Newfield Exploration (NFX) 10-K 28 Feb 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Feb. 24, 2014	Jun. 30, 2013
Document and Entity Information [Abstract]	'	'	'
Entity Registrant Name	'NEWFIELD EXPLORATION CO /DE/	'	'
Entity Central Index Key	'0000912750	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Amendment Flag	'false	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Entity Public Float	'	'	$3,200,000,000
Entity Common Stock, Shares Outstanding	'	136,316,871	'

Consolidated_Balance_Sheet

Consolidated Balance Sheet (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
In Millions, unless otherwise specified
Current assets:	'	'	'	'
Cash and cash equivalents	$95	$88	$76	$39
Restricted Cash and Cash Equivalents, Current	90	0	'	'
Accounts receivable	474	452	'	'
Inventories	163	132	'	'
Derivative assets	0	125	'	'
Deferred Tax Assets, Net, Current	22	0	'	'
Other current assets	57	69	'	'
Total current assets	901	866	'	'
Property, Plant and Equipment, Gross	16,650	14,346	'	'
Less - accumulated depreciation, depletion and amortization	8,375	7,444	'	'
Property, Plant and Equipment, Net	8,275	6,902	'	'
Derivative assets	26	17	'	'
Long-term investments	63	58	'	'
Deferred taxes	19	24	'	'
Other assets	37	45	'	'
Total assets	9,321	7,912	'	'
Current liabilities:	'	'	'	'
Accounts payable	76	69	'	'
Accrued liabilities	978	801	'	'
Deposit Liability, Current	90	0	'	'
Advances from joint owners	30	31	'	'
Asset retirement obligations	54	10	'	'
Derivative liabilities	62	6	'	'
Deferred taxes	0	42	'	'
Total current liabilities	1,290	959	'	'
Other liabilities	38	47	'	'
Derivative liabilities	0	15	'	'
Long-term debt	3,694	3,045	'	'
Asset retirement obligations	201	132	'	'
Deferred taxes	1,142	934	'	'
Total long-term liabilities	5,075	4,173	'	'
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	1	1
Additional Paid in Capital	1,539	1,522	1,495	1,450
Treasury stock (at cost)	-13	-36	-50	-41
Accumulated other comprehensive loss	2	-7	-10	-12
Retained earnings	1,427	1,300	2,484	1,945
Total stockholders' equity	2,956	2,780	3,920	3,343
Total liabilities and stockholders' equity	$9,321	$7,912	'	'

Consolidated_Balance_Sheet_Par

Consolidated Balance Sheet (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
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	$1,300	$1,485
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	136,682,631	136,530,907
Treasury Stock, shares	460,914	1,216,591
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, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings Per Share [Abstract]	'	'	'
Income (Loss) from Continuing Operations, Per Basic Share	$0.80	($6.70)	$3
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share	$0.14	($2.10)	$1.03
Earnings (Loss) Per Share, Basic	$0.94	($8.80)	$4.03
Income (Loss) from Continuing Operations, Per Diluted Share	$0.80	($6.70)	$2.97
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share	$0.14	($2.10)	$1.02
Earnings (Loss) Per Share, Diluted	$0.94	($8.80)	$3.99
Operating expenses:	'	'	'
Depreciation, depletion and amortization	$930	$955	$767
Ceiling test impairment	0	1,488	0
Income tax provision (benefit):	'	'	'
Current	-4	2	17
Deferred	66	-513	201
Total income tax provision (benefit)	62	-511	218
Income (Loss) from Continuing Operations Attributable to Parent	108	-902	401
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	39	-282	138
Net income (loss)	147	-1,184	539
Other income (expenses):	'	'	'
Interest expense	-205	-205	-175
Interest Costs Capitalized Adjustment	53	68	82
Commodity derivative income (expense)	-97	120	195
Other	0	-2	2
Total other income (expenses)	-249	-19	104
Income (loss) before income taxes	170	-1,413	619
Weighted-average number of shares outstanding for basic earnings (loss) per share	135	135	134
Weighted average number of shares outstanding for diluted earnings (loss) per share	136	135	135
Continuing Operations [Member]	'	'	'
Statement [Line Items]	'	'	'
Oil, gas and NGL revenues	1,789	1,476	1,742
Operating expenses:	'	'	'
Lease operating	413	406	358
Production and other taxes	67	67	68
Depreciation, depletion and amortization	668	683	621
General and administrative	219	211	180
Ceiling test impairment	0	1,488	0
Other	3	15	0
Total operating expenses	1,370	2,870	1,227
Income (loss) from operations	$419	($1,394)	$515

Consolidated_Statement_of_Comp

Consolidated Statement of Comprehensive Income (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net Income (Loss) Attributable to Parent [Abstract]	'	'	'
Net income (loss)	$147	($1,184)	$539
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax, Including OTTI	7	'	'
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	'	3	3
Other comprehensive income (loss):	'	'	'
Other Comprehensive Income (Loss), Net of Tax	9	3	2
Unrealized gain (loss) on post-retirement benefits, net of tax	2	0	-1
Comprehensive income (loss)	$156	($1,181)	$541

Consolidated_Statement_of_Comp1

Consolidated Statement of Comprehensive Income (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
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	'	1	1
Unrealized gain (loss) on post-retirement benefits tax	$1	$0	$0

Consolidated_Statement_of_Stoc

Consolidated Statement of Stockholders' Equity (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Common Stock, shares	136,682,631	136,530,907	136,400,000
Common Stock Value	$1	$1	$1
Treasury Stock, Shares	-460,914	-1,216,591	-1,700,000
Treasury Stock	-13	-36	-50
Additional Paid in Capital	1,539	1,522	1,495
Retained Earnings (Accumulated Deficit)	1,427	1,300	2,484
Accumulated Other Comprehensive Income (Loss), Net of Tax	2	-7	-10
Issuances of common stock, shares	200,000	100,000	500,000
Issuances of common stock, value	1	2	13
Stock-based compensation	45	46	37
Treasury stock, net, shares acquired	'	'	0
Stock Issued During Period, Shares, Treasury Stock Reissued	700,000	500,000	'
Treasury stock, net value acquired	'	'	-14
Stock Issued During Period, Value, Treasury Stock Reissued	6	7	'
Net income (loss)	147	-1,184	539
Other Comprehensive Income (Loss), Net of Tax	9	3	2
Payments for Repurchase of Preferred Stock and Preference Stock	-20	0	0
Common Stock	'	'	'
Issuances of common stock, value	0	0	0
Treasury Stock	'	'	'
Treasury stock, net value acquired	'	'	-9
Stock Issued During Period, Value, Treasury Stock Reissued	23	14	'
Additional Paid-in Capital	'	'	'
Issuances of common stock, value	1	2	13
Stock-based compensation	45	46	37
Treasury stock, net value acquired	'	'	-5
Stock Issued During Period, Value, Treasury Stock Reissued	29	21	'
Retained Earnings	'	'	'
Net income (loss)	147	-1,184	539
Payments for Repurchase of Preferred Stock and Preference Stock	-20	'	'
Accumulated Other Comprehensive Income (Loss)	'	'	'
Other Comprehensive Income (Loss), Net of Tax	$9	$3	$2

Consolidated_Statement_of_Cash

Consolidated Statement of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities:	'	'	'
Net income (loss)	$147	($1,184)	$539
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'	'
Depreciation, depletion and amortization	930	955	767
Deferred Income Tax Expense (Benefit), Continuing and Discontinuing Operations	143	1	208
Stock-based compensation	43	35	29
Commodity derivative income	97	-120	-195
Cash receipts on derivative settlements, net	60	135	195
Ceiling test impairment	0	1,488	0
Other non-cash charges	14	19	6
Changes in operating assets and liabilities:	'	'	'
(Increase) decrease in accounts receivable	-62	-70	-24
(Increase) decrease in inventories	-11	-35	-16
(Increase) decrease in other current assets	12	5	-12
(Increase) decrease in other assets	6	7	-7
Increase (decrease) in accounts payable and accrued liabilities	74	-77	120
Increase (decrease) in advances from joint owners	-1	-14	-6
Increase (decrease) in other liabilities	-7	2	-15
Net cash provided by operating activities	1,445	1,147	1,589
Cash flows from investing activities:	'	'	'
Additions to oil and gas properties	-1,987	-1,758	-2,311
Acquisitions of oil and gas properties	-72	-9	-304
Proceeds from sales of oil and gas properties	36	630	406
Additions to furniture, fixtures and equipment	-36	-22	-29
Redemptions of investments	1	0	2
Net cash used in investing activities	-2,058	-1,159	-2,236
Cash flows from financing activities:	'	'	'
Proceeds from borrowings under credit arrangements	3,263	2,844	3,958
Repayments of borrowings under credit arrangements	-2,614	-2,930	-4,007
Proceeds from issuance of senior notes	0	1,000	750
Debt issue costs	-4	-10	-16
Repayment of senior subordinated notes	0	-875	0
Proceeds from issuances of common stock	1	2	13
Payments for Repurchase of Preferred Stock and Preference Stock	-20	0	0
Purchases of treasury stock, net	-6	-7	-14
Net cash provided by (used in) financing activities	620	24	684
Increase (decrease) in cash and cash equivalents	7	12	37
Cash and cash equivalents, beginning of period	88	76	39
Cash and cash equivalents, end of period	$95	$88	$76

Organization_and_Summary_of_Si

Organization and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
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 areas of operation include the Mid-Continent, the Rocky Mountains and the onshore Gulf Coast regions of North America.
	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. Accordingly, the results of our international 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. For information regarding the sale of our Malaysia business, see Note 17, "Subsequent Events." These financial statements and notes are inclusive of our international operations unless otherwise noted.
	Dependence on Commodity Prices
	As an independent oil and natural gas producer, our revenue, profitability and future rate of growth are substantially dependent on prevailing prices for oil, natural gas and NGLs. Historically, the energy markets have been very volatile, and there can be no assurance that commodity prices will not be subject to wide fluctuations in the future. A substantial or extended decline in commodity prices could have a material adverse effect on our financial position, results of operations, cash flows, access to capital and on the quantities of oil, natural gas and NGL reserves that we can economically produce.
	Use of Estimates
	The preparation of financial statements in accordance with accounting principles generally accepted in the United States of America requires our management to make estimates and assumptions that affect the reported amounts of assets and liabilities; disclosure of contingent assets and liabilities at the date of the financial statements; the reported amounts of revenues and expenses during the reporting period; and the quantities and values of proved oil, natural gas and NGL reserves used in calculating depletion and assessing impairment of our oil and gas properties. Actual results could differ significantly from these estimates. Our most significant financial estimates are associated with our estimated proved oil, natural gas and NGL reserves and the fair value of our derivative positions.
	Reclassifications and Out-of-Period Adjustments
	Certain reclassifications have been made to prior years’ reported amounts in order to conform to the current year presentation. These reclassifications, including those related to our discontinued operations disclosed in Note 3, "Discontinued Operations," did not impact our net income (loss), stockholders’ equity or cash flows.
	The Company's production and other taxes for continuing operations for the year ended December 31, 2013, were reduced by approximately $8 million in the fourth quarter due to a prior period adjustment related to our 2012 and prior ad valorem tax accrual to reflect the actual amounts payable at December 31, 2013. The Company's general and administrative expenses for the year ended December 31, 2013, were reduced by approximately $8 million due to a prior period adjustment related to our 2012 bonus accrual to reflect actual amounts approved and paid in the first quarter of 2013. The Company’s discontinued operations deferred tax expense for the year ended December 31, 2013 was increased by approximately $15 million due to prior period adjustments related to our 2012 repatriation of international earnings and a valuation allowance on a Malaysian deferred tax asset. The Company believes these correcting adjustments in the fourth quarter of 2013 were not material to its prior consolidated financial statements or its quarterly or annual results for the period ended December 31, 2013.
	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. 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 all of 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 2013 on the pending sale of our Malaysian business. Amounts are contractually restricted until the transaction closes. See Note 17, "Subsequent Events," for further discussion about the close of the sale of the Malaysian business in early February 2014.
	Investments
	Investments consist of debt and equity securities, as well as auction rate 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 as a separate component within the consolidated statement of comprehensive income. 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. We realized interest income and net gains on our investment securities in 2013, 2012 and 2011 of $3 million, $3 million and $2 million, respectively.
	Allowance for Doubtful Accounts
	We routinely assess the recoverability of all 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 offshore operations in Malaysia and China. See Note 3, "Discontinued Operations" for details on our international crude oil inventory. Tubular goods and well equipment inventories are carried at the lower of cost or market. At December 31, 2012, we wrote down subsea wellhead inventory that was not included in the sale of our Gulf of Mexico assets. The writedown of $8 million is included in “Operating expenses — Other” on our consolidated statement of operations.
	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 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 $145 million, $123 million and $113 million of internal costs in 2013, 2012 and 2011, respectively. Interest expense related to unproved properties also is capitalized into oil and gas properties.
	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.
	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, adjusted for market differentials (SEC pricing), applicable to our reserves (including the effects of hedging contracts that are designated for hedge accounting, if any); plus
	•	the cost 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, 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 ceiling with respect to our domestic full cost pool exceeded the net capitalized costs. As such, no ceiling test writedown was required at December 31, 2013. If there are declines in SEC pricing of oil and natural gas subsequent to December 31, 2013, we may be required to record a ceiling test writedown in future periods.
	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).
	At December 31, 2011, the ceiling value of our reserves was calculated based upon SEC pricing of $4.12 per MMBtu for natural gas and $96.13 per barrel for oil. Using these prices, the cost center ceiling with respect to our domestic full cost pool exceeded the net capitalized costs. As such, no ceiling test writedown was required at December 31, 2011.
	See Note 4, “Oil and Gas Assets,” for a detailed discussion regarding our acquisition and sales transactions during 2013, 2012 and 2011.
	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.
	Segment Reporting
	Our continuing operations are comprised of a single business segment, the domestic exploration, development and production of oil and natural gas. Prior to classifying our international businesses as held-for-sale and discontinued operations, we reported business segments for Malaysia and China.
	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 ARO to purchasers of our divested properties.
	In general, the amount of an ARO and the costs capitalized will equal the estimated future cost 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:
			2013			2012			2011
			(In millions)
	Balance at January 1		$	100		$	106		$	96
	Accretion expense		8			8			8
	Additions		12			20			5
	Revisions		8			12			3
	Settlements(1)		(8		)	(46		)	(6		)
	Balance at December 31		120			100			106
	Less: Current portion of ARO at December 31		(5		)	(5		)	(4		)
	Total long-term ARO at December 31		$	115		$	95		$	102
	_________________
	-1	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 14, “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, 2013, we did not have a liability for uncertain tax positions, and as such, we did not accrue related interest or penalties. The tax years 2010-2013 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-based compensation 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 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 partners 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. Historically, we have sold our oil, gas and NGLs to several purchasers.
All of our hedging transactions have been carried out in the over-the-counter market. The use of hedging transactions involves the risk that the counterparties will be unable to meet the financial terms of such transactions. The counterparties for all of our hedging 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 hedging 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 hedging 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, 2013, nine of our 15 counterparties accounted for approximately 85% of our estimated future hedged production, with no single counterparty accounting for more than 15% of that production. A portion of our 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
Sunoco Logistics Partners Operations GP LLC, Royal Dutch Shell plc and Tesoro Corporation accounted for 13%, 12% and 11% respectively, of our total revenues in 2013. During 2012, Royal Dutch Shell plc, Tesoro Corporation and Big West Oil LLC accounted for 14%, 14% and 10%, respectively, of our total revenues. During 2011, sales of our oil and gas production to Royal Dutch Shell plc and Tesoro Corporation accounted for 12% and 11%, respectively, of our total revenues. We believe that the loss of Sunoco Logistics Partners Operations GP LLC or Royal Dutch Shell plc would not have a material adverse effect on us because alternative purchasers are readily available. An extended loss of Tesoro Corporation or any of our other large purchasers of our Monument Butte field oil production could have a material adverse effect on us because there are limited purchasers of the black and yellow wax crude oil, which we produce from this field. Due to the higher paraffin content of this production, it must remain heated during shipping, so it cannot be transported in conventional pipelines, and there is limited refining capacity for it in the vicinity of our production. In poor economic environments and tight financial markets, there is an increased risk that the current purchasers of our production may fail to satisfy their obligations to us under our crude oil purchase contracts. We cannot guarantee that we will be able to continue to sell to these purchasers or that similar substitute arrangements could be made for sales of our black and yellow wax crude oil with other purchasers if desired.
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 all of the derivative instruments that we utilize are 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. We periodically utilize derivatives to manage our exposure to variable interest rates.
The related cash flow impact of our derivative activities are reflected as cash flows from operating 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 will likely sell the securities for a loss during 2014. As a result, the losses previously accumulated in AOCI related to these securities have been transferred and recognized in the consolidated statement of operations for the year ended December 31, 2013. 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, 2011		$	(12	)	$	—		$	(12	)
Current period other comprehensive income (loss)		3			(1		)	2
Balance at December 31, 2011		(9		)	(1		)	(10		)
Current period other comprehensive income (loss)		3			—			3
Balance at December 31, 2012		(6		)	(1		)	(7		)
Other comprehensive income (loss) 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
New Accounting Requirements
In February 2013, the FASB issued guidance regarding the reporting of amounts reclassified out of accumulated other comprehensive income. The guidance is effective for interim and annual periods beginning after December 15, 2012. We adopted the guidance in the quarter ended March 31, 2013. Adoption of the new reporting guidance did not have a material impact on our financial position or results of operations.
In December 2011, the FASB issued guidance regarding the disclosure of offsetting assets and liabilities. The guidance requires disclosure of gross information and net information about instruments and transactions eligible for offset arrangement. The guidance is effective for interim and annual periods beginning on or after January 1, 2013. We adopted the guidance in the quarter ended March 31, 2013. Adoption of the additional disclosures regarding offsetting assets and liabilities did not have a material impact on our financial position or results of operations.

Earnings_Per_Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2013
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:
			2013			2012			2011
			(In millions, except per share data)
	Income (numerator):
	Income (loss) from continuing operations		$	108		$	(902	)	$	401
	Income (loss) from discontinued operations, net of tax		39			(282		)	138
	Net income (loss)		147			(1,184		)	539
	Repurchase of preferred shares of subsidiary (3)		(20		)	—			—
	Net income (loss) attributable to common shareholders		$	127		$	(1,184	)	$	539
	Weighted-average shares (denominator):
	Weighted-average shares — basic		135			135			134
	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		136			135			135
	Earnings (loss) per share:
	Basic:
	Income (loss) from continuing operations		$	0.8		$	(6.70	)	$	3
	Income (loss) from discontinued operations before preferred share repurchase		0.29			(2.10		)	1.03
	Repurchase of preferred shares of subsidiary (3)		(0.15		)	—			—
	Income (loss) from discontinued operations		0.14			(2.10		)	1.03
	Basic earnings (loss) per share		$	0.94		$	(8.80	)	$	4.03
	Diluted:
	Income (loss) from continuing operations		$	0.8		$	(6.70	)	$	2.97
	Income (loss) from discontinued operations before preferred share repurchase		0.29			(2.10		)	1.02
	Repurchase of preferred shares of subsidiary (3)		(0.15		)	—			—
	Income (loss) from discontinued operations		0.14			(2.10		)	1.02
	Diluted earnings (loss) per share		$	0.94		$	(8.80	)	$	3.99
	_________________
	-1	Excludes 4.0 million and 1.4 million shares of unvested restricted stock or restricted stock units and stock options for the years ended December 31, 2013 and 2011, 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 discontinued operations. See Note 16, "Related Party Transaction," for additional information.

Discontinued_Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	'
	Discontinued Operations:
	In February 2013, we announced our decision to explore strategic alternatives for our international businesses. In accordance with specific accounting requirements, we met the criteria to classify our international businesses as held-for-sale and discontinued operations during the second quarter of 2013. As a result, the historical results of operations for our Malaysia and China businesses are reflected in our financial statements as “discontinued operations.”
	Malaysia Update
	As discussed in Note 17, "Subsequent Events," we closed the sale of our Malaysia business on February 10, 2014.
	China Update
	In August of 2013, during the installation of the LF-7 topside facilities by a third-party contractor, a hydraulic jacking system malfunctioned and the installation was suspended. The installation of the facility has been delayed and the potential cost and timing for the reinstallation is uncertain at this time. As a result of this incident, the timing of the China divestiture has been delayed. The Company continues to actively market its China business. After reevaluating the criteria to be classified as discontinued operations, we believe that our China operations continue to meet the “held for sale” criteria and therefore remain in discontinued operations as of December 31, 2013. We will continue to monitor the facts and circumstances surrounding the completion of the production facilities and sale of our China operations on a quarterly basis.
	Financial Results of Discontinued Operations
		Year Ended December 31,
		2013			2012			2011
		(In millions)
	Oil and gas revenues (1)	$	891		$	1,092		$	729
	Operating expenses	689			664			508
	Income from discontinued operations	202			428			221
	Other income (expense)	4			(3		)	—
	Income from discontinued operations before income taxes	206			425			221
	Income tax provision (benefit):
	Current	90			193			76
	Deferred	77			514			7
	Total income tax provision (benefit)	167			707			83
	Income (loss) from discontinued operations, net of tax	$	39		$	(282	)	$	138
	________________
	(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
	The effective tax rates for our discontinued operations for the year ended December 31, 2013, 2012 and 2011 were 81%, 166% and 37%, respectively. Historically, our international effective tax rate was approximately 37%. However, the effective tax rates for 2013 and 2012 were affected by our decision to repatriate earnings from our foreign operations, which resulted in net income of our international businesses being taxed both in the U.S. and the local country, and the recording of a valuation allowance related to our deferred tax asset in Malaysia.
	Assets and Liabilities in the Consolidated Balance Sheet from Discontinued Operations
		December 31,
		2013			2012
		(In millions)
	Current assets:
	Cash and cash equivalents	$	84		$	76
	Accounts receivable	200			207
	Inventories	130			91
	Other current assets	33			31
	Total current assets	447			405
	Noncurrent assets:
	Oil and gas properties, net of accumulated depreciation, depletion and amortization of $1,121 and $843 as of December 31, 2013 and 2012, respectively	989			781
	Deferred taxes	19			24
	Other assets	4			4
	Total noncurrent assets	1,012			809
	Total assets	$	1,459		$	1,214
	Current liabilities:
	Accounts payable	$	38		$	50
	Accrued liabilities	324			269
	Asset retirement obligations	49			5
	Other current liabilities	18			16
	Total current liabilities	429			340
	Noncurrent liabilities:
	Asset retirement obligations	86			37
	Deferred taxes	129			41
	Other liabilities	11			24
	Total noncurrent liabilities	226			102
	Total liabilities	$	655		$	442
	Crude Oil Inventories
	Substantially all of the crude oil from our offshore operations in Malaysia and China is produced into floating production, storage and off-loading vessels (FPSOs) or onshore storage terminals and “lifted” and sold periodically as barge quantities are accumulated. The product inventory from our international operations consisted of approximately 1.1 million barrels and 0.7 million barrels of crude oil valued at cost of $90 million and $64 million at December 31, 2013 and 2012, respectively, and are included in the "Inventories" line item in the preceding table and 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, the oil and gas properties associated with our discontinued operations included $115 million not subject to amortization, comprised of $45 million incurred prior to 2011, $2 million incurred in 2011, $24 million incurred in 2012 and $44 million incurred in 2013.
	At December 31, 2013, we performed a fair value assessment of our Malaysia and China discontinued operations, noting no indication of impairment based on the current carrying value.
	During 2012, when our Malaysia and China businesses were reported as continuing operations, we performed a ceiling test for each 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. At December 31, 2011, the ceiling value of our reserves was calculated based upon SEC pricing of $4.12 per MMBtu for natural gas and $96.13 per barrel for oil. Using these prices, the cost center ceilings with respect to our Malaysia and China full cost pools exceeded the net capitalized costs of the respective cost centers at December 31, 2012 and December 31, 2011, and as such, no ceiling test writedowns were required.
	The change in our ARO for discontinued operations for each of the three years ended December 31, is set forth below:
		2013			2012			2011
		(In millions)
	Balance at January 1	$	42		$	39		$	12
	Accretion expense	3			3			2
Additions	4			4			29
Revisions	101			—			—
Settlements	(15		)	(4		)	(4		)
Balance at December 31	135			42			39
Less: Current portion of ARO at December 31	(49		)	(5		)	(6		)
Total long-term ARO at December 31	$	86		$	37		$	33

Oil_and_Gas_Assets

Oil and Gas Assets	12 Months Ended
	Dec. 31, 2013
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:
		2013			2012
		(In millions)
	Oil and gas properties:
	Subject to amortization	$	15,107		$	12,647
	Not subject to amortization	1,300			1,485
	Gross oil and gas properties	16,407			14,132
	Accumulated depreciation, depletion and amortization	(8,306		)	(7,378		)
	Net oil and gas properties	8,101			6,754
	Other property and equipment:
	Furniture, fixtures and equipment	139			141
	Gathering systems and equipment	104			73
	Accumulated depreciation and amortization	(69		)	(66		)
	Net other property and equipment	174			148
	Total property and equipment, net	$	8,275		$	6,902
	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 December 31 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.
	The following is a summary of our oil and gas properties not subject to amortization as of December 31, 2013. At December 31, 2013, approximately 82% of our oil and gas properties not subject to amortization were associated with unconventional resource plays. Because of the size of our unconventional resource plays, the entire evaluation can take significantly longer than four years. However, we believe that our evaluation activities related to substantially all of our conventional properties not subject to amortization will be completed within four years.
		Costs Incurred In
		2013			2012			2011		2010 and Prior		Total
		(In millions)
	Acquisition costs	$	206		$	114		$	188	$	300	$	808
	Exploration costs	175			21			9		35		240
	Development costs	13			31			25		—		69
	Fee mineral interests	1			—			—		23		24
	Capitalized interest	53			68			38		—		159
	Total oil and gas properties not subject to amortization	$	448		$	234		$	260	$	358	$	1,300
	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.
	Uinta Basin Asset Acquisitions
	In May 2011, we closed two transactions to acquire assets in the Uinta basin of Utah for a total of approximately $303 million. The assets include approximately 65,000 net acres, which are largely undeveloped and located north of our Greater Monument Butte Unit.
	Other Asset Acquisitions and Sales
	During 2013, 2012 and 2011, we acquired various other oil and gas properties for approximately $72 million, $9 million and $1 million, respectively, and sold certain oil and gas properties for proceeds of approximately $36 million, $630 million(includes Gulf of Mexico asset sale discussed above) and $406 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, 2013
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 hedge against the variability in cash flows associated with the forecasted sale of our future oil and natural gas production domestically.
	•	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.
	While the use of these derivative instruments limits 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 and time to maturity. The calculation of the fair value of collars and sold puts requires the use of an option-pricing model. See Note 8, “Fair Value Measurements.”
	At December 31, 2013, we had outstanding positions with respect to our future production 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)
		January 2014 — March 2014
		Fixed-price swaps		21,150			$	3.98			—			—			—				$	(6	)
		Collars		5,850			—				—			$	3.75		$	4.62			(1		)
		April 2014 — June 2014
		Fixed-price swaps		21,385			3.98				—			—			—				(3		)
		Collars		5,915			—				—			3.75			4.62				—
		July 2014 — September 2014
		Fixed-price swaps		21,620			3.98				—			—			—				(4		)
		Collars		5,980			—				—			3.75			4.62				—
		October 2014 — December 2014
		Fixed-price swaps		21,620			3.98				—			—			—				(5		)
		Collars		5,980			—				—			3.75			4.62				(1		)
		January 2015 — December 2015
		Fixed-price swaps		49,275			4.28				—			—			—				7
		Collars		38,325			—				—			3.93			4.74				2
																					$	(11	)
	Crude Oil
	Period and Type of Instrument		Volume in MBbls			NYMEX Contract Price Per Bbl															Estimated
																					Fair Value
														Collars							Asset
						Swaps				Sold Puts (Weighted				Floors (Weighted			Ceilings (Weighted				(Liability)
						(Weighted				Average)				Average)			Average)
						Average)
																					(In millions)
	January 2014 — March 2014
	Fixed-price swaps		1,350			$	89.6			—				—			—				$	(12	)
	Fixed-price swaps with sold puts		1,440			95.16				$	75			—			—				(4		)
	Collars with sold puts		540			—				75.83				$	90.83		$	102.93			(1		)
	April 2014 — June 2014
	Fixed-price swaps		1,729			90.07				—				—			—				(12		)
	Fixed-price swaps with sold puts		1,456			95.16				75				—			—				(3		)
	Collars with sold puts		546			—				75.83				90.83			102.93				—
	July 2014 — September 2014
	Fixed-price swaps		1,932			89.86				—				—			—				(9		)
	Fixed-price swaps with sold puts		1,472			95.16				75				—			—				—
	Collars with sold puts		552			—				75.83				90.83			102.93				1
	October 2014 — December 2014
	Fixed-price swaps		2,116			89.95				—				—			—				(5		)
	Fixed-price swaps with sold puts		1,472			95.16				75				—			—				2
	Collars with sold puts		552			—				75.83				90.83			102.93				1
	January 2015 — December 2015
	Fixed-price swaps		6,567			90.39				—				—			—				14
	Fixed-price swaps with sold puts		4,567			90.03				68.2				—			—				3
																					$	(25	)
	Additional Disclosures about Derivative Instruments and Hedging Activities
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-13		(In millions)															(In millions)
Natural gas positions		$	11			$	(2	)		$	—			$	9		$	(22	)		$	2	$	(20	)	$	—
Oil positions		26				(9		)		—				17			(51		)		9		(42		)	—
Total		$	37			$	(11	)		$	—			$	26		$	(73	)		$	11	$	(62	)	$	—
31-Dec-12
Natural gas positions		$	86			$	(5	)		$	79			$	2		$	(16	)		$	5	$	(4	)	$	(7	)
Oil positions		77				(16		)		46				15			(26		)		16		(2		)	(8		)
Total		$	163			$	(21	)		$	125			$	17		$	(42	)		$	21	$	(6	)	$	(15	)
The amount of gain (loss) recognized in “Commodity derivative income (expense)” in our consolidated statement of operations related to our derivative financial instruments was as follows:
		2013				2012				2011
		(In millions)
Derivatives not designated as hedging instruments:
Realized gain (loss) on natural gas positions		$	66			$	144			$	249
Realized gain (loss) on oil positions		(6		)		1				(47		)
Realized gain (loss) on basis positions		—				(10		)		(7		)
Total realized gain(1)		60				135				195
Unrealized gain (loss) on natural gas positions		(81		)		(124		)		(48		)
Unrealized gain (loss) on oil positions		(76		)		99				47
Unrealized gain (loss) on basis positions		—				10				1
Total unrealized loss		(157		)		(15		)		—
Total		$	(97	)		$	120			$	195
________
-1	The total realized gain on commodity derivatives may differ from the cash receipts on derivative settlements as a result of the receipt or payment of premiums, or due to the recognition of premiums previously received associated with derivatives settled during the period.

Accounts_Receivable

Accounts Receivable	12 Months Ended
	Dec. 31, 2013
Accounts Receivable, Net, Current [Abstract]	'
Accounts Receivable Text Block	'
	Accounts Receivable:
	Accounts receivable consisted of the following at December 31:
		2013			2012
		(In millions)
	Revenue	$	294		$	291
	Joint interest	156			154
	Other	25			8
	Reserve for doubtful accounts	(1		)	(1		)
	Total accounts receivable	$	474		$	452

Accrued_Liabilities

Accrued Liabilities	12 Months Ended
	Dec. 31, 2013
Accrued Liabilities, Current [Abstract]	'
Accrued Liabilities Text Block	'
	Accrued Liabilities:
	Accrued liabilities consisted of the following at December 31:
		2013		2012
		(In millions)
	Revenue payable	$	175	$	95
	Accrued capital costs	458		355
	Accrued lease operating expenses	71		95
	Employee incentive expense	51		50
	Accrued interest on debt	72		43
	Taxes payable	93		108
	Other	58		55
	Total accrued liabilities	$	978	$	801

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2013
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 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 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 (price collars and sold puts) 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) quoted forward prices for commodities, (b) time value, (c) volatility factors, (d) counterparty credit risk and (e) current market and contractual prices for the underlying commodities, as well as other relevant economic measures.
	•	Our valuation methodology for investments is a discounted cash flow model that considers various inputs including: (a) the coupon rate specified under the debt instruments, (b) the current credit ratings of the underlying issuers, (c) collateral characteristics and (d) risk-adjusted discount rates.
	•	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 levels.
	Fair Value of Financial Instruments
	The following table summarizes the valuation of our financial assets (liabilities) of our continuing operations by measurement levels:
			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, 2012:
	Money market fund investments		$	22		$	—		$	—			$	22
	Deferred compensation plan assets		6			—			—				6
	Investments available-for-sale:
	Equity securities		7			—			—				7
	Auction rate securities		—			—			36				36
	Oil and gas derivative swap contracts		—			6			—				6
	Oil and gas derivative option contracts		—			—			115				115
	Stock-based compensation liability awards		(2		)	—			—				(2		)
	Total		$	33		$	6		$	151			$	190
	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 contracts		—			—			(8		)		(8		)
	Stock-based compensation liability awards		(11		)	—			(5		)		(16		)
	Total		$	7		$	(28	)	$	26			$	5
	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.
	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, 2011		$	30		$	48		$	—			$	78
	Total realized or unrealized gains (losses):
	Included in earnings		—			87			—				87
	Included in other comprehensive income (loss)		4			—			—				4
	Purchases, issuances and settlements:
	Settlements		(2		)	(64		)	—				(66		)
	Transfers in and out of Level 3		—			—			—				—
	Balance at December 31, 2011		$	32		$	71		$	—			$	103
	Change in unrealized gains or losses included in earnings relating to		$	—		$	56		$	—			$	56
	Level 3 assets and liabilities still held at December 31, 2011
	Balance at January 1, 2012		$	32		$	71		$	—			$	103
	Total realized or unrealized gains (losses):
	Included in earnings		—			135			—				135
	Included in other comprehensive income (loss)		4			—			—				4
	Purchases, issuances and settlements:
	Settlements		—			(91		)	—				(91		)
	Transfers in and 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 assets and liabilities still held at December 31, 2012
Balance at January 1, 2013		$	36		$	115		$	—			$	151
Total realized or unrealized gains (losses):
Included in earnings		(6		)	(66		)	(18		)		(90		)
Included in other comprehensive income (loss)		10			—			—				10
Purchases, issuances and settlements:
Settlements		(1		)	(57		)	13				(45		)
Transfers in and 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 assets and liabilities still held at December 31, 2013
Qualitative Disclosures about Unobservable Inputs for Level 3 Fair Value Measurements
Investments.   We utilize a discounted cash flow model in the determination of the valuation of our auction rate securities classified as Level 3. This model considers various inputs including (a) the coupon rate specified under the debt instrument, (b) the current credit rating of the underlying issuers, (c) collateral characteristics and (d) risk-adjusted discount rates. The most significant unobservable factor in the determination of the investments fair value, however, is market liquidity for these instruments. A significant change in the liquidity of the market for auction rate securities would lead to a corresponding change in the fair value measurement of these investments.
As of December 31, 2013, we held $39 million of auction rate securities maturing beginning in 2033 that are classified as a Level 3 fair value measurement. This amount reflects 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 under the caption “Other income (expense) — Other, net" on our consolidated statement of operations as a result of our decision to liquidate our auction rate investments. As of December 31, 2012, we held $36 million of auction rate securities, which reflected a decrease in the fair value of $9 million ($6 million net of tax) recorded under the caption "Accumulated other comprehensive income" on our consolidated balance sheet. The debt instruments underlying our auction rate securities are mostly investment grade (rated BBB or better) and are guaranteed by the United States government or backed by private loan collateral. Please see Note 1, "Organization and Summary of Significant Accounting Policies" for additional disclosure regarding our auction rate securities.
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) quoted forward prices for commodities, (b) volatility factors and (c) 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 the hedge agreements, and the resulting estimated future cash inflows or outflows over the lives of the hedges are discounted to calculate the fair value of the derivative contracts. 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.
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 hedging 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 requires the use of unobservable inputs. The simulation predicts multiple scenarios of future stock return 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 positions		$	(9	)	Option model		NYMEX Oil price forward curve	$86.29		—	$98.77
							Oil price volatility curves	14.33	%	—	23.22%
							Credit risk	0.01	%	—	0.89%
Natural gas option positions		$	1		Option model		NYMEX Natural gas price	$4.01		—	$4.42
							forward curve
							Natural gas price volatility curves	18.74	%	—	50.02%
							Credit risk	0.01	%	—	1.58%
SVAP		$	(5	)	Monte Carlo		Historical volatility				37.40%
							Implied volatility				41.20%
The underlying inputs in the determination of the valuation of our auction rate securities are developed by a third party and, therefore, not included in the quantitative analysis above.
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:
		2013			2012
		(In millions)
5¾% Senior Notes due 2022		$	767		$	836
5⅝% Senior Notes due 2024		1,025			1,074
7⅛% Senior Subordinated Notes due 2018		624			630
6⅞% Senior Subordinated Notes due 2020		755			749
Any amounts outstanding under our credit arrangements at December 31, 2013 and 2012 are stated at cost, which approximates fair value. Please see Note 9, "Debt."

Debt

Debt	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Debt Text Block	'
	Debt:
	At December 31, our debt consisted of the following:
			2013			2012
			(In millions)
	Senior unsecured debt:
	Revolving credit facility — LIBOR based loans		$	585		$	—
	Money market lines of credit(1)		64			—
	Total credit arrangements		649			—
	5¾% Senior Notes due 2022		750			750
	5⅝% Senior Notes due 2024		1,000			1,000
	Total senior unsecured debt		1,750			1,750
	7⅛% Senior Subordinated Notes due 2018		600			600
	6⅞% Senior Subordinated Notes due 2020		700			700
	Discount on notes		(5		)	(5		)
	Total long-term debt		$	3,694		$	3,045
	_________________
	-1	Because capacity under our credit facility was available to repay borrowings under our money market lines of credit as of the indicated dates, amounts outstanding under these obligations, if any, are classified as long-term.
	Credit Arrangements
	In April 2013, we entered into the second amendment to the credit facility, which allows the sale of the Company's international businesses pursuant to certain terms and conditions. In June 2013, we entered into the third amendment of our Credit Agreement. This amendment extended the maturity date of the revolving credit facility from June 2016 to June 2018 and increased the borrowing capacity from $1.25 billion to $1.4 billion. We incurred $4 million of deferred financing costs related to this amendment. As of December 31, 2013, 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, 2013) 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, 2013).
	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, 2013). We incurred aggregate commitment fees under our current and previous credit facilities of approximately $3 million, $3 million and $2 million for each of the years ended December 31, 2013, 2012 and 2011, 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, 2013, we were in compliance with all of our debt covenants.
	As of December 31, 2013, we had $58 million 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, 2013).
	Subject to compliance with the restrictive covenants in our credit facility, at December 31, 2013, we also had a total of $96 million of 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 hedging arrangements contain provisions that provide for cross defaults and acceleration of those debt and hedging instruments in certain situations.
	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, 2013, we were in compliance with all of our debt covenants.
	Senior Subordinated 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.
	We may redeem some or all of our 7⅛% Senior Subordinated Notes due 2018 at any time at a redemption price stated in the indenture governing the notes. 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. Prior to February 1, 2015, we may redeem some or all of these notes at a make-whole redemption price.
	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, 2013, we were in compliance with all of our debt covenants.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes Text Block	'
	Income Taxes:
	For the years ended December 31, the total provision (benefit) for income taxes for continuing operations consisted of the following:
		2013			2012			2011
		(In millions)
	Current taxes:
	U.S. federal	$	(4	)	$	1		$	17
	U.S. state	—			1			—
	Deferred taxes:
	U.S. federal	53			(479		)	171
	U.S. state	13			(34		)	30
	Total provision (benefit) for income taxes	$	62		$	(511	)	$	218
	The provision for income taxes for each of the indicated years was different than the amount computed using the federal statutory rate (35%) for the following reasons:
		2013			2012			2011
		(In millions)
	Amount computed using the statutory rate	$	60		$	(495	)	$	217
	Increase (decrease) in taxes resulting from:
	State and local income taxes, net of federal effect	8			(18		)	10
	Valuation allowance, state net of federal	(2		)	—			5
	Other	(4		)	2			(14		)
	Total provision (benefit) for income taxes	$	62		$	(511	)	$	218
	At December 31, the components of our deferred tax asset (liability) were as follows:
		2013			2012
		(In millions)
	Deferred tax asset:
	Net operating loss carryforwards	$	335		$	213
	Alternative minimum tax credit	99			103
	Stock-based compensation	25			24
	Marketable securities	3			4
	Oil and gas properties	59			49
	Foreign tax credit	535			421
	Commodity derivatives	13			—
	Other	6			18
	Total deferred tax asset	1,075			832
	Deferred tax asset valuation allowances	(584		)	(457		)
	Net deferred tax asset	491			375
	Deferred tax liability:
	Commodity derivatives	—			(44		)
	Oil and gas properties	(1,592		)	(1,283		)
	Total deferred tax liability	(1,592		)	(1,327		)
	Net deferred tax liability	(1,101		)	(952		)
	Less: Net current deferred tax asset (liability)	22			(42		)
	Net noncurrent deferred tax liability	$	(1,123	)	$	(910	)
	As of December 31, 2013 and 2012, we had gross net operating loss (NOL) carryforwards of approximately $1.0 billion and $0.5 billion for federal income tax and $1.7 billion and $1.6 billion for state income tax purposes, respectively, which may be used in future years to offset taxable income. NOL carryforwards of $189 million are subject to annual limitations due to stock ownership changes. We currently estimate that we will not be able to utilize $74 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 and 2012, we had gross NOL carryforwards for international income tax purposes of approximately $17 million, respectively. We currently estimate that we will not be able to utilize these NOLs because we do not have sufficient estimated future taxable income in the appropriate jurisdictions. As a result, valuation allowances were established for these items in 2005 and 2006.
	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:
		2013			2012			2011
		(In millions)
	Balance at the beginning of the year	$	(457	)	$	(11	)	$	(6	)
	Charged to provision for income taxes:
	Malaysia valuation allowance	(15		)	(25		)	—
	Foreign tax credit valuation allowance	(114		)	(421		)	—
	U.S. state net operating loss carryforwards	2			—			(5		)
	Balance at the end of the year	$	(584	)	$	(457	)	$	(11	)
	In the fourth quarter of 2013 and 2012, we recorded a $15 million and $25 million valuation allowance for our deferred tax asset in Malaysia, respectively, due to insufficient estimated future taxable income. Also in the fourth quarter of 2013 and 2012, we recorded a valuation allowance related to insufficient estimated future domestic taxable income to fully utilize foreign tax credits of $114 million and $421 million, respectively. The foreign tax credit deferred tax asset is fully offset by a valuation allowance. In 2013, we released $2 million of state valuation allowances due to utilization of the related state NOLs.

StockBased_Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2013
Share-based Compensation [Abstract]	'
Stock-Based Compensation Text Block	'
	Stock-Based Compensation:
	For the years ended December 31, our stock-based compensation consisted of the following:
			2013				2012				2011
			(In millions)
	Equity awards		$	48			$	46			$	37
	Liability awards		27				1				3
	Total stock-based compensation		75				47				40
	Capitalized in oil and gas properties		(20		)		(12		)		(11		)
	Net stock-based compensation expense		$	55			$	35			$	29
	As of December 31, 2013, we had approximately $116 million of total unrecognized stock-based compensation expense related to unvested stock-based compensation awards. The full amount is expected to be recognized within five 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 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, 2013, we had approximately (1) 2.7 million additional shares available for issuance pursuant to our existing plan if all future awards under our 2011 Plan are stock options, or (2) 1.5 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, 2013, our employees held approximately three million shares of non-vested restricted stock and restricted stock units. The vesting of these shares and units is dependent upon the employee’s continued service with our Company. In addition, at December 31, 2013, our employees held 0.7 million shares of restricted stock subject to performance-based vesting criteria (substantially all of which are considered market-based restricted stock under authoritative accounting guidance). We primarily utilize treasury shares when restricted stock is issued or restricted stock units vest.
	The table below provides information about restricted stock and restricted stock unit activity for the following years:
			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, 2011		2,178			316			2,494			$	36.84
	Granted		1,014			130			1,144			64.35
	Forfeited		(233	)		—			(233	)		44.79
	Vested		(836	)		(89	)		(925	)		34.86
	Non-vested shares outstanding at December 31, 2011		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
	The total fair value of restricted stock and restricted stock units that vested during the years ended December 31, 2013, 2012 and 2011 was $47 million, $44 million and $32 million, respectively.
	Stock Options.    We have granted stock options under several plans. 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 2013, 2012 or 2011 because we did not have sufficient taxable income to fully realize the deduction. At December 31, 2013, we had unrecognized net operating losses of $102 million related to stock-based compensation.
	The table below provides information about stock option activity for the following years:
			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 December 31, 2010		1,539			$	34.58							4.7		$	58
	Granted		—			—				$	—
	Exercised		(446	)		29.54										18
	Forfeited		(34	)		46.73
	Outstanding at December 31, 2011		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		$	—
	Exercisable at December 31, 2013		687			$	39.68							1.9		$	—
	_________________
	-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, 2013, the last reported sales price of our common stock on the New York Stock Exchange was $24.63 per share.
	The table below summarizes information about stock options outstanding and exercisable at December 31, 2013:
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)
$22.51 to $27.50		93			0.2		$	24.9			93			$	24.9
27.51 to 35.00		202			0.9		31.03				202			31.03
35.01 to 41.72		31			1.3		38.33				31			38.33
41.73 to 48.45		361			3		48.45				361			48.45
		687			1.9		$	39.68			687			$	39.68
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 day of the period or the last day of the period. No employee may purchase common stock under the plan valued at more than $25,000 in any calendar year. Employees of our foreign subsidiaries are not eligible to participate in the plan.
During 2013, options to purchase approximately 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%. At December 31, 2013, 524,300 shares of our common stock remained available for issuance under the current plan.
During 2012, options to purchase 165,722 shares of our common stock at a weighted-average fair value of $9.86 per share were issued under the plan. 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%.
During 2011, options to purchase 85,982 shares of our common stock at a weighted-average fair value of $16.95 per share were issued under the plan. 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 0.14%, an expected life of six months and weighted-average volatility of 32.21%.
Liability Awards
Liability awards consist of cash-based performance awards under the Stockholder Value Appreciation Program and cash-settled restricted stock units.
Stockholder Value Appreciation Program. In September 2013, the Compensation and Management Development Committee of the Board approved the Stockholder Value Appreciation Program, to be administered under the 2011 Omnibus Stock 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. The first price threshold that would trigger a payment under the SVAP was $27.50. The SVAP’s performance period lasts through December 31, 2015.
Based upon the expected duration of the performance period, the expected remaining payout is $19 million, of which $5 million has been accrued as of December 31, 2013. The total expected cost was determined using a Monte Carlo simulation assuming no dividends, a risk-free weighted-average interest rate of 0.38%, an expected life of two years and an average of implied and historical stock price volatility of 39.3%. In October 2013, the first price threshold of $27.50 was achieved, which led to a cash payment of approximately $13 million that was paid to eligible employees. As of December 31, 2013, we had unrecognized stock-based compensation expense related to the SVAP of approximately $14 million.
Cash-Settled Restricted Stock Units.    During 2011 and 2013, we granted cash-settled restricted stock units to employees that vest over three years. The value of the awards, and the associated stock-based compensation expense, is based on the Company’s stock price. During the year ended December 31, 2013, approximately 85,000 cash-settled restricted stock units vested and settled for approximately $2 million. During the year ended, December 31, 2012, approximately 44,000 cash-settled restricted units for approximately $2 million. As of December 31, 2013, 1.2 million cash-settled restricted stock units outstanding and unrecognized stock-based compensation expense of approximately $15 million for cash-settled restricted stock units.

Employee_Benefit_Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2013
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, 2013, both our accumulated benefit obligation and our accrued benefit costs were $10 million. Our net periodic benefit cost was approximately $2 million for each of the years ended December 31, 2013, 2012 and 2011.
	The expected future benefit payments under our post-retirement medical plan for the next ten years include $3 million for the five-year period 2014 through 2018 and $5 million for the five-year period 2019 through 2023.
	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 for the years ended December 31, 2013, 2012 and 2011 was $40 million, $41 million and $39 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, 2013 and 2012 and $8 million for the year ended December 31, 2011.

Voluntary_Severance_Program

Voluntary Severance Program	12 Months Ended
	Dec. 31, 2013
Restructuring and Related Activities [Abstract]	'
Restructuring and Related Activities Disclosure [Text Block]	'
	Voluntary Severance Program:
	During the second quarter of 2013, we implemented a voluntary severance program in order to lower cash operating costs and change the structure of our organization to better align with our focus on domestic resource plays. At December 31, 2013, the total expense of the voluntary severance program was approximately $9 million, all of which has been recognized in "General and administrative" expense in our consolidated statement of operations.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
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, 2013, future minimum payments under these non-cancelable agreements are as follows:
			Firm			Operating		Other		Total
			Transportation			Leases
			(In millions)
	Year Ending December 31,
	2014		$	78		$	17	$	61	$	156
	2015		76			18		16		110
	2016		73			15		—		88
	2017		71			15		—		86
	2018		62			14		—		76
	Thereafter		85			36		—		121
	Total minimum future payments		$	445		$	115	$	77	$	637
	Firm transportation is comprised of various agreements with third parties for oil and gas gathering and transportation. Rent expense for continuing operations with respect to our lease commitments for office space for the years ended December 31, 2013, 2012 and 2011 was $18 million, $17 million and $14 million, respectively. Our other agreements are primarily drilling rigs. Payments under these contracts are accounted for as capital additions to our oil and gas properties.
	At December 31, 2013, we had approximately $5 million in operating leases and $245 million of other agreements related to our discontinued operations. Our other agreements related to discontinued operations primarily consist of platform construction and drilling rigs. Payments under these contracts are accounted for as capital additions to our oil and gas properties. We also have work-related commitments for, among other things, drilling wells, obtaining and processing seismic data, transportation of our production and fulfilling other related commitments attributable to our discontinued operations.
	We have various oil and gas production volume delivery commitments that are related to our domestic operations. As of December 31, 2013, our delivery commitments through 2024 were as follows:
			Natural		Oil(1)
			Gas
	Year Ending December 31,		(MMMBtus)		(MBbls)
	2014		11,250		7,483
	2015		—		7,483
	2016		—		9,190
	2017		—		13,870
	2018		—		13,870
	Thereafter		—		50,748
	Total delivery commitments		11,250		102,644
	_________________
	-1	Our oil delivery commitments include a particular commitment with a Salt Lake City, Utah refiner. This delivery commitment will begin upon the refiner completing the expansion of their facility, which is expected in late 2015. Our delivery commitment is to deliver approximately 20,000 barrels of oil per day over a 10-year period. This delivery commitment represents approximately 7,300 MBbls of our committed oil volumes for each of the years 2016 through 2024. The timing may change due to timing of the completion of the refinery expansion.
	Given the size of our proved natural gas and oil reserves and production capacity in the respective divisions, we currently believe that we have sufficient reserves and production to fulfill these commitments. However, in the event that we are unable to meet our crude oil volume delivery commitments, we would incur deficiency fees ranging from $2.67 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.
	We have been made aware of an indemnity demand related to properties that were sold in 2008 and 2009. At this time we cannot estimate the liability that we may incur but we do not expect it to have a material adverse effect on our financial position.
	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.

Supplemental_Cash_Flows_Inform

Supplemental Cash Flows Information	12 Months Ended
	Dec. 31, 2013
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:
		2013			2012			2011
		(In millions)
	Cash Payments:
	Interest payments	$	148		$	137		$	79
	Income tax payments	128			206			70
	Non-cash items excluded from the statement of cash flows:
	(Increase) decrease in receivables for property sales	$	(9	)	$	3		$	28
	(Increase) decrease in accrued capital expenditures	(75		)	(124		)	90
	(Increase) decrease in asset retirement costs	(125		)	(8		)	(33		)
	Increase (decrease) in deferred liabilities	90			—			—

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transaction Text Block	'
	Related Party Transaction:
	Kevin M. Robinson, our Vice President — Asia through February 10, 2014, and Susan G. Riggs, our Treasurer, are minority owners of Huffco International L.L.C. (Huffco). In May 1997, before Mr. Robinson and Ms. Riggs joined us, we acquired from Huffco an entity now known as Newfield China, LDC, the owner of a 12% interest in a three field unit located on Blocks 4/36 and 5/36 in Bohai Bay, offshore China. Huffco retained preferred shares of Newfield China that provide for an aggregate dividend equal to 10% of the excess of proceeds received by Newfield China from the sale of oil, gas and other minerals over all costs incurred with respect to exploration and production in Block 5/36, plus the cash purchase price we paid Huffco for Newfield China ($6 million). During 2013, 2012 and 2011, Newfield China paid dividends of $2 million, $7 million and $5 million, respectively, to Huffco on the preferred shares of Newfield China. During 2013, we purchased from Huffco the outstanding preferred shares of Newfield China for approximately $20 million. The repurchase of the preferred shares was recorded as a charge against retained earnings.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events [Text Block]	'
	Subsequent Events:
	On February 10, 2014, Newfield International Holdings Inc., a wholly-owned subsidiary of the Company, closed the stock purchase agreement to sell our Malaysian business to SapuraKencana Petroleum Berhad, a Malaysian public company, for $898 million in cash (subject to customary purchase price adjustments). We expect to record a gain in the first quarter of 2014 of approximately $400 million. As of December 31, 2013, we had received 10%, or $90 million, of the purchase price in the form of a deposit, which is reflected as restricted cash on our consolidated balance sheet.

Quarterly_Results_of_Operation

Quarterly Results of Operations	12 Months Ended
	Dec. 31, 2013
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:
			2013 Quarter Ended
			March 31			June 30		September 30			December 31
			(In millions, except per share data)
	Oil, gas and NGL revenues(1)		$	370		$	435	$	486		$	498
	Income (loss) from operations(1)		78			89		131			121
	Income (loss) from continuing operations, net of tax		(25		)	106		(4		)	31
	Income (loss) from discontinued operations, net of tax		17			5		31			(14		)
	Net income (loss)		$	(8	)	$	111	$	27		$	17
	Basic earnings (loss) per common share(2)
	Income (loss) from continuing operations		$	(0.19	)	$	0.78	$	(0.03	)	$	0.23
	Income (loss) from discontinued operations		0.13			0.04		0.08			(0.10		)
	Basic earnings (loss) per share		$	(0.06	)	$	0.82	$	0.05		$	0.13
	Diluted earnings (loss) per common share(2)
	Income (loss) from continuing operations		$	(0.19	)	$	0.78	$	(0.03	)	$	0.23
	Income (loss) from discontinued operations		0.13			0.04		0.08			(0.10		)
	Diluted earnings (loss) per share		$	(0.06	)	$	0.82	$	0.05		$	0.13
			2012 Quarter Ended
			March 31			June 30		September 30			December 31
			(In millions, except per share data)
	Oil, gas and NGL revenues(1)		$	403		$	350	$	371		$	352
	Income (loss) from operations(1)(3)		69			1		19			(1,483		)
	Income (loss) from continuing operations, net of tax		39			64		(82		)	(923		)
	Income (loss) from discontinued operations, net of tax		77			71		49			(479		)
	Net income (loss)		$	116		$	135	$	(33	)	$	(1,402	)
	Basic earnings (loss) per common share(2)
	Income (loss) from continuing operations		$	0.29		$	0.47	$	(0.61	)	$	(6.86	)
	Income (loss) from discontinued operations		0.57			0.53		0.37			(3.53		)
	Basic earnings (loss) per share		$	0.86		$	1	$	(0.24	)	$	(10.39	)
	Diluted earnings (loss) per common share(2)
	Income (loss) from continuing operations		$	0.29		$	0.47	$	(0.61	)	$	(6.86	)
	Income (loss) from discontinued operations		0.57			0.53		0.37			(3.53		)
	Diluted earnings (loss) per share		$	0.86		$	1	$	(0.24	)	$	(10.39	)
	_________________
	-1	Oil, gas and NGL revenues and Income (loss) from operations are specific to our continuing operations.
	-2	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.
	-3	Income (loss) from operations for the fourth quarter of 2012 includes a full cost ceiling test writedown of $1.5 billion.

Supplementary_Oil_and_Gas_Disc

Supplementary Oil and Gas Disclosure	12 Months Ended
	Dec. 31, 2013
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 respective years.
			Continuing Operations				Discontinued Operations
			Domestic				Malaysia				China			Total
			(In millions)
	Year Ended December 31, 2013
	Revenues		$	1,777			$	822			$	69		$	2,668
	Production costs		265				117				8			390
	Production taxes and other operating expenses		204				272				12			488
	Depreciation, depletion and amortization		668				244				18			930
	Income taxes		224				72				8			304
	Results of operations for oil and gas producing activities		$	416			$	117			$	23		$	556
	Year Ended December 31, 2012
	Revenues		$	1,469			$	1,005			$	86		$	2,560
	Production costs		292				101				7			400
	Production taxes and other operating expenses		174				259				18			451
	Depreciation, depletion and amortization		683				251				21			955
	Impairment of oil and gas properties		1,488				—				—			1,488
	Income taxes		(410		)		150				10			(250		)
	Results of operations for oil and gas producing activities		$	(758	)		$	244			$	30		$	(484	)
	Year Ended December 31, 2011
	Revenues		$	1,735			$	647			$	82		$	2,464
	Production costs		258				90				5			353
	Production taxes and other operating expenses		161				242				20			423
	Depreciation, depletion and amortization		622				126				19			767
	Income taxes		243				72				10			325
	Results of operations for oil and gas producing activities		$	451			$	117			$	28		$	596
	Costs Incurred
	Costs incurred for oil and gas property acquisitions, exploration and development for each of the years in the three-year period ended December 31, 2013 are as follows:
			Continuing Operations				Discontinued Operations
			Domestic				Malaysia				China			Total
			(In millions)
	2013:00:00
	Property acquisitions:
	Unproved		$	154			$	—			$	—		$	154
	Proved		8				—				1			9
	Exploration(1)		966				101				33			1,100
	Development(2)		691				211				140			1,042
	Total costs incurred(3)		$	1,819			$	312			$	174		$	2,305
	2012:00:00
	Property acquisitions:
	Unproved		$	64			$	—			$	—		$	64
	Proved		3				—				—			3
	Exploration(1)		929				63				1			993
	Development(2)		659				108				86			853
	Total costs incurred(3)		$	1,655			$	171			$	87		$	1,913
	2011:00:00
	Property acquisitions:
	Unproved		$	361			$	—			$	—		$	361
	Proved		72				19				—			91
	Exploration(1)		980				9				25			1,014
	Development(2)		795				279				31			1,105
	Total costs incurred(3)		$	2,208			$	307			$	56		$	2,571
	_________________
	-1	Includes $250 million, $239 million and $237 million of domestic costs for non-exploitation activities for 2013, 2012 and 2011, respectively; $75 million, $63 million and $9 million of Malaysia costs for non-exploitation activities for 2013, 2012 and 2011, respectively; and $33 million, $1 million and $25 million of China costs for non-exploitation activities for 2013, 2012 and 2011, respectively.
	-2	Includes $121 million, $9 million and $33 million for 2013, 2012 and 2011, respectively, of asset retirement costs.
	-3	Other items impacting the capitalized costs of our oil and gas properties which are not included in total costs incurred are as follows:
			2013				2012				2011
			(In millions)
	Property sales — Domestic		$	23			$	606			$	434
	Ceiling test writedown — Domestic		—				1,488				—
			$	23			$	2,094			$	434
	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 three-year period ended December 31, 2013:
		Continuing Operations				Discontinued Operations
		Domestic				Malaysia				China			Total
		(In millions)
December 31, 2013:
Proved properties		$	13,185			$	1,441			$	550		$	15,176
Unproved properties		1,116				115				—			1,231
		14,301				1,556				550			16,407
Accumulated depreciation, depletion and amortization		(7,185		)		(1,009		)		(112		)	(8,306		)
Net capitalized costs		$	7,116			$	547			$	438		$	8,101
December 31, 2012:
Proved properties		$	11,221			$	1,140			$	375		$	12,736
Unproved properties		1,291				104				1			1,396
		12,512				1,244				376			14,132
Accumulated depreciation, depletion and amortization		(6,535		)		(747		)		(96		)	(7,378		)
Net capitalized costs		$	5,977			$	497			$	280		$	6,754
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 20 years of experience in reserve estimation). For additional information regarding our reserves estimation process, please see Items 1 and 2, “Business and Properties — Reserves.”
Reserves Activity Overview.    The following is a discussion of our proved reserves and reserve additions and revisions.
		Year Ended December 31,
		2013			2012			2011
		(MMBOE)
Proved Reserves:
Beginning of year		566			652			619
Reserve additions		82			86			151
Reserve revisions		14			(91	)		(48	)
Sales		(1	)		(30	)		(20	)
Production		(49	)		(51	)		(50	)
End of year		612			566			652
Our proved crude oil and condensate reserves at year-end 2013 were 270 million barrels compared to 237 million barrels and 247 million barrels at year-end 2012 and 2011, respectively. Our proved NGL reserves at year-end 2013 were 68 million barrels compared to 37 million barrels and 16 million barrels at year-end 2012 and 2011, respectively. Our proved natural gas reserves at year-end 2013 were 1.6 Tcf compared to 1.8 Tcf and 2.3 Tcf year-end 2012 and 2011, respectively. Liquids comprised about 55%, 48% and 40% of our proved reserves at year-end 2013, 2012 and 2011, respectively.
Reserve Additions and Revisions.    During 2013, our proved reserves increased 96 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 80 MMBOE of proved reserves through discoveries, extensions and other additions, and 2 MMBOE through purchases. Drilling additions related to our domestic resource plays constituted 98% of our additions. Of the drilling additions, 54 MMBOE were proved undeveloped additions and 17 million barrels were proved developed liquids reserves.
Revisions.    Total proved reserve revisions in 2013 were a positive 14 MMBOE or 2% of the beginning of year proved reserves. They included a positive 10 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 2013, our revisions associated with the development of existing fields were a positive 75 MMBOE. Our focus on developing our liquids assets resulted in the removal of 294 Bcf (49 MMBOE) of gas reserves because they will not be converted to developed status in the next five years. The remaining revisions are associated with development plan changes and well performance. In the Uinta Basin, a change to the gas and projected NGL yield resulted in a negative 14 MMBOE performance revision.
Sales.    In 2013, we sold 1 MMBOE of proved reserves associated with non-strategic assets and acreage trades. In 2012, we sold 30 MMBOE of proved reserves associated with non-strategic assets.
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, 2010, 2011, 2012 and 2013 and the changes in our total net proved reserves during the three-year period ended December 31, 2013:
		Crude Oil											Natural Gas (Bcf)
		and Condensate (MMBbls)
		Continuing Operations			Discontinued Operations								Continuing Operations			Discontinued Operations
		Domestic			Malaysia(1)			China(1)			Total		Domestic			Malaysia(1)		China(1)		Total
Proved developed and undeveloped reserves as of:
31-Dec-10		164			28			6			198		2,492			—		—		2,492
Revisions of previous estimates		(24	)		(2	)		—			(26	)	(175	)		—		—		(175	)
Extensions, discoveries and other additions		73			3			15			91		276			4		—		280
Purchases of properties		7			—			—			7		9			—		—		9
Sales of properties		(5	)		—			—			(5	)	(91	)		—		—		(91	)
Production		(11	)		(6	)		(1	)		(18	)	(182	)		—		—		(182	)
31-Dec-11		204			23			20			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	)		(10	)		(1	)		(22	)	(151	)		(2	)	—		(153	)
31-Dec-12		203			15			19			237		1,755			—		—		1,755
Revisions of previous estimates		19			2			7			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	)		(8	)		(1	)		(23	)	(124	)		—		—		(124	)
31-Dec-13		234			11			25			270		1,648			—		—		1,648
Proved developed reserves as of:
31-Dec-10		87			15			5			107		1,505			—		—		1,505
31-Dec-11		88			17			5			110		1,405			4		—		1,409
31-Dec-12		92			14			4			110		1,042			—		—		1,042
31-Dec-13		112			11			4			127		1,055			—		—		1,055
Proved undeveloped reserves as of:
31-Dec-10		77			13			1			91		987			—		—		987
31-Dec-11		116			6			15			137		924			—		—		924
31-Dec-12		111			1			15			127		713			—		—		713
31-Dec-13		122			—			21			143		593			—		—		593
_________________
-1	All of our reserves in Malaysia and China are associated with production sharing contracts and are calculated using the economic interest method.
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			Malaysia(1)			China(1)			Total		Domestic			Malaysia(1)		China(1)		Total
Proved developed and undeveloped reserves as of:
31-Dec-10		6			—			—			6		585			28		6		619
Revisions of previous estimates		7			—			—			7		(46	)		(2	)	—		(48	)
Extensions, discoveries and other additions		5			—			—			5		123			4		15		142
Purchases of properties		—			—			—			—		9			—		—		9
Sales of properties		—			—			—			—		(20	)		—		—		(20	)
Production		(2	)		—			—			(2	)	(43	)		(6	)	(1	)	(50	)
31-Dec-11		16			—			—			16		608			24		20		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	)		(10	)	(1	)	(51	)
31-Dec-12		37			—			—			37		532			15		19		566
Revisions of previous estimates		14			—			—			14		5			2		7		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	)		(8	)	(1	)	(49	)
31-Dec-13		68			—			—			68		576			11		25		612
Proved developed reserves as of:
31-Dec-10		3			—			—			3		341			15		5		361
31-Dec-11		10			—			—			10		332			18		5		355
31-Dec-12		15			—			—			15		280			14		4		298
31-Dec-13		35			—			—			35		322			11		4		337
Proved undeveloped reserves as of:
31-Dec-10		3			—			—			3		244			13		1		258
31-Dec-11		6			—			—			6		276			6		15		297
31-Dec-12		22			—			—			22		252			1		15		268
31-Dec-13		33			—			—			33		254			—		21		275
_________________
-1	All of our reserves in Malaysia and China are associated with production sharing contracts and are calculated using the economic interest method.
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				Malaysia				China			Total
		(In millions)
2013:00:00
Future cash inflows		$	26,600			$	1,245			$	2,640		$	30,485
Less related future:
Production costs		(8,302		)		(771		)		(959		)	(10,032		)
Development and abandonment costs		(4,166		)		(148		)		(143		)	(4,457		)
Future net cash flows before income taxes		14,132				326				1,538			15,996
Future income tax expense		(4,278		)		—				(316		)	(4,594		)
Future net cash flows before 10% discount		9,854				326				1,222			11,402
10% annual discount for estimating timing of cash flows		(5,226		)		(23		)		(320		)	(5,569		)
Standardized measure of discounted future net cash flows		$	4,628			$	303			$	902		$	5,833
2012:00:00
Future cash inflows		$	21,724			$	1,754			$	2,186		$	25,664
Less related future:
Production costs		(7,042		)		(1,135		)		(888		)	(9,065		)
Development and abandonment costs		(3,949		)		(82		)		(202		)	(4,233		)
Future net cash flows before income taxes		10,733				537				1,096			12,366
Future income tax expense		(2,786		)		(66		)		(239		)	(3,091		)
Future net cash flows before 10% discount		7,947				471				857			9,275
10% annual discount for estimating timing of cash flows		(4,539		)		(55		)		(245		)	(4,839		)
Standardized measure of discounted future net cash flows		$	3,408			$	416			$	612		$	4,436
2011:00:00
Future cash inflows		$	26,241			$	2,751			$	2,213		$	31,205
Less related future:
Production costs		(6,523		)		(1,563		)		(850		)	(8,936		)
Development and abandonment costs		(4,246		)		(161		)		(228		)	(4,635		)
Future net cash flows before income taxes		15,472				1,027				1,135			17,634
Future income tax expense		(4,344		)		(210		)		(268		)	(4,822		)
Future net cash flows before 10% discount		11,128				817				867			12,812
10% annual discount for estimating timing of cash flows		(6,404		)		(125		)		(302		)	(6,831		)
Standardized measure of discounted future net cash flows		$	4,724			$	692			$	565		$	5,981
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, 2013:
		Continuing Operations				Discontinued Operations
		Domestic				Malaysia				China			Total
		(In millions)
2013:00:00
Beginning of the period		$	3,408			$	416			$	612		$	4,436
Revisions of previous estimates:
Changes in prices and costs		944				33				2			979
Changes in quantities		81				76				302			459
Changes in future development costs		(83		)		(126		)		(50		)	(259		)
Previously estimated development costs incurred during the period		549				79				130			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				33				82			585
Sales of oil and gas, net of production costs		(973		)		(330		)		(46		)	(1,349		)
Net change in income taxes		(815		)		59				(63		)	(819		)
Production timing and other		22				14				(67		)	(31		)
Net increase (decrease)		1,220				(113		)		290			1,397
End of period		$	4,628			$	303			$	902		$	5,833
2012:00:00
Beginning of the period		$	4,724			$	692			$	565		$	5,981
Revisions of previous estimates:
Changes in prices and costs		(1,490		)		(14		)		(24		)	(1,528		)
Changes in quantities		(427		)		23				—			(404		)
Changes in future development costs		294				(19		)		(2		)	273
Previously estimated development costs incurred during the period		434				93				67			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				64				77			683
Sales of oil and gas, net of production costs		(1,129		)		(439		)		(63		)	(1,631		)
Net change in income taxes		650				119				4			773
Production timing and other		(223		)		(103		)		(36		)	(362		)
Net increase (decrease)		(1,316		)		(276		)		47			(1,545		)
End of period		$	3,408			$	416			$	612		$	4,436
2011:00:00
Beginning of the period		$	4,058			$	557			$	139		$	4,754
Revisions of previous estimates:
Changes in prices and costs		728				191				83			1,002
Changes in quantities		(829		)		(60		)		(7		)	(896		)
Changes in future development costs		(31		)		(110		)		—			(141		)
Previously estimated development costs incurred during the period		499				188				13			700
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs		1,366				101				497			1,964
Purchases and sales of reserves in place, net		(93		)		—				—			(93		)
Accretion of discount		591				71				17			679
Sales of oil and gas, net of production costs		(1,048		)		(197		)		(36		)	(1,281		)
Net change in income taxes		(222		)		(26		)		(141		)	(389		)
Production timing and other		(295		)		(23		)		—			(318		)
Net increase		666				135				426			1,227
End of period		$	4,724			$	692			$	565		$	5,981

Organization_and_Summary_of_Si1

Organization and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
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 areas of operation include the Mid-Continent, the Rocky Mountains and the onshore Gulf Coast regions of North America.
	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. Accordingly, the results of our international 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. For information regarding the sale of our Malaysia business, see Note 17, "Subsequent Events." These financial statements and notes are inclusive of our international operations unless otherwise noted.
Dependence on Oil and Gas Prices	'
	Dependence on Commodity Prices
	As an independent oil and natural gas producer, our revenue, profitability and future rate of growth are substantially dependent on prevailing prices for oil, natural gas and NGLs. Historically, the energy markets have been very volatile, and there can be no assurance that commodity prices will not be subject to wide fluctuations in the future. A substantial or extended decline in commodity prices could have a material adverse effect on our financial position, results of operations, cash flows, access to capital and on the quantities of oil, natural gas and NGL reserves that we can economically produce.
Use of Estimates	'
	Use of Estimates
	The preparation of financial statements in accordance with accounting principles generally accepted in the United States of America requires our management to make estimates and assumptions that affect the reported amounts of assets and liabilities; disclosure of contingent assets and liabilities at the date of the financial statements; the reported amounts of revenues and expenses during the reporting period; and the quantities and values of proved oil, natural gas and NGL reserves used in calculating depletion and assessing impairment of our oil and gas properties. Actual results could differ significantly from these estimates. Our most significant financial estimates are associated with our estimated proved oil, natural gas and NGL reserves and the fair value of our derivative positions.
Reclassifications	'
	Reclassifications and Out-of-Period Adjustments
	Certain reclassifications have been made to prior years’ reported amounts in order to conform to the current year presentation. These reclassifications, including those related to our discontinued operations disclosed in Note 3, "Discontinued Operations," did not impact our net income (loss), stockholders’ equity or cash flows.
	The Company's production and other taxes for continuing operations for the year ended December 31, 2013, were reduced by approximately $8 million in the fourth quarter due to a prior period adjustment related to our 2012 and prior ad valorem tax accrual to reflect the actual amounts payable at December 31, 2013. The Company's general and administrative expenses for the year ended December 31, 2013, were reduced by approximately $8 million due to a prior period adjustment related to our 2012 bonus accrual to reflect actual amounts approved and paid in the first quarter of 2013. The Company’s discontinued operations deferred tax expense for the year ended December 31, 2013 was increased by approximately $15 million due to prior period adjustments related to our 2012 repatriation of international earnings and a valuation allowance on a Malaysian deferred tax asset. The Company believes these correcting adjustments in the fourth quarter of 2013 were not material to its prior consolidated financial statements or its quarterly or annual results for the period ended December 31, 2013.
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. 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 all of 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 2013 on the pending sale of our Malaysian business. Amounts are contractually restricted until the transaction closes. See Note 17, "Subsequent Events," for further discussion about the close of the sale of the Malaysian business in early February 2014.
Investments	'
	Investments
	Investments consist of debt and equity securities, as well as auction rate 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 as a separate component within the consolidated statement of comprehensive income. 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. We realized interest income and net gains on our investment securities in 2013, 2012 and 2011 of $3 million, $3 million and $2 million, respectively.
Allowance for Doubtful Accounts	'
	Allowance for Doubtful Accounts
	We routinely assess the recoverability of all 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 offshore operations in Malaysia and China. See Note 3, "Discontinued Operations" for details on our international crude oil inventory. Tubular goods and well equipment inventories are carried at the lower of cost or market. At December 31, 2012, we wrote down subsea wellhead inventory that was not included in the sale of our Gulf of Mexico assets. The writedown of $8 million is included in “Operating expenses — Other” on our consolidated statement of operations.
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 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 $145 million, $123 million and $113 million of internal costs in 2013, 2012 and 2011, respectively. Interest expense related to unproved properties also is capitalized into oil and gas properties.
	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.
	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, adjusted for market differentials (SEC pricing), applicable to our reserves (including the effects of hedging contracts that are designated for hedge accounting, if any); plus
	•	the cost 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, 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 ceiling with respect to our domestic full cost pool exceeded the net capitalized costs. As such, no ceiling test writedown was required at December 31, 2013. If there are declines in SEC pricing of oil and natural gas subsequent to December 31, 2013, we may be required to record a ceiling test writedown in future periods.
	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).
	At December 31, 2011, the ceiling value of our reserves was calculated based upon SEC pricing of $4.12 per MMBtu for natural gas and $96.13 per barrel for oil. Using these prices, the cost center ceiling with respect to our domestic full cost pool exceeded the net capitalized costs. As such, no ceiling test writedown was required at December 31, 2011.
	See Note 4, “Oil and Gas Assets,” for a detailed discussion regarding our acquisition and sales transactions during 2013, 2012 and 2011.
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.
Segment Reporting, Policy [Policy Text Block]	'
	Segment Reporting
	Our continuing operations are comprised of a single business segment, the domestic exploration, development and production of oil and natural gas. Prior to classifying our international businesses as held-for-sale and discontinued operations, we reported business segments for Malaysia and China.
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 ARO to purchasers of our divested properties.
	In general, the amount of an ARO and the costs capitalized will equal the estimated future cost 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:
			2013			2012			2011
			(In millions)
	Balance at January 1		$	100		$	106		$	96
	Accretion expense		8			8			8
	Additions		12			20			5
	Revisions		8			12			3
	Settlements(1)		(8		)	(46		)	(6		)
	Balance at December 31		120			100			106
	Less: Current portion of ARO at December 31		(5		)	(5		)	(4		)
	Total long-term ARO at December 31		$	115		$	95		$	102
	_________________
	-1	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 14, “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, 2013, we did not have a liability for uncertain tax positions, and as such, we did not accrue related interest or penalties. The tax years 2010-2013 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-based compensation 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 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 partners 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. Historically, we have sold our oil, gas and NGLs to several purchasers.
	All of our hedging transactions have been carried out in the over-the-counter market. The use of hedging transactions involves the risk that the counterparties will be unable to meet the financial terms of such transactions. The counterparties for all of our hedging 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 hedging 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 hedging 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, 2013, nine of our 15 counterparties accounted for approximately 85% of our estimated future hedged production, with no single counterparty accounting for more than 15% of that production. A portion of our 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
	Sunoco Logistics Partners Operations GP LLC, Royal Dutch Shell plc and Tesoro Corporation accounted for 13%, 12% and 11% respectively, of our total revenues in 2013. During 2012, Royal Dutch Shell plc, Tesoro Corporation and Big West Oil LLC accounted for 14%, 14% and 10%, respectively, of our total revenues. During 2011, sales of our oil and gas production to Royal Dutch Shell plc and Tesoro Corporation accounted for 12% and 11%, respectively, of our total revenues. We believe that the loss of Sunoco Logistics Partners Operations GP LLC or Royal Dutch Shell plc would not have a material adverse effect on us because alternative purchasers are readily available. An extended loss of Tesoro Corporation or any of our other large purchasers of our Monument Butte field oil production could have a material adverse effect on us because there are limited purchasers of the black and yellow wax crude oil, which we produce from this field. Due to the higher paraffin content of this production, it must remain heated during shipping, so it cannot be transported in conventional pipelines, and there is limited refining capacity for it in the vicinity of our production. In poor economic environments and tight financial markets, there is an increased risk that the current purchasers of our production may fail to satisfy their obligations to us under our crude oil purchase contracts. We cannot guarantee that we will be able to continue to sell to these purchasers or that similar substitute arrangements could be made for sales of our black and yellow wax crude oil with other purchasers if desired.
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 all of the derivative instruments that we utilize are 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. We periodically utilize derivatives to manage our exposure to variable interest rates.
	The related cash flow impact of our derivative activities are reflected as cash flows from operating 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 will likely sell the securities for a loss during 2014. As a result, the losses previously accumulated in AOCI related to these securities have been transferred and recognized in the consolidated statement of operations for the year ended December 31, 2013. 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, 2011		$	(12	)	$	—		$	(12	)
	Current period other comprehensive income (loss)		3			(1		)	2
	Balance at December 31, 2011		(9		)	(1		)	(10		)
	Current period other comprehensive income (loss)		3			—			3
	Balance at December 31, 2012		(6		)	(1		)	(7		)
	Other comprehensive income (loss) 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
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 February 2013, the FASB issued guidance regarding the reporting of amounts reclassified out of accumulated other comprehensive income. The guidance is effective for interim and annual periods beginning after December 15, 2012. We adopted the guidance in the quarter ended March 31, 2013. Adoption of the new reporting guidance did not have a material impact on our financial position or results of operations.
	In December 2011, the FASB issued guidance regarding the disclosure of offsetting assets and liabilities. The guidance requires disclosure of gross information and net information about instruments and transactions eligible for offset arrangement. The guidance is effective for interim and annual periods beginning on or after January 1, 2013. We adopted the guidance in the quarter ended March 31, 2013. Adoption of the additional disclosures regarding offsetting assets and liabilities did not have a material impact on our financial position or results of operations.

Organization_and_Summary_of_Si2

Organization and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
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:
			2013			2012			2011
			(In millions)
	Balance at January 1		$	100		$	106		$	96
	Accretion expense		8			8			8
	Additions		12			20			5
	Revisions		8			12			3
	Settlements(1)		(8		)	(46		)	(6		)
	Balance at December 31		120			100			106
	Less: Current portion of ARO at December 31		(5		)	(5		)	(4		)
	Total long-term ARO at December 31		$	115		$	95		$	102
	_________________
	-1	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, 2011		$	(12	)	$	—		$	(12	)
	Current period other comprehensive income (loss)		3			(1		)	2
	Balance at December 31, 2011		(9		)	(1		)	(10		)
	Current period other comprehensive income (loss)		3			—			3
	Balance at December 31, 2012		(6		)	(1		)	(7		)
	Other comprehensive income (loss) 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

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2013
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:
			2013			2012			2011
			(In millions, except per share data)
	Income (numerator):
	Income (loss) from continuing operations		$	108		$	(902	)	$	401
	Income (loss) from discontinued operations, net of tax		39			(282		)	138
	Net income (loss)		147			(1,184		)	539
	Repurchase of preferred shares of subsidiary (3)		(20		)	—			—
	Net income (loss) attributable to common shareholders		$	127		$	(1,184	)	$	539
	Weighted-average shares (denominator):
	Weighted-average shares — basic		135			135			134
	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		136			135			135
	Earnings (loss) per share:
	Basic:
	Income (loss) from continuing operations		$	0.8		$	(6.70	)	$	3
	Income (loss) from discontinued operations before preferred share repurchase		0.29			(2.10		)	1.03
	Repurchase of preferred shares of subsidiary (3)		(0.15		)	—			—
	Income (loss) from discontinued operations		0.14			(2.10		)	1.03
	Basic earnings (loss) per share		$	0.94		$	(8.80	)	$	4.03
	Diluted:
	Income (loss) from continuing operations		$	0.8		$	(6.70	)	$	2.97
	Income (loss) from discontinued operations before preferred share repurchase		0.29			(2.10		)	1.02
	Repurchase of preferred shares of subsidiary (3)		(0.15		)	—			—
	Income (loss) from discontinued operations		0.14			(2.10		)	1.02
	Diluted earnings (loss) per share		$	0.94		$	(8.80	)	$	3.99
	_________________
	-1	Excludes 4.0 million and 1.4 million shares of unvested restricted stock or restricted stock units and stock options for the years ended December 31, 2013 and 2011, 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 discontinued operations. See Note 16, "Related Party Transaction," for additional information.

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2013
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,
		2013			2012			2011
		(In millions)
	Oil and gas revenues (1)	$	891		$	1,092		$	729
	Operating expenses	689			664			508
	Income from discontinued operations	202			428			221
	Other income (expense)	4			(3		)	—
	Income from discontinued operations before income taxes	206			425			221
	Income tax provision (benefit):
	Current	90			193			76
	Deferred	77			514			7
	Total income tax provision (benefit)	167			707			83
	Income (loss) from discontinued operations, net of tax	$	39		$	(282	)	$	138
Schedule of Disposal Groups, Including Discontinued Operations, Balance Sheet [Table Text Block]	'
		December 31,
		2013			2012
		(In millions)
	Current assets:
	Cash and cash equivalents	$	84		$	76
	Accounts receivable	200			207
	Inventories	130			91
	Other current assets	33			31
	Total current assets	447			405
	Noncurrent assets:
	Oil and gas properties, net of accumulated depreciation, depletion and amortization of $1,121 and $843 as of December 31, 2013 and 2012, respectively	989			781
	Deferred taxes	19			24
	Other assets	4			4
	Total noncurrent assets	1,012			809
	Total assets	$	1,459		$	1,214
	Current liabilities:
	Accounts payable	$	38		$	50
	Accrued liabilities	324			269
	Asset retirement obligations	49			5
	Other current liabilities	18			16
	Total current liabilities	429			340
	Noncurrent liabilities:
	Asset retirement obligations	86			37
	Deferred taxes	129			41
	Other liabilities	11			24
	Total noncurrent liabilities	226			102
	Total liabilities	$	655		$	442
ScheduleOfChangeInAssetRetirementObligationDiscontinued [Table Text Block]	'
	The change in our ARO for discontinued operations for each of the three years ended December 31, is set forth below:
		2013			2012			2011
		(In millions)
	Balance at January 1	$	42		$	39		$	12
	Accretion expense	3			3			2
	Additions	4			4			29
	Revisions	101			—			—
	Settlements	(15		)	(4		)	(4		)
	Balance at December 31	135			42			39
	Less: Current portion of ARO at December 31	(49		)	(5		)	(6		)
	Total long-term ARO at December 31	$	86		$	37		$	33

Oil_and_Gas_Assets_Tables

Oil and Gas Assets (Tables)	12 Months Ended
	Dec. 31, 2013
Oil and Gas Property [Abstract]	'
Costs incurred by year for oil and gas properties not subject to amortization	'
		Costs Incurred In
		2013			2012			2011		2010 and Prior		Total
		(In millions)
	Acquisition costs	$	206		$	114		$	188	$	300	$	808
	Exploration costs	175			21			9		35		240
	Development costs	13			31			25		—		69
	Fee mineral interests	1			—			—		23		24
	Capitalized interest	53			68			38		—		159
	Total oil and gas properties not subject to amortization	$	448		$	234		$	260	$	358	$	1,300
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:
		2013			2012
		(In millions)
	Oil and gas properties:
	Subject to amortization	$	15,107		$	12,647
	Not subject to amortization	1,300			1,485
	Gross oil and gas properties	16,407			14,132
	Accumulated depreciation, depletion and amortization	(8,306		)	(7,378		)
	Net oil and gas properties	8,101			6,754
	Other property and equipment:
	Furniture, fixtures and equipment	139			141
	Gathering systems and equipment	104			73
	Accumulated depreciation and amortization	(69		)	(66		)
	Net other property and equipment	174			148
	Total property and equipment, net	$	8,275		$	6,902

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedges, Assets [Abstract]	'
Outstanding contracts that are not designated for hedge accounting	'
	At December 31, 2013, we had outstanding positions with respect to our future production 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)
		January 2014 — March 2014
		Fixed-price swaps		21,150			$	3.98			—			—			—				$	(6	)
		Collars		5,850			—				—			$	3.75		$	4.62			(1		)
		April 2014 — June 2014
		Fixed-price swaps		21,385			3.98				—			—			—				(3		)
		Collars		5,915			—				—			3.75			4.62				—
		July 2014 — September 2014
		Fixed-price swaps		21,620			3.98				—			—			—				(4		)
		Collars		5,980			—				—			3.75			4.62				—
		October 2014 — December 2014
		Fixed-price swaps		21,620			3.98				—			—			—				(5		)
		Collars		5,980			—				—			3.75			4.62				(1		)
		January 2015 — December 2015
		Fixed-price swaps		49,275			4.28				—			—			—				7
		Collars		38,325			—				—			3.93			4.74				2
																					$	(11	)
	Crude Oil
	Period and Type of Instrument		Volume in MBbls			NYMEX Contract Price Per Bbl															Estimated
																					Fair Value
														Collars							Asset
						Swaps				Sold Puts (Weighted				Floors (Weighted			Ceilings (Weighted				(Liability)
						(Weighted				Average)				Average)			Average)
						Average)
																					(In millions)
	January 2014 — March 2014
	Fixed-price swaps		1,350			$	89.6			—				—			—				$	(12	)
	Fixed-price swaps with sold puts		1,440			95.16				$	75			—			—				(4		)
	Collars with sold puts		540			—				75.83				$	90.83		$	102.93			(1		)
	April 2014 — June 2014
	Fixed-price swaps		1,729			90.07				—				—			—				(12		)
	Fixed-price swaps with sold puts		1,456			95.16				75				—			—				(3		)
	Collars with sold puts		546			—				75.83				90.83			102.93				—
	July 2014 — September 2014
	Fixed-price swaps		1,932			89.86				—				—			—				(9		)
	Fixed-price swaps with sold puts		1,472			95.16				75				—			—				—
	Collars with sold puts		552			—				75.83				90.83			102.93				1
	October 2014 — December 2014
	Fixed-price swaps		2,116			89.95				—				—			—				(5		)
	Fixed-price swaps with sold puts		1,472			95.16				75				—			—				2
	Collars with sold puts		552			—				75.83				90.83			102.93				1
	January 2015 — December 2015
	Fixed-price swaps		6,567			90.39				—				—			—				14
	Fixed-price swaps with sold puts		4,567			90.03				68.2				—			—				3
																					$	(25	)
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-13		(In millions)															(In millions)
	Natural gas positions		$	11			$	(2	)		$	—			$	9		$	(22	)		$	2	$	(20	)	$	—
	Oil positions		26				(9		)		—				17			(51		)		9		(42		)	—
	Total		$	37			$	(11	)		$	—			$	26		$	(73	)		$	11	$	(62	)	$	—
	31-Dec-12
	Natural gas positions		$	86			$	(5	)		$	79			$	2		$	(16	)		$	5	$	(4	)	$	(7	)
	Oil positions		77				(16		)		46				15			(26		)		16		(2		)	(8		)
	Total		$	163			$	(21	)		$	125			$	17		$	(42	)		$	21	$	(6	)	$	(15	)
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 was as follows:
			2013				2012				2011
			(In millions)
	Derivatives not designated as hedging instruments:
	Realized gain (loss) on natural gas positions		$	66			$	144			$	249
	Realized gain (loss) on oil positions		(6		)		1				(47		)
	Realized gain (loss) on basis positions		—				(10		)		(7		)
	Total realized gain(1)		60				135				195
	Unrealized gain (loss) on natural gas positions		(81		)		(124		)		(48		)
	Unrealized gain (loss) on oil positions		(76		)		99				47
	Unrealized gain (loss) on basis positions		—				10				1
	Total unrealized loss		(157		)		(15		)		—
	Total		$	(97	)		$	120			$	195
	________
	-1	The total realized gain on commodity derivatives may differ from the cash receipts on derivative settlements as a result of the receipt or payment of premiums, or due to the recognition of premiums previously received associated with derivatives settled during the period.

Accounts_Receivable_Tables

Accounts Receivable (Tables)	12 Months Ended
	Dec. 31, 2013
Accounts Receivable, Net, Current [Abstract]	'
Accounts Receivable	'
	Accounts receivable consisted of the following at December 31:
		2013			2012
		(In millions)
	Revenue	$	294		$	291
	Joint interest	156			154
	Other	25			8
	Reserve for doubtful accounts	(1		)	(1		)
	Total accounts receivable	$	474		$	452

Accrued_Liabilities_Tables

Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2013
Accrued Liabilities, Current [Abstract]	'
Accrued Liabilities	'
	Accrued liabilities consisted of the following at December 31:
		2013		2012
		(In millions)
	Revenue payable	$	175	$	95
	Accrued capital costs	458		355
	Accrued lease operating expenses	71		95
	Employee incentive expense	51		50
	Accrued interest on debt	72		43
	Taxes payable	93		108
	Other	58		55
	Total accrued liabilities	$	978	$	801

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2013
Table Text Block Supplement [Abstract]	'
Fair value by measurement classification and type Table	'
	The following table summarizes the valuation of our financial assets (liabilities) of our continuing operations by measurement levels:
		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, 2012:
	Money market fund investments	$	22		$	—		$	—			$	22
	Deferred compensation plan assets	6			—			—				6
	Investments available-for-sale:
	Equity securities	7			—			—				7
	Auction rate securities	—			—			36				36
	Oil and gas derivative swap contracts	—			6			—				6
	Oil and gas derivative option contracts	—			—			115				115
	Stock-based compensation liability awards	(2		)	—			—				(2		)
	Total	$	33		$	6		$	151			$	190
	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 contracts	—			—			(8		)		(8		)
	Stock-based compensation liability awards	(11		)	—			(5		)		(16		)
	Total	$	7		$	(28	)	$	26			$	5
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, 2011	$	30		$	48		$	—			$	78
	Total realized or unrealized gains (losses):
	Included in earnings	—			87			—				87
	Included in other comprehensive income (loss)	4			—			—				4
	Purchases, issuances and settlements:
	Settlements	(2		)	(64		)	—				(66		)
	Transfers in and out of Level 3	—			—			—				—
	Balance at December 31, 2011	$	32		$	71		$	—			$	103
	Change in unrealized gains or losses included in earnings relating to	$	—		$	56		$	—			$	56
	Level 3 assets and liabilities still held at December 31, 2011
	Balance at January 1, 2012	$	32		$	71		$	—			$	103
	Total realized or unrealized gains (losses):
	Included in earnings	—			135			—				135
	Included in other comprehensive income (loss)	4			—			—				4
	Purchases, issuances and settlements:
	Settlements	—			(91		)	—				(91		)
	Transfers in and 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 assets and liabilities still held at December 31, 2012
	Balance at January 1, 2013	$	36		$	115		$	—			$	151
	Total realized or unrealized gains (losses):
	Included in earnings	(6		)	(66		)	(18		)		(90		)
	Included in other comprehensive income (loss)	10			—			—				10
	Purchases, issuances and settlements:
	Settlements	(1		)	(57		)	13				(45		)
	Transfers in and 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 assets and liabilities still held at December 31, 2013
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 positions	$	(9	)	Option model		NYMEX Oil price forward curve	$86.29		—	$98.77
							Oil price volatility curves	14.33	%	—	23.22%
							Credit risk	0.01	%	—	0.89%
	Natural gas option positions	$	1		Option model		NYMEX Natural gas price	$4.01		—	$4.42
							forward curve
							Natural gas price volatility curves	18.74	%	—	50.02%
							Credit risk	0.01	%	—	1.58%
	SVAP	$	(5	)	Monte Carlo		Historical volatility				37.40%
							Implied volatility				41.20%
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:
		2013			2012
		(In millions)
	5¾% Senior Notes due 2022	$	767		$	836
	5⅝% Senior Notes due 2024	1,025			1,074
	7⅛% Senior Subordinated Notes due 2018	624			630
	6⅞% Senior Subordinated Notes due 2020	755			749

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Instruments [Abstract]	'
Debt	'
	At December 31, our debt consisted of the following:
			2013			2012
			(In millions)
	Senior unsecured debt:
	Revolving credit facility — LIBOR based loans		$	585		$	—
	Money market lines of credit(1)		64			—
	Total credit arrangements		649			—
	5¾% Senior Notes due 2022		750			750
	5⅝% Senior Notes due 2024		1,000			1,000
	Total senior unsecured debt		1,750			1,750
	7⅛% Senior Subordinated Notes due 2018		600			600
	6⅞% Senior Subordinated Notes due 2020		700			700
	Discount on notes		(5		)	(5		)
	Total long-term debt		$	3,694		$	3,045
	_________________
	-1	Because capacity under our credit facility was available 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, 2013
Income Tax Disclosure [Abstract]	'
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:
		2013			2012			2011
		(In millions)
	Current taxes:
	U.S. federal	$	(4	)	$	1		$	17
	U.S. state	—			1			—
	Deferred taxes:
	U.S. federal	53			(479		)	171
	U.S. state	13			(34		)	30
	Total provision (benefit) for income taxes	$	62		$	(511	)	$	218
Provision for income taxes using federal statutory rate	'
	The provision for income taxes for each of the indicated years was different than the amount computed using the federal statutory rate (35%) for the following reasons:
		2013			2012			2011
		(In millions)
	Amount computed using the statutory rate	$	60		$	(495	)	$	217
	Increase (decrease) in taxes resulting from:
	State and local income taxes, net of federal effect	8			(18		)	10
	Valuation allowance, state net of federal	(2		)	—			5
	Other	(4		)	2			(14		)
	Total provision (benefit) for income taxes	$	62		$	(511	)	$	218
Components of deferred tax asset and deferred tax liability	'
	At December 31, the components of our deferred tax asset (liability) were as follows:
		2013			2012
		(In millions)
	Deferred tax asset:
	Net operating loss carryforwards	$	335		$	213
	Alternative minimum tax credit	99			103
	Stock-based compensation	25			24
	Marketable securities	3			4
	Oil and gas properties	59			49
	Foreign tax credit	535			421
	Commodity derivatives	13			—
	Other	6			18
	Total deferred tax asset	1,075			832
	Deferred tax asset valuation allowances	(584		)	(457		)
	Net deferred tax asset	491			375
	Deferred tax liability:
	Commodity derivatives	—			(44		)
	Oil and gas properties	(1,592		)	(1,283		)
	Total deferred tax liability	(1,592		)	(1,327		)
	Net deferred tax liability	(1,101		)	(952		)
	Less: Net current deferred tax asset (liability)	22			(42		)
	Net noncurrent deferred tax liability	$	(1,123	)	$	(910	)
Roll forward of deferred tax asset valuation allowance	'
	The change in our deferred tax asset valuation allowance is as follows at December 31:
		2013			2012			2011
		(In millions)
	Balance at the beginning of the year	$	(457	)	$	(11	)	$	(6	)
	Charged to provision for income taxes:
	Malaysia valuation allowance	(15		)	(25		)	—
	Foreign tax credit valuation allowance	(114		)	(421		)	—
	U.S. state net operating loss carryforwards	2			—			(5		)
	Balance at the end of the year	$	(584	)	$	(457	)	$	(11	)

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2013
Share-based Compensation [Abstract]	'
Schedule of Stock Based Compensation Expense Table	'
	For the years ended December 31, our stock-based compensation consisted of the following:
			2013				2012				2011
			(In millions)
	Equity awards		$	48			$	46			$	37
	Liability awards		27				1				3
	Total stock-based compensation		75				47				40
	Capitalized in oil and gas properties		(20		)		(12		)		(11		)
	Net stock-based compensation expense		$	55			$	35			$	29
Stock Option Activity Table	'
	The table below provides information about stock option activity for the following years:
			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 December 31, 2010		1,539			$	34.58							4.7		$	58
	Granted		—			—				$	—
	Exercised		(446	)		29.54										18
	Forfeited		(34	)		46.73
	Outstanding at December 31, 2011		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		$	—
	Exercisable at December 31, 2013		687			$	39.68							1.9		$	—
	_________________
	-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 table below summarizes information about stock options outstanding and exercisable at December 31, 2013:
	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)
	$22.51 to $27.50		93			0.2		$	24.9			93			$	24.9
	27.51 to 35.00		202			0.9		31.03				202			31.03
	35.01 to 41.72		31			1.3		38.33				31			38.33
	41.73 to 48.45		361			3		48.45				361			48.45
			687			1.9		$	39.68			687			$	39.68
Restricted Stock and Restricted Stock Unit Activity Table	'
	The table below provides information about restricted stock and restricted stock unit activity for the following years:
			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, 2011		2,178			316			2,494			$	36.84
	Granted		1,014			130			1,144			64.35
	Forfeited		(233	)		—			(233	)		44.79
	Vested		(836	)		(89	)		(925	)		34.86
	Non-vested shares outstanding at December 31, 2011		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

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Future minimum payments under non-cancellable agreements	'
	As of December 31, 2013, future minimum payments under these non-cancelable agreements are as follows:
		Firm			Operating		Other		Total
		Transportation			Leases
		(In millions)
	Year Ending December 31,
	2014	$	78		$	17	$	61	$	156
	2015	76			18		16		110
	2016	73			15		—		88
	2017	71			15		—		86
	2018	62			14		—		76
	Thereafter	85			36		—		121
	Total minimum future payments	$	445		$	115	$	77	$	637
Oil and gas production volume delivery commitments	'
	As of December 31, 2013, our delivery commitments through 2024 were as follows:
		Natural		Oil(1)
		Gas
	Year Ending December 31,	(MMMBtus)		(MBbls)
	2014	11,250		7,483
	2015	—		7,483
	2016	—		9,190
	2017	—		13,870
	2018	—		13,870
	Thereafter	—		50,748
	Total delivery commitments	11,250		102,644

Supplemental_Cash_Flows_Inform1

Supplemental Cash Flows Information (Tables)	12 Months Ended
	Dec. 31, 2013
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:
		2013			2012			2011
		(In millions)
	Cash Payments:
	Interest payments	$	148		$	137		$	79
	Income tax payments	128			206			70
	Non-cash items excluded from the statement of cash flows:
	(Increase) decrease in receivables for property sales	$	(9	)	$	3		$	28
	(Increase) decrease in accrued capital expenditures	(75		)	(124		)	90
	(Increase) decrease in asset retirement costs	(125		)	(8		)	(33		)
	Increase (decrease) in deferred liabilities	90			—			—

Quarterly_Results_of_Operation1

Quarterly Results of Operations (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of Quarterly Financial Information Table	'
	The results of operations by quarter for the indicated periods are as follows:
			2013 Quarter Ended
			March 31			June 30		September 30			December 31
			(In millions, except per share data)
	Oil, gas and NGL revenues(1)		$	370		$	435	$	486		$	498
	Income (loss) from operations(1)		78			89		131			121
	Income (loss) from continuing operations, net of tax		(25		)	106		(4		)	31
	Income (loss) from discontinued operations, net of tax		17			5		31			(14		)
	Net income (loss)		$	(8	)	$	111	$	27		$	17
	Basic earnings (loss) per common share(2)
	Income (loss) from continuing operations		$	(0.19	)	$	0.78	$	(0.03	)	$	0.23
	Income (loss) from discontinued operations		0.13			0.04		0.08			(0.10		)
	Basic earnings (loss) per share		$	(0.06	)	$	0.82	$	0.05		$	0.13
	Diluted earnings (loss) per common share(2)
	Income (loss) from continuing operations		$	(0.19	)	$	0.78	$	(0.03	)	$	0.23
	Income (loss) from discontinued operations		0.13			0.04		0.08			(0.10		)
	Diluted earnings (loss) per share		$	(0.06	)	$	0.82	$	0.05		$	0.13
			2012 Quarter Ended
			March 31			June 30		September 30			December 31
			(In millions, except per share data)
	Oil, gas and NGL revenues(1)		$	403		$	350	$	371		$	352
	Income (loss) from operations(1)(3)		69			1		19			(1,483		)
	Income (loss) from continuing operations, net of tax		39			64		(82		)	(923		)
	Income (loss) from discontinued operations, net of tax		77			71		49			(479		)
	Net income (loss)		$	116		$	135	$	(33	)	$	(1,402	)
	Basic earnings (loss) per common share(2)
	Income (loss) from continuing operations		$	0.29		$	0.47	$	(0.61	)	$	(6.86	)
	Income (loss) from discontinued operations		0.57			0.53		0.37			(3.53		)
	Basic earnings (loss) per share		$	0.86		$	1	$	(0.24	)	$	(10.39	)
	Diluted earnings (loss) per common share(2)
	Income (loss) from continuing operations		$	0.29		$	0.47	$	(0.61	)	$	(6.86	)
	Income (loss) from discontinued operations		0.57			0.53		0.37			(3.53		)
	Diluted earnings (loss) per share		$	0.86		$	1	$	(0.24	)	$	(10.39	)
	_________________
	-1	Oil, gas and NGL revenues and Income (loss) from operations are specific to our continuing operations.
	-2	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.
	-3	Income (loss) from operations for the fourth quarter of 2012 includes a full cost ceiling test writedown of $1.5 billion.

Supplementary_Oil_and_Gas_Disc1

Supplementary Oil and Gas Disclosure (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Supplementary Oil And Gas Disclosures Tables [Abstract]	'
Total Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities	'
	Costs incurred for oil and gas property acquisitions, exploration and development for each of the years in the three-year period ended December 31, 2013 are as follows:
			Continuing Operations				Discontinued Operations
			Domestic				Malaysia				China			Total
			(In millions)
	2013:00:00
	Property acquisitions:
	Unproved		$	154			$	—			$	—		$	154
	Proved		8				—				1			9
	Exploration(1)		966				101				33			1,100
	Development(2)		691				211				140			1,042
	Total costs incurred(3)		$	1,819			$	312			$	174		$	2,305
	2012:00:00
	Property acquisitions:
	Unproved		$	64			$	—			$	—		$	64
	Proved		3				—				—			3
	Exploration(1)		929				63				1			993
	Development(2)		659				108				86			853
	Total costs incurred(3)		$	1,655			$	171			$	87		$	1,913
	2011:00:00
	Property acquisitions:
	Unproved		$	361			$	—			$	—		$	361
	Proved		72				19				—			91
	Exploration(1)		980				9				25			1,014
	Development(2)		795				279				31			1,105
	Total costs incurred(3)		$	2,208			$	307			$	56		$	2,571
	_________________
	-1	Includes $250 million, $239 million and $237 million of domestic costs for non-exploitation activities for 2013, 2012 and 2011, respectively; $75 million, $63 million and $9 million of Malaysia costs for non-exploitation activities for 2013, 2012 and 2011, respectively; and $33 million, $1 million and $25 million of China costs for non-exploitation activities for 2013, 2012 and 2011, respectively.
	-2	Includes $121 million, $9 million and $33 million for 2013, 2012 and 2011, respectively, of asset retirement costs.
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, 2010, 2011, 2012 and 2013 and the changes in our total net proved reserves during the three-year period ended December 31, 2013:
			Crude Oil											Natural Gas (Bcf)
			and Condensate (MMBbls)
			Continuing Operations			Discontinued Operations								Continuing Operations			Discontinued Operations
			Domestic			Malaysia(1)			China(1)			Total		Domestic			Malaysia(1)		China(1)		Total
	Proved developed and undeveloped reserves as of:
	31-Dec-10		164			28			6			198		2,492			—		—		2,492
	Revisions of previous estimates		(24	)		(2	)		—			(26	)	(175	)		—		—		(175	)
	Extensions, discoveries and other additions		73			3			15			91		276			4		—		280
	Purchases of properties		7			—			—			7		9			—		—		9
	Sales of properties		(5	)		—			—			(5	)	(91	)		—		—		(91	)
	Production		(11	)		(6	)		(1	)		(18	)	(182	)		—		—		(182	)
	31-Dec-11		204			23			20			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	)		(10	)		(1	)		(22	)	(151	)		(2	)	—		(153	)
	31-Dec-12		203			15			19			237		1,755			—		—		1,755
	Revisions of previous estimates		19			2			7			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	)		(8	)		(1	)		(23	)	(124	)		—		—		(124	)
	31-Dec-13		234			11			25			270		1,648			—		—		1,648
	Proved developed reserves as of:
	31-Dec-10		87			15			5			107		1,505			—		—		1,505
	31-Dec-11		88			17			5			110		1,405			4		—		1,409
	31-Dec-12		92			14			4			110		1,042			—		—		1,042
	31-Dec-13		112			11			4			127		1,055			—		—		1,055
	Proved undeveloped reserves as of:
	31-Dec-10		77			13			1			91		987			—		—		987
	31-Dec-11		116			6			15			137		924			—		—		924
	31-Dec-12		111			1			15			127		713			—		—		713
	31-Dec-13		122			—			21			143		593			—		—		593
	_________________
	-1	All of our reserves in Malaysia and China are associated with production sharing contracts and are calculated using the economic interest method.
	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			Malaysia(1)			China(1)			Total		Domestic			Malaysia(1)		China(1)		Total
	Proved developed and undeveloped reserves as of:
	31-Dec-10		6			—			—			6		585			28		6		619
	Revisions of previous estimates		7			—			—			7		(46	)		(2	)	—		(48	)
	Extensions, discoveries and other additions		5			—			—			5		123			4		15		142
	Purchases of properties		—			—			—			—		9			—		—		9
	Sales of properties		—			—			—			—		(20	)		—		—		(20	)
	Production		(2	)		—			—			(2	)	(43	)		(6	)	(1	)	(50	)
	31-Dec-11		16			—			—			16		608			24		20		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	)		(10	)	(1	)	(51	)
	31-Dec-12		37			—			—			37		532			15		19		566
	Revisions of previous estimates		14			—			—			14		5			2		7		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	)		(8	)	(1	)	(49	)
	31-Dec-13		68			—			—			68		576			11		25		612
	Proved developed reserves as of:
	31-Dec-10		3			—			—			3		341			15		5		361
31-Dec-11		10			—			—			10		332			18		5		355
31-Dec-12		15			—			—			15		280			14		4		298
31-Dec-13		35			—			—			35		322			11		4		337
Proved undeveloped reserves as of:
31-Dec-10		3			—			—			3		244			13		1		258
31-Dec-11		6			—			—			6		276			6		15		297
31-Dec-12		22			—			—			22		252			1		15		268
31-Dec-13		33			—			—			33		254			—		21		275
_________________
-1	All of our reserves in Malaysia and China are associated with production sharing contracts and are calculated using the economic interest method.
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, 2013:
			Continuing Operations				Discontinued Operations
			Domestic				Malaysia				China			Total
			(In millions)
	2013:00:00
	Beginning of the period		$	3,408			$	416			$	612		$	4,436
	Revisions of previous estimates:
	Changes in prices and costs		944				33				2			979
	Changes in quantities		81				76				302			459
	Changes in future development costs		(83		)		(126		)		(50		)	(259		)
	Previously estimated development costs incurred during the period		549				79				130			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				33				82			585
	Sales of oil and gas, net of production costs		(973		)		(330		)		(46		)	(1,349		)
	Net change in income taxes		(815		)		59				(63		)	(819		)
	Production timing and other		22				14				(67		)	(31		)
	Net increase (decrease)		1,220				(113		)		290			1,397
	End of period		$	4,628			$	303			$	902		$	5,833
	2012:00:00
	Beginning of the period		$	4,724			$	692			$	565		$	5,981
	Revisions of previous estimates:
	Changes in prices and costs		(1,490		)		(14		)		(24		)	(1,528		)
	Changes in quantities		(427		)		23				—			(404		)
	Changes in future development costs		294				(19		)		(2		)	273
	Previously estimated development costs incurred during the period		434				93				67			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				64				77			683
	Sales of oil and gas, net of production costs		(1,129		)		(439		)		(63		)	(1,631		)
	Net change in income taxes		650				119				4			773
	Production timing and other		(223		)		(103		)		(36		)	(362		)
	Net increase (decrease)		(1,316		)		(276		)		47			(1,545		)
	End of period		$	3,408			$	416			$	612		$	4,436
	2011:00:00
	Beginning of the period		$	4,058			$	557			$	139		$	4,754
	Revisions of previous estimates:
	Changes in prices and costs		728				191				83			1,002
	Changes in quantities		(829		)		(60		)		(7		)	(896		)
	Changes in future development costs		(31		)		(110		)		—			(141		)
	Previously estimated development costs incurred during the period		499				188				13			700
	Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs		1,366				101				497			1,964
	Purchases and sales of reserves in place, net		(93		)		—				—			(93		)
	Accretion of discount		591				71				17			679
	Sales of oil and gas, net of production costs		(1,048		)		(197		)		(36		)	(1,281		)
	Net change in income taxes		(222		)		(26		)		(141		)	(389		)
	Production timing and other		(295		)		(23		)		—			(318		)
	Net increase		666				135				426			1,227
	End of period		$	4,724			$	692			$	565		$	5,981
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:
			2013				2012				2011
			(In millions)
	Property sales — Domestic		$	23			$	606			$	434
	Ceiling test writedown — Domestic		—				1,488				—
			$	23			$	2,094			$	434
Summary Schedule of Estimated Quantities of Proved Oil and Gas Reserves	'
			Year Ended December 31,
			2013			2012			2011
			(MMBOE)
	Proved Reserves:
	Beginning of year		566			652			619
	Reserve additions		82			86			151
	Reserve revisions		14			(91	)		(48	)
	Sales		(1	)		(30	)		(20	)
	Production		(49	)		(51	)		(50	)
	End of year		612			566			652
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				Malaysia				China			Total
			(In millions)
	2013:00:00
	Future cash inflows		$	26,600			$	1,245			$	2,640		$	30,485
	Less related future:
	Production costs		(8,302		)		(771		)		(959		)	(10,032		)
	Development and abandonment costs		(4,166		)		(148		)		(143		)	(4,457		)
	Future net cash flows before income taxes		14,132				326				1,538			15,996
	Future income tax expense		(4,278		)		—				(316		)	(4,594		)
	Future net cash flows before 10% discount		9,854				326				1,222			11,402
	10% annual discount for estimating timing of cash flows		(5,226		)		(23		)		(320		)	(5,569		)
	Standardized measure of discounted future net cash flows		$	4,628			$	303			$	902		$	5,833
	2012:00:00
	Future cash inflows		$	21,724			$	1,754			$	2,186		$	25,664
	Less related future:
	Production costs		(7,042		)		(1,135		)		(888		)	(9,065		)
	Development and abandonment costs		(3,949		)		(82		)		(202		)	(4,233		)
	Future net cash flows before income taxes		10,733				537				1,096			12,366
	Future income tax expense		(2,786		)		(66		)		(239		)	(3,091		)
	Future net cash flows before 10% discount		7,947				471				857			9,275
	10% annual discount for estimating timing of cash flows		(4,539		)		(55		)		(245		)	(4,839		)
	Standardized measure of discounted future net cash flows		$	3,408			$	416			$	612		$	4,436
	2011:00:00
	Future cash inflows		$	26,241			$	2,751			$	2,213		$	31,205
	Less related future:
	Production costs		(6,523		)		(1,563		)		(850		)	(8,936		)
	Development and abandonment costs		(4,246		)		(161		)		(228		)	(4,635		)
	Future net cash flows before income taxes		15,472				1,027				1,135			17,634
	Future income tax expense		(4,344		)		(210		)		(268		)	(4,822		)
	Future net cash flows before 10% discount		11,128				817				867			12,812
	10% annual discount for estimating timing of cash flows		(6,404		)		(125		)		(302		)	(6,831		)
	Standardized measure of discounted future net cash flows		$	4,724			$	692			$	565		$	5,981
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 three-year period ended December 31, 2013:
			Continuing Operations				Discontinued Operations
			Domestic				Malaysia				China			Total
			(In millions)
	December 31, 2013:
	Proved properties		$	13,185			$	1,441			$	550		$	15,176
	Unproved properties		1,116				115				—			1,231
			14,301				1,556				550			16,407
	Accumulated depreciation, depletion and amortization		(7,185		)		(1,009		)		(112		)	(8,306		)
	Net capitalized costs		$	7,116			$	547			$	438		$	8,101
	December 31, 2012:
	Proved properties		$	11,221			$	1,140			$	375		$	12,736
	Unproved properties		1,291				104				1			1,396
			12,512				1,244				376			14,132
	Accumulated depreciation, depletion and amortization		(6,535		)		(747		)		(96		)	(7,378		)
	Net capitalized costs		$	5,977			$	497			$	280		$	6,754
Results of Operations for Oil and Gas Producing Activities	'
	The following tables present the results of our oil and gas producing activities for the respective years.
			Continuing Operations				Discontinued Operations
			Domestic				Malaysia				China			Total
			(In millions)
	Year Ended December 31, 2013
	Revenues		$	1,777			$	822			$	69		$	2,668
	Production costs		265				117				8			390
	Production taxes and other operating expenses		204				272				12			488
	Depreciation, depletion and amortization		668				244				18			930
	Income taxes		224				72				8			304
	Results of operations for oil and gas producing activities		$	416			$	117			$	23		$	556
	Year Ended December 31, 2012
	Revenues		$	1,469			$	1,005			$	86		$	2,560
	Production costs		292				101				7			400
	Production taxes and other operating expenses		174				259				18			451
	Depreciation, depletion and amortization		683				251				21			955
	Impairment of oil and gas properties		1,488				—				—			1,488
	Income taxes		(410		)		150				10			(250		)
	Results of operations for oil and gas producing activities		$	(758	)		$	244			$	30		$	(484	)
	Year Ended December 31, 2011
	Revenues		$	1,735			$	647			$	82		$	2,464
	Production costs		258				90				5			353
	Production taxes and other operating expenses		161				242				20			423
	Depreciation, depletion and amortization		622				126				19			767
	Income taxes		243				72				10			325
	Results of operations for oil and gas producing activities		$	451			$	117			$	28		$	596

Organization_and_Summary_of_Si3

Organization and Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'	'
Accumulated Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	$1,000,000	($6,000,000)	($9,000,000)	($12,000,000)
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1,000,000	-1,000,000	-1,000,000	0
Accumulated Other Comprehensive Income (Loss), Net of Tax	2,000,000	-7,000,000	-10,000,000	-12,000,000
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	'	3,000,000	3,000,000	'
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	2,000,000	0	-1,000,000	'
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	9,000,000	3,000,000	2,000,000	'
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax, Including OTTI	7,000,000	'	'	'
Change in asset retirement obligations [Line Items]	'	'	'	'
Less: Current portion of ARO	-54,000,000	-10,000,000	'	'
Asset Retirement Obligations, Noncurrent	201,000,000	132,000,000	'	'
Organization and Summary of Significant Accounting Policies (Textuals) [Abstract]	'	'	'	'
Realized interest income and gains on investment securities	3,000,000	3,000,000	2,000,000	'
Capitalization of internal costs per full cost method of accounting	145,000,000	123,000,000	113,000,000	'
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)	3.67	2.76	4.12	'
Unweighted average commodity price of oil based on first-day-of-the-month prices for the prior 12 months (per barrel)	96.82	94.84	96.13	'
Capitalized Costs Exceeding Ceiling, Net	'	948,000,000	'	'
Capitalized Cost Exceeding Ceiling, Gross	1,500,000,000	'	'	'
Unrealized loss on post-retirement benefits	1,000,000	-1,000,000	-1,000,000	0
Inventory Write-down	'	8,000,000	'	'
Asset retirement obligation liabilities settled through property sales	'	28,000,000	'	'
Primary Derivative Counterparties	9	'	'	'
Total Derivative Counterparties	15	'	'	'
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%	'	'	'
Statement [Line Items]	'	'	'	'
Property, Plant and Equipment, Useful Life	'25 years 0 months 0 days	'	'	'
Sunoco Logistics Partners [Member]	'	'	'	'
Statement [Line Items]	'	'	'	'
Sales of oil and gas to customer	13.00%	'	'	'
Royal Dutch Shell [Member]	'	'	'	'
Statement [Line Items]	'	'	'	'
Sales of oil and gas to customer	12.00%	14.00%	12.00%	'
Tesoro Corporation [Member]	'	'	'	'
Statement [Line Items]	'	'	'	'
Sales of oil and gas to customer	11.00%	14.00%	11.00%	'
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	'	'	'
Continuing Operations, Production and Other Taxes [Member]	'	'	'	'
Error Corrections and Prior Period Adjustments Restatement [Line Items]	'	'	'	'
Prior Period Other Adjustment	8,000,000	'	'	'
Continuing Operations, Bonus Accrual [Member]	'	'	'	'
Error Corrections and Prior Period Adjustments Restatement [Line Items]	'	'	'	'
Prior Period Other Adjustment	8,000,000	'	'	'
Discontinued Operations, Deferred Tax Expense [Member]	'	'	'	'
Error Corrections and Prior Period Adjustments Restatement [Line Items]	'	'	'	'
Prior Period Other Adjustment	-15,000,000	'	'	'
Continuing Operations [Member]	'	'	'	'
Change in asset retirement obligations [Line Items]	'	'	'	'
Beginning Balance	100,000,000	106,000,000	96,000,000	'
Accretion expense	8,000,000	8,000,000	8,000,000	'
Additions	12,000,000	20,000,000	5,000,000	'
Revisions	8,000,000	12,000,000	3,000,000	'
Settlements	-8,000,000	-46,000,000	-6,000,000	'
Ending Balance	120,000,000	100,000,000	106,000,000	'
Less: Current portion of ARO	-5,000,000	-5,000,000	-4,000,000	'
Asset Retirement Obligations, Noncurrent	115,000,000	95,000,000	102,000,000	'
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, Portion Attributable to Parent	4,000,000	'	'	'
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI for Write-down of Securities, Net of Tax	4,000,000	'	'	'
Other Comprehensive Income (Loss) [Member]	'	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'	'
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, Net of Tax	3,000,000	'	'	'
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	'	3,000,000	3,000,000	'
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	-2,000,000	0	1,000,000	'
Other Comprehensive Income (Loss), Net of Tax	'	3,000,000	2,000,000	'
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	$5,000,000	'	'	'

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, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013										Dec. 31, 2012	Dec. 31, 2011
Income (numerator):	'	'	'	'	'	'	'	'	'										'	'
Income (Loss) from Continuing Operations Attributable to Parent	$31	($4)	$106	($25)	($923)	($82)	$64	$39	$108										($902)	$401
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	-14	31	5	17	-479	49	71	77	39										-282	138
Net income (loss)	17	27	111	-8	-1,402	-33	135	116	147										-1,184	539
Preferred Stock Dividends and Other Adjustments	'	'	'	'	'	'	'	'	-20										0	0
Net Income (Loss) Available to Common Stockholders, Basic	'	'	'	'	'	'	'	'	127										-1,184	539
Weighted average shares (denominator):	'	'	'	'	'	'	'	'	'										'	'
Weighted average shares - basic	'	'	'	'	'	'	'	'	135										135	134
Dilution effect of stock options and unvested restricted stock and restricted stock units outstanding at end of period	'	'	'	'	'	'	'	'	1										0	1
Weighted average shares - diluted	'	'	'	'	'	'	'	'	136										135	135
Basic --	'	'	'	'	'	'	'	'	'										'	'
Income (Loss) from Continuing Operations, Per Basic Share	$0.23	($0.03)	$0.78	($0.19)	($6.86)	($0.61)	$0.47	$0.29	$0.80										($6.70)	$3
Income (Loss) from Discontinued Operations, Net of Tax, Before Preferred Share Repurchase, Per Basic Share	'	'	'	'	'	'	'	'	$0.29										($2.10)	$1.03
Income (Loss) Attributable to Repurchase of Preferred Shares of Wholly-owned Subsidiary, Per Basic Share	'	'	'	'	'	'	'	'	($0.15)										$0	$0
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share	($0.10)	$0.08	$0.04	$0.13	($3.53)	$0.37	$0.53	$0.57	$0.14										($2.10)	$1.03
Earnings (Loss) Per Share, Basic	$0.13	$0.05	$0.82	($0.06)	($10.39)	($0.24)	$1	$0.86	$0.94										($8.80)	$4.03
Diluted --	'	'	'	'	'	'	'	'	'										'	'
Income (Loss) from Continuing Operations, Per Diluted Share	$0.23	($0.03)	$0.78	($0.19)	($6.86)	($0.61)	$0.47	$0.29	$0.80										($6.70)	$2.97
Income (Loss) from Discontinued Operations, Net of Tax, Before Preferred Share Repurchase, Per Diluted Share	'	'	'	'	'	'	'	'	$0.29										($2.10)	$1.02
Income (Loss) Attributable to Repurchase of Preferred Shares of Wholly-owned Subsidiary, Per Diluted Share	'	'	'	'	'	'	'	'	($0.15)										$0	$0
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share	($0.10)	$0.08	$0.04	$0.13	($3.53)	$0.37	$0.53	$0.57	$0.14										($2.10)	$1.02
Earnings (Loss) Per Share, Diluted	$0.13	$0.05	$0.82	($0.06)	($10.39)	($0.24)	$1	$0.86	$0.94										($8.80)	$3.99
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:
											2013			2012			2011
											(In millions, except per share data)
									Income (numerator):
									Income (loss) from continuing operations		$	108		$	(902	)	$	401
									Income (loss) from discontinued operations, net of tax		39			(282		)	138
									Net income (loss)		147			(1,184		)	539
									Repurchase of preferred shares of subsidiary (3)		(20		)	—			—
									Net income (loss) attributable to common shareholders		$	127		$	(1,184	)	$	539
									Weighted-average shares (denominator):
									Weighted-average shares — basic		135			135			134
									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		136			135			135
									Earnings (loss) per share:
									Basic:
									Income (loss) from continuing operations		$	0.8		$	(6.70	)	$	3
									Income (loss) from discontinued operations before preferred share repurchase		0.29			(2.10		)	1.03
									Repurchase of preferred shares of subsidiary (3)		(0.15		)	—			—
									Income (loss) from discontinued operations		0.14			(2.10		)	1.03
									Basic earnings (loss) per share		$	0.94		$	(8.80	)	$	4.03
									Diluted:
									Income (loss) from continuing operations		$	0.8		$	(6.70	)	$	2.97
									Income (loss) from discontinued operations before preferred share repurchase		0.29			(2.10		)	1.02
									Repurchase of preferred shares of subsidiary (3)		(0.15		)	—			—
									Income (loss) from discontinued operations		0.14			(2.10		)	1.02
									Diluted earnings (loss) per share		$	0.94		$	(8.80	)	$	3.99
									_________________
									-1	Excludes 4.0 million and 1.4 million shares of unvested restricted stock or restricted stock units and stock options for the years ended December 31, 2013 and 2011, 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 discontinued 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	'	'	'	'	'	'	'	'	4										0.7	1.4
Payments for Repurchase of Preferred Stock and Preference Stock	'	'	'	'	'	'	'	'	$20										$0	$0

Discontinued_Operations_Detail

Discontinued Operations (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MBbls				MBbls				MBbls	MBbls
Change in asset retirement obligations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Less: Current portion of ARO	($54)	'	'	'	($10)	'	'	'	($54)	($10)	'
Asset Retirement Obligations, Noncurrent	201	'	'	'	132	'	'	'	201	132	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Disposal Group, Including Discontinued Operation, Revenue	'	'	'	'	'	'	'	'	891	1,092	729
Disposal Group, Including Discontinued Operation, Operating Expense	'	'	'	'	'	'	'	'	689	664	508
Disposal Group, Including Discontinued Operation, Operating Income (Loss)	'	'	'	'	'	'	'	'	202	428	221
Discontinued Operation, Amount of Other Income (Loss) from Disposition of Discontinued Operations, before Income Tax	'	'	'	'	'	'	'	'	4	-3	0
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	'	'	'	'	'	'	'	'	206	425	221
Discontinued Operation, Tax Effect of Discontinued Operation	'	'	'	'	'	'	'	'	167	707	83
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	-14	31	5	17	-479	49	71	77	39	-282	138
Disposal Group, Including Discontinued Operation, Cash and Cash Equivalents	84	'	'	'	76	'	'	'	84	76	'
Disposal Group, Including Discontinued Operation, Accounts, Notes and Loans Receivable, Net	200	'	'	'	207	'	'	'	200	207	'
Disposal Group, Including Discontinued Operation, Inventory	130	'	'	'	91	'	'	'	130	91	'
Disposal Group, Including Discontinued Operation, Other Current Assets	33	'	'	'	31	'	'	'	33	31	'
Assets of Disposal Group, Including Discontinued Operation, Current	447	'	'	'	405	'	'	'	447	405	'
Disposal Group, including Discontinued Operations, Oil and Gas Properties, Net	989	'	'	'	781	'	'	'	989	781	'
Disposal Group, Including Discontinued Operation, Other Noncurrent Assets	4	'	'	'	4	'	'	'	4	4	'
Assets of Disposal Group, Including Discontinued Operation, Noncurrent	1,012	'	'	'	809	'	'	'	1,012	809	'
Assets of Disposal Group, Including Discontinued Operation	1,459	'	'	'	1,214	'	'	'	1,459	1,214	'
Disposal Group, Including Discontinued Operation, Deferred Tax Assets	19	'	'	'	24	'	'	'	19	24	'
Disposal Group, Including Discontinued Operation, Accounts Payable	38	'	'	'	50	'	'	'	38	50	'
Disposal Group, Including Discontinued Operation, Accrued Liabilities	324	'	'	'	269	'	'	'	324	269	'
Disposal Group, Including Discontinued Operations, Asset Retirement Obligation, Current	49	'	'	'	5	'	'	'	49	5	'
Disposal Group, Including Discontinued Operation, Other Current Liabilities	18	'	'	'	16	'	'	'	18	16	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	429	'	'	'	340	'	'	'	429	340	'
Disposal Group, Including Discontinued Operations, Asset Retirement Obligations	86	'	'	'	37	'	'	'	86	37	'
Disposal Group, Including Discontinued Operation, Deferred Tax Liabilities	129	'	'	'	41	'	'	'	129	41	'
Disposal Group, Including Discontinued Operation, Other Noncurrent Liabilities	11	'	'	'	24	'	'	'	11	24	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	226	'	'	'	102	'	'	'	226	102	'
Liabilities of Disposal Group, Including Discontinued Operation	655	'	'	'	442	'	'	'	655	442	'
Disposal Group, Including Discontinued Operations, Accumulated Depreciation, Depletion and Amortization, Property Plant and Equipment	1,121	'	'	'	843	'	'	'	1,121	843	'
Effective Income Tax Rate, Discontinuing Operations	'	'	'	'	'	'	'	'	81.00%	166.00%	37.00%
Crude oil inventory in barrels	1,100	'	'	'	700	'	'	'	1,100	700	'
Not subject to amortization, Discontinued Operations	115	'	'	'	'	'	'	'	115	'	'
Energy Related Inventory, Petroleum	90	'	'	'	64	'	'	'	90	64	'
Unweighted average commodity price of natural gas based on first day of month prices for prior twelve months	3.67	'	'	'	2.76	'	'	'	3.67	2.76	4.12
Unweighted average commodity price of oil based on first day of month prices for prior twelve months	96.82	'	'	'	94.84	'	'	'	96.82	94.84	96.13
Historical Effective Tax Rate, Discontinuing Operations	'	'	'	'	'	'	'	'	37.00%	'	'
Costs incurred in 2010 and prior not subject to amortization [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Not subject to amortization, Discontinued Operations	45	'	'	'	'	'	'	'	45	'	'
Costs incurred in 2011 not subject to amortization [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Not subject to amortization, Discontinued Operations	2	'	'	'	'	'	'	'	2	'	'
Costs incurred in 2012 not subject to amortization [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Not subject to amortization, Discontinued Operations	24	'	'	'	'	'	'	'	24	'	'
Costs incurred in 2013 not subject to amortization [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Not subject to amortization, Discontinued Operations	44	'	'	'	'	'	'	'	44	'	'
Discontinued Operations, Deferred Tax Expense [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Prior Period Other Adjustment	'	'	'	'	'	'	'	'	15	'	'
Current [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Discontinued Operation, Tax Effect of Discontinued Operation	'	'	'	'	'	'	'	'	90	193	76
Deferred [Member]	'	'	'	'	'	'	'	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Discontinued Operation, Tax Effect of Discontinued Operation	'	'	'	'	'	'	'	'	77	514	7
Discontinued Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Change in asset retirement obligations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Beginning Balance	'	'	'	42	'	'	'	39	42	39	12
Accretion expense	'	'	'	'	'	'	'	'	3	3	2
Additions	'	'	'	'	'	'	'	'	4	4	29
Revisions	'	'	'	'	'	'	'	'	101	0	0
Settlements	'	'	'	'	'	'	'	'	-15	-4	-4
Ending Balance	135	'	'	'	42	'	'	'	135	42	39
Less: Current portion of ARO	-49	'	'	'	-5	'	'	'	-49	-5	-6
Asset Retirement Obligations, Noncurrent	$86	'	'	'	$37	'	'	'	$86	$37	$33

Oil_and_Gas_Assets_Details

Oil and Gas Assets (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
			acre
Oil and gas properties:	'	'	'
Subject to amortization	$15,107	$12,647	'
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	1,300	1,485	'
Gross oil and gas properties	16,407	14,132	'
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance for Relating to Oil and Gas Producing Activities	-8,306	-7,378	'
Net oil and gas properties	8,101	6,754	'
Accumulated depreciation and amortization	-69	-66	'
Net other property and equipment	174	148	'
Property, Plant and Equipment, Net	8,275	6,902	'
Cost of oil and gas properties not subject to amortization	'	'	'
Acquisition costs	808	'	'
Exploration costs	240	'	'
Development costs	69	'	'
Fee mineral interests	24	'	'
Capitalized interest	159	'	'
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	1,300	1,485	'
Oil and Gas Assets (Textuals) [Abstract]	'	'	'
Other oil and gas properties acquired	72	9	1
Non Strategic Assets Sold	'	208	'
Percent of oil and gas properties not subject to amortization associated with unconventional resource plays	82.00%	'	'
Value of Assets acquired Two	'	'	303
Net acres acquired in asset acquisition Two	'	'	65,000
Evaluation, in years, of conventional oil and gas properties not subject to amortization.	'P4Y	'	'
Proceeds from Sale of Oil and Gas Property and Equipment	36	630	406
Furniture and Fixtures [Member]	'	'	'
Oil and gas properties:	'	'	'
Other property and equipment	139	141	'
Gas Gathering and Processing Equipment [Member]	'	'	'
Oil and gas properties:	'	'	'
Other property and equipment	104	73	'
Costs incurred in 2013 not subject to amortization [Member]	'	'	'
Oil and gas properties:	'	'	'
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	448	'	'
Cost of oil and gas properties not subject to amortization	'	'	'
Acquisition costs	206	'	'
Exploration costs	175	'	'
Development costs	13	'	'
Fee mineral interests	1	'	'
Capitalized interest	53	'	'
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	448	'	'
Costs incurred in 2012 not subject to amortization [Member]	'	'	'
Oil and gas properties:	'	'	'
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	234	'	'
Cost of oil and gas properties not subject to amortization	'	'	'
Acquisition costs	114	'	'
Exploration costs	21	'	'
Development costs	31	'	'
Fee mineral interests	0	'	'
Capitalized interest	68	'	'
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	234	'	'
Costs incurred in 2011 not subject to amortization [Member]	'	'	'
Oil and gas properties:	'	'	'
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	260	'	'
Cost of oil and gas properties not subject to amortization	'	'	'
Acquisition costs	188	'	'
Exploration costs	9	'	'
Development costs	25	'	'
Fee mineral interests	0	'	'
Capitalized interest	38	'	'
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	260	'	'
Costs incurred in 2010 and prior not subject to amortization [Member]	'	'	'
Oil and gas properties:	'	'	'
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	358	'	'
Cost of oil and gas properties not subject to amortization	'	'	'
Acquisition costs	300	'	'
Exploration costs	35	'	'
Development costs	0	'	'
Fee mineral interests	23	'	'
Capitalized interest	0	'	'
Capitalized Costs of Unproved Properties Excluded from Amortization, Cumulative	$358	'	'

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Textuals) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Natural gas contracts [Member]	'
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$11
Oil contracts [Member]	'
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	$25

Outstanding_Natural_Gas_Contra

Outstanding Natural Gas Contracts That Are Not Designated for Hedge Accounting (Details) (Natural gas contracts [Member], USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	($11)
Collars [Member] | January 2014 - March 2014 [Member]	'
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-1
Natural Gas Volumes	5,850,000
Derivative, Weighted Average Floor Price	3.75
Derivative, Weighted Average Ceiling Price	4.62
Collars [Member] | April 2014 - June 2014 [Member]	'
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	0
Natural Gas Volumes	5,915,000
Derivative, Weighted Average Floor Price	3.75
Derivative, Weighted Average Ceiling Price	4.62
Collars [Member] | July 2014 - September 2014 [Member]	'
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	0
Natural Gas Volumes	5,980,000
Derivative, Weighted Average Floor Price	3.75
Derivative, Weighted Average Ceiling Price	4.62
Collars [Member] | October 2014 - December 2014 [Member]	'
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-1
Natural Gas Volumes	5,980,000
Derivative, Weighted Average Floor Price	3.75
Derivative, Weighted Average Ceiling Price	4.62
Collars [Member] | January 2015 - December 2015 [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	2
Fixed-price swaps | January 2014 - March 2014 [Member]	'
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-6
Natural Gas Volumes	21,150,000
Derivative, Swap Type, Average Fixed Price	3.98
Fixed-price swaps | April 2014 - June 2014 [Member]	'
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-3
Natural Gas Volumes	21,385,000
Derivative, Swap Type, Average Fixed Price	3.98
Fixed-price swaps | July 2014 - September 2014 [Member]	'
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-4
Natural Gas Volumes	21,620,000
Derivative, Swap Type, Average Fixed Price	3.98
Fixed-price swaps | October 2014 - December 2014 [Member]	'
Derivative [Line Items]	'
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value	-5
Natural Gas Volumes	21,620,000
Derivative, Swap Type, Average Fixed Price	3.98
Fixed-price swaps | January 2015 - December 2015 [Member]	'
Derivative [Line Items]	'
Natural Gas Volumes	49,275,000
Derivative, Swap Type, Average Fixed Price	4.28
Derivative Asset, Fair Value, Total	$7

Outstanding_Oil_Contracts_That

Outstanding Oil Contracts That Are Not Designated For Hedge Accounting (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Oil contracts [Member]	'
Derivative [Line Items]	'
Derivative Liability, Fair Value, Total	($25)
Natural gas contracts [Member]	'
Derivative [Line Items]	'
Derivative Liability, Fair Value, Total	-11
Fixed Price Swaps With Sold Puts [Member] | Oil contracts [Member] | January 2014 - March 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	1,440,000
Derivative, Swap Type, Average Fixed Price	95.16
Derivative Weighted Average Additional Put Price	75
Derivative Liability, Fair Value, Total	-4
Fixed Price Swaps With Sold Puts [Member] | Oil contracts [Member] | April 2014 - June 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	1,456,000
Derivative, Swap Type, Average Fixed Price	95.16
Derivative Weighted Average Additional Put Price	75
Derivative Liability, Fair Value, Total	-3
Fixed Price Swaps With Sold Puts [Member] | Oil contracts [Member] | July 2014 - September 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	1,472,000
Derivative, Swap Type, Average Fixed Price	95.16
Derivative Weighted Average Additional Put Price	75
Derivative Liability, Fair Value, Total	0
Fixed Price Swaps With Sold Puts [Member] | Oil contracts [Member] | October 2014 - December 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	1,472,000
Derivative, Swap Type, Average Fixed Price	95.16
Derivative Weighted Average Additional Put Price	75
Derivative Asset, Fair Value, Total	2
Fixed Price Swaps With Sold Puts [Member] | Oil contracts [Member] | January 2015 - December 2015 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	4,567,000
Derivative, Swap Type, Average Fixed Price	90.03
Derivative Weighted Average Additional Put Price	68.2
Derivative Asset, Fair Value, Total	3
Collars With Sold Puts [Member] | Oil contracts [Member] | January 2014 - March 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	540,000
Derivative Weighted Average Additional Put Price	75.83
Derivative, Weighted Average Floor Price	90.83
Derivative, Weighted Average Ceiling Price	103
Derivative Liability, Fair Value, Total	-1
Collars With Sold Puts [Member] | Oil contracts [Member] | April 2014 - June 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	546,000
Derivative Weighted Average Additional Put Price	75.83
Derivative, Weighted Average Floor Price	90.83
Derivative, Weighted Average Ceiling Price	103
Derivative Liability, Fair Value, Total	0
Collars With Sold Puts [Member] | Oil contracts [Member] | July 2014 - September 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	552,000
Derivative Weighted Average Additional Put Price	75.83
Derivative, Weighted Average Floor Price	90.83
Derivative, Weighted Average Ceiling Price	103
Derivative Asset, Fair Value, Total	1
Collars With Sold Puts [Member] | Oil contracts [Member] | October 2014 - December 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	552,000
Derivative Weighted Average Additional Put Price	75.83
Derivative, Weighted Average Floor Price	90.83
Derivative, Weighted Average Ceiling Price	103
Derivative Asset, Fair Value, Total	1
Fixed-price swaps | Oil contracts [Member] | January 2014 - March 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	1,350,000
Derivative, Swap Type, Average Fixed Price	89.6
Derivative Liability, Fair Value, Total	-12
Fixed-price swaps | Oil contracts [Member] | April 2014 - June 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	1,729,000
Derivative, Swap Type, Average Fixed Price	90.07
Derivative Liability, Fair Value, Total	-12
Fixed-price swaps | Oil contracts [Member] | July 2014 - September 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	1,932,000
Derivative, Swap Type, Average Fixed Price	89.86
Derivative Liability, Fair Value, Total	-9
Fixed-price swaps | Oil contracts [Member] | October 2014 - December 2014 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	2,116,000
Derivative, Swap Type, Average Fixed Price	89.95
Derivative Liability, Fair Value, Total	-5
Fixed-price swaps | Oil contracts [Member] | January 2015 - December 2015 [Member]	'
Derivative [Line Items]	'
Volume in MBbls	6,567,000
Derivative, Swap Type, Average Fixed Price	90.39
Derivative Asset, Fair Value, Total	14
Fixed-price swaps | Natural gas contracts [Member] | January 2014 - March 2014 [Member]	'
Derivative [Line Items]	'
Derivative, Swap Type, Average Fixed Price	3.98
Derivative Liability, Fair Value, Total	-6
Fixed-price swaps | Natural gas contracts [Member] | April 2014 - June 2014 [Member]	'
Derivative [Line Items]	'
Derivative, Swap Type, Average Fixed Price	3.98
Derivative Liability, Fair Value, Total	-3
Fixed-price swaps | Natural gas contracts [Member] | July 2014 - September 2014 [Member]	'
Derivative [Line Items]	'
Derivative, Swap Type, Average Fixed Price	3.98
Derivative Liability, Fair Value, Total	-4
Fixed-price swaps | Natural gas contracts [Member] | October 2014 - December 2014 [Member]	'
Derivative [Line Items]	'
Derivative, Swap Type, Average Fixed Price	3.98
Derivative Liability, Fair Value, Total	-5
Fixed-price swaps | Natural gas contracts [Member] | January 2015 - December 2015 [Member]	'
Derivative [Line Items]	'
Derivative, Swap Type, Average Fixed Price	4.28
Derivative Asset, Fair Value, Total	$7

Derivative_Financial_Instrumen3

Derivative Financial Instruments Recorded in Balance Sheet (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivative, Fair Value, Net [Abstract]	'	'
Derivative Liability Not Designated as Hedging Instrument Fair Value	($73)	($42)
Derivative Asset Not Designated As Hedging Instrument, Fair Value	37	163
Derivative Asset, Current	0	125
Derivative Asset, Noncurrent	26	17
Derivative Liability, Current	-62	-6
Derivative Liability, Noncurrent	0	-15
Derivative Assets Offset Against Derivative Liabilities	11	21
Derivative Liability, Fair Value, Gross Liability	-73	-42
Natural gas contracts [Member]	'	'
Derivative, Fair Value, Net [Abstract]	'	'
Derivative Liability Not Designated as Hedging Instrument Fair Value	-22	-16
Derivative Asset Not Designated As Hedging Instrument, Fair Value	11	86
Derivative Asset, Current	0	79
Derivative Asset, Noncurrent	9	2
Derivative Liability, Current	-20	-4
Derivative Liability, Noncurrent	0	-7
Derivative Assets Offset Against Derivative Liabilities	2	5
Derivative Liability, Fair Value, Gross Liability	-22	-16
Oil contracts [Member]	'	'
Derivative, Fair Value, Net [Abstract]	'	'
Derivative Liability Not Designated as Hedging Instrument Fair Value	-51	-26
Derivative Asset Not Designated As Hedging Instrument, Fair Value	26	77
Derivative Asset, Current	0	46
Derivative Asset, Noncurrent	17	15
Derivative Liability, Current	-42	-2
Derivative Liability, Noncurrent	0	-8
Derivative Assets Offset Against Derivative Liabilities	9	16
Derivative Liability, Fair Value, Gross Liability	($51)	($26)

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, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]	'	'	'
Realized Gain (Loss) on Derivatives	$60	$135	$195
Unrealized Gain (Loss) on Derivatives	-157	-15	0
Derivative, Gain (Loss) on Derivative, Net	-97	120	195
Natural gas contracts [Member]	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]	'	'	'
Realized Gain (Loss) on Derivatives	66	144	249
Unrealized Gain (Loss) on Derivatives	-81	-124	-48
Oil contracts [Member]	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]	'	'	'
Realized Gain (Loss) on Derivatives	-6	1	-47
Unrealized Gain (Loss) on Derivatives	-76	99	47
Basis contracts [Member]	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net [Abstract]	'	'	'
Realized Gain (Loss) on Derivatives	0	-10	-7
Unrealized Gain (Loss) on Derivatives	$0	$10	$1

Accounts_Receivable_Details

Accounts Receivable (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Accounts Receivable	'	'
Accounts receivable	$474	$452
Revenue [Member]	'	'
Accounts Receivable	'	'
Accounts receivable	294	291
Other accounts receivable [Member]	'	'
Accounts Receivable	'	'
Accounts receivable	25	8
Allowance For Doubtful Accounts [Member]	'	'
Accounts Receivable	'	'
Accounts receivable	-1	-1
Oil and Gas Joint Interest Billing [Member]	'	'
Accounts Receivable	'	'
Accounts receivable	$156	$154

Accrued_Liabilities_Details

Accrued Liabilities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Accrued Liabilities	'	'
Accrued liabilities	$978	$801
Revenue payable [Member]	'	'
Accrued Liabilities	'	'
Accrued liabilities	175	95
Accrued capital costs [Member]	'	'
Accrued Liabilities	'	'
Accrued liabilities	458	355
Accrued lease operating expenses [Member]	'	'
Accrued Liabilities	'	'
Accrued liabilities	71	95
Employee incentive expense [Member]	'	'
Accrued Liabilities	'	'
Accrued liabilities	51	50
Accrued interest on debt [Member]	'	'
Accrued Liabilities	'	'
Accrued liabilities	72	43
Taxes payable [Member]	'	'
Accrued Liabilities	'	'
Accrued liabilities	93	108
Other accrued liabilities [Member]	'	'
Accrued Liabilities	'	'
Accrued liabilities	$58	$55

Fair_Value_Measurements_Textua

Fair Value Measurements (Textuals) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$26	$151	$103	$78
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) Included in Investment Income	-16	82	56	'
Money Market Funds, at Carrying Value	2	22	'	'
Deferred Compensation Plan Assets	8	6	'	'
Other than Temporary Impairment Losses, Investments, Available-for-sale Securities	6	'	'	'
Other than Temporary Impairment Losses, Investments, Available-for-sale Securities, Net of Tax	4	'	'	'
Assets, Fair Value Disclosure	-5	-190	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	-90	135	87	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	10	4	4	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	-45	-91	-66	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net	0	0	0	'
Obligations, Fair Value Disclosure	-16	-2	'	'
Accumulated Other Comprehensive Income Loss Available For Sale Securities Adjustment Gross Of Tax	'	-9	'	'
Natural Gas [Member]	'	'	'	'
Derivative Liability, Fair Value, Total	-11	'	'	'
Natural Gas [Member] | Options Held [Member]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	1	'	'	'
Natural Gas [Member] | Minimum [Member] | Options Held [Member]	'	'	'	'
Derivative, Forward Price	4.01	'	'	'
Fair Value Assumptions Expected Volatility Curves	18.74%	'	'	'
Fair Value Inputs, Entity Credit Risk	0.01%	'	'	'
Natural Gas [Member] | Maximum [Member] | Options Held [Member]	'	'	'	'
Derivative, Forward Price	4.42	'	'	'
Fair Value Assumptions Expected Volatility Curves	50.02%	'	'	'
Fair Value Inputs, Entity Credit Risk	1.58%	'	'	'
Oil contracts [Member]	'	'	'	'
Derivative Liability, Fair Value, Total	-25	'	'	'
Oil contracts [Member] | Options Held [Member]	'	'	'	'
Derivative Liability, Fair Value, Total	-9	'	'	'
Oil contracts [Member] | Minimum [Member] | Options Held [Member]	'	'	'	'
Derivative, Forward Price	86.29	'	'	'
Fair Value Assumptions Expected Volatility Curves	14.33%	'	'	'
Fair Value Inputs, Entity Credit Risk	0.01%	'	'	'
Oil contracts [Member] | Maximum [Member] | Options Held [Member]	'	'	'	'
Derivative, Forward Price	98.77	'	'	'
Fair Value Assumptions Expected Volatility Curves	23.22%	'	'	'
Fair Value Inputs, Entity Credit Risk	0.89%	'	'	'
Auction Rate Securities [Member]	'	'	'	'
Available-for-sale Securities, Fair Value Disclosure	39	36	'	'
Swap [Member]	'	'	'	'
Derivative Assets	'	-6	'	'
Derivative Liability	-28	'	'	'
Commodity Option [Member]	'	'	'	'
Derivative Assets	'	-115	'	'
Derivative Liability	-8	'	'	'
Equity Securities [Member]	'	'	'	'
Available-for-sale Securities, Fair Value Disclosure	8	7	'	'
Quoted Prices In Active Markets for Identical Assets or Liabilities, Fair Value Inputs (Level 1) [Member]	'	'	'	'
Money Market Funds, at Carrying Value	2	22	'	'
Deferred Compensation Plan Assets	8	6	'	'
Assets, Fair Value Disclosure	-7	-33	'	'
Obligations, Fair Value Disclosure	-11	-2	'	'
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	0	'	'
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] | 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	8	7	'	'
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	'	-6	'	'
Financial and Nonfinancial Liabilities, Fair Value Disclosure	-28	'	'	'
Obligations, Fair Value Disclosure	0	0	'	'
Significant Other Observable Fair Value Inputs (Level 2) [Member] | Auction Rate Securities [Member]	'	'	'	'
Available-for-sale Securities, Fair Value Disclosure	0	0	'	'
Significant Other Observable Fair Value Inputs (Level 2) [Member] | Swap [Member]	'	'	'	'
Derivative Assets	'	-6	'	'
Derivative Liability	-28	'	'	'
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]	'	'	'	'
Money Market Funds, at Carrying Value	0	0	'	'
Deferred Compensation Plan Assets	0	0	'	'
Assets, Fair Value Disclosure	-26	-151	'	'
Obligations, Fair Value Disclosure	-5	0	'	'
Fair Value, Inputs, Level 3 [Member] | Auction Rate Securities [Member]	'	'	'	'
Available-for-sale Securities, Fair Value Disclosure	39	36	'	'
Fair Value, Inputs, Level 3 [Member] | Swap [Member]	'	'	'	'
Derivative Assets	0	0	'	'
Fair Value, Inputs, Level 3 [Member] | Commodity Option [Member]	'	'	'	'
Derivative Assets	'	-115	'	'
Derivative Liability	-8	'	'	'
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member]	'	'	'	'
Available-for-sale Securities, Fair Value Disclosure	0	0	'	'
Investments [Member]	'	'	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	39	36	32	30
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) Included in Investment Income	-6	0	0	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	-6	0	0	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	10	4	4	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	-1	0	-2	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net	0	0	0	'
Derivative Financial Instruments, Assets [Member]	'	'	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	'	115	71	48
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) Included in Investment Income	'	82	56	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	'	135	87	'
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, Settlements	'	-91	-64	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net	'	0	0	'
5.75 %Senior Notes Due 2022 [Member]	'	'	'	'
Debt Instrument, Fair Value Disclosure	767	836	'	'
5.625% Senior Notes Due 2024 [Member]	'	'	'	'
Debt Instrument, Fair Value Disclosure	1,025	1,074	'	'
7.125% Senior Subordinated Notes due 2018 [Member]	'	'	'	'
Debt Instrument, Fair Value Disclosure	624	630	'	'
6.875% Senior Subordinated Notes due 2020 [Member]	'	'	'	'
Debt Instrument, Fair Value Disclosure	755	749	'	'
Stockholder Value Appreciation Program [Member]	'	'	'	'
Liability Value	-5	'	'	'
Derivative Financial Instruments, Assets [Member]	'	'	'	'
Liability Value	-8	'	'	'
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) Included in Investment Income	-10	'	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	-66	'	'	'
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, Asset, Settlements	-57	'	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net	0	'	'	'
Stock Compensation Plan [Member]	'	'	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	'	0	0	0
Liability Value	-5	'	'	'
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) Included in Investment Income	0	0	0	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	-18	0	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, Settlements	'	0	0	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	13	'	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net	$0	$0	$0	'
Implied [Member] | Stockholder Value Appreciation Program [Member]	'	'	'	'
SBC Expected Volatility Rate, Maximum	37.40%	'	'	'
Implied [Member] | Stockholder Value Appreciation Program [Member]	'	'	'	'
SBC Expected Volatility Rate, Maximum	41.20%	'	'	'

Valuation_of_Investments_and_F

Valuation of Investments and Financial Instrument Assets Liabilities By Pricing Levels (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Money market fund investments	$2	$22
Deferred Compensation Plan Assets	8	6
Total	5	190
Equity Securities [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Available-for-sale Securities	8	7
Auction Rate Securities [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Available-for-sale Securities	39	36
Swap [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Oil and gas derivative contracts	'	6
Commodity Option [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Oil and gas derivative contracts	'	115
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	2	22
Deferred Compensation Plan Assets	8	6
Total	7	33
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	8	7
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	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	'	6
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	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	'	6
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	151
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	36
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
Fair Value, Inputs, Level 3 [Member] | Commodity Option [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Oil and gas derivative contracts	'	$115

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, 2013	Dec. 31, 2012	Dec. 31, 2011
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'	'
Beginning Balance	$151	$103	$78
Included in earnings	-90	135	87
Included in other comprehensive income (loss)	10	4	4
Settlements	-45	-91	-66
Transfers in and out of Level 3	0	0	0
Ending Balance	26	151	103
Change in unrealized gains (losses) relating to investments and derivatives still held	-16	82	56
Derivatives [Member]	'	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'	'
Beginning Balance	'	71	48
Included in earnings	'	135	87
Included in other comprehensive income (loss)	'	0	0
Settlements	'	-91	-64
Transfers in and out of Level 3	'	0	0
Ending Balance	'	115	71
Change in unrealized gains (losses) relating to investments and derivatives still held	'	82	56
Investments [Member]	'	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'	'
Beginning Balance	36	32	30
Included in earnings	-6	0	0
Included in other comprehensive income (loss)	10	4	4
Settlements	-1	0	-2
Transfers in and out of Level 3	0	0	0
Ending Balance	39	36	32
Change in unrealized gains (losses) relating to investments and derivatives still held	($6)	$0	$0

Quantitative_Information_about

Quantitative Information about Level 3 Fair Value Measurements (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Stockholder Value Appreciation Program [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Liability Value	-5
Stockholder Value Appreciation Program [Member] | Historical [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
SBC Expected Volatility Rate, Maximum	37.40%
Stockholder Value Appreciation Program [Member] | Implied [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
SBC Expected Volatility Rate, Maximum	41.20%
Natural gas contracts [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Derivative Liability, Fair Value, Total	11
Oil contracts [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Derivative Liability, Fair Value, Total	25
Options Held [Member] | Natural gas contracts [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Derivative Asset, Fair Value, Total	1
Options Held [Member] | Natural gas contracts [Member] | Maximum [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Credit Risk	1.58%
NYMEX Forward Curve Future Price	4.42
Fair Value Assumptions Expected Volatility Curves	50.02%
Options Held [Member] | Natural gas contracts [Member] | Minimum [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Credit Risk	0.01%
NYMEX Forward Curve Future Price	4.01
Fair Value Assumptions Expected Volatility Curves	18.74%
Options Held [Member] | Oil contracts [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Derivative Liability, Fair Value, Total	9
Options Held [Member] | Oil contracts [Member] | Maximum [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Credit Risk	0.89%
NYMEX Forward Curve Future Price	98.77
Fair Value Assumptions Expected Volatility Curves	23.22%
Options Held [Member] | Oil contracts [Member] | Minimum [Member]	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'
Credit Risk	0.01%
NYMEX Forward Curve Future Price	86.29
Fair Value Assumptions Expected Volatility Curves	14.33%

Debt_Details

Debt (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Mar. 31, 2013
Debt Instrument [Line Items]	'	'	'	'
Line of Credit Facility, Amount Outstanding	$649,000,000	$0	'	'
Long-term debt	3,694,000,000	3,045,000,000	'	'
Debt issuance costs	4,000,000	'	'	'
Net proceeds from issuance of Senior Notes	'	990,000,000	'	'
Debt (Textuals)	'	'	'	'
Line of Credit Facility, Maximum Borrowing Capacity	1,400,000,000	'	'	1,250,000,000
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	3,000,000	3,000,000	2,000,000	'
Ratio of Indebtedness to Net Capital 1	0.6	'	'	'
Ratio of total debt to earnings before gain or loss on disposition of assets, interest expense, income taxes and noncash items	3	'	'	'
Letters of Credit Outstanding, Amount	58,000,000	'	'	'
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	96,000,000	'	'	'
Discount On Notes [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Long-term debt	-5,000,000	-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	600,000,000	600,000,000	'	'
Debt Instrument, Interest Rate, Stated Percentage	7.13%	7.13%	'	'
Total senior unsecured debt	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Long-term debt	1,750,000,000	1,750,000,000	'	'
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	64,000,000	0	'	'
Revolving Credit Facility Libor Based Loans [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Line of Credit Facility, Amount Outstanding	$585,000,000	$0	'	'

Income_Taxes_Details

Income Taxes (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Components of Deferred Tax Assets and Liabilities [Abstract]	'	'	'	'
Valuation Allowance, Amount	($584,000,000)	($457,000,000)	($11,000,000)	($6,000,000)
Deferred tax asset:	'	'	'	'
Net operating loss carryforwards	335,000,000	213,000,000	'	'
Alternative minimum tax credit	99,000,000	103,000,000	'	'
Stock compensation	25,000,000	24,000,000	'	'
Marketable securities	3,000,000	4,000,000	'	'
Oil and gas properties	59,000,000	49,000,000	'	'
Valuation Allowance	-584,000,000	-457,000,000	-11,000,000	-6,000,000
Foreign tax credit	535,000,000	421,000,000	'	'
Other	6,000,000	18,000,000	'	'
Deferred tax asset	491,000,000	375,000,000	'	'
Commodity derivatives	13,000,000	0	'	'
Deferred tax liability:	'	'	'	'
Commodity derivatives	0	-44,000,000	'	'
Oil and gas properties	-1,592,000,000	-1,283,000,000	'	'
Deferred tax liability	-1,592,000,000	-1,327,000,000	'	'
Deferred Tax Assets (Liabilities), Net, Total	-1,101,000,000	-952,000,000	'	'
Less net current deferred tax liability	22,000,000	0	'	'
Deferred Tax Liabilities, Net, Current	0	-42,000,000	'	'
Deferred Tax Assets (Liabilities), Net, Noncurrent	-1,123,000,000	-910,000,000	'	'
Deferred Tax Assets, Gross	1,075,000,000	832,000,000	'	'
Income tax reconciliation to US federal statutory rate	'	'	'	'
Amount computed using the statutory rate	60,000,000	-495,000,000	217,000,000	'
Increase (decrease) in taxes resulting from:	'	'	'	'
State and local income taxes, net of federal effect	8,000,000	-18,000,000	10,000,000	'
Valuation allowance, state net of federal	-2,000,000	0	5,000,000	'
Other	-4,000,000	2,000,000	-14,000,000	'
Total income tax provision (benefit)	62,000,000	-511,000,000	218,000,000	'
Income Taxes (Textuals) [Abstract]	'	'	'	'
Federal statutory tax rate	35.00%	'	'	'
Net operating loss carryforwards subject to annual limitations	189,000,000	'	'	'
International Nols That We Do Not Anticipate Utilizing	'	17,000,000	'	'
US state NOLs that we do not anticipate utilizing	74,000,000	'	'	'
State and Local Jurisdiction [Member]	'	'	'	'
Components of Deferred Tax Assets and Liabilities [Abstract]	'	'	'	'
Operating Loss Carryforwards	1,700,000,000	1,600,000,000	'	'
Federal [Member]	'	'	'	'
Components of Deferred Tax Assets and Liabilities [Abstract]	'	'	'	'
Operating Loss Carryforwards	1,000,000,000	500,000,000	'	'
Valuation Allowance, Tax Credit Carryforward [Member] | Foreign [Member]	'	'	'	'
Income Tax Contingency [Line Items]	'	'	'	'
Valuation Allowance, Deferred Tax Asset, Change in Amount	114,000,000	421,000,000	0	'
Valuation Allowance, Tax Credit Carryforward [Member] | Malaysia [Member]	'	'	'	'
Income Tax Contingency [Line Items]	'	'	'	'
Valuation Allowance, Deferred Tax Asset, Change in Amount	15,000,000	25,000,000	0	'
Valuation Allowance, Operating Loss Carryforwards [Member] | U.S. [Member]	'	'	'	'
Income Tax Contingency [Line Items]	'	'	'	'
Valuation Allowance, Deferred Tax Asset, Change in Amount	($2,000,000)	$0	$5,000,000	'

Income_Taxes_Breakout_of_Provi

Income Taxes- Breakout of Provision (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Current taxes:	'	'	'
U.S. federal	($4)	$1	$17
U.S. state	0	1	0
Deferred taxes:	'	'	'
U.S. federal	53	-479	171
U.S. state	13	-34	30
Total income tax provision (benefit)	$62	($511)	$218

Income_Taxes_Breakout_of_Incom

Income Taxes- Breakout of Income (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Total income (loss) before income taxes	$170	($1,413)	$619

Income_Taxes_DTA_Valuation_Rol

Income Taxes- DTA Valuation Rollforward (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

In Millions, unless otherwise specified

Valuation Allowance, Tax Credit Carryforward [Member]

Valuation Allowance, Tax Credit Carryforward [Member]

Valuation Allowance, Tax Credit Carryforward [Member]

Valuation Allowance, Tax Credit Carryforward [Member]

Valuation Allowance, Tax Credit Carryforward [Member]

Valuation Allowance, Tax Credit Carryforward [Member]

Valuation Allowance, Operating Loss Carryforwards [Member]

Valuation Allowance, Operating Loss Carryforwards [Member]

Valuation Allowance, Operating Loss Carryforwards [Member]

Malaysia [Member]

Malaysia [Member]

Malaysia [Member]

Foreign [Member]

Foreign [Member]

Foreign [Member]

U.S. [Member]

U.S. [Member]

U.S. [Member]

Valuation Allowance [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance at the beginning of the year

($584)

($457)

($11)

($6)

'

'

'

'

'

'

'

'

'

Valuation Allowance, Deferred Tax Asset, Change in Amount

'

'

'

'

-15

-25

0

-114

-421

0

2

0

-5

Balance at the end of the year

($584)

($457)

($11)

($6)

'

'

'

'

'

'

'

'

'

StockBased_Compensation_Detail

Stock-Based Compensation (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Total stock-based compensation expense	$75	$47	$40	'
Capitalized in oil and gas properties	-20	-12	-11	'
Net stock-based compensation expense	55	35	29	'
Number of restricted stock shares vested	1,195,000	1,066,000	925,000	'
Number of restricted stock shares outstanding	3,705,000	2,809,000	2,480,000	2,494,000
Fair value of units vested during the period	47	44	32	'
Share Based Compensation Arrangement Exercise Rate	20.00%	'	'	'
Nonvested Awards, Total Compensation Cost Not yet Recognized	116	'	'	'
SVAP Price Threshold	$27.50	'	'	'
SVAP Incremental Price Threshold	$5	'	'	'
Stock-Based Compensation (Textuals) [Abstract]	'	'	'	'
Unrecognized net operating loss related to Stock Based Compensation	102	'	'	'
Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition	'5 years	'	'	'
Last reported sales price of our common stock on the New York Stock Exchange per share	$24.63	'	'	'
Equity [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Total stock-based compensation expense	48	46	37	'
Liability [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Total stock-based compensation expense	27	1	3	'
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	2,700,000	'	'	'
Cash-Settled Restricted Stock Units [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Service Period	'3 years	'	'	'
Number of restricted stock shares vested	85,000	44,000	'	'
Number of restricted stock shares outstanding	1,200,000	'	'	'
Nonvested Awards, Total Compensation Cost Not yet Recognized	15	'	'	'
Liability Settlements	2	2	'	'
Stockholder Value Appreciation Program [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Service Period	'2 years	'	'	'
Nonvested Awards, Total Compensation Cost Not yet Recognized	14	'	'	'
Weighted Average Volatility Rate	39.30%	'	'	'
Liability Value	5	'	'	'
Liability Settlements	13	'	'	'
Employee Service Shared-based Compensation, Nonvested Awards, Compensation Cost Not yet Paid	$19	'	'	'
Fair Value Assumptions, Risk Free Interest Rate	0.38%	'	'	'
Service - Based Shares [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Number of restricted stock shares vested	1,195,000	977,000	836,000	'
Number of restricted stock shares outstanding	2,999,000	2,371,000	2,123,000	2,178,000
Performance Market Based Shares [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Number of restricted stock shares vested	0	89,000	89,000	'
Number of restricted stock shares outstanding	706,000	438,000	357,000	316,000
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	1,500,000	'	'	'

StockBased_Compensation_Stock_

Stock-Based Compensation- Stock Option Activity (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Stock option activity	'	'	'	'
Outstanding, Beginning Balance, Number of Shares Underlying Options	901,000	1,059,000	1,539,000	'
Granted, Number of Shares Underlying Options	0	0	0	'
Exercised, Number of Shares Underlying Options	-53,000	-94,000	-446,000	'
Forfeited, Number of Shares Underlying Options	-161,000	-64,000	-34,000	'
Outstanding, Ending Balance, Number of Shares Underlying Options	687,000	901,000	1,059,000	1,539,000
Exercisable, Number of Shares Underlying Options	687,000	'	'	'
Outstanding, Beginning Balance, Weighted Average Exercise Price per Share	$38.06	$36.31	$34.58	'
Granted, Weighted Average Exercise Price per Share	$0	$0	$0	'
Exercised, Weighted Average Exercise Price per Share	$19.68	$19.52	$29.54	'
Forfeited, Weighted Average Exercise Price per Share	$37.26	$36.19	$46.73	'
Outstanding, Ending Balance, Weighted Average Exercise Price per Share	$39.68	$38.06	$36.31	$34.58
Exercisable, Weighted Average Exercise Price per Share	$39.68	'	'	'
Weighted average fair value of each option	$0	$0	$0	'
Outstanding, Beginning Balance, Weighted Average Remaining Contractual Life (In years)	'1 year 11 months	'3 years 4 months 0 days	'4 years 0 months 0 days	'4 years 8 months 0 days
Outstanding, Ending Balance, Weighted Average Remaining Contractual Life (In years)	'1 year 11 months	'3 years 4 months 0 days	'4 years 0 months 0 days	'4 years 8 months 0 days
Exercisable, Weighted Average Remaining Contractual Life (In years)	'1 year 11 months	'	'	'
Outstanding, Beginning Balance, Aggregate Intrinsic Value	$1	$7	$58	'
Exercised, Aggregate Intrinsic Value	1	1	18	'
Outstanding, Ending Balance, Aggregate Intrinsic Value	0	1	7	58
Exercisable, Aggregate Intrinsic Value	$0	'	'	'

StockBased_Compensation_Stock_1

Stock-Based Compensation- Stock Option Summary (Details) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'	'	'
Options Outstanding, Number of Shares Underlying Options	687	901	1,059	1,539
Options Outstanding, Weighted Average Remaining Contractual Life (In years)	'1 year 11 months	'3 years 4 months 0 days	'4 years 0 months 0 days	'4 years 8 months 0 days
Options Outstanding, Weighted Average Exercise Price per Share	$39.68	'	'	'
Options Exercisable, Number of Shares Underlying Options	687	'	'	'
Options Exercisable, Weighted Average Exercise Price per Share	$39.68	'	'	'
Range One Twenty-two Dollars Fifty-one Cent To Seventeen Dollars Fifty Cents [Member]	'	'	'	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'	'	'
Exercise Price Lower Range Limit	$22.51	'	'	'
Exercise Price Upper Range Limit	$27.50	'	'	'
Options Outstanding, Number of Shares Underlying Options	93	'	'	'
Options Outstanding, Weighted Average Remaining Contractual Life (In years)	'0 years 2 months	'	'	'
Options Outstanding, Weighted Average Exercise Price per Share	$24.90	'	'	'
Options Exercisable, Number of Shares Underlying Options	93	'	'	'
Options Exercisable, Weighted Average Exercise Price per Share	$24.90	'	'	'
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	202	'	'	'
Options Outstanding, Weighted Average Remaining Contractual Life (In years)	'0 years 11 months	'	'	'
Options Outstanding, Weighted Average Exercise Price per Share	$31.03	'	'	'
Options Exercisable, Number of Shares Underlying Options	202	'	'	'
Options Exercisable, Weighted Average Exercise Price per Share	$31.03	'	'	'
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	31	'	'	'
Options Outstanding, Weighted Average Remaining Contractual Life (In years)	'1 year 4 months	'	'	'
Options Outstanding, Weighted Average Exercise Price per Share	$38.33	'	'	'
Options Exercisable, Number of Shares Underlying Options	31	'	'	'
Options Exercisable, Weighted Average Exercise Price per Share	$38.33	'	'	'
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	361	'	'	'
Options Outstanding, Weighted Average Remaining Contractual Life (In years)	'3 years	'	'	'
Options Outstanding, Weighted Average Exercise Price per Share	$48.45	'	'	'
Options Exercisable, Number of Shares Underlying Options	0	'	'	'
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, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Non-vested shares outstanding, Beginning balance	2,809,000	2,480,000	2,494,000
Granted	2,728,000	1,773,000	1,144,000
Forfeited	-637,000	-378,000	-233,000
Vested	-1,195,000	-1,066,000	-925,000
Non-vested shares outstanding, Ending balance	3,705,000	2,809,000	2,480,000
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Beginning balance	$43.31	$49.52	$36.84
Granted, Weighted Average Grant Date Fair Value per Share	$27.24	$35.29	$64.35
Forfeited, Weighted Average Grant Date Fair Value per Share	$39.47	$47.34	$44.79
Vested, Weighted Average Grant Date Fair Value per Share	$39.64	$41.70	$34.86
Non-vested shares outstanding, Weighted Average Grant Date Fair Value per Share, Ending balance	$33.31	$43.31	$49.52
Service - Based Shares [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Non-vested shares outstanding, Beginning balance	2,371,000	2,123,000	2,178,000
Granted	2,428,000	1,589,000	1,014,000
Forfeited	-605,000	-364,000	-233,000
Vested	-1,195,000	-977,000	-836,000
Non-vested shares outstanding, Ending balance	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]	'	'	'
Non-vested shares outstanding, Beginning balance	438,000	357,000	316,000
Granted	300,000	184,000	130,000
Forfeited	-32,000	-14,000	0
Vested	0	-89,000	-89,000
Non-vested shares outstanding, Ending balance	706,000	438,000	357,000

StockBased_Compensation_Employ

Stock-Based Compensation- Employee Stock Purchase Plan (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
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	'	'
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]	'	'	'
Additional shares available for issuance	524,300	'	'
Options To Purchase Common Stock Shares	178,733	165,722	85,982
Weighted average fair value of each option	$6.59	$9.86	$16.95
Expected volatility	39.45%	49.43%	32.21%
Risk-free weighted average interest rate	0.10%	0.10%	0.14%
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, 2013	Dec. 31, 2012	Dec. 31, 2011
Employeebenfitplanstextualsabstract [Abstract]	'	'	'
Expected future benefit payments in years one through five for post-retirement medical plan	$3,000,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter	5,000,000	'	'
Maximum age for retire employees to be covered under post-retirement medical plan	65	'	'
Defined Benefit Plan, Benefit Obligation	10,000,000	'	'
Defined Benefit Plan, Net Periodic Benefit Cost	2,000,000	2,000,000	2,000,000
Total incentive compensation plan expense	40,000,000	41,000,000	39,000,000
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	$8,000,000

Voluntary_Severance_Program_Vo

Voluntary Severance Program Voluntary Severance Program (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Restructuring and Related Activities [Abstract]	'
Severance Costs	$9

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MBbls
	MMBTU
Future minimum payments under non-cancellable agreements	'	'	'
Natural Gas Commitments Current	11,250,000	'	'
2014	$156	'	'
2015	110	'	'
2016	88	'	'
2017	86	'	'
2018	76	'	'
Thereafter	121	'	'
Total minimum future payments	637	'	'
Delivery Commitments, Current	7,483,000	'	'
Natural Gas Commitments Due In Two Years	0	'	'
Delivery Commitments, Due In Two Years	7,483,000	'	'
Natural Gas Commitments Due In Three Years	0	'	'
Delivery Commitments, Due In Three Years	9,190,000	'	'
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	50,748,000	'	'
Total Natural Gas Commitments	11,250,000	'	'
Total Delivery Commitments	102,644,000	'	'
Commitments and Contingencies (Textuals) [Abstract]	'	'	'
Rent expense under lease commitments	18	17	14
Operating Leases, discontinuing Operations	5	'	'
Other Agreements, Discontinued Operations	245	'	'
Firm Transportation [Member]	'	'	'
Future minimum payments under non-cancellable agreements	'	'	'
2014	78	'	'
2015	76	'	'
2016	73	'	'
2017	71	'	'
2018	62	'	'
Thereafter	85	'	'
Total minimum future payments	445	'	'
Operating Leases [Member]	'	'	'
Future minimum payments under non-cancellable agreements	'	'	'
2014	17	'	'
2015	18	'	'
2016	15	'	'
2017	15	'	'
2018	14	'	'
Thereafter	36	'	'
Total minimum future payments	115	'	'
Other Commitments [Member]	'	'	'
Future minimum payments under non-cancellable agreements	'	'	'
2014	61	'	'
2015	16	'	'
2016	0	'	'
2017	0	'	'
2018	0	'	'
Thereafter	0	'	'
Total minimum future payments	$77	'	'

Delivery_Commitments_Details

Delivery Commitments (Details) (USD $)	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2013
		bbls
		MBbls
		MMBTU
Delivery Commitments [Line Items]	'	'
Delivery Commitments, Current (2014)	'	7,483,000
Delivery Commitments, Due In Two Years (2015)	'	7,483,000
Delivery Commitments, Due In Three Years (2016)	'	9,190,000
Delivery Commitments, Due In Four Years (2017)	'	13,870,000
Delivery Commitments, Due In Five Years (2018)	'	13,870,000
Delivery Commitments, Due Thereafter	'	50,748,000
Total Delivery Commitments	'	102,644,000
Natural Gas Commitments, Current (2014)	'	11,250,000
Natural Gas Commitments, Due In Two Years (2015)	'	0
Natural Gas Commitments, Due In Three Years (2016)	'	0
Natural Gas Commitments, Due In Four Years (2017)	'	0
Natural Gas Commitments, Due In Five Years (2018)	'	0
Natural Gas Commitments, Due Thereafter	'	0
Total Natural Gas Commitments	'	11,250,000
Oil and Gas Delivery Commitments and Contracts Additional Information [Abstract]	'	'
Oil and Gas Delivery Commitments and Contracts, Term in Years	'	'10 years 0 months 0 days
Oil and Gas Delivery Commitments and Contracts, Daily Production	'	20,000
Gain (Loss) Related to Litigation Settlement	$13	'
Commitment Volumes 2024	'	7,300
Minimum [Member]	'	'
Delivery Commitments [Line Items]	'	'
Deficiency Fees	'	2.67
Maximum [Member]	'	'
Delivery Commitments [Line Items]	'	'
Deficiency Fees	'	6.5

Supplemental_Cash_Flows_Inform2

Supplemental Cash Flows Information (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash Payments [Abstract]	'	'	'
Interest payments, net of capitalized interest	$148	$137	$79
Income tax payments	128	206	70
Increase (Decrease) in Other Receivables	-9	3	28
Non Cash Items Excluded From Statement of Cash Flows [Abstract]	'	'	'
(Increase) decrease in accrued capital expenditures	-75	-124	90
Increase in asset retirement costs	-125	-8	-33
Increase (Decrease) in Other Deposits	$90	$0	$0

Related_Party_Transaction_Deta

Related Party Transaction (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Related Party Transaction [Line Items]	'	'	'
Cash purchase price	$6	'	'
Dividends paid to Huffco on preferred shares	2	7	5
Ownership interest percentage in Bohai Bay Unit	12.00%	'	'
Preferred share dividend percentage retained by Huffco	10.00%	'	'
Payments for Repurchase of Preferred Stock and Preference Stock	$20	$0	$0

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Subsequent Events [Abstract]	'	'
Purchase Price on Disposal of Business	$898	'
Gain (Loss) on Disposition of Business	400	'
Deposit on Disposal of Business	'	$90
Percent of Purchase Price for Deposit on Disposal of Business	'	10.00%

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, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Ceiling test impairment	'	'	'	'	$1,500	'	'	'	$0	$1,488	$0
Income (Loss) from Continuing Operations Attributable to Parent	31	-4	106	-25	-923	-82	64	39	108	-902	401
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	-14	31	5	17	-479	49	71	77	39	-282	138
Net Income (Loss) Attributable to Parent	17	27	111	-8	-1,402	-33	135	116	147	-1,184	539
Income (Loss) from Continuing Operations, Per Basic Share	$0.23	($0.03)	$0.78	($0.19)	($6.86)	($0.61)	$0.47	$0.29	$0.80	($6.70)	$3
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share	($0.10)	$0.08	$0.04	$0.13	($3.53)	$0.37	$0.53	$0.57	$0.14	($2.10)	$1.03
Earnings (Loss) Per Share, Basic	$0.13	$0.05	$0.82	($0.06)	($10.39)	($0.24)	$1	$0.86	$0.94	($8.80)	$4.03
Income (Loss) from Continuing Operations, Per Diluted Share	$0.23	($0.03)	$0.78	($0.19)	($6.86)	($0.61)	$0.47	$0.29	$0.80	($6.70)	$2.97
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share	($0.10)	$0.08	$0.04	$0.13	($3.53)	$0.37	$0.53	$0.57	$0.14	($2.10)	$1.02
Earnings (Loss) Per Share, Diluted	$0.13	$0.05	$0.82	($0.06)	($10.39)	($0.24)	$1	$0.86	$0.94	($8.80)	$3.99
Continuing Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Oil and Gas Revenue	498	486	435	370	352	371	350	403	1,789	1,476	1,742
Ceiling test impairment	'	'	'	'	'	'	'	'	0	1,488	0
Income (loss) from operations	$121	$131	$89	$78	($1,483)	$19	$1	$69	$419	($1,394)	$515

Supplementary_Oil_and_Gas_Disc2

Supplementary Oil and Gas Disclosure (Unaudited) - (Textuals) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MMBTU	MBbls	MBbls
	MBbls
Costs Incurred, Asset Retirement Obligation Incurred	121	$9	$33
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	82,000	86,000	151,000
Percentage of Liquids Comprising Proved Reserves	55.00%	48.00%	40.00%
Percentage of drillling additions related out major, domestic resource plays	98.00%	'	'
Proved Undeveloped Reserves Additions	54	'	'
Proved developed liquids additions	17	'	'
Proved Reserve Revisions Percentage of Beginning Reserves	2.00%	'	'
Proved Reserves Price Related Revisions	10	'	'
Proved Reserve Revisions Development	75	'	'
Proved Undeveloped Reserves Reclassified To Probable Reserves	294,000,000	'	'
Proved Undeveloped Reserves Development Horizon	'5 years 0 months 0 days	'	'
Proved Reserves Performance Related Revisions	14	'	'
Net effect of proved reserve revisions, additions and purchases	96	'	'
Domestic [Member]	'	'	'
Costs of Non Exploitation Activities For Exploration	250	239	237
Malaysia [Member]	'	'	'
Costs of Non Exploitation Activities For Exploration	75	63	9
China [Member]	'	'	'
Costs of Non Exploitation Activities For Exploration	33	$1	$25

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, 2013	Dec. 31, 2012	Dec. 31, 2011
Results Of Operations Income Before Income Taxes Abstract	'	'	'
Revenues	$2,668	$2,560	$2,464
Production costs	390	400	353
Production taxes and other operating expenses	488	451	423
Depreciation, depletion and amortization	930	955	767
Impairment of oil and gas properties	'	1,488	'
Income taxes	304	-250	325
Results of Operations, Oil and Gas Producing Activities Net Income (Excluding Corporate Overhead and Interest Costs), Total	556	-484	596
Domestic [Member]	'	'	'
Results Of Operations Income Before Income Taxes Abstract	'	'	'
Revenues	1,777	1,469	1,735
Production costs	265	292	258
Production taxes and other operating expenses	204	174	161
Depreciation, depletion and amortization	668	683	622
Impairment of oil and gas properties	'	1,488	'
Income taxes	224	-410	243
Results of Operations, Oil and Gas Producing Activities Net Income (Excluding Corporate Overhead and Interest Costs), Total	416	-758	451
Malaysia [Member]	'	'	'
Results Of Operations Income Before Income Taxes Abstract	'	'	'
Revenues	822	1,005	647
Production costs	117	101	90
Production taxes and other operating expenses	272	259	242
Depreciation, depletion and amortization	244	251	126
Impairment of oil and gas properties	'	0	'
Income taxes	72	150	72
Results of Operations, Oil and Gas Producing Activities Net Income (Excluding Corporate Overhead and Interest Costs), Total	117	244	117
China [Member]	'	'	'
Results Of Operations Income Before Income Taxes Abstract	'	'	'
Revenues	69	86	82
Production costs	8	7	5
Production taxes and other operating expenses	12	18	20
Depreciation, depletion and amortization	18	21	19
Impairment of oil and gas properties	'	0	'
Income taxes	8	10	10
Results of Operations, Oil and Gas Producing Activities Net Income (Excluding Corporate Overhead and Interest Costs), Total	$23	$30	$28

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, 2013	Dec. 31, 2012	Dec. 31, 2011
Costs Incurred, Acquisition of Oil and Gas Properties [Abstract]	'	'	'
Costs Incurred, Acquisition of Unproved Oil and Gas Properties	$154	$64	$361
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves	9	3	91
Costs Incurred, Exploration Costs	1,100	993	1,014
Costs Incurred, Development Costs	1,042	853	1,105
Costs Incurred Oil And Gas Property Acquisition Exploration And Development Activities Total	2,305	1,913	2,571
Domestic [Member]	'	'	'
Costs Incurred, Acquisition of Oil and Gas Properties [Abstract]	'	'	'
Costs Incurred, Acquisition of Unproved Oil and Gas Properties	154	64	361
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves	8	3	72
Costs Incurred, Exploration Costs	966	929	980
Costs Incurred, Development Costs	691	659	795
Costs Incurred Oil And Gas Property Acquisition Exploration And Development Activities Total	1,819	1,655	2,208
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	19
Costs Incurred, Exploration Costs	101	63	9
Costs Incurred, Development Costs	211	108	279
Costs Incurred Oil And Gas Property Acquisition Exploration And Development Activities Total	312	171	307
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	1	0	0
Costs Incurred, Exploration Costs	33	1	25
Costs Incurred, Development Costs	140	86	31
Costs Incurred Oil And Gas Property Acquisition Exploration And Development Activities Total	$174	$87	$56

Supplementary_Oil_and_Gas_Disc5

Supplementary Oil and Gas Disclosure (Unaudited) - Other Costs Incurred (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Capitalized costs of oil and gas properties not included in total costs incurred	$23	$2,094	$434
Domestic [Member]	'	'	'
Capitalized Costs Exceeding Ceiling - Effect on Full cost Pool	0	1,488	0
Property sales excluded from cost incurred	$23	$606	$434

Supplementary_Oil_and_Gas_Disc6

Supplementary Oil and Gas Disclosure (Unaudited) - Capitalized Costs (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Capitalized Costs, Oil and Gas Producing Activities, Gross [Abstract]	'	'
Capitalized Costs, Proved Properties	$15,176	$12,736
Capitalized Costs, Unproved Properties	1,231	1,396
Gross oil and gas properties	16,407	14,132
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance Relating to Oil and Gas Producing Activities	-8,306	-7,378
Net oil and gas properties	8,101	6,754
Domestic [Member]	'	'
Capitalized Costs, Oil and Gas Producing Activities, Gross [Abstract]	'	'
Capitalized Costs, Proved Properties	13,185	11,221
Capitalized Costs, Unproved Properties	1,116	1,291
Gross oil and gas properties	14,301	12,512
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance Relating to Oil and Gas Producing Activities	-7,185	-6,535
Net oil and gas properties	7,116	5,977
Malaysia [Member]	'	'
Capitalized Costs, Oil and Gas Producing Activities, Gross [Abstract]	'	'
Capitalized Costs, Proved Properties	1,441	1,140
Capitalized Costs, Unproved Properties	115	104
Gross oil and gas properties	1,556	1,244
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance Relating to Oil and Gas Producing Activities	-1,009	-747
Net oil and gas properties	547	497
China [Member]	'	'
Capitalized Costs, Oil and Gas Producing Activities, Gross [Abstract]	'	'
Capitalized Costs, Proved Properties	550	375
Capitalized Costs, Unproved Properties	0	1
Gross oil and gas properties	550	376
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance Relating to Oil and Gas Producing Activities	-112	-96
Net oil and gas properties	$438	$280

Supplementary_Oil_and_Gas_Disc7

Supplementary Oil and Gas Disclosure (Unaudited) - Standardized Measure (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Cash Inflows	$30,485	$25,664	$31,205	'
Related Future [Abstract]	'	'	'	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Production Costs	10,032	9,065	8,936	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Development Costs	4,457	4,233	4,635	'
DiscountedFutureNetCashFlowsRelatingToProvedOilAndGasReservesBeforeIncomeTaxExpense	15,996	12,366	17,634	'
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	5,833	4,436	5,981	4,754
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Income Tax Expense	4,594	3,091	4,822	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Net Cash Flows, Total	11,402	9,275	12,812	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, 10 Percent Annual Discount for Estimated Timing of Cash Flows	-5,569	-4,839	-6,831	'
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	5,833	4,436	5,981	'
Domestic [Member]	'	'	'	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Cash Inflows	26,600	21,724	26,241	'
Related Future [Abstract]	'	'	'	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Production Costs	8,302	7,042	6,523	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Development Costs	4,166	3,949	4,246	'
DiscountedFutureNetCashFlowsRelatingToProvedOilAndGasReservesBeforeIncomeTaxExpense	14,132	10,733	15,472	'
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	4,628	3,408	4,724	4,058
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Income Tax Expense	4,278	2,786	4,344	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Net Cash Flows, Total	9,854	7,947	11,128	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, 10 Percent Annual Discount for Estimated Timing of Cash Flows	-5,226	-4,539	-6,404	'
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	4,628	3,408	4,724	'
Malaysia [Member]	'	'	'	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Cash Inflows	1,245	1,754	2,751	'
Related Future [Abstract]	'	'	'	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Production Costs	771	1,135	1,563	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Development Costs	148	82	161	'
DiscountedFutureNetCashFlowsRelatingToProvedOilAndGasReservesBeforeIncomeTaxExpense	326	537	1,027	'
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	303	416	692	557
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Income Tax Expense	0	66	210	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Net Cash Flows, Total	326	471	817	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, 10 Percent Annual Discount for Estimated Timing of Cash Flows	-23	-55	-125	'
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	303	416	692	'
China [Member]	'	'	'	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Cash Inflows	2,640	2,186	2,213	'
Related Future [Abstract]	'	'	'	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Production Costs	959	888	850	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Development Costs	143	202	228	'
DiscountedFutureNetCashFlowsRelatingToProvedOilAndGasReservesBeforeIncomeTaxExpense	1,538	1,096	1,135	'
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	902	612	565	139
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Income Tax Expense	316	239	268	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Net Cash Flows, Total	1,222	857	867	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, 10 Percent Annual Discount for Estimated Timing of Cash Flows	-320	-245	-302	'
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	$902	$612	$565	'

Supplementary_Oil_and_Gas_Disc8

Supplementary Oil and Gas Disclosure (Unaudited) - Reserves (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2010
	MBbls	MBbls	MBbls	MBbls	MBbls
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	566,000	652,000	619,000	612,000	'
Revisions of previous estimates	14,000	-91,000	-48,000	'	'
Extensions, discoveries and other additions	80,000	86,000	142,000	'	'
Purchase of properties	2,000	0	9,000	'	'
Sales of properties	-1,000	-30,000	-20,000	'	'
Production	-49,000	-51,000	-50,000	'	'
Proved developed reserves as of:	'	'	'	'	'
Proved developed reserves	337,000	298,000	355,000	'	361,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	275,000	268,000	297,000	'	258,000
Natural Gas [Member]	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	1,755,000	2,333,000	2,492,000	1,648,000	'
Revisions of previous estimates	-166,000	-527,000	-175,000	'	'
Extensions, discoveries and other additions	187,000	181,000	280,000	'	'
Purchase of properties	1,000	1,000	9,000	'	'
Sales of properties	-5,000	-80,000	-91,000	'	'
Production	-124,000	-153,000	-182,000	'	'
Proved developed reserves as of:	'	'	'	'	'
Proved developed reserves	1,055,000	1,042,000	1,409,000	'	1,505,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	593,000	713,000	924,000	'	987,000
Oil [Member]	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	237,000	247,000	198,000	270,000	'
Revisions of previous estimates	28,000	-11,000	-26,000	'	'
Extensions, discoveries and other additions	27,000	38,000	91,000	'	'
Purchase of properties	1,000	0	7,000	'	'
Sales of properties	0	-15,000	-5,000	'	'
Production	-23,000	-22,000	-18,000	'	'
Proved developed reserves as of:	'	'	'	'	'
Proved developed reserves	127,000	110,000	110,000	'	107,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	143,000	127,000	137,000	'	91,000
natural gas liquids	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	37,000	16,000	6,000	68,000	'
Revisions of previous estimates	14,000	9,000	7,000	'	'
Extensions, discoveries and other additions	22,000	17,000	5,000	'	'
Purchase of properties	0	0	0	'	'
Sales of properties	0	-2,000	0	'	'
Production	-5,000	-3,000	-2,000	'	'
Proved developed reserves as of:	'	'	'	'	'
Proved developed reserves	35,000	15,000	10,000	'	3,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	33,000	22,000	6,000	'	3,000
Domestic [Member]	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	532,000	608,000	585,000	576,000	'
Revisions of previous estimates	5,000	-92,000	-46,000	'	'
Extensions, discoveries and other additions	78,000	86,000	123,000	'	'
Purchase of properties	2,000	0	9,000	'	'
Sales of properties	-1,000	-30,000	-20,000	'	'
Production	-40,000	-40,000	-43,000	'	'
Proved developed reserves as of:	'	'	'	'	'
Proved developed reserves	322,000	280,000	332,000	'	341,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	254,000	252,000	276,000	'	244,000
Domestic [Member] | Natural Gas [Member]	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	1,755,000	2,329,000	2,492,000	1,648,000	'
Revisions of previous estimates	-166,000	-525,000	-175,000	'	'
Extensions, discoveries and other additions	187,000	181,000	276,000	'	'
Purchase of properties	1,000	1,000	9,000	'	'
Sales of properties	-5,000	-80,000	-91,000	'	'
Production	-124,000	-151,000	-182,000	'	'
Proved developed reserves as of:	'	'	'	'	'
Proved developed reserves	1,055,000	1,042,000	1,405,000	'	1,505,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	593,000	713,000	924,000	'	987,000
Domestic [Member] | Oil [Member]	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	203,000	204,000	164,000	234,000	'
Revisions of previous estimates	19,000	-13,000	-24,000	'	'
Extensions, discoveries and other additions	25,000	38,000	73,000	'	'
Purchase of properties	1,000	0	7,000	'	'
Sales of properties	0	-15,000	-5,000	'	'
Production	-14,000	-11,000	-11,000	'	'
Proved developed reserves as of:	'	'	'	'	'
Proved developed reserves	112,000	92,000	88,000	'	87,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	122,000	111,000	116,000	'	77,000
Domestic [Member] | natural gas liquids	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	37,000	16,000	6,000	68,000	'
Revisions of previous estimates	14,000	9,000	7,000	'	'
Extensions, discoveries and other additions	22,000	17,000	5,000	'	'
Purchase of properties	0	0	0	'	'
Sales of properties	0	-2,000	0	'	'
Production	-5,000	-3,000	-2,000	'	'
Proved developed reserves as of:	'	'	'	'	'
Proved developed reserves	35,000	15,000	10,000	'	3,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	33,000	22,000	6,000	'	3,000
Malaysia [Member]	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	15,000	24,000	28,000	11,000	'
Revisions of previous estimates	2,000	1,000	-2,000	'	'
Extensions, discoveries and other additions	2,000	0	4,000	'	'
Purchase of properties	0	0	0	'	'
Sales of properties	0	0	0	'	'
Production	-8,000	-10,000	-6,000	'	'
Proved developed reserves as of:	'	'	'	'	'
Proved developed reserves	11,000	14,000	18,000	'	15,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	0	1,000	6,000	'	13,000
Malaysia [Member] | Natural Gas [Member]	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	0	4,000	0	0	'
Revisions of previous estimates	0	-2,000	0	'	'
Extensions, discoveries and other additions	0	0	4,000	'	'
Purchase of properties	0	0	0	'	'
Sales of properties	0	0	0	'	'
Production	0	-2,000	0	'	'
Proved developed reserves as of:	'	'	'	'	'
Proved developed reserves	0	0	4,000	'	0
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	15,000	23,000	28,000	11,000	'
Revisions of previous estimates	2,000	2,000	-2,000	'	'
Extensions, discoveries and other additions	2,000	0	3,000	'	'
Purchase of properties	0	0	0	'	'
Sales of properties	0	0	0	'	'
Production	-8,000	-10,000	-6,000	'	'
Proved developed reserves as of:	'	'	'	'	'
Proved developed reserves	11,000	14,000	17,000	'	15,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	0	1,000	6,000	'	13,000
Malaysia [Member] | natural gas liquids	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	0	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	19,000	20,000	6,000	25,000	'
Revisions of previous estimates	7,000	0	0	'	'
Extensions, discoveries and other additions	0	0	15,000	'	'
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	4,000	4,000	5,000	'	5,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	21,000	15,000	15,000	'	1,000
China [Member] | Natural Gas [Member]	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	0	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	19,000	20,000	6,000	25,000	'
Revisions of previous estimates	7,000	0	0	'	'
Extensions, discoveries and other additions	0	0	15,000	'	'
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	4,000	4,000	5,000	'	5,000
Proved undeveloped reserves as of:	'	'	'	'	'
Proved Undeveloped Reserves	21,000	15,000	15,000	'	1,000
China [Member] | natural gas liquids	'	'	'	'	'
Proved developed and undeveloped reserves as of:	'	'	'	'	'
Beginning balance	0	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, 2013	Dec. 31, 2012
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	$767	$836
5.625% Senior Notes Due 2024 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value of debt	1,025	1,074
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	624	630
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	$755	$749

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, 2013	Dec. 31, 2012	Dec. 31, 2011
Beginning of the Period	$4,436	$5,981	$4,754
Revision of Previous Estimates [Abstract]	'	'	'
Changes in Prices and Costs	979	-1,528	1,002
Changes in Quantities	459	-404	-896
Changes in Future Development Costs	-259	273	-141
Development Costs Incurred During The Period	758	594	700
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs	1,061	815	1,964
Purchases and sales of reserves in place, net	13	-758	-93
Accretion of Discount	585	683	679
Sales of oil and gas, net of production costs	-1,349	-1,631	-1,281
Net change in income taxes	-819	773	-389
Production timing and other	-31	-362	-318
Net increase (decrease)	1,397	-1,545	1,227
Ending Balance	5,833	4,436	5,981
Domestic [Member]	'	'	'
Beginning of the Period	3,408	4,724	4,058
Revision of Previous Estimates [Abstract]	'	'	'
Changes in Prices and Costs	944	-1,490	728
Changes in Quantities	81	-427	-829
Changes in Future Development Costs	-83	294	-31
Development Costs Incurred During The Period	549	434	499
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs	1,012	791	1,366
Purchases and sales of reserves in place, net	13	-758	-93
Accretion of Discount	470	542	591
Sales of oil and gas, net of production costs	-973	-1,129	-1,048
Net change in income taxes	-815	650	-222
Production timing and other	22	-223	-295
Net increase (decrease)	1,220	-1,316	666
Ending Balance	4,628	3,408	4,724
Malaysia [Member]	'	'	'
Beginning of the Period	416	692	557
Revision of Previous Estimates [Abstract]	'	'	'
Changes in Prices and Costs	33	-14	191
Changes in Quantities	76	23	-60
Changes in Future Development Costs	-126	-19	-110
Development Costs Incurred During The Period	79	93	188
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs	49	0	101
Purchases and sales of reserves in place, net	0	0	0
Accretion of Discount	33	64	71
Sales of oil and gas, net of production costs	-330	-439	-197
Net change in income taxes	59	119	-26
Production timing and other	14	-103	-23
Net increase (decrease)	-113	-276	135
Ending Balance	303	416	692
China [Member]	'	'	'
Beginning of the Period	612	565	139
Revision of Previous Estimates [Abstract]	'	'	'
Changes in Prices and Costs	2	-24	83
Changes in Quantities	302	0	-7
Changes in Future Development Costs	-50	-2	0
Development Costs Incurred During The Period	130	67	13
Additions to proved reserves resulting from extensions, discoveries and improved recovery, less related costs	0	24	497
Purchases and sales of reserves in place, net	0	0	0
Accretion of Discount	82	77	17
Sales of oil and gas, net of production costs	-46	-63	-36
Net change in income taxes	-63	4	-141
Production timing and other	-67	-36	0
Net increase (decrease)	290	47	426
Ending Balance	$902	$612	$565