
Increase in asset retirement costs	($56)	($125)	($8)

Related_Party_Transaction_Deta

Related Party Transaction (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Related Party Transaction [Line Items]
Ownership interest percentage in Bohai Bay Unit	12.00%
Payments for Repurchase of Preferred Stock and Preference Stock	$0	$20	$0

Subsequent_Events_Details

Subsequent Events (Details) (Subsequent Event [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015
Subsequent Event [Member]
Subsequent Event [Line Items]
Severance Costs	$10
Headcount Reduction	15.00%

Quarterly_Results_of_Operation2

Quarterly Results of Operations (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Ceiling test impairment									$0	$0	$1,488
Income (Loss) from Continuing Operations Attributable to Parent	367	279	-23	27	-16	3	107	-21	650	73	-922
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	-7	-1	1	257	33	24	4	13	250	74	-262
Net Income (Loss) Attributable to Parent	360	278	-22	284	17	27	111	-8	900	147	-1,184
Income (Loss) from Continuing Operations, Per Basic Share	$2.67	$2.04	($0.16)	$0.19	($0.12)	($0.13)	$0.79	($0.15)	$4.76	$0.39	($6.85)
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share	($0.05)	$0	$0	$1.89	$0.25	$0.18	$0.03	$0.09	$1.83	$0.55	($1.95)
Earnings (Loss) Per Share, Basic	$2.62	$2.04	($0.16)	$2.08	$0.13	$0.05	$0.82	($0.06)	$6.59	$0.94	($8.80)
Income (Loss) from Continuing Operations, Per Diluted Share	$2.65	$2.01	($0.16)	$0.19	($0.12)	($0.13)	$0.79	($0.15)	$4.71	$0.39	($6.85)
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share	($0.05)	$0	$0	$1.88	$0.25	$0.18	$0.03	$0.09	$1.81	$0.55	($1.95)
Earnings (Loss) Per Share, Diluted	$2.60	$2.01	($0.16)	$2.07	$0.13	$0.05	$0.82	($0.06)	$6.52	$0.94	($8.80)
Gain on Sale of Malaysia, Before Income Tax									373	0	0
Payments for Repurchase of Preferred Stock and Preference Stock									0	20	0
Continuing Operations [Member]
Oil and Gas Revenue	495	610	612	571	510	505	449	393	2,288	1,857	1,562
Ceiling test impairment									0	0	1,488
Income (loss) from operations	46	167	180	182	126	140	93	91	575	450	-1,354
Malaysia [Member]
Gain on Sale of Malaysia, Before Income Tax	-15			388
Gain on Sale of Malaysia, Net of Tax	($10)			$252

Supplementary_Oil_and_Gas_Disc2

Supplementary Oil and Gas Disclosure (Unaudited) - (Textuals) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	MMBoe	MMBoe	MMBoe
Costs Incurred, Asset Retirement Obligation Incurred	$56	$121	$9
Years experience employee overseeing reserve estimation is greater than	30 years 0 months 0 days
Years reserve estimation experience	20 years 0 months 0 days
Proved Reserves Extensions, Discoveries, Additions and Purchase of Minerals in Place	81	82	86
Percentage of Liquids Comprising Proved Reserves	58.00%	55.00%	48.00%
Net effect of proved reserve revisions, additions and purchases	132
Percentage of drillling additions related out major, domestic resource plays	99.00%
Proved Undeveloped Reserves Additions	52
Proved developed liquids additions	54
Proved Reserve Revisions Percentage of Beginning Reserves	8.00%
Proved Reserves Price Related Revisions	3
Proved Reserve Revisions Development	77
Proved Reserves Performance Related Revisions	29

Supplementary_Oil_and_Gas_Disc3

Supplementary Oil and Gas Disclosure (Unaudited) - Results of Operations of O&G Producing Activities (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Results Of Operations Income Before Income Taxes Abstract
Revenues	$2,369	$2,668	$2,560
Production costs	322	390	400
Production taxes and other operating expenses	310	488	451
Depreciation, depletion and amortization	903	930	955
Impairment of oil and gas properties			1,488
Income taxes	292	304	-250
Results of Operations, Oil and Gas Producing Activities Net Income (Excluding Corporate Overhead and Interest Costs), Total	542	556	-484
Domestic [Member]
Results Of Operations Income Before Income Taxes Abstract
Revenues	2,240	1,777	1,469
Production costs	299	265	292
Production taxes and other operating expenses	279	204	174
Depreciation, depletion and amortization	857	668	683
Impairment of oil and gas properties			1,488
Income taxes	282	224	-410
Results of Operations, Oil and Gas Producing Activities Net Income (Excluding Corporate Overhead and Interest Costs), Total	523	416	-758
Malaysia [Member]
Results Of Operations Income Before Income Taxes Abstract
Revenues	90	822	1,005
Production costs	11	117	101
Production taxes and other operating expenses	25	272	259
Depreciation, depletion and amortization	33	244	251
Impairment of oil and gas properties			0
Income taxes	8	72	150
Results of Operations, Oil and Gas Producing Activities Net Income (Excluding Corporate Overhead and Interest Costs), Total	13	117	244
China [Member]
Results Of Operations Income Before Income Taxes Abstract
Revenues	39	69	86
Production costs	12	8	7
Production taxes and other operating expenses	6	12	18
Depreciation, depletion and amortization	13	18	21
Impairment of oil and gas properties			0
Income taxes	2	8	10
Results of Operations, Oil and Gas Producing Activities Net Income (Excluding Corporate Overhead and Interest Costs), Total	$6	$23	$30

Supplementary_Oil_and_Gas_Disc4

Supplementary Oil and Gas Disclosure (Unaudited) - Costs Incurred (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Costs Incurred, Acquisition of Oil and Gas Properties [Abstract]
Costs Incurred, Acquisition of Unproved Oil and Gas Properties	$146	$154	$64
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves	6	9	3
Costs Incurred, Exploration Costs	1,089	1,100	993
Costs Incurred, Development Costs	942	1,042	853
Costs Incurred Oil And Gas Property Acquisition Exploration And Development Activities Total	2,183	2,305	1,913
Domestic [Member]
Costs Incurred, Acquisition of Oil and Gas Properties [Abstract]
Costs Incurred, Acquisition of Unproved Oil and Gas Properties	146	154	64
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves	6	8	3
Costs Incurred, Exploration Costs	1,089	966	929
Costs Incurred, Development Costs	772	691	659
Costs Incurred Oil And Gas Property Acquisition Exploration And Development Activities Total	2,013	1,819	1,655
Malaysia [Member]
Costs Incurred, Acquisition of Oil and Gas Properties [Abstract]
Costs Incurred, Acquisition of Unproved Oil and Gas Properties	0	0	0
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves	0	0	0
Costs Incurred, Exploration Costs	0	101	63
Costs Incurred, Development Costs	14	211	108
Costs Incurred Oil And Gas Property Acquisition Exploration And Development Activities Total	14	312	171
China [Member]
Costs Incurred, Acquisition of Oil and Gas Properties [Abstract]
Costs Incurred, Acquisition of Unproved Oil and Gas Properties	0	0	0
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves	0	1	0
Costs Incurred, Exploration Costs	0	33	1
Costs Incurred, Development Costs	156	140	86
Costs Incurred Oil And Gas Property Acquisition Exploration And Development Activities Total	$156	$174	$87

Supplementary_Oil_and_Gas_Disc5

Supplementary Oil and Gas Disclosure (Unaudited) - Other Costs Incurred (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Ceiling test impairment	$0	$0	$1,488,000,000
Capitalized costs of oil and gas properties not included in total costs incurred	2,206,000,000	23,000,000	2,094,000,000
Domestic [Member]
Ceiling test impairment	0	0	1,488,000,000
Property sales excluded from cost incurred	635,000,000	23,000,000	606,000,000
Malaysia [Member]
Property sales excluded from cost incurred	$1,571,000,000	$0	$0

Supplementary_Oil_and_Gas_Disc6

Supplementary Oil and Gas Disclosure (Unaudited) - Capitalized Costs (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Capitalized Costs, Oil and Gas Producing Activities, Gross [Abstract]
Capitalized Costs, Proved Properties	$15,707	$15,176
Capitalized Costs, Unproved Properties	677	1,231
Gross oil and gas properties	16,384	16,407
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance Relating to Oil and Gas Producing Activities	-8,152	-8,306
Net oil and gas properties	8,232	8,101
Domestic [Member]
Capitalized Costs, Oil and Gas Producing Activities, Gross [Abstract]
Capitalized Costs, Proved Properties	14,998	13,185
Capitalized Costs, Unproved Properties	677	1,116
Gross oil and gas properties	15,675	14,301
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance Relating to Oil and Gas Producing Activities	-8,022	-7,185
Net oil and gas properties	7,653	7,116
Malaysia [Member]
Capitalized Costs, Oil and Gas Producing Activities, Gross [Abstract]
Capitalized Costs, Proved Properties	0	1,441
Capitalized Costs, Unproved Properties	0	115
Gross oil and gas properties	0	1,556
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance Relating to Oil and Gas Producing Activities	0	-1,009
Net oil and gas properties	0	547
China [Member]
Capitalized Costs, Oil and Gas Producing Activities, Gross [Abstract]
Capitalized Costs, Proved Properties	709	550
Capitalized Costs, Unproved Properties	0	0
Gross oil and gas properties	709	550
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance Relating to Oil and Gas Producing Activities	-130	-112
Net oil and gas properties	$579	$438

Supplementary_Oil_and_Gas_Disc7

Supplementary Oil and Gas Disclosure (Unaudited) - Standardized Measure (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Cash Inflows	$33,941	$30,485	$25,664
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Net Cash Flows [Abstract]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Production Costs	-12,292	-10,032	-9,065
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Development Costs	-4,684	-4,457	-4,233
DiscountedFutureNetCashFlowsRelatingToProvedOilAndGasReservesBeforeIncomeTaxExpense	16,965	15,996	12,366
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Income Tax Expense	-4,670	-4,594	-3,091
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Net Cash Flows, Total	12,295	11,402	9,275
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, 10 Percent Annual Discount for Estimated Timing of Cash Flows	-6,083	-5,569	-4,839
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	6,212	5,833	4,436	5,981
Domestic [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Cash Inflows	31,758	26,600	21,724
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Net Cash Flows [Abstract]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Production Costs	-11,508	-8,302	-7,042
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Development Costs	-4,611	-4,166	-3,949
DiscountedFutureNetCashFlowsRelatingToProvedOilAndGasReservesBeforeIncomeTaxExpense	15,639	14,132	10,733
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Income Tax Expense	-4,449	-4,278	-2,786
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Net Cash Flows, Total	11,190	9,854	7,947
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, 10 Percent Annual Discount for Estimated Timing of Cash Flows	-5,860	-5,226	-4,539
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	5,330	4,628	3,408	4,724
Malaysia [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Cash Inflows	0	1,245	1,754
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Net Cash Flows [Abstract]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Production Costs	0	-771	-1,135
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Development Costs	0	-148	-82
DiscountedFutureNetCashFlowsRelatingToProvedOilAndGasReservesBeforeIncomeTaxExpense	0	326	537
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Income Tax Expense	0	0	-66
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Net Cash Flows, Total	0	326	471
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, 10 Percent Annual Discount for Estimated Timing of Cash Flows	0	-23	-55
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	0	303	416	692
China [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Cash Inflows	2,183	2,640	2,186
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Net Cash Flows [Abstract]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Production Costs	-784	-959	-888
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Development Costs	-73	-143	-202
DiscountedFutureNetCashFlowsRelatingToProvedOilAndGasReservesBeforeIncomeTaxExpense	1,326	1,538	1,096
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Income Tax Expense	-221	-316	-239
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Net Cash Flows, Total	1,105	1,222	857
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, 10 Percent Annual Discount for Estimated Timing of Cash Flows	-223	-320	-245
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	$882	$902	$612	$565

Supplementary_Oil_and_Gas_Disc8

Supplementary Oil and Gas Disclosure (Unaudited) - Reserves (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MMBoe	MMBoe	MMBoe	MMBoe
Proved developed and undeveloped reserves as of:
Beginning Balance (Energy)	645	612	566	652
Revisions of previous estimates (Energy)	51	14	-91
Extensions, discoveries and other additions (Energy)	72	80	86
Purchase of properties (Energy)	9	2	0
Sales of properties (Energy)	-49	-1	-30
Production (Energy)	-50	-49	-51
Proved developed reserves as of:
Proved developed reserves (Energy)	338	337	298	355
Proved undeveloped reserves as of:
Proved undeveloped reserves (Energy)	307	275	268	297
Natural Gas [Member]
Proved developed and undeveloped reserves as of:
Beginning balance	1,648,000	1,755,000	2,333,000
Revisions of previous estimates	129,000	-166,000	-527,000
Extensions, discoveries and other additions	112,000	187,000	181,000
Purchase of properties	9,000	1,000	1,000
Sales of properties	-164,000	-5,000	-80,000
Production	-127,000	-124,000	-153,000
Proved developed reserves as of:
Proved developed reserves	938,000	1,055,000	1,042,000	1,409,000
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	669,000	593,000	713,000	924,000
Oil [Member]
Proved developed and undeveloped reserves as of:
Beginning balance	270,000	237,000	247,000
Revisions of previous estimates	16,000	28,000	-11,000
Extensions, discoveries and other additions	42,000	27,000	38,000
Purchase of properties	6,000	1,000	0
Sales of properties	-13,000	0	-15,000
Production	-20,000	-23,000	-22,000
Proved developed reserves as of:
Proved developed reserves	144,000	127,000	110,000	110,000
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	157,000	143,000	127,000	137,000
natural gas liquids
Proved developed and undeveloped reserves as of:
Beginning balance	68,000	37,000	16,000
Revisions of previous estimates	13,000	14,000	9,000
Extensions, discoveries and other additions	12,000	22,000	17,000
Purchase of properties	1,000	0	0
Sales of properties	-9,000	0	-2,000
Production	-9,000	-5,000	-3,000
Proved developed reserves as of:
Proved developed reserves	38,000	35,000	15,000	10,000
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	38,000	33,000	22,000	6,000
Domestic [Member]
Proved developed and undeveloped reserves as of:
Beginning Balance (Energy)	622	576	532	608
Revisions of previous estimates (Energy)	53	5	-92
Extensions, discoveries and other additions (Energy)	71	78	86
Purchase of properties (Energy)	9	2	0
Sales of properties (Energy)	-39	-1	-30
Production (Energy)	-48	-40	-40
Proved developed reserves as of:
Proved developed reserves (Energy)	329	322	280	332
Proved undeveloped reserves as of:
Proved undeveloped reserves (Energy)	293	254	252	276
Domestic [Member] | Natural Gas [Member]
Proved developed and undeveloped reserves as of:
Beginning balance	1,648,000	1,755,000	2,329,000
Revisions of previous estimates	129,000	-166,000	-525,000
Extensions, discoveries and other additions	112,000	187,000	181,000
Purchase of properties	9,000	1,000	1,000
Sales of properties	-164,000	-5,000	-80,000
Production	-127,000	-124,000	-151,000
Proved developed reserves as of:
Proved developed reserves	938,000	1,055,000	1,042,000	1,405,000
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	669,000	593,000	713,000	924,000
Domestic [Member] | Oil [Member]
Proved developed and undeveloped reserves as of:
Beginning balance	234,000	203,000	204,000
Revisions of previous estimates	18,000	19,000	-13,000
Extensions, discoveries and other additions	41,000	25,000	38,000
Purchase of properties	6,000	1,000	0
Sales of properties	-3,000	0	-15,000
Production	-18,000	-14,000	-11,000
Proved developed reserves as of:
Proved developed reserves	135,000	112,000	92,000	88,000
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	143,000	122,000	111,000	116,000
Domestic [Member] | natural gas liquids
Proved developed and undeveloped reserves as of:
Beginning balance	68,000	37,000	16,000
Revisions of previous estimates	13,000	14,000	9,000
Extensions, discoveries and other additions	12,000	22,000	17,000
Purchase of properties	1,000	0	0
Sales of properties	-9,000	0	-2,000
Production	-9,000	-5,000	-3,000
Proved developed reserves as of:
Proved developed reserves	38,000	35,000	15,000	10,000
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	38,000	33,000	22,000	6,000
Malaysia [Member]
Proved developed and undeveloped reserves as of:
Beginning Balance (Energy)	0	11	15	24
Revisions of previous estimates (Energy)	0	2	1
Extensions, discoveries and other additions (Energy)	0	2	0
Purchase of properties (Energy)	0	0	0
Sales of properties (Energy)	-10	0	0
Production (Energy)	-1	-8	-10
Proved developed reserves as of:
Proved developed reserves (Energy)	0	11	14	18
Proved undeveloped reserves as of:
Proved undeveloped reserves (Energy)	0	0	1	6
Malaysia [Member] | Natural Gas [Member]
Proved developed and undeveloped reserves as of:
Beginning balance	0	0	4,000
Revisions of previous estimates	0	0	-2,000
Extensions, discoveries and other additions	0	0	0
Purchase of properties	0	0	0
Sales of properties	0	0	0
Production	0	0	-2,000
Proved developed reserves as of:
Proved developed reserves	0	0	0	4,000
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	0	0	0	0
Malaysia [Member] | Oil [Member]
Proved developed and undeveloped reserves as of:
Beginning balance	11,000	15,000	23,000
Revisions of previous estimates	0	2,000	2,000
Extensions, discoveries and other additions	0	2,000	0
Purchase of properties	0	0	0
Sales of properties	-10,000	0	0
Production	-1,000	-8,000	-10,000
Proved developed reserves as of:
Proved developed reserves	0	11,000	14,000	17,000
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	0	0	1,000	6,000
Malaysia [Member] | natural gas liquids
Proved developed and undeveloped reserves as of:
Beginning balance	0	0	0
Revisions of previous estimates	0	0	0
Extensions, discoveries and other additions	0	0	0
Purchase of properties	0	0	0
Sales of properties	0	0	0
Production	0	0	0
Proved developed reserves as of:
Proved developed reserves	0	0	0	0
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	0	0	0	0
China [Member]
Proved developed and undeveloped reserves as of:
Beginning Balance (Energy)	23	25	19	20
Revisions of previous estimates (Energy)	-2	7	0
Extensions, discoveries and other additions (Energy)	1	0	0
Purchase of properties (Energy)	0	0	0
Sales of properties (Energy)	0	0	0
Production (Energy)	-1	-1	-1
Proved developed reserves as of:
Proved developed reserves (Energy)	9	4	4	5
Proved undeveloped reserves as of:
Proved undeveloped reserves (Energy)	14	21	15	15
China [Member] | Natural Gas [Member]
Proved developed and undeveloped reserves as of:
Beginning balance	0	0	0
Revisions of previous estimates	0	0	0
Extensions, discoveries and other additions	0	0	0
Purchase of properties	0	0	0
Sales of properties	0	0	0
Production	0	0	0
Proved developed reserves as of:
Proved developed reserves	0	0	0	0
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	0	0	0	0
China [Member] | Oil [Member]
Proved developed and undeveloped reserves as of:
Beginning balance	25,000	19,000	20,000
Revisions of previous estimates	-2,000	7,000	0
Extensions, discoveries and other additions	1,000	0	0
Purchase of properties	0	0	0
Sales of properties	0	0	0
Production	-1,000	-1,000	-1,000
Proved developed reserves as of:
Proved developed reserves	9,000	4,000	4,000	5,000
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	14,000	21,000	15,000	15,000
China [Member] | natural gas liquids
Proved developed and undeveloped reserves as of:
Beginning balance	0	0	0
Revisions of previous estimates	0	0	0
Extensions, discoveries and other additions	0	0	0
Purchase of properties	0	0	0
Sales of properties	0	0	0
Production	0	0	0
Proved developed reserves as of:
Proved developed reserves	0	0	0	0
Proved undeveloped reserves as of:
Proved Undeveloped Reserves	0	0	0	0

Estimated_Fair_Value_of_Notes_

Estimated Fair Value of Notes Based on Quoted Market Prices (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
5.75 %Senior Notes Due 2022 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of debt	$772	$767
5.625% Senior Notes Due 2024 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of debt	989	1,025
7.125% Senior Subordinated Notes due 2018 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of debt	0	624
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	$721	$755

Supplementary_Oil_and_Gas_Disc9

Supplementary Oil and Gas Disclosure (Unaudited) - Changes in Standardized Measure (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Beginning of the Period	$5,833	$4,436	$5,981
Revision of Previous Estimates [Abstract]
Changes in Prices and Costs	-743	979	-1,528
Changes in Quantities	680	459	-404
Changes in Future Development Costs	310	-259	273
Development Costs Incurred During The Period	-857	-758	-594
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs	860	1,061	815
Purchases and sales of reserves in place, net	-450	13	-758
Accretion of Discount	788	585	683
Sales of oil and gas, net of production costs	1,737	1,349	1,631
Net change in income taxes	-332	-819	773
Production timing and other	146	-31	-362
Net increase (decrease)	379	1,397	-1,545
Ending Balance	6,212	5,833	4,436
Domestic [Member]
Beginning of the Period	4,628	3,408	4,724
Revision of Previous Estimates [Abstract]
Changes in Prices and Costs	-492	944	-1,490
Changes in Quantities	784	81	-427
Changes in Future Development Costs	253	-83	294
Development Costs Incurred During The Period	-698	-549	-434
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs	860	1,012	791
Purchases and sales of reserves in place, net	-171	13	-758
Accretion of Discount	655	470	542
Sales of oil and gas, net of production costs	1,662	973	1,129
Net change in income taxes	-383	-815	650
Production timing and other	160	22	-223
Net increase (decrease)	702	1,220	-1,316
Ending Balance	5,330	4,628	3,408
Malaysia [Member]
Beginning of the Period	303	416	692
Revision of Previous Estimates [Abstract]
Changes in Prices and Costs	-132	33	-14
Changes in Quantities	0	76	23
Changes in Future Development Costs	129	-126	-19
Development Costs Incurred During The Period	-12	-79	-93
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs	0	49	0
Purchases and sales of reserves in place, net	-279	0	0
Accretion of Discount	19	33	64
Sales of oil and gas, net of production costs	54	330	439
Net change in income taxes	0	59	119
Production timing and other	2	14	-103
Net increase (decrease)	-303	-113	-276
Ending Balance	0	303	416
China [Member]
Beginning of the Period	902	612	565
Revision of Previous Estimates [Abstract]
Changes in Prices and Costs	-119	2	-24
Changes in Quantities	-104	302	0
Changes in Future Development Costs	-72	-50	-2
Development Costs Incurred During The Period	-147	-130	-67
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs	0	0	24
Purchases and sales of reserves in place, net	0	0	0
Accretion of Discount	114	82	77
Sales of oil and gas, net of production costs	21	46	63
Net change in income taxes	51	-63	4
Production timing and other	-16	-67	-36
Net increase (decrease)	-20	290	47
Ending Balance	$882	$902	$612

Uncategorized_Items

Uncategorized Items
[us-gaap_ProvedDevelopedAndUndevelopedReservesNet]	76,000	1,607,000	301,000	0	0	76,000	0	0	1,607,000	23,000	0	278,000