Continental Resources Inc (CLR) 10-Q 6 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Jun. 30, 2014	Aug. 01, 2014
Document Document And Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Jun-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'
Trading Symbol	'CLR	'
Entity Registrant Name	'CONTINENTAL RESOURCES, INC	'
Entity Central Index Key	'0000732834	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	186,109,846

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$776,963	$28,482
Receivables:	'	'
Crude oil and natural gas sales	746,569	643,498
Affiliated parties	15,014	13,107
Joint interest and other, net	386,586	349,579
Derivative assets	0	3,616
Inventories	77,959	54,440
Deferred and prepaid taxes	100,664	44,337
Prepaid expenses and other	19,281	10,207
Total current assets	2,123,036	1,147,266
Net property and equipment, based on successful efforts method of accounting	12,166,106	10,721,272
Net debt issuance costs and other	87,815	72,644
Noncurrent derivative assets	549	0
Total assets	14,377,506	11,941,182
Current liabilities:	'	'
Accounts payable trade	1,044,099	885,289
Revenues and royalties payable	332,914	291,772
Payables to affiliated parties	7,336	5,436
Accrued liabilities and other	207,632	198,113
Derivative liabilities	236,694	90,535
Current portion of long-term debt	300,467	2,011
Total current liabilities	2,129,142	1,473,156
Long-term debt, net of current portion	5,832,872	4,713,821
Other noncurrent liabilities:	'	'
Deferred income tax liabilities	1,984,802	1,736,812
Asset retirement obligations, net of current portion	59,367	54,353
Noncurrent derivative liabilities	63,394	7,829
Other noncurrent liabilities	3,668	2,093
Total other noncurrent liabilities	2,111,231	1,801,087
Commitments and contingencies (Note 7)	'	'
Shareholders’ equity:	'	'
Preferred stock, $0.01 par value; 25,000,000 shares authorized; no shares issued and outstanding	0	0
Common stock, $0.01 par value; 500,000,000 shares authorized; 186,105,662 shares issued and outstanding at June 30, 2014; 185,658,659 shares issued and outstanding at December 31, 2013	1,861	1,857
Additional paid-in capital	1,273,401	1,252,034
Retained earnings	3,028,999	2,699,227
Total shareholders’ equity	4,304,261	3,953,118
Total liabilities and shareholders’ equity	$14,377,506	$11,941,182

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]	'	'
Preferred stock, par value	$0.01	$0.01
Preferred stock, shares authorized	25,000,000	25,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Common stock, par value	$0.01	$0.01
Common stock, shares authorized	500,000,000	500,000,000
Common Stock, Shares, Issued	186,105,662	185,658,659
Common Stock, Shares, Outstanding	186,105,662	185,658,659

Unaudited_Condensed_Consolidat

Unaudited Condensed Consolidated Statements of Income (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues	'	'	'	'
Crude oil and natural gas sales	$1,112,998	$858,029	$2,085,145	$1,614,246
Crude oil and natural gas sales to affiliates	25,087	26,463	55,273	46,177
Gain (loss) on derivative instruments, net	-262,524	199,056	-302,198	114,225
Crude oil and natural gas service operations	10,534	9,509	20,370	21,052
Total revenues	886,095	1,093,057	1,858,590	1,795,700
Operating costs and expenses	'	'	'	'
Production expenses	84,236	73,143	160,211	134,460
Production and other expenses to affiliates	285	309	1,196	795
Production taxes and other expenses	97,025	74,541	175,327	139,384
Exploration expenses	11,205	11,151	16,018	20,965
Crude oil and natural gas service operations	5,979	7,317	14,053	15,914
Depreciation, depletion, amortization and accretion	326,871	236,790	599,732	450,468
Property impairments	79,316	79,712	137,524	119,793
General and administrative expenses	46,919	35,873	90,455	69,690
(Gain) loss on sale of assets, net	-2,135	349	6,363	213
Total operating costs and expenses	649,701	519,185	1,200,879	951,682
Income from operations	236,394	573,872	657,711	844,018
Other income (expense):	'	'	'	'
Interest expense	-72,841	-61,378	-135,816	-108,853
Other	793	634	1,552	1,180
Total other income (expense)	-72,048	-60,744	-134,264	-107,673
Income before income taxes	164,346	513,128	523,447	736,345
Provision for income taxes	60,808	189,858	193,675	272,448
Net income	$103,538	$323,270	$329,772	$463,897
Basic net income per share (in dollars per share)	$0.56	$1.76	$1.79	$2.52
Diluted net income per share (in dollars per share)	$0.56	$1.75	$1.78	$2.51

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Shareholders Equity (USD $)	Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]
In Thousands, except Share data, unless otherwise specified
Balance at Dec. 31, 2013	$3,953,118	$1,857	$1,252,034	$2,699,227
Balance, shares at Dec. 31, 2013	185,658,659	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'
Net income	329,772	'	'	329,772
Stock-based compensation (unaudited)	26,012	'	26,012	'
Restricted stock:	'	'	'	'
Issued (unaudited)	6	6	'	'
Issued (unaudited), shares	'	602,217	'	'
Repurchased and canceled (unaudited)	-4,646	-1	-4,645	'
Repurchased and canceled (unaudited), shares	'	-38,216	'	'
Forfeited (unaudited), shares	'	-116,998	'	'
Forfeitures (unaudited), value	-1	-1	'	'
Common Stock, Shares, Issued	186,105,662	'	'	'
Balance at Jun. 30, 2014	$4,304,261	$1,861	$1,273,401	$3,028,999
Balance, shares at Jun. 30, 2014	186,105,662	'	'	'

Unaudited_Condensed_Consolidat1

Unaudited Condensed Consolidated Statements of Cash Flows (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Cash flows from operating activities	'	'
Net income	$329,772	$463,897
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, depletion, amortization and accretion	606,638	448,639
Property impairments	137,524	119,793
Non-cash (gain) loss on derivatives, net	204,791	-125,787
Stock-based compensation	26,017	18,998
Provision for deferred income taxes	190,571	266,618
Dry hole costs	4,383	8,063
(Gain) loss on sale of assets, net	6,363	213
Other, net	4,411	2,466
Changes in assets and liabilities:	'	'
Accounts receivable	-144,821	-100,542
Inventories	-23,519	4,658
Prepaid expenses and other	-7,938	-6,526
Accounts payable trade	44,505	21,678
Revenues and royalties payable	42,051	12,920
Accrued liabilities and other	9,186	16,018
Other noncurrent assets and liabilities	2,519	5,839
Net cash provided by operating activities	1,432,453	1,156,945
Cash flows from investing activities	'	'
Exploration and development	-2,052,870	-1,823,215
Purchase of producing crude oil and natural gas properties	-33,606	-9,311
Purchase of other property and equipment	-29,829	-18,545
Proceeds from sale of assets	39,018	894
Net cash used in investing activities	-2,077,287	-1,850,177
Cash flows from financing activities	'	'
Credit facility borrowings	1,105,000	440,000
Repayment of credit facility	-1,380,000	-1,035,000
Proceeds from Issuance of Senior Notes	1,681,834	1,479,375
Repayment of other debt	-999	-969
Debt issuance costs	-7,874	-2,231
Repurchase of equity grants	-4,646	-3,259
Net cash provided by financing activities	1,393,315	877,916
Net change in cash and cash equivalents	748,481	184,684
Cash and cash equivalents at beginning of period	28,482	35,729
Cash and cash equivalents at end of period	$776,963	$220,413

Organization_and_Nature_of_Bus

Organization and Nature of Business	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization and Nature of Business	'
	Organization and Nature of Business
	Continental Resources, Inc. (the “Company”) was originally formed in 1967 and is incorporated under the laws of the State of Oklahoma. The Company's principal business is crude oil and natural gas exploration, development and production with properties in the North, South, and East regions of the United States. The North region consists of properties north of Kansas and west of the Mississippi River and includes North Dakota Bakken, Montana Bakken and the Red River units. The South region includes Kansas and all properties south of Kansas and west of the Mississippi River including various plays in the South Central Oklahoma Oil Province (“SCOOP”), Northwest Cana, and Arkoma areas of Oklahoma. The East region is comprised of undeveloped leasehold acreage east of the Mississippi River with no current drilling or production operations.
	The Company’s operations are geographically concentrated in the North region, with that region comprising approximately 74% of the Company’s crude oil and natural gas production and approximately 83% of its crude oil and natural gas revenues for the six months ended June 30, 2014. Our principal producing properties in the North region are located in the Bakken field of North Dakota and Montana. The remainder of the Company's crude oil and natural gas production and revenue is derived from the South region, primarily from producing properties in the emerging SCOOP play in south-central Oklahoma.
	The Company has focused its operations on the exploration and development of crude oil since the 1980s. For the six months ended June 30, 2014, crude oil accounted for approximately 70% of the Company’s total production and approximately 85% of its crude oil and natural gas revenues.

Basis_of_Presentation_and_Sign

Basis of Presentation and Significant Accounting Policies	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Basis of Presentation and Significant Accounting Policies	'
	Basis of Presentation and Significant Accounting Policies
	Basis of presentation
	The condensed consolidated financial statements include the accounts of the Company and its subsidiaries, all of which are 100% owned, after all significant intercompany accounts and transactions have been eliminated upon consolidation.
	This report has been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) applicable to interim financial information. Because this is an interim period filing presented using a condensed format, it does not include all disclosures required by accounting principles generally accepted in the United States (“U.S. GAAP”), although the Company believes the disclosures are adequate to make the information not misleading. You should read this Form 10-Q together with the Company’s Annual Report on Form 10-K for the year ended December 31, 2013 (“2013 Form 10-K”), which includes a summary of the Company’s significant accounting policies and other disclosures.
	The condensed consolidated financial statements as of June 30, 2014 and for the three and six month periods ended June 30, 2014 and 2013 are unaudited. The condensed consolidated balance sheet as of December 31, 2013 was derived from the audited balance sheet included in the 2013 Form 10-K. The Company has evaluated events or transactions through the date this report on Form 10-Q was filed with the SEC in conjunction with its preparation of these condensed consolidated financial statements.
	The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure and estimation of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting periods. Actual results may differ from those estimates. The most significant of the estimates and assumptions that affect reported results are the estimates of the Company’s crude oil and natural gas reserves, which are used to compute depreciation, depletion, amortization and impairment of proved crude oil and natural gas properties. In the opinion of management, all adjustments (consisting only of normal recurring adjustments) necessary for a fair presentation in accordance with U.S. GAAP have been included in these unaudited interim condensed consolidated financial statements. The results of operations for any interim period are not necessarily indicative of the results of operations that may be expected for any other interim period or for an entire year.
	Inventories
	Inventories are stated at the lower of cost or market and consist of the following:
	In thousands	June 30, 2014			December 31, 2013
	Tubular goods and equipment	$	17,892		$	11,139
	Crude oil	60,067			43,301
	Total	$	77,959		$	54,440
	Crude oil inventories are valued at the lower of cost or market using the first-in, first-out inventory method. Crude oil inventories consist of the following volumes:
	MBbls	June 30, 2014		31-Dec-13
	Crude oil line fill and tank requirements	422		370
	Temporarily stored crude oil	624		344
	Total	1,046		714
	Earnings per share
	Basic net income per share is computed by dividing net income by the weighted-average number of shares outstanding for the period. Diluted net income per share reflects the potential dilution of non-vested restricted stock awards, which are calculated using the treasury stock method. The following table presents the calculation of basic and diluted weighted average shares outstanding and net income per share for the three and six months ended June 30, 2014 and 2013.
		Three months ended June 30,					Six months ended June 30,
	In thousands, except per share data	2014			2013		2014		2013
	Income (numerator):
	Net income - basic and diluted	$	103,538		$	323,270	$	329,772	$	463,897
	Weighted average shares (denominator):
	Weighted average shares - basic	184,373			184,039		184,351		184,019
	Non-vested restricted stock	794			700		843		685
	Weighted average shares - diluted	185,167			184,739		185,194		184,704
	Net income per share:
	Basic	$	0.56		$	1.76	$	1.79	$	2.52
	Diluted	$	0.56		$	1.75	$	1.78	$	2.51
	New accounting pronouncement
	In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers (Topic 606). The standard’s core principle is that an entity shall recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The standard generally requires an entity to identify performance obligations in its contracts, estimate the amount of variable consideration to be received in the transaction price, allocate the transaction price to each separate performance obligation, and recognize revenue as obligations are satisfied. The standard will be effective for annual and interim periods beginning after December 15, 2016. The standard allows for either full retrospective adoption, meaning the standard is applied to all periods presented in the financial statements, or modified retrospective adoption, meaning the standard is applied only to the most current period presented. The Company is currently evaluating the impact of the provisions of ASU 2014-09; however, the standard is not expected to have a material effect on the Company’s financial position, results of operations or cash flows.
	Reclassifications
	Certain prior year amounts have been reclassified to conform to the current year presentation. In the prior year, the Company presented charges related to natural gas transportation and processing under the caption “Production taxes and other expenses” or “Production and other expenses to affiliates” in the unaudited condensed consolidated statements of income. Such charges, which totaled $7.7 million for the three months ended June 30, 2013, including transactions with an affiliate totaling $1.2 million, and $15.3 million for the six months ended June 30, 2013, including transactions with an affiliate totaling $2.4 million, have been reclassified to be netted within “Crude oil and natural gas sales” or "Crude oil and natural gas sales to affiliates", as applicable, in order to conform to the current year presentation. The reclassifications had no impact on previously reported operating income, net income, current assets, total assets, current liabilities, total liabilities, stockholders' equity or cash flows.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information	6 Months Ended
	Jun. 30, 2014
Supplemental Cash Flow Elements [Abstract]	'
Supplemental Cash Flow Information	'
	Supplemental Cash Flow Information
	The following table discloses supplemental cash flow information about cash paid for interest and income taxes. Also disclosed is information about investing activities that affects recognized assets and liabilities but does not result in cash receipts or payments.
		Six months ended June 30,
	In thousands	2014			2013
	Supplemental cash flow information:
	Cash paid for interest	$	122,879		$	88,856
	Cash paid for income taxes	2,012			16,883
	Cash received for income tax refunds	(5		)	(173		)
	Non-cash investing activities:
	Increase in accrued capital expenditures	115,956			59,414
	Asset retirement obligation additions and revisions, net	3,710			3,403

Derivative_Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Instruments	'
	Derivative Instruments
	The Company recognizes all derivative instruments on the balance sheet as either assets or liabilities measured at fair value. The Company has not designated its derivative instruments as hedges for accounting purposes and, as a result, marks its derivative instruments to fair value and recognizes the changes in fair value in the unaudited condensed consolidated statements of income under the caption “Gain (loss) on derivative instruments, net.”
	The Company has utilized swap and collar derivative contracts to economically hedge against the variability in cash flows associated with the forecasted sale of future crude oil and natural gas production. While the use of these derivative instruments limits the downside risk of adverse price movements, their use also limits future revenues from upward price movements.
	With respect to a fixed price swap contract, the counterparty is required to make a payment to the Company if the settlement price for any settlement period is less than the swap price, and the Company is required to make a payment to the counterparty if the settlement price for any settlement period is greater than the swap price. For a collar contract, the counterparty is required to make a payment to the Company if the settlement price for any settlement period is below the floor price, the Company is required to make a payment to the counterparty if the settlement price for any settlement period is above the ceiling price, and neither party is required to make a payment to the other party if the settlement price for any settlement period is between the floor price and the ceiling price.
	The Company’s derivative contracts are settled based upon reported settlement prices on commodity exchanges, with crude oil derivative settlements based on NYMEX West Texas Intermediate (“WTI”) pricing or Inter-Continental Exchange (“ICE”) pricing for Brent crude oil and natural gas derivative settlements based on NYMEX Henry Hub pricing. The estimated fair value of derivative contracts is based upon various factors, including commodity exchange prices, over-the-counter quotations, and, in the case of collars, volatility, the risk-free interest rate, and the time to expiration. The calculation of the fair value of collars requires the use of an option-pricing model. See Note 5. Fair Value Measurements.
	At June 30, 2014, the Company had outstanding derivative contracts with respect to future production as set forth in the tables below.
	Crude Oil - NYMEX WTI				Swaps Weighted Average
					Price
	Period and Type of Contract	Bbls
	July 2014 - December 2014
	Swaps - WTI	6,670,000			$	96.22
									Collars
	Crude Oil - ICE Brent				Swaps Weighted Average Price				Floors								Ceilings
													Weighted Average						Weighted Average
	Period and Type of Contract	Bbls							Range				Price				Range		Price
	July 2014 - December 2014
	Swaps - ICE Brent	9,016,000			$	103.29
	Collars - ICE Brent	1,104,000							$90.00 - $95.00				$	90.83			$104.70 - $108.85		$	107.13
	January 2015 - December 2015
	Swaps - ICE Brent	24,637,500			$	100.85
	Collars - ICE Brent	730,000							$	95			$	95			$	107.4	$	107.4
									Collars
	Natural Gas - NYMEX Henry Hub				Swaps Weighted Average Price				Floors						Ceilings
											Weighted Average Price						Weighted Average Price
	Period and Type of Contract	MMBtus							Range						Range
	July 2014 - December 2014
	Swaps - Henry Hub	61,640,000			$	4.2
	January 2015 - December 2015
	Swaps - Henry Hub	24,500,000			$	4.27
	Collars - Henry Hub	29,200,000							$3.50 - $3.75		$	3.69			$4.89 - $5.48		$	5.04
	January 2016 - December 2016
	Swaps - Henry Hub	4,550,000			$	4.27
	Derivative gains and losses
	The following table presents cash settlements on matured derivative instruments and non-cash gains and losses on open derivative instruments for the periods presented. Cash receipts and payments below reflect the gain or loss on derivative contracts which matured during the period, calculated as the difference between the contract price and the market settlement price of matured contracts. Non-cash gains and losses below represent the change in fair value of derivative instruments which continue to be held at period end and the reversal of previously recognized non-cash gains or losses on derivative contracts that matured during the period.
		Three months ended June 30,								Six months ended June 30,
	In thousands	2014				2013				2014				2013
	Cash received (paid) on derivatives:
	Crude oil fixed price swaps	$	(50,499	)		$	2,081			$	(73,022	)		$	(7,512	)
	Crude oil collars	(1,453		)		254				(2,037		)		379
	Natural gas fixed price swaps	(12,191		)		(7,087		)		(22,348		)		(4,429		)
	Cash paid on derivatives, net	(64,143		)		(4,752		)		(97,407		)		(11,562		)
	Non-cash gain (loss) on derivatives:
	Crude oil fixed price swaps	(201,482		)		141,912				(187,792		)		108,548
	Crude oil collars	(4,369		)		15,968				914				2,206
	Natural gas fixed price swaps	7,494				45,928				(17,907		)		15,033
	Natural gas collars	(24		)		—				(6		)		—
	Non-cash gain (loss) on derivatives, net	(198,381		)		203,808				(204,791		)		125,787
	Gain (loss) on derivative instruments, net	$	(262,524	)		$	199,056			$	(302,198	)		$	114,225
	Balance sheet offsetting of derivative assets and liabilities
	All of the Company’s derivative contracts are recorded at fair value in the condensed consolidated balance sheets under the captions “Derivative assets”, “Noncurrent derivative assets”, “Derivative liabilities”, and “Noncurrent derivative liabilities”. Derivative assets and liabilities with the same counterparty that are subject to contractual terms which provide for net settlement are reported on a net basis in the condensed consolidated balance sheets.
	The following table presents the gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the condensed consolidated balance sheets for the periods presented, all at fair value.
	In thousands	30-Jun-14				31-Dec-13
	Commodity derivative assets:
	Gross amounts of recognized assets	$	549			$	4,213
	Gross amounts offset on balance sheet	—				(597		)
	Net amounts of assets on balance sheet	549				3,616
	Commodity derivative liabilities:
	Gross amounts of recognized liabilities	(300,418		)		(125,709		)
	Gross amounts offset on balance sheet	330				27,345
	Net amounts of liabilities on balance sheet	$	(300,088	)		$	(98,364	)
	The following table reconciles the net amounts disclosed above to the individual financial statement line items in the condensed consolidated balance sheets.
	In thousands	June 30, 2014				December 31, 2013
	Derivative assets	$	—			$	3,616
Noncurrent derivative assets	549				—
Net amounts of assets on balance sheet	549				3,616
Derivative liabilities	(236,694		)		(90,535		)
Noncurrent derivative liabilities	(63,394		)		(7,829		)
Net amounts of liabilities on balance sheet	(300,088		)		(98,364		)
Total derivative liabilities, net	$	(299,539	)		$	(94,748	)

Fair_Value_Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	Fair Value Measurements
	The Company follows a three-level valuation hierarchy for disclosure of fair value measurements. The valuation hierarchy categorizes assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. The three levels are defined as follows:
	•	Level 1: Observable inputs that reflect unadjusted quoted prices for identical assets or liabilities in active markets as of the reporting date.
	•	Level 2: Observable market-based inputs or unobservable inputs that are corroborated by market data. These are inputs other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date.
	•	Level 3: Unobservable inputs that are not corroborated by market data and may be used with internally developed methodologies that result in management’s best estimate of fair value.
	A financial instrument’s categorization within the hierarchy is based upon the lowest level of input that is significant to the fair value measurement. Level 1 inputs are given the highest priority in the fair value hierarchy while Level 3 inputs are given the lowest priority. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the hierarchy. As Level 1 inputs generally provide the most reliable evidence of fair value, the Company uses Level 1 inputs when available. The Company’s policy is to recognize transfers between the hierarchy levels as of the beginning of the reporting period in which the event or change in circumstances caused the transfer.
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	The Company's derivative instruments are reported at fair value on a recurring basis. In determining the fair values of fixed price swaps, a discounted cash flow method is used due to the unavailability of relevant comparable market data for the Company’s exact contracts. The discounted cash flow method estimates future cash flows based on quoted market prices for forward commodity prices and a risk-adjusted discount rate. The fair values of fixed price swaps are calculated mainly using significant observable inputs (Level 2). Calculation of the fair values of collar contracts requires the use of an industry-standard option pricing model that considers various inputs including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. These assumptions are observable in the marketplace or can be corroborated by active markets or broker quotes and are therefore designated as Level 2 within the valuation hierarchy. The Company’s calculation of fair value for each of its derivative positions is compared to the counterparty valuation for reasonableness.
	The following tables summarize the valuation of financial instruments by pricing levels that were accounted for at fair value on a recurring basis as of June 30, 2014 and December 31, 2013.
			Fair value measurements at June 30, 2014 using:
	In thousands		Level 1		Level 2			Level 3		Total
	Derivative assets (liabilities):
	Fixed price swaps		$	—	$	(290,591	)	$	—	$	(290,591	)
	Collars		—		(8,948		)	—		(8,948		)
	Total		$	—	$	(299,539	)	$	—	$	(299,539	)
			Fair value measurements at December 31, 2013 using:
	In thousands		Level 1		Level 2			Level 3		Total
	Derivative assets (liabilities):
	Fixed price swaps		$	—	$	(84,893	)	$	—	$	(84,893	)
	Collars		—		(9,855		)	—		(9,855		)
	Total		$	—	$	(94,748	)	$	—	$	(94,748	)
	Assets Measured at Fair Value on a Nonrecurring Basis
	Certain assets are reported at fair value on a nonrecurring basis in the condensed consolidated financial statements. The following methods and assumptions were used to estimate the fair values for those assets.
	Asset Impairments – Proved crude oil and natural gas properties are reviewed for impairment on a field-by-field basis each quarter, or when events and circumstances indicate a possible decline in the recoverability of the carrying value of such field. The estimated future cash flows expected in connection with the field are compared to the carrying amount of the field to determine if the carrying amount is recoverable. If the carrying amount of the field exceeds its estimated undiscounted future cash flows, the carrying amount of the field is reduced to its estimated fair value. Due to the unavailability of relevant comparable market data, a discounted cash flow method is used to determine the fair value of proved properties. The discounted cash flow method estimates future cash flows based on management’s estimates of future crude oil and natural gas production, commodity prices based on commodity futures price strips, operating and development costs, and a risk-adjusted discount rate. The fair value of proved crude oil and natural gas properties is calculated using significant unobservable inputs (Level 3). The following table sets forth quantitative information about the significant unobservable inputs used by the Company to calculate the fair value of proved crude oil and natural gas properties using a discounted cash flow method.
	Unobservable Input		Assumption
	Future production		Future production estimates for each property
	Forward commodity prices		Forward NYMEX swap prices through 2018 (adjusted for differentials), escalating 3% per year thereafter
	Operating and development costs		Estimated costs for the current year, escalating 3% per year thereafter
	Productive life of field		Ranging from 0 to 50 years
	Discount rate		10%
	Unobservable inputs to the fair value assessment are reviewed quarterly and are revised as warranted based on a number of factors, including reservoir performance, new drilling, crude oil and natural gas prices, changes in costs, technological advances, new geological or geophysical data, or other economic factors. Fair value measurements of proved properties are reviewed and approved by certain members of the Company’s management.
	During the periods ended June 30, 2014 and June 30, 2013, the Company determined the carrying amounts of certain proved properties were not recoverable from future cash flows and, therefore, were impaired. Impairments of proved properties amounted to $27.5 million and $31.3 million for the three and six months ended June 30, 2014, respectively, which primarily reflect fair value adjustments made for certain properties in non-core areas of the South region. The impaired properties were written down to their estimated fair value totaling approximately $10.2 million. Impairment provisions for proved properties totaled $39.6 million for the three and six months ended June 30, 2013, primarily reflecting uneconomic results for certain wells drilled in the Niobrara play in Colorado and Wyoming. Those impaired properties were written down to their estimated fair value totaling approximately $22.2 million as of June 30, 2013.
	Certain unproved crude oil and natural gas properties were impaired during the three and six months ended June 30, 2014 and 2013, reflecting recurring amortization of undeveloped leasehold costs on properties that management expects will not be transferred to proved properties over the lives of the leases based on experience of successful drilling and the average holding period.
	The following table sets forth the non-cash impairments of both proved and unproved properties for the indicated periods. Proved and unproved property impairments are recorded under the caption “Property impairments” in the unaudited condensed consolidated statements of income.
			Three months ended June 30,					Six months ended June 30,
	In thousands		2014		2013			2014		2013
	Proved property impairments		$	27,529	$	39,635		$	31,291	$	39,635
	Unproved property impairments		51,787		40,077			106,233		80,158
	Total		$	79,316	$	79,712		$	137,524	$	119,793
	Financial Instruments Not Recorded at Fair Value
	The following table sets forth the fair values of financial instruments that are not recorded at fair value in the condensed consolidated financial statements.
			June 30, 2014					December 31, 2013
	In thousands		Carrying		Fair Value			Carrying		Fair Value
			Amount					Amount
	Debt:
	Credit facility		$	—	$	—		$	275,000	$	275,000
	Note payable		17,471		15,764			18,470		16,500
	8.25% Senior Notes due 2019		298,422		316,950			298,305		327,800
	7.375% Senior Notes due 2020		198,770		223,100			198,695		223,700
	7.125% Senior Notes due 2021		400,000		453,600			400,000		450,300
	5% Senior Notes due 2022		2,024,180		2,172,600			2,025,362		2,063,300
	4.5% Senior Notes due 2023		1,500,000		1,595,250			1,500,000		1,519,400
	3.8% Senior Notes due 2024		996,474		1,009,000			—		—
	4.9% Senior Notes due 2044		698,022		720,930			—		—
	Total debt		$	6,133,339	$	6,507,194		$	4,715,832	$	4,876,000
	The fair value of credit facility borrowings approximates carrying value based on borrowing rates available to the Company for bank loans with similar terms and maturities and is classified as Level 2 in the fair value hierarchy.
	The fair value of the note payable is determined using a discounted cash flow approach based on the interest rate and payment terms of the note payable and an assumed discount rate. The fair value of the note payable is significantly influenced by the discount rate assumption, which is derived by the Company and is unobservable. Accordingly, the fair value of the note payable is classified as Level 3 in the fair value hierarchy.
	The fair values of the 8.25% Senior Notes due 2019 (“2019 Notes”), the 7.375% Senior Notes due 2020 (“2020 Notes”), the 7.125% Senior Notes due 2021 (“2021 Notes”), the 5% Senior Notes due 2022 (“2022 Notes”), the 4.5% Senior Notes due 2023 ("2023 Notes"), the 3.8% Senior Notes due 2024 ("2024 Notes"), and the 4.9% Senior Notes due 2044 ("2044 Notes") are based on quoted market prices and, accordingly, are classified as Level 1 in the fair value hierarchy.
	The carrying values of all classes of cash and cash equivalents, trade receivables, and trade payables are considered to be representative of their respective fair values due to the short term maturities of those instruments.

LongTerm_Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Long-Term Debt	'
	Long-Term Debt
	Long-term debt consists of the following at June 30, 2014 and December 31, 2013:
	In thousands		June 30, 2014			December 31, 2013
	Credit facility		$	—		$	275,000
	Note payable		17,471			18,470
	8.25% Senior Notes due 2019 (1)		298,422			298,305
	7.375% Senior Notes due 2020 (2)		198,770			198,695
	7.125% Senior Notes due 2021 (3)		400,000			400,000
	5% Senior Notes due 2022 (4)		2,024,180			2,025,362
	4.5% Senior Notes due 2023 (3)		1,500,000			1,500,000
	3.8% Senior Notes due 2024 (5)		996,474			—
	4.9% Senior Notes due 2044 (6)		698,022			—
	Total debt		6,133,339			4,715,832
	Less: Current portion of long-term debt (7)		(300,467		)	(2,011		)
	Long-term debt, net of current portion		$	5,832,872		$	4,713,821
	-1	The carrying amount is net of unamortized discounts of $1.6 million and $1.7 million at June 30, 2014 and December 31, 2013, respectively. The 2019 Notes were redeemed on July 11, 2014. See Note 10. Subsequent Event.
	-2	The carrying amount is net of unamortized discounts of $1.2 million and $1.3 million at June 30, 2014 and December 31, 2013, respectively.
	-3	These notes were sold at par and are recorded at 100% of face value.
	-4	The carrying amount includes an unamortized premium of $24.2 million and $25.4 million at June 30, 2014 and December 31, 2013, respectively.
	-5	The carrying amount is net of an unamortized discount of $3.5 million at June 30, 2014.
	-6	The carrying amount is net of an unamortized discount of $2.0 million at June 30, 2014.
	-7	Balance at June 30, 2014 is mainly comprised of the $298.4 million carrying amount of the Company's 2019 Notes that were redeemed on July 11, 2014 as disclosed in Note 10. Subsequent Event.
	Credit Facility
	On May 16, 2014, the Company entered into a new unsecured credit facility (the “New Credit Facility”) that provides for increased aggregate commitments and an extended maturity beyond the term of its previous credit facility. The New Credit Facility matures on May 16, 2019 and has aggregate commitments totaling $1.75 billion, which may be increased up to $4.0 billion in the future upon agreement between the Company and participating lenders. The New Credit Facility replaced the Company’s previous $1.5 billion unsecured credit facility that was due to mature on July 1, 2015.
	The Company had no outstanding borrowings and approximately $1.75 billion of unused commitments on its New Credit Facility at June 30, 2014. Borrowings under the New Credit Facility bear interest at market-based interest rates plus a margin that is based on the terms of the borrowing and the credit ratings assigned to the Company's senior unsecured debt. The Company incurs commitment fees based on currently assigned credit ratings of 0.225% per annum of the daily average amount of unused borrowing availability.
	The New Credit Facility contains certain restrictive covenants including a requirement that the Company maintain a net debt to capitalization ratio of no greater than 0.65 to 1.00. This ratio represents the ratio of net debt (total debt less cash and cash equivalents) divided by the sum of net debt plus total shareholders’ equity. The Company was in compliance with this covenant at June 30, 2014.
	Senior Notes
	On May 19, 2014, the Company issued $1.0 billion of new 3.8% Senior Notes due 2024 and $700 million of new 4.9% Senior Notes due 2044 and received total net proceeds of approximately $1.68 billion after deducting the initial purchasers' fees. The Company used a portion of the net proceeds from the offerings to repay all borrowings then outstanding under its credit facility, which had a balance prior to payoff of $1.01 billion. The remaining net proceeds will be used to fund a portion of the Company's 2014 capital program, to finance the redemption of its 8.25% Senior Notes due 2019 (see Note 10) and for general corporate purposes.
	The following table summarizes the maturity dates, semi-annual interest payment dates, and optional redemption periods related to the Company’s outstanding senior note obligations at June 30, 2014, excluding the 2019 Notes that were redeemed in July 2014 as disclosed in Note 10. Subsequent Event.
			2020 Notes		2021 Notes	2022 Notes		2023 Notes	2024 Notes	2044 Notes
	Maturity date		Oct 1, 2020		April 1, 2021	Sep 15, 2022		April 15, 2023	June 1, 2024	June 1, 2044
	Interest payment dates		April 1, Oct. 1		April 1, Oct. 1	March 15, Sept. 15		April 15, Oct. 15	June 1, Dec. 1	June 1, Dec.1
	Call premium redemption period (1)		Oct 1, 2015		April 1, 2016	March 15, 2017		—	—	—
	Make-whole redemption period (2)		Oct 1, 2015		April 1, 2016	March 15, 2017		Jan 15, 2023	Mar 1, 2024	Dec 1, 2043
	Equity offering redemption period (3)		—		—	March 15, 2015		—	—	—
	-1	On or after these dates, the Company has the option to redeem all or a portion of its senior notes at the decreasing redemption prices specified in the respective senior note indentures (together, the “Indentures”) plus any accrued and unpaid interest to the date of redemption.
	-2	At any time prior to these dates, the Company has the option to redeem all or a portion of its senior notes at the “make-whole” redemption prices or amounts specified in the Indentures plus any accrued and unpaid interest to the date of redemption.
	-3	At any time prior to this date, the Company may redeem up to 35% of the principal amount of its 2022 Notes under certain circumstances with the net cash proceeds from one or more equity offerings at the redemption price specified in the indenture for the 2022 Notes plus any accrued and unpaid interest to the date of redemption.
	The Company’s senior notes are not subject to any mandatory redemption or sinking fund requirements.
	The indentures governing the Company's senior notes contain covenants that, among others, limit the Company's ability to create liens securing certain indebtedness, enter into certain sale-leaseback transactions, and consolidate, merge or transfer certain assets. The senior note covenants are subject to a number of important exceptions and qualifications. The Company was in compliance with these covenants at June 30, 2014. Two of the Company’s subsidiaries, Banner Pipeline Company, L.L.C. and CLR Asset Holdings, LLC, which have no material assets or operations, fully and unconditionally guarantee the senior notes. The Company’s other subsidiaries, the value of whose assets and operations are minor, do not guarantee the senior notes.
	Note Payable
	In February 2012, 20 Broadway Associates LLC, a 100% owned subsidiary of the Company, borrowed $22 million under a 10-year amortizing term loan secured by the Company’s corporate office building in Oklahoma City, Oklahoma. The loan bears interest at a fixed rate of 3.14% per annum. Principal and interest are payable monthly through the loan’s maturity date of February 26, 2022.

Commitments_and_Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	Included below is a discussion of various future commitments of the Company as of June 30, 2014. The commitments under these arrangements are not recorded in the accompanying condensed consolidated balance sheets.
	Drilling commitments – As of June 30, 2014, the Company had drilling rig contracts with various terms extending through July 2018. These contracts were entered into in the ordinary course of business to ensure rig availability to allow the Company to execute its business objectives in its key strategic plays. Future commitments as of June 30, 2014 total approximately $335 million, of which $64 million is expected to be incurred in the remainder of 2014, $92 million in 2015, $86 million in 2016, $65 million in 2017, and $28 million in 2018.
	Pipeline transportation commitments – The Company has entered into firm transportation commitments to guarantee pipeline access capacity on operational crude oil and natural gas pipelines in order to reduce the impact of possible production curtailments that may arise due to limited transportation capacity. The commitments, which have varying terms extending as far as 2024, require the Company to pay per-unit transportation charges regardless of the amount of pipeline capacity used. Future commitments remaining as of June 30, 2014 under the operational pipeline transportation arrangements amount to approximately $91 million, of which $10 million is expected to be incurred in the remainder of 2014, $20 million in 2015, $16 million in 2016, $11 million in 2017, $6 million in 2018, and $28 million thereafter.
	Further, the Company is a party to additional firm transportation commitments for future crude oil and natural gas pipeline projects being constructed or considered for development that are not yet operational. Such projects require the granting of regulatory approvals or otherwise require additional construction efforts by counterparties before being completed. Future commitments under the non-operational arrangements total approximately $1.2 billion at June 30, 2014, which includes approximately $96 million subject to a joint tariff arrangement between an unaffiliated party and an affiliate controlled by the Company's principal shareholder. These commitments represent aggregate transportation charges expected to be incurred over the terms of the arrangements assuming the proposed pipeline projects are completed and become operational. The exact timing of the commencement of pipeline operations is not known due to uncertainties involving matters such as regulatory approvals, resolution of legal and environmental disputes, construction progress, and the ultimate probability of pipeline completion. Accordingly, the timing of the Company’s obligations under these non-operational arrangements cannot be predicted with certainty and may not be incurred on a ratable basis over a calendar year or may not be incurred at all. Although timing is uncertain, operators have indicated that certain pipeline projects may become operational in the fourth quarter of 2014 and first half of 2015, which, if accurate, would obligate the Company for transportation charges totaling $36 million in 2014, $160 million in 2015, $168 million annually in years 2016 through 2018, and $206 million thereafter.
	The Company’s pipeline commitments are for production primarily in the North region where the Company allocates a significant portion of its capital expenditures. The Company is not committed under these contracts to deliver fixed and determinable quantities of crude oil or natural gas in the future.
	Cost sharing commitment – The Company has entered into an arrangement to share certain costs associated with a local utility company's construction and installation of electrical infrastructure that will provide service to parts of North Dakota where the Company operates. This arrangement extends through January 2016 and requires the Company to make scheduled periodic payments based on the projected total cost of the project and the progress of construction. Future commitments under the arrangement as of June 30, 2014 total approximately $16 million, of which $6 million is expected to be incurred in the remainder of 2014, $8 million in 2015, and $2 million in 2016.
	Litigation – In November 2010, an alleged class action was filed against the Company alleging the Company improperly deducted post-production costs from royalties paid to plaintiffs and other royalty interest owners as categorized in the petition from crude oil and natural gas wells located in Oklahoma. The plaintiffs have alleged a number of claims, including breach of contract, fraud, breach of fiduciary duty, unjust enrichment, and other claims and seek recovery of compensatory damages, interest, punitive damages and attorney fees on behalf of the alleged class. The Company has responded to the petition, denied the allegations and raised a number of affirmative defenses. Discovery is ongoing and information and documents continue to be exchanged. The Company is not currently able to estimate a reasonably possible loss or range of loss or what impact, if any, the action will have on its financial condition, results of operations or cash flows due to the preliminary status of the matter, the complexity and number of legal and factual issues presented by the matter and uncertainties with respect to, among other things, the nature of the claims and defenses, the potential size of the class, the scope and types of the properties and agreements involved, the production years involved, and the ultimate potential outcome of the matter. The class has not been certified. Plaintiffs have indicated that if the class is certified they may seek damages in excess of $165 million which may increase with the passage of time, a majority of which would be comprised of interest. The Company disputes plaintiffs’ claims, disputes that the case meets the requirements for a class action and is vigorously defending the case.
	The Company is involved in various other legal proceedings including, but not limited to, commercial disputes, claims from royalty and surface owners, property damage claims, personal injury claims and other matters. While the outcome of these legal matters cannot be predicted with certainty, the Company does not expect them to have a material effect on its financial condition, results of operations or cash flows. As of June 30, 2014 and December 31, 2013, the Company had recorded a liability in the condensed consolidated balance sheets under the caption “Other noncurrent liabilities” of $2.9 million and $1.7 million, respectively, for various matters, none of which are believed to be individually significant.
	Environmental risk – Due to the nature of the crude oil and natural gas business, the Company is exposed to possible environmental risks. The Company is not aware of any material environmental issues or claims.

StockBased_Compensation

Stock-Based Compensation	6 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Stock-Based Compensation	'
	Stock-Based Compensation
	The Company has granted restricted stock to employees and directors pursuant to the Continental Resources, Inc. 2005 Long-Term Incentive Plan (“2005 Plan”) and 2013 Long-Term Incentive Plan ("2013 Plan") as discussed below. The Company’s associated compensation expense, which is included in the caption “General and administrative expenses” in the unaudited condensed consolidated statements of income, is reflected in the table below for the periods presented.
		Three months ended June 30,					Six months ended June 30,
	In thousands	2014			2013		2014		2013
	Non-cash equity compensation	$	14,978		$	9,756	$	26,017	$	18,998
	In May 2013, the Company adopted the 2013 Plan and reserved a maximum of 9,840,036 shares of common stock that may be issued pursuant to the plan. The 2013 Plan replaced the Company's 2005 Plan as the instrument used to grant long-term incentive awards and no further awards will be granted under the 2005 Plan. However, restricted stock awards granted under the 2005 Plan prior to the adoption of the 2013 Plan will remain outstanding in accordance with their terms. As of June 30, 2014, the Company had a maximum of 9,091,028 shares of restricted stock available to grant to officers, directors and select employees under the 2013 Plan.
	Restricted stock is awarded in the name of the recipient and constitutes issued and outstanding shares of the Company’s common stock for all corporate purposes during the period of restriction and, except as otherwise provided under the 2013 Plan or agreement relevant to a given award, includes the right to vote the restricted stock or to receive dividends, subject to forfeiture. Restricted stock grants generally vest over periods ranging from one to three years.
	A summary of changes in non-vested restricted shares outstanding for the six months ended June 30, 2014 is presented below:
		Number of		Weighted
		non-vested		average
		shares		grant-date
				fair value
	Non-vested restricted shares outstanding at December 31, 2013	1,357,156		$	74.99
	Granted	602,217		122.41
	Vested	(131,556	)	73.29
	Forfeited	(116,998	)	85.06
	Non-vested restricted shares outstanding at June 30, 2014	1,710,819		$	91.12
	The grant date fair value of restricted stock represents the closing market price of the Company’s common stock on the date of grant. Compensation expense for a restricted stock grant is a fixed amount determined at the grant date fair value and is recognized ratably over the vesting period as services are rendered by employees and directors. The expected life of restricted stock is based on the non-vested period that remains subsequent to the date of grant. There are no post-vesting restrictions related to the Company’s restricted stock. The fair value of restricted stock that vested during the six months ended June 30, 2014 at the vesting date was approximately $16.1 million. As of June 30, 2014, there was approximately $96 million of unrecognized compensation expense related to non-vested restricted stock. This expense is expected to be recognized ratably over a weighted average period of 1.5 years.

Basis_of_Presentation_and_Sign1

Basis of Presentation and Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Description of the Company	'
	Continental Resources, Inc. (the “Company”) was originally formed in 1967 and is incorporated under the laws of the State of Oklahoma. The Company's principal business is crude oil and natural gas exploration, development and production with properties in the North, South, and East regions of the United States. The North region consists of properties north of Kansas and west of the Mississippi River and includes North Dakota Bakken, Montana Bakken and the Red River units. The South region includes Kansas and all properties south of Kansas and west of the Mississippi River including various plays in the South Central Oklahoma Oil Province (“SCOOP”), Northwest Cana, and Arkoma areas of Oklahoma. The East region is comprised of undeveloped leasehold acreage east of the Mississippi River with no current drilling or production operations.
	The Company’s operations are geographically concentrated in the North region, with that region comprising approximately 74% of the Company’s crude oil and natural gas production and approximately 83% of its crude oil and natural gas revenues for the six months ended June 30, 2014. Our principal producing properties in the North region are located in the Bakken field of North Dakota and Montana. The remainder of the Company's crude oil and natural gas production and revenue is derived from the South region, primarily from producing properties in the emerging SCOOP play in south-central Oklahoma.
	The Company has focused its operations on the exploration and development of crude oil since the 1980s. For the six months ended June 30, 2014, crude oil accounted for approximately 70% of the Company’s total production and approximately 85% of its crude oil and natural gas revenues.
Basis of Presentation	'
	Basis of presentation
	The condensed consolidated financial statements include the accounts of the Company and its subsidiaries, all of which are 100% owned, after all significant intercompany accounts and transactions have been eliminated upon consolidation.
	This report has been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) applicable to interim financial information. Because this is an interim period filing presented using a condensed format, it does not include all disclosures required by accounting principles generally accepted in the United States (“U.S. GAAP”), although the Company believes the disclosures are adequate to make the information not misleading. You should read this Form 10-Q together with the Company’s Annual Report on Form 10-K for the year ended December 31, 2013 (“2013 Form 10-K”), which includes a summary of the Company’s significant accounting policies and other disclosures.
	The condensed consolidated financial statements as of June 30, 2014 and for the three and six month periods ended June 30, 2014 and 2013 are unaudited. The condensed consolidated balance sheet as of December 31, 2013 was derived from the audited balance sheet included in the 2013 Form 10-K. The Company has evaluated events or transactions through the date this report on Form 10-Q was filed with the SEC in conjunction with its preparation of these condensed consolidated financial statements.
	The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure and estimation of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting periods. Actual results may differ from those estimates. The most significant of the estimates and assumptions that affect reported results are the estimates of the Company’s crude oil and natural gas reserves, which are used to compute depreciation, depletion, amortization and impairment of proved crude oil and natural gas properties. In the opinion of management, all adjustments (consisting only of normal recurring adjustments) necessary for a fair presentation in accordance with U.S. GAAP have been included in these unaudited interim condensed consolidated financial statements. The results of operations for any interim period are not necessarily indicative of the results of operations that may be expected for any other interim period or for an entire year.
Inventories	'
	Inventories
	Inventories are stated at the lower of cost or market and consist of the following:
	In thousands	June 30, 2014			December 31, 2013
	Tubular goods and equipment	$	17,892		$	11,139
	Crude oil	60,067			43,301
	Total	$	77,959		$	54,440
	Crude oil inventories are valued at the lower of cost or market using the first-in, first-out inventory method. Crude oil inventories consist of the following volumes:
	MBbls	June 30, 2014		31-Dec-13
	Crude oil line fill and tank requirements	422		370
	Temporarily stored crude oil	624		344
	Total	1,046		714
Earnings Per Share	'
	Earnings per share
	Basic net income per share is computed by dividing net income by the weighted-average number of shares outstanding for the period. Diluted net income per share reflects the potential dilution of non-vested restricted stock awards, which are calculated using the treasury stock method.

Basis_of_Presentation_and_Sign2

Basis of Presentation and Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Components of Inventories	'
	Inventories are stated at the lower of cost or market and consist of the following:
	In thousands	June 30, 2014			December 31, 2013
	Tubular goods and equipment	$	17,892		$	11,139
	Crude oil	60,067			43,301
	Total	$	77,959		$	54,440
Components of Crude Oil Inventories Volumes	'
	Crude oil inventories consist of the following volumes:
	MBbls	June 30, 2014		31-Dec-13
	Crude oil line fill and tank requirements	422		370
	Temporarily stored crude oil	624		344
	Total	1,046		714
Calculation of Basic and Diluted Weighted Average Shares and Net Income Per Share	'
	The following table presents the calculation of basic and diluted weighted average shares outstanding and net income per share for the three and six months ended June 30, 2014 and 2013.
		Three months ended June 30,					Six months ended June 30,
	In thousands, except per share data	2014			2013		2014		2013
	Income (numerator):
	Net income - basic and diluted	$	103,538		$	323,270	$	329,772	$	463,897
	Weighted average shares (denominator):
	Weighted average shares - basic	184,373			184,039		184,351		184,019
	Non-vested restricted stock	794			700		843		685
	Weighted average shares - diluted	185,167			184,739		185,194		184,704
	Net income per share:
	Basic	$	0.56		$	1.76	$	1.79	$	2.52
	Diluted	$	0.56		$	1.75	$	1.78	$	2.51

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2014
Supplemental Cash Flow Elements [Abstract]	'
Summary of Supplemental Cash Flow Information	'
	The following table discloses supplemental cash flow information about cash paid for interest and income taxes. Also disclosed is information about investing activities that affects recognized assets and liabilities but does not result in cash receipts or payments.
		Six months ended June 30,
	In thousands	2014			2013
	Supplemental cash flow information:
	Cash paid for interest	$	122,879		$	88,856
	Cash paid for income taxes	2,012			16,883
	Cash received for income tax refunds	(5		)	(173		)
	Non-cash investing activities:
	Increase in accrued capital expenditures	115,956			59,414
	Asset retirement obligation additions and revisions, net	3,710			3,403

Derivative_Instruments_Tables

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Summary of Outstanding Contracts with Respect to Natural Gas	'
									Collars
	Natural Gas - NYMEX Henry Hub				Swaps Weighted Average Price				Floors						Ceilings
											Weighted Average Price						Weighted Average Price
	Period and Type of Contract	MMBtus							Range						Range
	July 2014 - December 2014
	Swaps - Henry Hub	61,640,000			$	4.2
	January 2015 - December 2015
	Swaps - Henry Hub	24,500,000			$	4.27
	Collars - Henry Hub	29,200,000							$3.50 - $3.75		$	3.69			$4.89 - $5.48		$	5.04
	January 2016 - December 2016
	Swaps - Henry Hub	4,550,000			$	4.27
Cash and Non-Cash Gains and Losses on Derivative Instruments	'
	The following table presents cash settlements on matured derivative instruments and non-cash gains and losses on open derivative instruments for the periods presented. Cash receipts and payments below reflect the gain or loss on derivative contracts which matured during the period, calculated as the difference between the contract price and the market settlement price of matured contracts. Non-cash gains and losses below represent the change in fair value of derivative instruments which continue to be held at period end and the reversal of previously recognized non-cash gains or losses on derivative contracts that matured during the period.
		Three months ended June 30,								Six months ended June 30,
	In thousands	2014				2013				2014				2013
	Cash received (paid) on derivatives:
	Crude oil fixed price swaps	$	(50,499	)		$	2,081			$	(73,022	)		$	(7,512	)
	Crude oil collars	(1,453		)		254				(2,037		)		379
	Natural gas fixed price swaps	(12,191		)		(7,087		)		(22,348		)		(4,429		)
	Cash paid on derivatives, net	(64,143		)		(4,752		)		(97,407		)		(11,562		)
	Non-cash gain (loss) on derivatives:
	Crude oil fixed price swaps	(201,482		)		141,912				(187,792		)		108,548
	Crude oil collars	(4,369		)		15,968				914				2,206
	Natural gas fixed price swaps	7,494				45,928				(17,907		)		15,033
	Natural gas collars	(24		)		—				(6		)		—
	Non-cash gain (loss) on derivatives, net	(198,381		)		203,808				(204,791		)		125,787
	Gain (loss) on derivative instruments, net	$	(262,524	)		$	199,056			$	(302,198	)		$	114,225
Gross Amounts of Recognized Derivative Assets and Liabilities	'
	The following table presents the gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the condensed consolidated balance sheets for the periods presented, all at fair value.
	In thousands	30-Jun-14				31-Dec-13
	Commodity derivative assets:
	Gross amounts of recognized assets	$	549			$	4,213
	Gross amounts offset on balance sheet	—				(597		)
	Net amounts of assets on balance sheet	549				3,616
	Commodity derivative liabilities:
	Gross amounts of recognized liabilities	(300,418		)		(125,709		)
	Gross amounts offset on balance sheet	330				27,345
	Net amounts of liabilities on balance sheet	$	(300,088	)		$	(98,364	)
Reconciles Net Amounts Derivative Assets and Liabilities	'
	The following table reconciles the net amounts disclosed above to the individual financial statement line items in the condensed consolidated balance sheets.
	In thousands	June 30, 2014				December 31, 2013
	Derivative assets	$	—			$	3,616
	Noncurrent derivative assets	549				—
	Net amounts of assets on balance sheet	549				3,616
	Derivative liabilities	(236,694		)		(90,535		)
	Noncurrent derivative liabilities	(63,394		)		(7,829		)
	Net amounts of liabilities on balance sheet	(300,088		)		(98,364		)
	Total derivative liabilities, net	$	(299,539	)		$	(94,748	)
NYMEX WTI [Member]	'
Summary of Outstanding Contracts with Respect to Crude Oil	'
	At June 30, 2014, the Company had outstanding derivative contracts with respect to future production as set forth in the tables below.
	Crude Oil - NYMEX WTI				Swaps Weighted Average
					Price
	Period and Type of Contract	Bbls
	July 2014 - December 2014
	Swaps - WTI	6,670,000			$	96.22
ICE Brent [Member]	'
Summary of Outstanding Contracts with Respect to Crude Oil	'
									Collars
	Crude Oil - ICE Brent				Swaps Weighted Average Price				Floors								Ceilings
													Weighted Average						Weighted Average
	Period and Type of Contract	Bbls							Range				Price				Range		Price
	July 2014 - December 2014
	Swaps - ICE Brent	9,016,000			$	103.29
	Collars - ICE Brent	1,104,000							$90.00 - $95.00				$	90.83			$104.70 - $108.85		$	107.13
	January 2015 - December 2015
	Swaps - ICE Brent	24,637,500			$	100.85
	Collars - ICE Brent	730,000							$	95			$	95			$	107.4	$	107.4

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Valuation of Financial Instruments by Pricing Levels	'
	The following tables summarize the valuation of financial instruments by pricing levels that were accounted for at fair value on a recurring basis as of June 30, 2014 and December 31, 2013.
		Fair value measurements at June 30, 2014 using:
	In thousands	Level 1		Level 2			Level 3		Total
	Derivative assets (liabilities):
	Fixed price swaps	$	—	$	(290,591	)	$	—	$	(290,591	)
	Collars	—		(8,948		)	—		(8,948		)
	Total	$	—	$	(299,539	)	$	—	$	(299,539	)
		Fair value measurements at December 31, 2013 using:
	In thousands	Level 1		Level 2			Level 3		Total
	Derivative assets (liabilities):
	Fixed price swaps	$	—	$	(84,893	)	$	—	$	(84,893	)
	Collars	—		(9,855		)	—		(9,855		)
	Total	$	—	$	(94,748	)	$	—	$	(94,748	)
Quantitative Information about Significant Unobservable Inputs	'
	The following table sets forth quantitative information about the significant unobservable inputs used by the Company to calculate the fair value of proved crude oil and natural gas properties using a discounted cash flow method.
	Unobservable Input	Assumption
	Future production	Future production estimates for each property
	Forward commodity prices	Forward NYMEX swap prices through 2018 (adjusted for differentials), escalating 3% per year thereafter
	Operating and development costs	Estimated costs for the current year, escalating 3% per year thereafter
	Productive life of field	Ranging from 0 to 50 years
	Discount rate	10%
Property Impairments	'
		Three months ended June 30,					Six months ended June 30,
	In thousands	2014		2013			2014		2013
	Proved property impairments	$	27,529	$	39,635		$	31,291	$	39,635
	Unproved property impairments	51,787		40,077			106,233		80,158
	Total	$	79,316	$	79,712		$	137,524	$	119,793
Fair Values of Financial Instruments not Recorded at Fair Value	'
	The following table sets forth the fair values of financial instruments that are not recorded at fair value in the condensed consolidated financial statements.
		June 30, 2014					December 31, 2013
	In thousands	Carrying		Fair Value			Carrying		Fair Value
		Amount					Amount
	Debt:
	Credit facility	$	—	$	—		$	275,000	$	275,000
	Note payable	17,471		15,764			18,470		16,500
	8.25% Senior Notes due 2019	298,422		316,950			298,305		327,800
	7.375% Senior Notes due 2020	198,770		223,100			198,695		223,700
	7.125% Senior Notes due 2021	400,000		453,600			400,000		450,300
	5% Senior Notes due 2022	2,024,180		2,172,600			2,025,362		2,063,300
	4.5% Senior Notes due 2023	1,500,000		1,595,250			1,500,000		1,519,400
	3.8% Senior Notes due 2024	996,474		1,009,000			—		—
	4.9% Senior Notes due 2044	698,022		720,930			—		—
	Total debt	$	6,133,339	$	6,507,194		$	4,715,832	$	4,876,000

LongTerm_Debt_Tables

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Summary of Maturity Dates, Semi-Annual Interest Payment Dates, and Optional Redemption Periods of Outstanding Senior Note Obligations	'
	The following table summarizes the maturity dates, semi-annual interest payment dates, and optional redemption periods related to the Company’s outstanding senior note obligations at June 30, 2014, excluding the 2019 Notes that were redeemed in July 2014 as disclosed in Note 10. Subsequent Event.
			2020 Notes		2021 Notes	2022 Notes		2023 Notes	2024 Notes	2044 Notes
	Maturity date		Oct 1, 2020		April 1, 2021	Sep 15, 2022		April 15, 2023	June 1, 2024	June 1, 2044
	Interest payment dates		April 1, Oct. 1		April 1, Oct. 1	March 15, Sept. 15		April 15, Oct. 15	June 1, Dec. 1	June 1, Dec.1
	Call premium redemption period (1)		Oct 1, 2015		April 1, 2016	March 15, 2017		—	—	—
	Make-whole redemption period (2)		Oct 1, 2015		April 1, 2016	March 15, 2017		Jan 15, 2023	Mar 1, 2024	Dec 1, 2043
	Equity offering redemption period (3)		—		—	March 15, 2015		—	—	—
	-1	On or after these dates, the Company has the option to redeem all or a portion of its senior notes at the decreasing redemption prices specified in the respective senior note indentures (together, the “Indentures”) plus any accrued and unpaid interest to the date of redemption.
	-2	At any time prior to these dates, the Company has the option to redeem all or a portion of its senior notes at the “make-whole” redemption prices or amounts specified in the Indentures plus any accrued and unpaid interest to the date of redemption.
	-3	At any time prior to this date, the Company may redeem up to 35% of the principal amount of its 2022 Notes under certain circumstances with the net cash proceeds from one or more equity offerings at the redemption price specified in the indenture for the 2022 Notes plus any accrued and unpaid interest to the date of redemption.
Schedule of Long-term Debt Instruments [Table Text Block]	'
	Long-term debt consists of the following at June 30, 2014 and December 31, 2013:
	In thousands		June 30, 2014			December 31, 2013
	Credit facility		$	—		$	275,000
	Note payable		17,471			18,470
	8.25% Senior Notes due 2019 (1)		298,422			298,305
	7.375% Senior Notes due 2020 (2)		198,770			198,695
	7.125% Senior Notes due 2021 (3)		400,000			400,000
	5% Senior Notes due 2022 (4)		2,024,180			2,025,362
	4.5% Senior Notes due 2023 (3)		1,500,000			1,500,000
	3.8% Senior Notes due 2024 (5)		996,474			—
	4.9% Senior Notes due 2044 (6)		698,022			—
	Total debt		6,133,339			4,715,832
	Less: Current portion of long-term debt (7)		(300,467		)	(2,011		)
	Long-term debt, net of current portion		$	5,832,872		$	4,713,821
	-1	The carrying amount is net of unamortized discounts of $1.6 million and $1.7 million at June 30, 2014 and December 31, 2013, respectively. The 2019 Notes were redeemed on July 11, 2014. See Note 10. Subsequent Event.
	-2	The carrying amount is net of unamortized discounts of $1.2 million and $1.3 million at June 30, 2014 and December 31, 2013, respectively.
	-3	These notes were sold at par and are recorded at 100% of face value.
	-4	The carrying amount includes an unamortized premium of $24.2 million and $25.4 million at June 30, 2014 and December 31, 2013, respectively.
	-5	The carrying amount is net of an unamortized discount of $3.5 million at June 30, 2014.
	-6	The carrying amount is net of an unamortized discount of $2.0 million at June 30, 2014.
	-7	Balance at June 30, 2014 is mainly comprised of the $298.4 million carrying amount of the Company's 2019 Notes that were redeemed on July 11, 2014 as disclosed in Note 10. Subsequent Event.

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2014
Stock-Based Compensation Expense	'
	The Company has granted restricted stock to employees and directors pursuant to the Continental Resources, Inc. 2005 Long-Term Incentive Plan (“2005 Plan”) and 2013 Long-Term Incentive Plan ("2013 Plan") as discussed below. The Company’s associated compensation expense, which is included in the caption “General and administrative expenses” in the unaudited condensed consolidated statements of income, is reflected in the table below for the periods presented.
		Three months ended June 30,					Six months ended June 30,
	In thousands	2014			2013		2014		2013
	Non-cash equity compensation	$	14,978		$	9,756	$	26,017	$	18,998
Restricted stock [Member]	'
Summary of Changes in Non-vested Shares of Restricted Stock Outstanding	'
	A summary of changes in non-vested restricted shares outstanding for the six months ended June 30, 2014 is presented below:
		Number of		Weighted
		non-vested		average
		shares		grant-date
				fair value
	Non-vested restricted shares outstanding at December 31, 2013	1,357,156		$	74.99
	Granted	602,217		122.41
	Vested	(131,556	)	73.29
	Forfeited	(116,998	)	85.06
	Non-vested restricted shares outstanding at June 30, 2014	1,710,819		$	91.12

Organization_and_Nature_of_Bus1

Organization and Nature of Business - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Percentage of operations concentrated in geographic areas	74.00%
Percentage of revenues concentrated in geographic areas	83.00%
Percentage of crude oil and natural gas production concentrated in crude oil	70.00%
Percentage of crude oil and natural gas revenue concentrated in crude oil	85.00%

Basis_of_Presentation_and_Sign3

Basis of Presentation and Significant Accounting Policies - Components of Inventories (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Accounting Policies [Abstract]	'	'
Tubular goods and equipment	$17,892	$11,139
Crude oil	60,067	43,301
Total	$77,959	$54,440

Basis_of_Presentation_and_Sign4

Basis of Presentation and Significant Accounting Policies - Components of Crude Oil Inventories Volumes (Detail)	Jun. 30, 2014	Dec. 31, 2013
	bbl	bbl
Accounting Policies [Abstract]	'	'
Crude oil line fill and tank requirements	422,000	370,000
Temporarily stored crude oil	624,000	344,000
Total	1,046,000	714,000

Basis_of_Presentation_and_Sign5

Basis of Presentation and Significant Accounting Policies - Earnings Per Share (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Income (numerator):	'	'	'	'
Net income - basic and diluted	$103,538	$323,270	$329,772	$463,897
Weighted average shares - basic	184,373	184,039	184,351	184,019
Non-vested restricted stock	794	700	843	685
Weighted average shares - diluted	185,167	184,739	185,194	184,704
Net income per share:	'	'	'	'
Basic (in dollars per share)	$0.56	$1.76	$1.79	$2.52
Diluted (in dollars per share)	$0.56	$1.75	$1.78	$2.51

Basis_of_Presentation_and_Sign6

Basis of Presentation and Significant Accounting Policies Basis of Presentation and Significant Accounting Policies - Reclassifications (Details) (USD $)	3 Months Ended	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2013	Jun. 30, 2013
Reclassified Gas Transportation Charges [Line Items]	'	'
Reclassified Gas Transportation Charges	$7.70	$15.30
Affiliated Entity [Member]	'	'
Reclassified Gas Transportation Charges [Line Items]	'	'
Reclassified Gas Transportation Charges	$1.20	$2.40

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information (Detail) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Noncash Investing Activities [Abstract]	'	'
Increase in accrued capital expenditures	$115,956	$59,414
Asset retirement obligation additions and revisions, net	3,710	3,403
Supplemental Cash Flow Elements [Abstract]	'	'
Cash paid for interest	122,879	88,856
Cash paid for income taxes	2,012	16,883
Cash received for income tax refunds	($5)	($173)

Derivative_Instruments_Summary

Derivative Instruments - Summary of Outstanding Contracts with Respect to Crude Oil (Detail)	6 Months Ended
	Jun. 30, 2014
	bbl
West Texas Intermediate [Member] | July 2014 to December 2014 Swaps [Member]	'
Derivative [Line Items]	'
Oil Production Derivative Volume	6,670,000
Swaps Weighted Average Price	96.22
ICE Brent [Member] | July 2014 to December 2014 Swaps [Member]	'
Derivative [Line Items]	'
Oil Production Derivative Volume	9,016,000
Swaps Weighted Average Price	103.29
ICE Brent [Member] | July 2014 to December 2014 Collars [Member]	'
Derivative [Line Items]	'
Oil Production Derivative Volume	1,104,000
Floors, Weighted Average Price	90.83
Ceilings, Weighted Average Price	107.13
ICE Brent [Member] | January 2015 - December 2015 Swaps [Member]	'
Derivative [Line Items]	'
Oil Production Derivative Volume	24,637,500
Swaps Weighted Average Price	100.85
ICE Brent [Member] | January 2015 to December 2015 Collars [Member]	'
Derivative [Line Items]	'
Oil Production Derivative Volume	730,000
Floors, Weighted Average Price	95
Ceilings, Weighted Average Price	107.4
ICE Brent [Member] | Minimum [Member] | July 2014 to December 2014 Collars [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	90
Derivative, Cap Price	104.7
ICE Brent [Member] | Minimum [Member] | January 2015 to December 2015 Collars [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	95
Derivative, Cap Price	107.4
ICE Brent [Member] | Maximum [Member] | July 2014 to December 2014 Collars [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	95
Derivative, Cap Price	108.85
ICE Brent [Member] | Maximum [Member] | January 2015 to December 2015 Collars [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	95
Derivative, Cap Price	107.4

Derivative_Instruments_Summary1

Derivative Instruments - Summary of Outstanding Contracts with Respect to Natural Gas (Detail) (Natural Gas [Member])	6 Months Ended
	Jun. 30, 2014
	MMBTU
July 2014 to December 2014 Swaps [Member]	'
Derivative [Line Items]	'
Natural Gas Production Derivative Volume, MMBtus	61,640,000
Swaps Weighted Average Price	4.2
January 2015 - December 2015 Swaps [Member]	'
Derivative [Line Items]	'
Natural Gas Production Derivative Volume, MMBtus	24,500,000
Swaps Weighted Average Price	4.27
January 2015 to December 2015 Collars [Member]	'
Derivative [Line Items]	'
Natural Gas Production Derivative Volume, MMBtus	29,200,000
Floors, Weighted Average Price	3.69
Ceilings, Weighted Average Price	5.04
January 2016 to December 2016 Swaps [Member]	'
Derivative [Line Items]	'
Natural Gas Production Derivative Volume, MMBtus	4,550,000
Swaps Weighted Average Price	4.27
Minimum [Member] | January 2015 to December 2015 Collars [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	3.5
Derivative, Cap Price	4.89
Maximum [Member] | January 2015 to December 2015 Collars [Member]	'
Derivative [Line Items]	'
Derivative, Floor Price	3.75
Derivative, Cap Price	5.48

Derivative_Instruments_Cash_an

Derivative Instruments - Cash and Non-Cash Gains and Losses on Derivative Instruments (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Cash received (paid) on derivatives:	'	'	'	'
Cash received (paid) on derivatives, net	($64,143)	($4,752)	($97,407)	($11,562)
Non-cash gain (loss) on derivatives:	'	'	'	'
Non-cash gain (loss) on derivatives, net	-198,381	203,808	-204,791	125,787
Gain (loss) on derivative instruments, net	-262,524	199,056	-302,198	114,225
Fixed price swaps | Crude Oil [Member]	'	'	'	'
Cash received (paid) on derivatives:	'	'	'	'
Cash received (paid) on derivatives, net	-50,499	2,081	-73,022	-7,512
Non-cash gain (loss) on derivatives:	'	'	'	'
Non-cash gain (loss) on derivatives, net	-201,482	141,912	-187,792	108,548
Fixed price swaps | Natural Gas [Member]	'	'	'	'
Cash received (paid) on derivatives:	'	'	'	'
Cash received (paid) on derivatives, net	-12,191	-7,087	-22,348	-4,429
Non-cash gain (loss) on derivatives:	'	'	'	'
Non-cash gain (loss) on derivatives, net	7,494	45,928	-17,907	15,033
Collars | Crude Oil [Member]	'	'	'	'
Cash received (paid) on derivatives:	'	'	'	'
Cash received (paid) on derivatives, net	-1,453	254	-2,037	379
Non-cash gain (loss) on derivatives:	'	'	'	'
Non-cash gain (loss) on derivatives, net	-4,369	15,968	914	2,206
Collars | Natural Gas [Member]	'	'	'	'
Non-cash gain (loss) on derivatives:	'	'	'	'
Non-cash gain (loss) on derivatives, net	($24)	$0	($6)	$0

Derivative_Instruments_Gross_A

Derivative Instruments - Gross Amounts of Recognized Derivative Assets and Liabilities (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'
Gross amounts of recognized assets	$549	$4,213
Gross amounts offset on balance sheet	0	-597
Net amounts of assets on balance sheet	549	3,616
Gross amounts of recognized liabilities	-300,418	-125,709
Gross amounts offset on balance sheet	330	27,345
Net amounts of liabilities on balance sheet	($300,088)	($98,364)

Derivative_Instruments_Reconci

Derivative Instruments - Reconciles Net Amounts Derivative Assets and Liabilities (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'
Derivative assets	$0	$3,616
Noncurrent derivative assets	549	0
Net amounts of assets on balance sheet	549	3,616
Derivative liabilities	-236,694	-90,535
Noncurrent derivative liabilities	-63,394	-7,829
Net amounts of liabilities on balance sheet	-300,088	-98,364
Total derivative assets (liabilities), net	($299,539)	($94,748)

Fair_Value_Measurements_Valuat

Fair Value Measurements - Valuation of Financial Instruments by Pricing Levels (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	($299,539,000)	($94,748,000)
Fixed price swaps	'	'
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	-290,591,000	-84,893,000
Collars	'	'
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	-8,948,000	-9,855,000
Fair Value, Inputs, Level 1 [Member]	'	'
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	0	0
Fair Value, Inputs, Level 1 [Member] | Fixed price swaps	'	'
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	0	0
Fair Value, Inputs, Level 1 [Member] | Collars	'	'
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	0	0
Fair Value, Inputs, Level 2 [Member]	'	'
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	-299,539,000	-94,748,000
Fair Value, Inputs, Level 2 [Member] | Fixed price swaps	'	'
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	-290,591,000	-84,893,000
Fair Value, Inputs, Level 2 [Member] | Collars	'	'
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	-8,948,000	-9,855,000
Fair Value, Inputs, Level 3 [Member]	'	'
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	0	0
Fair Value, Inputs, Level 3 [Member] | Fixed price swaps	'	'
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	0	0
Fair Value, Inputs, Level 3 [Member] | Collars	'	'
Derivative assets (liabilities):	'	'
Derivative assets (liabilities)	$0	$0

Fair_Value_Measurements_Additi

Fair Value Measurements - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2014
Fair Value Measurements [Line Items]	'
Operating cost escalation assumption used in impairment assessment	3.00%
Discount factor utilized as standardized measure for future net cash flows	10.00%
Minimum [Member]	'
Fair Value Measurements [Line Items]	'
Productive life of field (in years)	'0 years
Maximum [Member]	'
Fair Value Measurements [Line Items]	'
Productive life of field (in years)	'50 years
Forward Commodity Prices [Member]	'
Fair Value Measurements [Line Items]	'
Forward commodity price escalation assumption used in impairment assessment	3.00%

Fair_Value_Measurements_Proper

Fair Value Measurements - Property Impairments (Detail) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Fair Value Disclosures [Abstract]	'	'	'	'
Proved property impairments	$27,529,000	$39,635,000	$31,291,000	$39,635,000
Unproved property impairments	51,787,000	40,077,000	106,233,000	80,158,000
Total	79,316,000	79,712,000	137,524,000	119,793,000
Oil and gas property fair value after impairment	$10,200,000	$22,200,000	$10,200,000	$22,200,000

Fair_Value_Measurements_Fair_V

Fair Value Measurements - Fair Values of Financial Instruments not Recorded at Fair Value (Detail) (USD $)	Jun. 30, 2014	19-May-14	Dec. 31, 2013
In Thousands, unless otherwise specified
4.9% Senior Notes due 2044	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	$700,000	'	'
3.8% Senior Notes due 2024	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	1,000,000	'	'
Carrying Amount	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Credit facility	0	1,010,000	275,000
Note payable	17,471	'	18,470
Total debt	6,133,339	'	4,715,832
Carrying Amount | 8.25% Senior Notes due 2019	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	298,422	'	298,305
Carrying Amount | 7.375% Senior Notes due 2020	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	198,770	'	198,695
Carrying Amount | 7.125% Senior Notes due 2021	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	400,000	'	400,000
Carrying Amount | 5% Senior Notes due 2022	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	2,024,180	'	2,025,362
Carrying Amount | 4.5% Senior Notes Due 2023	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	1,500,000	'	1,500,000
Carrying Amount | 4.9% Senior Notes due 2044	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	698,022	'	0
Carrying Amount | 3.8% Senior Notes due 2024	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	996,474	'	0
Fair Value	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Credit facility	0	'	275,000
Note payable	15,764	'	16,500
Total debt	6,507,194	'	4,876,000
Fair Value | 8.25% Senior Notes due 2019	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	316,950	'	327,800
Fair Value | 7.375% Senior Notes due 2020	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	223,100	'	223,700
Fair Value | 7.125% Senior Notes due 2021	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	453,600	'	450,300
Fair Value | 5% Senior Notes due 2022	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	2,172,600	'	2,063,300
Fair Value | 4.5% Senior Notes Due 2023	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	1,595,250	'	1,519,400
Fair Value | 4.9% Senior Notes due 2044	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	720,930	'	0
Fair Value | 3.8% Senior Notes due 2024	'	'	'
Fair Value Measurements [Line Items]	'	'	'
Senior notes	$1,009,000	'	$0

LongTerm_Debt_LongTerm_Debt_De

Long-Term Debt - Long-Term Debt (Detail) (USD $)	Jun. 30, 2014	19-May-14	Dec. 31, 2013
Debt Instrument [Line Items]	'	'	'
Less: Current portion of long-term debt	($300,467,000)	'	($2,011,000)
Long-term debt, net of current portion	5,832,872,000	'	4,713,821,000
8.25% Senior Notes due 2019	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, stated interest rate	8.25%	'	'
Debt Instrument, Unamortized Discount	1,600,000	'	1,700,000
7.375% Senior Notes due 2020	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, stated interest rate	7.38%	'	'
Debt Instrument, Unamortized Discount	1,200,000	'	1,300,000
7.125% Senior Notes due 2021	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, stated interest rate	7.13%	'	'
Debt Instrument Carrying Value To Face Value Percentage	100.00%	'	'
5% Senior Notes due 2022	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, stated interest rate	5.00%	'	'
Debt Instrument, Unamortized Premium	24,200,000	'	25,400,000
3.8% Senior Notes due 2024	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, stated interest rate	3.80%	'	'
Debt Instrument, Unamortized Discount	3,500,000	'	'
Senior notes	1,000,000,000	'	'
Note Payable [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, stated interest rate	3.14%	'	'
Note payable	22,000,000	'	'
4.9% Senior Notes due 2044	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, stated interest rate	4.90%	'	'
Debt Instrument, Unamortized Discount	2,000,000	'	'
Senior notes	700,000,000	'	'
Carrying Amount	'	'	'
Debt Instrument [Line Items]	'	'	'
Credit facility	0	1,010,000,000	275,000,000
Note payable	17,471,000	'	18,470,000
Total debt	6,133,339,000	'	4,715,832,000
Carrying Amount | 8.25% Senior Notes due 2019	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	298,422,000	'	298,305,000
Carrying Amount | 7.375% Senior Notes due 2020	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	198,770,000	'	198,695,000
Carrying Amount | 7.125% Senior Notes due 2021	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	400,000,000	'	400,000,000
Carrying Amount | 5% Senior Notes due 2022	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	2,024,180,000	'	2,025,362,000
Carrying Amount | 3.8% Senior Notes due 2024	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	996,474,000	'	0
Carrying Amount | 4.5% Senior Notes Due 2023	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	1,500,000,000	'	1,500,000,000
Carrying Amount | 4.9% Senior Notes due 2044	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	698,022,000	'	0
Fair Value	'	'	'
Debt Instrument [Line Items]	'	'	'
Credit facility	0	'	275,000,000
Note payable	15,764,000	'	16,500,000
Total debt	6,507,194,000	'	4,876,000,000
Fair Value | 8.25% Senior Notes due 2019	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	316,950,000	'	327,800,000
Fair Value | 7.375% Senior Notes due 2020	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	223,100,000	'	223,700,000
Fair Value | 7.125% Senior Notes due 2021	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	453,600,000	'	450,300,000
Fair Value | 5% Senior Notes due 2022	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	2,172,600,000	'	2,063,300,000
Fair Value | 3.8% Senior Notes due 2024	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	1,009,000,000	'	0
Fair Value | 4.5% Senior Notes Due 2023	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	1,595,250,000	'	1,519,400,000
Fair Value | 4.9% Senior Notes due 2044	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes	$720,930,000	'	$0

LongTerm_Debt_Additional_Infor

Long-Term Debt - Additional Information (Detail) (USD $)

3 Months Ended

6 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

19-May-14

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Revolving Credit Facility [Member]

4.5% Senior Notes due 2023 [Member]

Note Payable [Member]

8.25% Senior Notes due 2019

7.375% Senior Notes due 2020

7.125% Senior Notes due 2021

5% Senior Notes due 2022

3.8% Senior Notes due 2024

4.9% Senior Notes due 2044

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

Carrying Amount

8.25% Senior Notes due 2019

8.25% Senior Notes due 2019

7.375% Senior Notes due 2020

7.375% Senior Notes due 2020

7.125% Senior Notes due 2021

7.125% Senior Notes due 2021

5% Senior Notes due 2022

5% Senior Notes due 2022

3.8% Senior Notes due 2024

3.8% Senior Notes due 2024

4.9% Senior Notes due 2044

4.9% Senior Notes due 2044

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit facility, amount outstanding

'

'

'

'

'

'

'

'

'

'

'

'

$0

$1,010,000,000

$275,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit facility, maturity date

'

16-May-19

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate amount of lender commitments on credit facility

1,750,000,000

1,750,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

4,000,000,000

4,000,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit facility, unused commitments

'

'

'

1,750,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit facility, commitment fee percentage, per annum

0.23%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit Facility Debt to Capitalization Ratio Covenant Requirement

'

'0.65

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notes Payable

'

'

'

'

'

22,000,000

'

'

'

'

'

'

17,471,000

'

18,470,000

'

'

'

'

'

'

'

'

'

'

'

'

Loan term

'

'

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, stated interest rate

'

'

'

'

4.50%

3.14%

8.25%

7.38%

7.13%

5.00%

3.80%

4.90%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Maturity Date

'

'

'

'

'

26-Feb-22

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current portion of long-term debt

300,467,000

300,467,000

2,011,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes

'

'

'

'

'

'

'

'

'

'

1,000,000,000

700,000,000

'

'

'

298,422,000

298,305,000

198,770,000

198,695,000

400,000,000

400,000,000

2,024,180,000

2,025,362,000

996,474,000

0

698,022,000

0

Debt Instrument, Maturity Date, Description

'

'

'

'

'2023

'

'2019

'2020

'2021

'2022

'2024

'2044

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Debt, Net of Issuance Costs

$1,680,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

LongTerm_Debt_LongTerm_Debt_Su

Long-Term Debt Long-Term Debt - Summary of Maturity Dates, Semi-Annual Interest Payment Dates, and Optional Redemption Periods of Outstanding Senior Note Obligations (Details)	6 Months Ended
	Jun. 30, 2014
2020 Notes [Member]	'
Debt Instrument [Line Items]	'
Maturity date	1-Oct-20
Interest payment dates	'April 1, Oct. 1
Call premium redemption period	1-Oct-15
Make-whole redemption period	1-Oct-15
2021 Notes [Member]	'
Debt Instrument [Line Items]	'
Maturity date	1-Apr-21
Interest payment dates	'April 1, Oct. 1
Call premium redemption period	1-Apr-16
Make-whole redemption period	1-Apr-16
2022 Notes [Member]	'
Debt Instrument [Line Items]	'
Maturity date	15-Sep-22
Interest payment dates	'March 15, Sept. 15
Call premium redemption period	15-Mar-17
Make-whole redemption period	15-Mar-17
Equity offering redemption period	15-Mar-15
2023 Notes [Member]	'
Debt Instrument [Line Items]	'
Maturity date	15-Apr-23
Interest payment dates	'April 15, Oct. 15
Make-whole redemption period	15-Jan-23
2024 Notes [Member]	'
Debt Instrument [Line Items]	'
Maturity date	1-Jun-24
Interest payment dates	'June 1, Dec. 1
Make-whole redemption period	1-Mar-24
2044 Notes [Member]	'
Debt Instrument [Line Items]	'
Maturity date	1-Jun-44
Interest payment dates	'June 1, Dec.1
Make-whole redemption period	1-Dec-43

LongTerm_Debt_Summary_of_Matur

Long-Term Debt - Summary of Maturity Dates, Semi-Annual Interest Payment Dates, and Optional Redemption Periods of Outstanding Senior Note Obligations (Parenthetical) (Detail)	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Debt instrument, percentage redeemable on each note	35.00%

Commitments_and_Contingencies_

Commitments and Contingencies - Additional Information (Detail) (USD $)	1 Months Ended	3 Months Ended
	Nov. 30, 2010	Jun. 30, 2014	Dec. 31, 2013
Long-term Purchase Commitment [Line Items]	'	'	'
Total future drilling commitments at balance sheet date	'	$335,000,000	'
Drilling commitments due remainder of current year	'	64,000,000	'
Drilling commitments Year Two	'	92,000,000	'
Drilling Commitments Year Three	'	86,000,000	'
Drilling Commitments Year Four	'	65,000,000	'
Drilling Commitments Year Five	'	28,000,000	'
Future Drilling Commitments End Date	'	'2018-07	'
Loss related to contingency damages	165,000,000	'	'
Legal proceedings recorded as a liability under other noncurrent liabilities	'	-2,900,000	-1,700,000
Pipeline Transportation Commitments [Member]	'	'	'
Long-term Purchase Commitment [Line Items]	'	'	'
Purchase commitment, end date	'	'2024	'
Purchase commitment, total	'	91,000,000	'
Purchase commitment, due in remainder of current year	'	10,000,000	'
Purchase commitment, due second year	'	20,000,000	'
Purchase commitment, due third year	'	16,000,000	'
Purchase commitment, due fourth year	'	11,000,000	'
Purchase commitment, due fifth year	'	6,000,000	'
Purchase commitment, due after fifth year	'	28,000,000	'
Non-operational [Member]	'	'	'
Long-term Purchase Commitment [Line Items]	'	'	'
Purchase commitment, due in remainder of current year	'	36,000,000	'
Purchase commitment, due second year	'	160,000,000	'
Purchase commitment due in third through fifth year	'	168,000,000	'
Purchase commitment, due after fifth year	'	206,000,000	'
Crude oil non-op transportation commitment, total	'	1,200,000,000	'
Crude oil non-op transportation commitment with affiliate	'	96,000,000	'
Cost Sharing Commitment [Member]	'	'	'
Long-term Purchase Commitment [Line Items]	'	'	'
Purchase commitment, end date	'	'2016	'
Purchase commitment, total	'	16,000,000	'
Purchase commitment, due in remainder of current year	'	6,000,000	'
Purchase commitment, due second year	'	8,000,000	'
Purchase commitment, due third year	'	$2,000,000	'

Stock_Based_Compensation_Stock

Stock Based Compensation - Stock Based Compensation Expenses (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'	'	'	'
Non-cash equity compensation	$14,978	$9,756	$26,017	$18,998

StockBased_Compensation_Additi

Stock-Based Compensation - Additional Information (Detail) (USD $)	6 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Common stock available for issue	9,840,036
Restricted stock [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Stock available to grant	9,091,028
Fair value at vesting date	$16.10
Unrecognized compensation expense related to non-vested	$96
Unrecognized compensation expense related to non-vested, period for recognition, in years	'1 year 6 months 1 day
Restricted stock [Member] | Minimum [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Grants vest over periods, in years	'1 year
Restricted stock [Member] | Maximum [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Grants vest over periods, in years	'3 years

Stock_Based_Compensation_Summa

Stock Based Compensation - Summary of Changes in Non Vested Shares of Restricted Stock Outstanding (Detail) (USD $)	6 Months Ended
	Jun. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]	'
Non-vested shares, beginning balance	1,357,156
Granted shares	602,217
Vested shares	-131,556
Forfeited shares	-116,998
Non-vested shares, ending balance	1,710,819
Non-vested, weighted average grant-date fair value, beginning of period	$74.99
Granted, weighted average grant-date fair value	$122.41
Vested, weighted average grant-date fair value	$73.29
Forfeited, weighted average grant-date fair value	$85.06
Non-vested, weighted average grant-date fair value, end of period	$91.12

Property_Dispositions_Addition

Property Dispositions - Additional Information (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Property Dispositions (Line Items)	'	'	'	'
Proceeds from sale of assets	'	'	$39,018	$894
Gain (Loss) on Disposition of Property Plant Equipment	$2,135	($349)	($6,363)	($213)

Subsequent_Event_Details

Subsequent Event (Details) (8.25% Senior Notes due 2019, USD $)	3 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Sep. 30, 2014
		Subsequent Event [Member]
Subsequent Event [Line Items]	'	'
Senior Notes	$300	'
Total Redemption Amount	324.4	'
Debt Instrument, Redemption Price, Percentage	108.12%	'
Loss on Extinguishment of Debt	'	$24