Continental Resources Inc (CLR) 10-Q 6 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015	Apr. 30, 2015
Document Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Trading Symbol	CLR
Entity Registrant Name	CONTINENTAL RESOURCES, INC
Entity Central Index Key	732834
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		373,112,044

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$47,645	$24,381
Receivables:
Crude oil and natural gas sales	455,837	552,476
Affiliated parties	232	13,360
Joint interest and other, net	506,216	567,476
Derivative assets	52,392	52,423
Inventories	108,347	102,179
Deferred and prepaid taxes	13,267	63,266
Prepaid expenses and other	16,944	14,040
Total current assets	1,200,880	1,389,601
Net property and equipment, based on successful efforts method of accounting	14,111,154	13,635,852
Net debt issuance costs and other	85,811	87,625
Noncurrent derivative assets	37,419	31,992
Total assets	15,435,264	15,145,070
Current liabilities:
Accounts payable trade	1,009,133	1,263,724
Revenues and royalties payable	226,912	272,755
Payables to affiliated parties	6,914	7,305
Accrued liabilities and other	355,633	404,506
Derivative liabilities	254	1,645
Current portion of long-term debt	2,093	2,078
Total current liabilities	1,600,939	1,952,013
Long-term debt, net of current portion	6,784,816	5,995,837
Other noncurrent liabilities:
Deferred income tax liabilities	2,119,281	2,141,447
Asset retirement obligations, net of current portion	78,819	75,462
Noncurrent derivative liabilities	576	3,109
Other noncurrent liabilities	9,795	9,358
Total other noncurrent liabilities	2,208,471	2,229,376
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; 373,121,054 shares issued and outstanding at March 31, 2015; 372,005,502 shares issued and outstanding at December 31, 2014	3,731	3,720
Additional paid-in capital	1,296,200	1,287,941
Accumulated Other Comprehensive Income (Loss), Net of Tax	-3,490	-385
Retained earnings	3,544,597	3,676,568
Total shareholders’ equity	4,841,038	4,967,844
Total liabilities and shareholders’ equity	$15,435,264	$15,145,070

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
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
Preferred stock, shares outstanding
Common stock, par value	$0.01	$0.01
Common stock, shares authorized	500,000,000	500,000,000
Common Stock, Shares, Issued	373,121,054	372,005,502
Common Stock, Shares, Outstanding	373,121,054	372,005,502

Unaudited_Condensed_Consolidat

Unaudited Condensed Consolidated Statements of Comprehensive Income (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Revenues
Crude oil and natural gas sales	$581,192	$972,147
Crude oil and natural gas sales to affiliates	1,400	30,186
Gain (loss) on derivative instruments, net	32,755	-39,674
Crude oil and natural gas service operations	10,297	9,836
Total revenues	625,644	972,495
Operating costs and expenses
Production expenses	91,355	75,976
Production expenses to affiliates	1,586	910
Production taxes and other expenses	48,362	78,302
Exploration expenses	14,340	4,813
Crude oil and natural gas service operations	3,894	8,074
Depreciation, depletion, amortization and accretion	386,512	272,861
Property impairments	147,561	58,208
General and administrative expenses	45,380	43,536
(Gain) loss on sale of assets, net	-2,070	8,498
Total operating costs and expenses	736,920	551,178
Income (loss) from operations	-111,276	421,317
Other income (expense):
Interest expense	-75,063	-62,975
Other	347	759
Total other income (expense)	-74,716	-62,216
Income (loss) before income taxes	-185,992	359,101
Provision (benefit) for income taxes	-54,021	132,867
Net income (loss)	-131,971	226,234
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Gain (Loss) Arising During Period, Net of Tax	-3,105	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	($135,076)	$226,234
Basic net income (loss) per share (in dollars per share)	($0.36)	$0.61
Diluted net income (loss) per share (in dollars per share)	($0.36)	$0.61

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Shareholders Equity (USD $)	Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Retained Earnings [Member]
In Thousands, except Share data, unless otherwise specified
Balance at Dec. 31, 2014	$4,967,844	$3,720	$1,287,941	($385)	$3,676,568
Balance, shares at Dec. 31, 2014	372,005,502	372,005,502
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) (unaudited)	-131,971				-131,971
Other Comprehensive Income (Loss), Net of Tax (unaudited)	-3,105			-3,105
Stock-based compensation (unaudited)	11,261		11,261
Restricted stock:
Issued (unaudited)	12	12
Issued (unaudited), shares		1,233,574
Repurchased and canceled (unaudited)	-3,003	-1	-3,002
Repurchased and canceled (unaudited), shares		-63,446
Forfeited (unaudited), shares		-54,576
Forfeitures (unaudited), value	0
Balance at Mar. 31, 2015	$4,841,038	$3,731	$1,296,200	($3,490)	$3,544,597
Balance, shares at Mar. 31, 2015	373,121,054	373,121,054

Unaudited_Condensed_Consolidat1

Unaudited Condensed Consolidated Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flows from operating activities
Net income (loss)	($131,971)	$226,234
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion, amortization and accretion	391,026	281,115
Property impairments	147,561	58,208
Non-cash (gain) loss on derivatives, net	-9,320	6,410
Stock-based compensation	11,263	11,039
Provision (benefit) for deferred income taxes	-54,026	131,315
Dry hole costs	8,401	0
(Gain) loss on sale of assets, net	-2,070	8,498
Other, net	2,261	1,754
Changes in assets and liabilities:
Accounts receivable	173,088	-53,857
Inventories	-6,236	-17,669
Prepaid expenses and other	48,967	-525
Accounts payable trade	5,185	13,854
Revenues and royalties payable	-45,844	34,623
Accrued liabilities and other	-17,460	-9,191
Other noncurrent assets and liabilities	1,365	-1,146
Net cash provided by operating activities	522,190	690,662
Cash flows from investing activities
Exploration and development	-1,267,252	-993,682
Purchase of producing crude oil and natural gas properties	-132	-30,278
Purchase of other property and equipment	-11,923	-30,953
Proceeds from sale of assets	903	35,433
Net cash used in investing activities	-1,278,404	-1,019,480
Cash flows from financing activities
Credit facility borrowings	930,000	525,000
Repayment of credit facility	-140,000	-170,000
Repayment of other debt	-515	-499
Debt issuance costs	-2,099	0
Repurchase of restricted stock for tax withholdings	-3,003	-2,630
Net cash provided by financing activities	784,383	351,871
Effect of Exchange Rate on Cash and Cash Equivalents	-4,905	0
Net change in cash and cash equivalents	23,264	23,053
Cash and cash equivalents at beginning of period	24,381	28,482
Cash and cash equivalents at end of period	$47,645	$51,535

Organization_and_Nature_of_Bus

Organization and Nature of Business	3 Months Ended
	Mar. 31, 2015
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 primarily located 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 72% of the Company’s crude oil and natural gas production and 78% of its crude oil and natural gas revenues for the three months ended March 31, 2015. The Company's principal producing properties in the North region are located in the Bakken field of North Dakota and Montana. In recent years, the Company has significantly expanded its activity in the South region with its discovery and announcement of the SCOOP play in Oklahoma. The South region now comprises 28% of the Company's crude oil and natural gas production and 22% of its crude oil and natural gas revenues for the three months ended March 31, 2015.
	The Company has focused its operations on the exploration and development of crude oil since the 1980s. For the three months ended March 31, 2015, crude oil accounted for 69% of the Company’s total production and 84% of its crude oil and natural gas revenues.

Basis_of_Presentation_and_Sign

Basis of Presentation and Significant Accounting Policies	3 Months Ended
	Mar. 31, 2015
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. All significant intercompany accounts and transactions have been eliminated upon consolidation.
	On August 18, 2014, the Company's Board of Directors declared a 2-for-1 stock split of the Company's common stock to be effected in the form of a stock dividend. The stock dividend was distributed on September 10, 2014 to shareholders of record as of September 3, 2014. Previously reported common stock and earnings per share amounts for the three months ended March 31, 2014 have been retroactively adjusted in the accompanying financial statements and related notes to reflect the stock split.
	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, 2014 (“2014 Form 10-K”), which includes a summary of the Company’s significant accounting policies and other disclosures.
	The condensed consolidated financial statements as of March 31, 2015 and for the three month periods ended March 31, 2015 and 2014 are unaudited. The condensed consolidated balance sheet as of December 31, 2014 was derived from the audited balance sheet included in the 2014 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.
	Earnings per share
	Basic net income (loss) per share is computed by dividing net income (loss) by the weighted-average number of shares outstanding for the period. Diluted net income (loss) 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 (loss) per share for the three months ended March 31, 2015 and 2014.
			Three months ended March 31,
	In thousands, except per share data		2015			2014
	Income (loss) (numerator):
	Net income (loss) - basic and diluted		$	(131,971	)	$	226,234
	Weighted average shares (denominator):
	Weighted average shares - basic		369,385			368,658
	Non-vested restricted stock (1)		—			1,398
	Weighted average shares - diluted		369,385			370,056
	Net income (loss) per share:
	Basic		$	(0.36	)	$	0.61
	Diluted		$	(0.36	)	$	0.61
	-1	The potential dilutive effect of 925,000 weighted average restricted shares were not included in the calculation of diluted net loss per share for the three months ended March 31, 2015 because to do so would have been anti-dilutive.
	Inventories
	Inventory is comprised of crude oil held in storage or as line fill in pipelines and tubular goods and equipment to be used in the Company's exploration and development activities. Crude oil inventories are valued at the lower of cost or market primarily using the first-in, first-out inventory method. Tubular goods and equipment are valued at the lower of cost or market, with cost determined primarily using a weighted average cost method applied to specific classes of inventory items.
	The components of inventory as of March 31, 2015 and December 31, 2014 consisted of the following:
	In thousands		March 31, 2015			December 31, 2014
	Tubular goods and equipment		$	16,214		$	15,659
	Crude oil		92,133			86,520
	Total		$	108,347		$	102,179
	Income taxes
	Income taxes are accounted for using the liability method under which deferred income taxes are recognized for the future tax effects of temporary differences between financial statement carrying amounts and the tax basis of existing assets and liabilities using the enacted statutory tax rates in effect at period-end. A valuation allowance for deferred tax assets is recorded when it is more likely than not that the benefit from the deferred tax asset will not be realized. The Company recorded an $11.1 million valuation allowance against deferred tax assets associated with operating loss carryforwards generated by its Canadian subsidiary in the 2015 first quarter for which the Company does not expect to realize a benefit.
	Affiliate transactions
	The affiliate transactions reflected in the accompanying unaudited condensed consolidated statements of comprehensive income (loss) for the three months ended March 31, 2015 and 2014 include transactions between the Company and Hiland Partners, LP and its subsidiaries ("Hiland"). Hiland was controlled by the Company's principal shareholder through February 13, 2015, at which time it was sold to an unaffiliated third party. As a result of the sale, the related party relationship that existed previously between the Company and Hiland terminated as of February 13, 2015, which resulted in a reduction in affiliate transactions recognized in the Company's financial statements at March 31, 2015 and for the three months then ended.
	New accounting pronouncement
	On April 7, 2015, the Financial Accounting Standards Board issued Accounting Standards Update 2015-03, Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The new standard requires debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with the presentation of a debt discount. Under previous guidance, debt issuance costs are required to be presented in the balance sheet as a deferred asset. The new standard does not affect the existing recognition and measurement guidance for debt issuance costs. The new standard will be effective for annual and interim periods beginning after December 15, 2015 and will be applied on a retrospective basis to all balance sheet periods presented. As of March 31, 2015, the Company's capitalized debt issuance costs subject to future reclassification under the new standard totaled $76 million, net of accumulated amortization.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information	3 Months Ended
	Mar. 31, 2015
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 tax payments and refunds. Also disclosed is information about investing activities that affects recognized assets and liabilities but does not result in cash receipts or payments.
		Three months ended March 31,
	In thousands	2015			2014
	Supplemental cash flow information:
	Cash paid for interest	$	51,790		$	52,194
	Cash paid for income taxes	6			—
	Cash received for income tax refunds	50,000			5
	Non-cash investing activities:
	Increase (decrease) in accrued capital expenditures	(260,204		)	47,508
	Asset retirement obligation additions and revisions, net	2,703			1,270

Derivative_Instruments

Derivative Instruments	3 Months Ended
	Mar. 31, 2015
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 comprehensive income (loss) under the caption “Gain (loss) on derivative instruments, net.”
	The Company may utilize swap and collar derivative contracts to economically hedge against the variability in cash flows associated with the 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 and written call options, volatility, the risk-free interest rate, and the time to expiration. The calculation of the fair value of collars and written call options requires the use of an option-pricing model. See Note 5. Fair Value Measurements.
	At March 31, 2015, the Company had outstanding derivative contracts with respect to future production as set forth in the tables below.
	Crude Oil - NYMEX WTI				Ceilings
							Weighted Average
	Period and Type of Contract	Bbls			Range		Price
	July 2015 - December 2015
	Written call options - WTI (1)	2,208,000			$95.85 - $103.75		$	98.36
	Crude Oil - ICE Brent				Ceilings
									Weighted Average
	Period and Type of Contract	Bbls			Range				Price
	July 2015 - December 2015
	Written call options - ICE Brent (1)	368,000			$	107.4			$	107.4
	January 2016 - December 2016
	Written call options - ICE Brent (1)	1,464,000			$	107.7			$	107.7
									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
	April 2015 - December 2015
	Swaps - Henry Hub	11,000,000			$	4.16
	Collars - Henry Hub	22,000,000							$3.50 - $3.75		$	3.69	$4.89 - $5.48	$	5.04
	January 2016 - December 2016
	Swaps - Henry Hub	63,110,000			$	3.98
	(1) Written call options represent the ceiling positions remaining from the Company's previous crude oil collar contracts. The floor positions of the collars were liquidated in the 2014 fourth quarter. For these written call options, the Company is required to make a payment to the counterparty if the settlement price for any settlement period is above the ceiling price.
	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 March 31,
	In thousands	2015				2014
	Cash received (paid) on derivatives:
	Crude oil fixed price swaps	$	—			$	(22,523	)
	Crude oil collars	—				(584		)
	Natural gas fixed price swaps	18,391				(10,157		)
	Natural gas collars	5,044				—
	Cash received (paid) on derivatives, net	23,435				(33,264		)
	Non-cash gain (loss) on derivatives:
	Crude oil fixed price swaps	—				13,690
	Crude oil collars	—				5,283
	Crude oil written call options	3,924				—
	Natural gas fixed price swaps	6,492				(25,401		)
	Natural gas collars	(1,096		)		18
	Non-cash gain (loss) on derivatives, net	9,320				(6,410		)
	Gain (loss) on derivative instruments, net	$	32,755			$	(39,674	)
	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	31-Mar-15				31-Dec-14
	Commodity derivative assets:
	Gross amounts of recognized assets	$	89,811			$	84,415
	Gross amounts offset on balance sheet	—				—
	Net amounts of assets on balance sheet	89,811				84,415
	Commodity derivative liabilities:
	Gross amounts of recognized liabilities	(830		)		(4,770		)
	Gross amounts offset on balance sheet	—				16
	Net amounts of liabilities on balance sheet	$	(830	)		$	(4,754	)
	The following table reconciles the net amounts disclosed above to the individual financial statement line items in the condensed consolidated balance sheets.
	In thousands	March 31, 2015				December 31, 2014
	Derivative assets	$	52,392			$	52,423
	Noncurrent derivative assets	37,419				31,992
	Net amounts of assets on balance sheet	89,811				84,415
	Derivative liabilities	(254		)		(1,645		)
Noncurrent derivative liabilities	(576		)		(3,109		)
Net amounts of liabilities on balance sheet	(830		)		(4,754		)
Total derivative assets, net	$	88,981			$	79,661

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2015
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 collars and written call options requires the use of an industry-standard option pricing model that considers various inputs including quoted forward commodity prices, 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 March 31, 2015 and December 31, 2014.
			Fair value measurements at March 31, 2015 using:
	In thousands		Level 1		Level 2			Level 3		Total
	Derivative assets (liabilities):
	Fixed price swaps		$	—	$	69,091		$	—	$	69,091
	Collars		—		20,720			—		20,720
	Written call options		—		(830		)	—		(830		)
	Total		$	—	$	88,981		$	—	$	88,981
			Fair value measurements at December 31, 2014 using:
	In thousands		Level 1		Level 2			Level 3		Total
	Derivative assets (liabilities):
	Fixed price swaps		$	—	$	62,599		$	—	$	62,599
	Collars		—		21,816			—		21,816
	Written call options		—		(4,754		)	—		(4,754		)
	Total		$	—	$	79,661		$	—	$	79,661
	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. 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 strip prices through 2019 (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.
	Impairments of proved properties amounted to $70.0 million for the three months ended March 31, 2015 resulting from a continued decrease in commodity prices in the first quarter that indicated the carrying amounts for certain fields were not recoverable. The impairments reflect fair value adjustments primarily concentrated in an emerging area with limited production history and costly reserve additions ($36.1 million), the Medicine Pole Hills units ($14.7 million), various non-core areas in the South region ($11.1 million), and non-Bakken areas of North Dakota and Montana ($8.1 million). The impaired properties were written down to their estimated fair value totaling approximately $38.2 million at March 31, 2015.
	Impairments of proved properties totaled $3.8 million for the three months ended March 31, 2014, which reflect fair value adjustments made for certain properties in a non-core area of our South region driven by uneconomic well results. The impaired properties were written down to their estimated fair value totaling approximately $1.1 million as of March 31, 2014.
	Certain unproved crude oil and natural gas properties were impaired during the three months ended March 31, 2015 and 2014, 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 drilling plans, 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 comprehensive income (loss).
			Three months ended March 31,
	In thousands		2015		2014
	Proved property impairments		$	70,016	$	3,762
	Unproved property impairments		77,545		54,446
	Total		$	147,561	$	58,208
	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.
			March 31, 2015					December 31, 2014
	In thousands		Carrying		Fair Value			Carrying		Fair Value
			Amount					Amount
	Debt:
	Credit facility		$	955,000	$	955,000		$	165,000	$	165,000
	Note payable		15,942		14,500			16,457		14,900
	7.375% Senior Notes due 2020		198,889		213,700			198,850		213,000
	7.125% Senior Notes due 2021		400,000		416,300			400,000		421,000
	5% Senior Notes due 2022		2,022,337		1,998,500			2,022,949		1,857,900
	4.5% Senior Notes due 2023		1,500,000		1,445,000			1,500,000		1,372,800
	3.8% Senior Notes due 2024		996,696		918,900			996,622		868,700
	4.9% Senior Notes due 2044		698,045		625,300			698,037		572,400
	Total debt		$	6,786,909	$	6,587,200		$	5,997,915	$	5,485,700
	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 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	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt
	Long-term debt consists of the following at March 31, 2015 and December 31, 2014:
	In thousands		31-Mar-15			December 31, 2014
	Credit facility		$	955,000		$	165,000
	Note payable		15,942			16,457
	7.375% Senior Notes due 2020 (1)		198,889			198,850
	7.125% Senior Notes due 2021 (2)		400,000			400,000
	5% Senior Notes due 2022 (3)		2,022,337			2,022,949
	4.5% Senior Notes due 2023 (2)		1,500,000			1,500,000
	3.8% Senior Notes due 2024 (4)		996,696			996,622
	4.9% Senior Notes due 2044 (5)		698,045			698,037
	Total debt		$	6,786,909		$	5,997,915
	Less: Current portion of long-term debt		2,093			2,078
	Long-term debt, net of current portion		$	6,784,816		$	5,995,837
	-1	The carrying amount is net of unamortized discounts of $1.1 million and $1.2 million at March 31, 2015 and December 31, 2014, respectively.
	-2	These notes were sold at par and are recorded at 100% of face value.
	-3	The carrying amount includes an unamortized premium of $22.3 million and $22.9 million at March 31, 2015 and December 31, 2014, respectively.
	-4	The carrying amount is net of unamortized discounts of $3.3 million and $3.4 million at March 31, 2015 and December 31, 2014, respectively.
	-5	The carrying amount is net of an unamortized discount of $2.0 million at both March 31, 2015 and December 31, 2014.
	Credit Facility
	The Company has an unsecured credit facility, maturing on May 16, 2019, with aggregate commitments totaling $2.5 billion, which may be increased up to a total of $4.0 billion upon agreement between the Company and participating lenders.
	The Company had $955 million and $165 million of outstanding borrowings on its credit facility at March 31, 2015 and December 31, 2014, respectively. Borrowings 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 weighted-average interest rate on outstanding borrowings at March 31, 2015 was 1.8%.
	The Company had approximately $1.54 billion of borrowing availability on its credit facility at March 31, 2015 and incurs commitment fees based on currently assigned credit ratings of 0.225% per annum of the daily average amount of unused borrowing availability.
	The credit facility contains certain restrictive covenants including a requirement that the Company maintain a consolidated net debt to total capitalization ratio of no greater than 0.65 to 1.00. As of March 31, 2015, 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 March 31, 2015. On May 4, 2015, the Company's credit facility was amended to exclude the impact of non-cash impairment charges recognized after June 30, 2014, net of any tax effect, from the determination of shareholders' equity in the calculation of the consolidated net debt to total capitalization ratio.
	Senior Notes
	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 March 31, 2015.
			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
	-1	On or after these dates, the Company has the option to redeem all or a portion of its senior notes of the applicable series 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 of the applicable series at the “make-whole” redemption prices or amounts specified in the Indentures 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 other things, limit the Company's ability to create liens securing certain indebtedness, enter into certain sale and 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 March 31, 2015. 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. Accordingly, approximately $2.1 million is reflected as a current liability under the caption “Current portion of long-term debt” in the condensed consolidated balance sheets as of March 31, 2015.

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2015
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 March 31, 2015. The commitments under these arrangements are not recorded in the accompanying condensed consolidated balance sheets.
	Drilling commitments – As of March 31, 2015, the Company had drilling rig contracts with various terms extending through September 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 strategic plays. Future commitments as of March 31, 2015 total approximately $564 million, of which $186 million is expected to be incurred in the remainder of 2015, $220 million in 2016, $125 million in 2017, and $33 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 2025, require the Company to pay per-unit transportation charges regardless of the amount of pipeline capacity used. Future commitments remaining as of March 31, 2015 under the operational pipeline transportation arrangements amount to approximately $1.0 billion, of which $153 million is expected to be incurred in the remainder of 2015, $207 million in 2016, $201 million in 2017, $195 million in 2018, $159 million in 2019, and $109 million thereafter.
	Further, the Company is a party to an additional five year firm transportation commitment for a future crude oil pipeline project being considered for development that is not yet operational. The project requires the granting of regulatory approvals and requires additional construction efforts by the counterparty before being completed. Future commitments under the non-operational arrangement total approximately $260 million at March 31, 2015. The timing of the Company’s obligations under this non-operational arrangement 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.
	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.
	Fuel purchase commitment – The Company has entered into a forward purchase contract with a third party to purchase specified quantities of diesel fuel at specified prices each month over the period from January 2015 through June 2016 for use in the normal course of drilling operations. Over the contract term, the Company has committed to purchase a total of approximately 31 million gallons of diesel fuel at varying prices depending on the grade of diesel fuel purchased and the timing and location of delivery. The contract satisfies a significant portion of the Company's anticipated diesel fuel needs and provides for physical delivery to desired locations. Future commitments under the arrangement as of March 31, 2015 total approximately $75 million, of which $44 million is expected to be incurred in the remainder of 2015 and $31 million is expected to be incurred 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 Amended Motion for Class Certification is presently set for evidentiary hearing on June 1, 2015. 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 both March 31, 2015 and December 31, 2014, the Company had recorded a liability in the condensed consolidated balance sheets under the caption “Other noncurrent liabilities” of $2.9 million 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	3 Months Ended
	Mar. 31, 2015
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 comprehensive income (loss), was $11.3 million and $11.0 million for the three months ended March 31, 2015 and 2014, respectively.
	In May 2013, the Company adopted the 2013 Plan and reserved a maximum of 19,680,072 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 March 31, 2015, the Company had a maximum of 16,944,983 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 three months ended March 31, 2015 is presented below:
		Number of		Weighted
		non-vested		average
		shares		grant-date
				fair value
	Non-vested restricted shares outstanding at December 31, 2014	2,678,764		$	49.4
	Granted	1,233,574		47.91
	Vested	(180,733	)	51.28
	Forfeited	(54,576	)	53.67
	Non-vested restricted shares outstanding at March 31, 2015	3,677,029		$	48.74
	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 three months ended March 31, 2015 at the vesting date was approximately $8.6 million. As of March 31, 2015, there was approximately $115 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 1.8 years.

Accumulated_Other_Comprehensiv

Accumulated Other Comprehensive Income (Notes)	3 Months Ended
	Mar. 31, 2015
Accumulated Other Comprehensive Income [Abstract]
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]	Accumulated Other Comprehensive Loss
	Adjustments resulting from the process of translating foreign functional currency financial statements into U.S. dollars are included in "Accumulated other comprehensive loss" within shareholders’ equity on the condensed consolidated balance sheets. The following table summarizes the change in accumulated other comprehensive loss for the three months ended March 31, 2015:
	In thousands		Three months ended March 31, 2015
	Beginning accumulated other comprehensive loss, net of tax		$	(385	)
	Foreign currency translation adjustments		(3,105		)
	Income tax benefit (1)		—
	Other comprehensive loss, net of tax		(3,105		)
	Ending accumulated other comprehensive loss, net of tax		$	(3,490	)
	-1	A valuation allowance has been recognized against deferred tax assets associated with losses generated by the Company's Canadian operations, thereby resulting in zero income tax benefit on other comprehensive loss for the period.

Basis_of_Presentation_and_Sign1

Basis of Presentation and Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Description of the Company	The Company's principal business is crude oil and natural gas exploration, development and production with properties primarily located 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 72% of the Company’s crude oil and natural gas production and 78% of its crude oil and natural gas revenues for the three months ended March 31, 2015. The Company's principal producing properties in the North region are located in the Bakken field of North Dakota and Montana. In recent years, the Company has significantly expanded its activity in the South region with its discovery and announcement of the SCOOP play in Oklahoma. The South region now comprises 28% of the Company's crude oil and natural gas production and 22% of its crude oil and natural gas revenues for the three months ended March 31, 2015.
	The Company has focused its operations on the exploration and development of crude oil since the 1980s. For the three months ended March 31, 2015, crude oil accounted for 69% of the Company’s total production and 84% 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. All significant intercompany accounts and transactions have been eliminated upon consolidation.
	On August 18, 2014, the Company's Board of Directors declared a 2-for-1 stock split of the Company's common stock to be effected in the form of a stock dividend. The stock dividend was distributed on September 10, 2014 to shareholders of record as of September 3, 2014. Previously reported common stock and earnings per share amounts for the three months ended March 31, 2014 have been retroactively adjusted in the accompanying financial statements and related notes to reflect the stock split.
	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, 2014 (“2014 Form 10-K”), which includes a summary of the Company’s significant accounting policies and other disclosures.
	The condensed consolidated financial statements as of March 31, 2015 and for the three month periods ended March 31, 2015 and 2014 are unaudited. The condensed consolidated balance sheet as of December 31, 2014 was derived from the audited balance sheet included in the 2014 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
	Inventory is comprised of crude oil held in storage or as line fill in pipelines and tubular goods and equipment to be used in the Company's exploration and development activities. Crude oil inventories are valued at the lower of cost or market primarily using the first-in, first-out inventory method. Tubular goods and equipment are valued at the lower of cost or market, with cost determined primarily using a weighted average cost method applied to specific classes of inventory items.
Earnings Per Share	Earnings per share
	Basic net income (loss) per share is computed by dividing net income (loss) by the weighted-average number of shares outstanding for the period. Diluted net income (loss) 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)	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Components of Inventories	The components of inventory as of March 31, 2015 and December 31, 2014 consisted of the following:
	In thousands		March 31, 2015			December 31, 2014
	Tubular goods and equipment		$	16,214		$	15,659
	Crude oil		92,133			86,520
	Total		$	108,347		$	102,179
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 (loss) per share for the three months ended March 31, 2015 and 2014.
			Three months ended March 31,
	In thousands, except per share data		2015			2014
	Income (loss) (numerator):
	Net income (loss) - basic and diluted		$	(131,971	)	$	226,234
	Weighted average shares (denominator):
	Weighted average shares - basic		369,385			368,658
	Non-vested restricted stock (1)		—			1,398
	Weighted average shares - diluted		369,385			370,056
	Net income (loss) per share:
	Basic		$	(0.36	)	$	0.61
	Diluted		$	(0.36	)	$	0.61
	-1	The potential dilutive effect of 925,000 weighted average restricted shares were not included in the calculation of diluted net loss per share for the three months ended March 31, 2015 because to do so would have been anti-dilutive.

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2015
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 tax payments and refunds. Also disclosed is information about investing activities that affects recognized assets and liabilities but does not result in cash receipts or payments.
		Three months ended March 31,
	In thousands	2015			2014
	Supplemental cash flow information:
	Cash paid for interest	$	51,790		$	52,194
	Cash paid for income taxes	6			—
	Cash received for income tax refunds	50,000			5
	Non-cash investing activities:
	Increase (decrease) in accrued capital expenditures	(260,204		)	47,508
	Asset retirement obligation additions and revisions, net	2,703			1,270

Derivative_Instruments_Tables

Derivative Instruments (Tables)	3 Months Ended
	Mar. 31, 2015
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
	April 2015 - December 2015
	Swaps - Henry Hub	11,000,000			$	4.16
	Collars - Henry Hub	22,000,000							$3.50 - $3.75		$	3.69	$4.89 - $5.48	$	5.04
	January 2016 - December 2016
	Swaps - Henry Hub	63,110,000			$	3.98
Realized and Unrealized 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 March 31,
	In thousands	2015				2014
	Cash received (paid) on derivatives:
	Crude oil fixed price swaps	$	—			$	(22,523	)
	Crude oil collars	—				(584		)
	Natural gas fixed price swaps	18,391				(10,157		)
	Natural gas collars	5,044				—
	Cash received (paid) on derivatives, net	23,435				(33,264		)
	Non-cash gain (loss) on derivatives:
	Crude oil fixed price swaps	—				13,690
	Crude oil collars	—				5,283
	Crude oil written call options	3,924				—
	Natural gas fixed price swaps	6,492				(25,401		)
	Natural gas collars	(1,096		)		18
	Non-cash gain (loss) on derivatives, net	9,320				(6,410		)
	Gain (loss) on derivative instruments, net	$	32,755			$	(39,674	)
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	31-Mar-15				31-Dec-14
	Commodity derivative assets:
	Gross amounts of recognized assets	$	89,811			$	84,415
	Gross amounts offset on balance sheet	—				—
	Net amounts of assets on balance sheet	89,811				84,415
	Commodity derivative liabilities:
	Gross amounts of recognized liabilities	(830		)		(4,770		)
	Gross amounts offset on balance sheet	—				16
	Net amounts of liabilities on balance sheet	$	(830	)		$	(4,754	)
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	March 31, 2015				December 31, 2014
	Derivative assets	$	52,392			$	52,423
	Noncurrent derivative assets	37,419				31,992
	Net amounts of assets on balance sheet	89,811				84,415
	Derivative liabilities	(254		)		(1,645		)
	Noncurrent derivative liabilities	(576		)		(3,109		)
	Net amounts of liabilities on balance sheet	(830		)		(4,754		)
	Total derivative assets, net	$	88,981			$	79,661
NYMEX WTI [Member]
Summary of Outstanding Contracts with Respect to Crude Oil	At March 31, 2015, the Company had outstanding derivative contracts with respect to future production as set forth in the tables below.
	Crude Oil - NYMEX WTI				Ceilings
							Weighted Average
	Period and Type of Contract	Bbls			Range		Price
	July 2015 - December 2015
	Written call options - WTI (1)	2,208,000			$95.85 - $103.75		$	98.36
ICE Brent [Member]
Summary of Outstanding Contracts with Respect to Crude Oil
	Crude Oil - ICE Brent				Ceilings
									Weighted Average
	Period and Type of Contract	Bbls			Range				Price
	July 2015 - December 2015
	Written call options - ICE Brent (1)	368,000			$	107.4			$	107.4
	January 2016 - December 2016
	Written call options - ICE Brent (1)	1,464,000			$	107.7			$	107.7

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2015
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 March 31, 2015 and December 31, 2014.
		Fair value measurements at March 31, 2015 using:
	In thousands	Level 1		Level 2			Level 3		Total
	Derivative assets (liabilities):
	Fixed price swaps	$	—	$	69,091		$	—	$	69,091
	Collars	—		20,720			—		20,720
	Written call options	—		(830		)	—		(830		)
	Total	$	—	$	88,981		$	—	$	88,981
		Fair value measurements at December 31, 2014 using:
	In thousands	Level 1		Level 2			Level 3		Total
	Derivative assets (liabilities):
	Fixed price swaps	$	—	$	62,599		$	—	$	62,599
	Collars	—		21,816			—		21,816
	Written call options	—		(4,754		)	—		(4,754		)
	Total	$	—	$	79,661		$	—	$	79,661
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 strip prices through 2019 (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 March 31,
	In thousands	2015		2014
	Proved property impairments	$	70,016	$	3,762
	Unproved property impairments	77,545		54,446
	Total	$	147,561	$	58,208
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.
		March 31, 2015					December 31, 2014
	In thousands	Carrying		Fair Value			Carrying		Fair Value
		Amount					Amount
	Debt:
	Credit facility	$	955,000	$	955,000		$	165,000	$	165,000
	Note payable	15,942		14,500			16,457		14,900
	7.375% Senior Notes due 2020	198,889		213,700			198,850		213,000
	7.125% Senior Notes due 2021	400,000		416,300			400,000		421,000
	5% Senior Notes due 2022	2,022,337		1,998,500			2,022,949		1,857,900
	4.5% Senior Notes due 2023	1,500,000		1,445,000			1,500,000		1,372,800
	3.8% Senior Notes due 2024	996,696		918,900			996,622		868,700
	4.9% Senior Notes due 2044	698,045		625,300			698,037		572,400
	Total debt	$	6,786,909	$	6,587,200		$	5,997,915	$	5,485,700

LongTerm_Debt_Tables

Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2015
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 March 31, 2015.
			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
	-1	On or after these dates, the Company has the option to redeem all or a portion of its senior notes of the applicable series 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 of the applicable series at the “make-whole” redemption prices or amounts specified in the Indentures 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 March 31, 2015 and December 31, 2014:
	In thousands		31-Mar-15			December 31, 2014
	Credit facility		$	955,000		$	165,000
	Note payable		15,942			16,457
	7.375% Senior Notes due 2020 (1)		198,889			198,850
	7.125% Senior Notes due 2021 (2)		400,000			400,000
	5% Senior Notes due 2022 (3)		2,022,337			2,022,949
	4.5% Senior Notes due 2023 (2)		1,500,000			1,500,000
	3.8% Senior Notes due 2024 (4)		996,696			996,622
	4.9% Senior Notes due 2044 (5)		698,045			698,037
	Total debt		$	6,786,909		$	5,997,915
	Less: Current portion of long-term debt		2,093			2,078
	Long-term debt, net of current portion		$	6,784,816		$	5,995,837
	-1	The carrying amount is net of unamortized discounts of $1.1 million and $1.2 million at March 31, 2015 and December 31, 2014, respectively.
	-2	These notes were sold at par and are recorded at 100% of face value.
	-3	The carrying amount includes an unamortized premium of $22.3 million and $22.9 million at March 31, 2015 and December 31, 2014, respectively.
	-4	The carrying amount is net of unamortized discounts of $3.3 million and $3.4 million at March 31, 2015 and December 31, 2014, respectively.
	-5	The carrying amount is net of an unamortized discount of $2.0 million at both March 31, 2015 and December 31, 2014

StockBased_Compensation_Tables

Stock-Based Compensation (Tables) (Restricted stock [Member])	3 Months Ended
	Mar. 31, 2015
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 three months ended March 31, 2015 is presented below:
		Number of		Weighted
		non-vested		average
		shares		grant-date
				fair value
	Non-vested restricted shares outstanding at December 31, 2014	2,678,764		$	49.4
	Granted	1,233,574		47.91
	Vested	(180,733	)	51.28
	Forfeited	(54,576	)	53.67
	Non-vested restricted shares outstanding at March 31, 2015	3,677,029		$	48.74

Organization_and_Nature_of_Bus1

Organization and Nature of Business - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2015
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of crude oil and natural gas production concentrated in crude oil	69.00%
Percentage of crude oil and natural gas revenue concentrated in crude oil	84.00%
North Region [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of operations concentrated in geographic areas	72.00%
Percentage of revenues concentrated in geographic areas	78.00%
South Region [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Percentage of operations concentrated in geographic areas	28.00%
Percentage of revenues concentrated in geographic areas	22.00%

Basis_of_Presentation_and_Sign3

Basis of Presentation and Significant Accounting Policies - Components of Inventories (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Accounting Policies [Abstract]
Tubular goods and equipment	$16,214	$15,659
Crude oil	92,133	86,520
Total	$108,347	$102,179

Basis_of_Presentation_and_Sign4

Basis of Presentation and Significant Accounting Policies - Earnings Per Share (Detail) (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Accounting Policies [Abstract]
Weighted Average Number Diluted Shares Outstanding Adjustment	925,000
Income (loss) (numerator):
Net income (loss) - basic and diluted	($131,971)	$226,234
Weighted average shares - basic	369,385,000	368,658,000
Non-vested restricted stock (1)	0	1,398,000
Weighted average shares - diluted	369,385,000	370,056,000
Net income (loss) per share:
Basic (in dollars per share)	($0.36)	$0.61
Diluted (in dollars per share)	($0.36)	$0.61

Basis_of_Presentation_and_Sign5

Basis of Presentation and Significant Accounting Policies Basis of Presentation and Significant Accounting Policies - New Accounting Pronouncements (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015
Accounting Policies [Abstract]
Estimated Debt Issue Costs to be Reclassified	$76

Basis_of_Presentation_and_Sign6

Basis of Presentation and Significant Accounting Policies Basis of Presentation and Significant Accounting Policies - Income Taxes (Details) (USD $)	Mar. 31, 2015
In Millions, unless otherwise specified
Income Tax Disclosure [Abstract]
Deferred Tax Assets, Valuation Allowance	$11.10

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Noncash Investing Activities [Abstract]
Increase (decrease) in accrued capital expenditures	($260,204)	$47,508
Asset retirement obligation additions and revisions, net	2,703	1,270
Supplemental Cash Flow Elements [Abstract]
Cash paid for interest	51,790	52,194
Cash paid for income taxes	6	0
Cash received for income tax refunds	$50,000	$5

Derivative_Instruments_Summary

Derivative Instruments - Summary of Outstanding Contracts with Respect to Crude Oil (Detail)	3 Months Ended
	Mar. 31, 2015
	bbl
West Texas Intermediate [Member] | Call Option July 2015 to December 2015 [Member]
Derivative [Line Items]
Oil Production Derivative Volume	2,208,000
Derivative, Average Price Risk Option Strike Price	98.36
West Texas Intermediate [Member] | Minimum [Member] | Call Option July 2015 to December 2015 [Member]
Derivative [Line Items]
Derivative, Price Risk Option Strike Price	95.85
West Texas Intermediate [Member] | Maximum [Member] | Call Option July 2015 to December 2015 [Member]
Derivative [Line Items]
Derivative, Price Risk Option Strike Price	103.75
ICE Brent [Member] | Call Option July 2015 to December 2015 [Member]
Derivative [Line Items]
Oil Production Derivative Volume	368,000
Derivative, Average Price Risk Option Strike Price	107.4
ICE Brent [Member] | Call Option January 2016 to December 2016 [Member]
Derivative [Line Items]
Oil Production Derivative Volume	1,464,000
Derivative, Average Price Risk Option Strike Price	107.7

Derivative_Instruments_Summary1

Derivative Instruments - Summary of Outstanding Contracts with Respect to Natural Gas (Detail) (Natural Gas [Member])	3 Months Ended
	Mar. 31, 2015
	MMBTU
April 2015 to December 2015 Swaps [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus	11,000,000
Swaps Weighted Average Price	4.16
April 2015 to December 2015 Collars [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus	22,000,000
Floors, Weighted Average Price	3.69
Ceilings, Weighted Average Price	5.04
January Two Thousand Sixteen to December Two Thousand Sixteen Swaps [Member]
Derivative [Line Items]
Natural Gas Production Derivative Volume, MMBtus	63,110,000
Swaps Weighted Average Price	3.98
Minimum [Member] | April 2015 to December 2015 Collars [Member]
Derivative [Line Items]
Derivative, Floor Price	3.5
Derivative, Cap Price	4.89
Maximum [Member] | April 2015 to December 2015 Collars [Member]
Derivative [Line Items]
Derivative, Floor Price	3.75
Derivative, Cap Price	5.48

Derivative_Instruments_Realize

Derivative Instruments - Realized and Unrealized Gains and Losses on Derivative Instruments (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	$23,435	($33,264)
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	9,320	-6,410
Gain (loss) on derivative instruments, net	32,755	-39,674
Fixed price swaps | Crude Oil [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	0	-22,523
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	0	13,690
Fixed price swaps | Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	18,391	-10,157
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	6,492	-25,401
Collars | Crude Oil [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	0	-584
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	0	5,283
Collars | Natural Gas [Member]
Cash received (paid) on derivatives:
Cash received (paid) on derivatives, net	5,044	0
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	-1,096	18
Call Option [Member] | Crude Oil [Member]
Non-cash gain (loss) on derivatives:
Non-cash gain (loss) on derivatives, net	$3,924	$0

Derivative_Instruments_Gross_A

Derivative Instruments - Gross Amounts of Recognized Derivative Assets and Liabilities (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Gross amounts of recognized assets	($89,811)	($84,415)
Derivative Asset, Fair Value, Gross Asset	0	0
Net amounts of assets on balance sheet	89,811	84,415
Gross amounts of recognized liabilities	-830	-4,770
Derivative Liability, Fair Value, Gross Asset	0	16
Net amounts of liabilities on balance sheet	($830)	($4,754)

Derivative_Instruments_Reconci

Derivative Instruments - Reconciles Net Amounts Derivative Assets and Liabilities (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative assets	$52,392	$52,423
Noncurrent derivative assets	37,419	31,992
Net amounts of assets on balance sheet	89,811	84,415
Derivative liabilities	-254	-1,645
Noncurrent derivative liabilities	-576	-3,109
Net amounts of liabilities on balance sheet	-830	-4,754
Total derivative assets, net	$88,981	$79,661

Fair_Value_Measurements_Valuat

Fair Value Measurements - Valuation of Financial Instruments by Pricing Levels (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Derivative assets (liabilities):
Derivative assets (liabilities)	$88,981	$79,661
Fixed price swaps
Derivative assets (liabilities):
Derivative assets (liabilities)	69,091	62,599
Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	20,720	21,816
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)	88,981	79,661
Fair Value, Inputs, Level 2 [Member] | Fixed price swaps
Derivative assets (liabilities):
Derivative assets (liabilities)	69,091	62,599
Fair Value, Inputs, Level 2 [Member] | Collars
Derivative assets (liabilities):
Derivative assets (liabilities)	20,720	21,816
Fair Value, Inputs, Level 2 [Member] | Call Option [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	-830	-4,754
Fair Value | Call Option [Member]
Derivative assets (liabilities):
Derivative assets (liabilities)	-830	-4,754
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)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 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
	Mar. 31, 2015	Mar. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	$70,016,000	$3,762,000
Unproved property impairments	77,545,000	54,446,000
Total	147,561,000	58,208,000
Oil and gas property fair value after impairment	38,200,000	1,100,000
Emerging Areas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	36,100,000
Non-Bakken North Region [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	8,100,000
Medicine Pole Hill Units [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	14,700,000
South Region [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proved property impairments	$11,100,000

Fair_Value_Measurements_Fair_V

Fair Value Measurements - Fair Values of Financial Instruments not Recorded at Fair Value (Detail) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Dec. 31, 2014
7.375% Senior Notes due 2020
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	7.38%
Debt Instrument, Maturity Date, Description	2020
7.125% Senior Notes due 2021
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	7.13%
Debt Instrument, Maturity Date, Description	2021
5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	5.00%
Debt Instrument, Maturity Date, Description	2022
4.5% Senior Notes due 2023 [Member]
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	4.50%
Debt Instrument, Maturity Date, Description	2023
3.8% Senior Notes due 2024 [Member]
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	3.80%
Debt Instrument, Maturity Date, Description	2024
4.9% Senior Notes due 2044 [Member]
Fair Value Measurements [Line Items]
Debt Instrument, stated interest rate	4.90%
Debt Instrument, Maturity Date, Description	2044
Carrying Amount
Fair Value Measurements [Line Items]
Credit facility	955,000		$165,000
Note payable	15,942		16,457
Total debt	6,786,909		5,997,915
Carrying Amount | 7.375% Senior Notes due 2020
Fair Value Measurements [Line Items]
Senior notes	198,889	[1]	198,850	[1]
Carrying Amount | 7.125% Senior Notes due 2021
Fair Value Measurements [Line Items]
Senior notes	400,000	[2]	400,000	[2]
Carrying Amount | 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	2,022,337	[3]	2,022,949	[3]
Carrying Amount | 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	1,500,000	[2]	1,500,000	[2]
Carrying Amount | 3.8% Senior Notes due 2024 [Member]
Fair Value Measurements [Line Items]
Senior notes	996,696	[4]	996,622	[4]
Carrying Amount | 4.9% Senior Notes due 2044 [Member]
Fair Value Measurements [Line Items]
Senior notes	698,045	[5]	698,037	[5]
Fair Value
Fair Value Measurements [Line Items]
Credit facility	955,000		165,000
Note payable	14,500		14,900
Total debt	6,587,200		5,485,700
Fair Value | 7.375% Senior Notes due 2020
Fair Value Measurements [Line Items]
Senior notes	213,700		213,000
Fair Value | 7.125% Senior Notes due 2021
Fair Value Measurements [Line Items]
Senior notes	416,300		421,000
Fair Value | 5% Senior Notes due 2022
Fair Value Measurements [Line Items]
Senior notes	1,998,500		1,857,900
Fair Value | 4 1/2% Senior Notes Due 2023
Fair Value Measurements [Line Items]
Senior notes	1,445,000		1,372,800
Fair Value | 3.8% Senior Notes due 2024 [Member]
Fair Value Measurements [Line Items]
Senior notes	918,900		868,700
Fair Value | 4.9% Senior Notes due 2044 [Member]
Fair Value Measurements [Line Items]
Senior notes	625,300		$572,400
[1]	The carrying amount is net of unamortized discounts of $1.1 million and $1.2 million at March 31, 2015 and December 31, 2014, respectively.
[2]	These notes were sold at par and are recorded at 100% of face value.
[3]	The carrying amount includes an unamortized premium of $22.3 million and $22.9 million at March 31, 2015 and December 31, 2014, respectively.
[4]	The carrying amount is net of unamortized discounts of $3.3 million and $3.4 million at March 31, 2015 and December 31, 2014, respectively.
[5]	The carrying amount is net of an unamortized discount of $2.0 million at both March 31, 2015 and December 31, 2014.

LongTerm_Debt_LongTerm_Debt_De

Long-Term Debt - Long-Term Debt (Detail) (USD $)	Mar. 31, 2015		Dec. 31, 2014
Debt Instrument [Line Items]
Less: Current portion of long-term debt	($2,093,000)		($2,078,000)
Long-term debt, net of current portion	6,784,816,000		5,995,837,000
7.375% Senior Notes due 2020
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	7.38%
Debt Instrument, Unamortized Discount	1,100,000		1,200,000
7.125% Senior Notes due 2021
Debt Instrument [Line Items]
Debt Instrument Carrying Value To Face Value Percentage	100.00%
Debt Instrument, stated interest rate	7.13%
5% Senior Notes due 2022
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	5.00%
Debt Instrument, Unamortized Premium	22,300,000		22,900,000
Note Payable [Member]
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	3.14%
Note payable	22,000,000
3.8% Senior Notes due 2024 [Member]
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	3.80%
Debt Instrument, Unamortized Discount	3,300,000		3,400,000
4.9% Senior Notes due 2044 [Member]
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.90%
Debt Instrument, Unamortized Discount	2,000,000		2,000,000
Carrying Amount
Debt Instrument [Line Items]
Credit facility	955,000,000		165,000,000
Note payable	15,942,000		16,457,000
Total debt	6,786,909,000		5,997,915,000
Carrying Amount | 7.375% Senior Notes due 2020
Debt Instrument [Line Items]
Senior notes	198,889,000	[1]	198,850,000	[1]
Carrying Amount | 7.125% Senior Notes due 2021
Debt Instrument [Line Items]
Senior notes	400,000,000	[2]	400,000,000	[2]
Carrying Amount | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	2,022,337,000	[3]	2,022,949,000	[3]
Carrying Amount | 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	1,500,000,000	[2]	1,500,000,000	[2]
Carrying Amount | 3.8% Senior Notes due 2024 [Member]
Debt Instrument [Line Items]
Senior notes	996,696,000	[4]	996,622,000	[4]
Carrying Amount | 4.9% Senior Notes due 2044 [Member]
Debt Instrument [Line Items]
Senior notes	698,045,000	[5]	698,037,000	[5]
Fair Value
Debt Instrument [Line Items]
Credit facility	955,000,000		165,000,000
Note payable	14,500,000		14,900,000
Total debt	6,587,200,000		5,485,700,000
Fair Value | 7.375% Senior Notes due 2020
Debt Instrument [Line Items]
Senior notes	213,700,000		213,000,000
Fair Value | 7.125% Senior Notes due 2021
Debt Instrument [Line Items]
Senior notes	416,300,000		421,000,000
Fair Value | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	1,998,500,000		1,857,900,000
Fair Value | 4 1/2% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	1,445,000,000		1,372,800,000
Fair Value | 3.8% Senior Notes due 2024 [Member]
Debt Instrument [Line Items]
Senior notes	918,900,000		868,700,000
Fair Value | 4.9% Senior Notes due 2044 [Member]
Debt Instrument [Line Items]
Senior notes	$625,300,000		$572,400,000
[1]	The carrying amount is net of unamortized discounts of $1.1 million and $1.2 million at March 31, 2015 and December 31, 2014, respectively.
[2]	These notes were sold at par and are recorded at 100% of face value.
[3]	The carrying amount includes an unamortized premium of $22.3 million and $22.9 million at March 31, 2015 and December 31, 2014, respectively.
[4]	The carrying amount is net of unamortized discounts of $3.3 million and $3.4 million at March 31, 2015 and December 31, 2014, respectively.
[5]	The carrying amount is net of an unamortized discount of $2.0 million at both March 31, 2015 and December 31, 2014.

LongTerm_Debt_Additional_Infor

Long-Term Debt - Additional Information (Detail) (USD $)	3 Months Ended
	Mar. 31, 2015		Dec. 31, 2014
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	1.80%
Line of credit facility, maturity date	16-May-19
Aggregate amount of lender commitments on credit facility	$2,500,000,000
Line of Credit Facility, Maximum Borrowing Capacity	4,000,000,000
Line of credit facility, commitment fee percentage, per annum	0.23%
Current portion of long-term debt	2,093,000		2,078,000
Line of Credit Facility, Covenant Terms	0.65
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of credit facility, unused commitments	1,540,000,000
4.5% Senior Notes due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.50%
Debt Instrument, Maturity Date, Description	2023
Note Payable [Member]
Debt Instrument [Line Items]
Notes Payable	22,000,000
Loan term	10 years
Debt Instrument, stated interest rate	3.14%
Debt Instrument, Maturity Date	26-Feb-22
7.375% Senior Notes due 2020
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	7.38%
Debt Instrument, Maturity Date, Description	2020
7.125% Senior Notes due 2021
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	7.13%
Debt Instrument, Maturity Date, Description	2021
5% Senior Notes due 2022
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	5.00%
Debt Instrument, Maturity Date, Description	2022
3.8% Senior Notes due 2024 [Member]
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	3.80%
Debt Instrument, Maturity Date, Description	2024
4.9% Senior Notes due 2044 [Member]
Debt Instrument [Line Items]
Debt Instrument, stated interest rate	4.90%
Debt Instrument, Maturity Date, Description	2044
Carrying Amount
Debt Instrument [Line Items]
Line of credit facility, amount outstanding	955,000,000		165,000,000
Notes Payable	15,942,000		16,457,000
Carrying Amount | 7.375% Senior Notes due 2020
Debt Instrument [Line Items]
Senior notes	198,889,000	[1]	198,850,000	[1]
Carrying Amount | 7.125% Senior Notes due 2021
Debt Instrument [Line Items]
Senior notes	400,000,000	[2]	400,000,000	[2]
Carrying Amount | 5% Senior Notes due 2022
Debt Instrument [Line Items]
Senior notes	2,022,337,000	[3]	2,022,949,000	[3]
Carrying Amount | 3.8% Senior Notes due 2024 [Member]
Debt Instrument [Line Items]
Senior notes	996,696,000	[4]	996,622,000	[4]
Carrying Amount | 4.9% Senior Notes due 2044 [Member]
Debt Instrument [Line Items]
Senior notes	$698,045,000	[5]	$698,037,000	[5]
[1]	The carrying amount is net of unamortized discounts of $1.1 million and $1.2 million at March 31, 2015 and December 31, 2014, respectively.
[2]	These notes were sold at par and are recorded at 100% of face value.
[3]	The carrying amount includes an unamortized premium of $22.3 million and $22.9 million at March 31, 2015 and December 31, 2014, respectively.
[4]	The carrying amount is net of unamortized discounts of $3.3 million and $3.4 million at March 31, 2015 and December 31, 2014, respectively.
[5]	The carrying amount is net of an unamortized discount of $2.0 million at both March 31, 2015 and December 31, 2014.

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)	3 Months Ended
	Mar. 31, 2015
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
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
Senior Notes due 2024 [Domain]
Debt Instrument [Line Items]
Maturity date	1-Jun-24
Interest payment dates	June 1, Dec. 1
Make-whole redemption period	1-Mar-24
Senior Notes due 2044 [Member]
Debt Instrument [Line Items]
Maturity date	1-Jun-44
Interest payment dates	June 1, Dec. 1
Make-whole redemption period	1-Dec-43

Commitments_and_Contingencies_

Commitments and Contingencies - Additional Information (Detail) (USD $)	1 Months Ended	3 Months Ended
In Millions, unless otherwise specified	Nov. 30, 2010	Mar. 31, 2015
Long-term Purchase Commitment [Line Items]
Total future drilling commitments at balance sheet date		$564
Drilling commitments due remainder of current year		186
Drilling commitments Year Two		220
Drilling Commitments Year Three		125
Drilling Commitments Year Four		33
Future Drilling Commitments End Date		2018-09
Loss related to contingency damages	165
Legal proceedings recorded as a liability under other noncurrent liabilities		-2.9
Fuel Purchase Commitment End Date		2016-01
Pipeline Transportation Commitments [Member]
Long-term Purchase Commitment [Line Items]
Pipeline commitments, end date		2025
Purchase Obligation, total		1,000
Purchase Obligation, due in remainder of current year		153
Purchase Obligation, due second year		207
Purchase Obligation, due third year		201
Purchase Obligation, due fourth year		195
Purchase Obligation, due fifth year		159
Purchase Obligation, Due after Fifth Year		109
Non-operational [Member]
Long-term Purchase Commitment [Line Items]
Crude oil non-op transportation commitment, total		260
Fuel [Member]
Long-term Purchase Commitment [Line Items]
Purchase Obligation, total		75
Purchase Obligation, Due in Next Twelve Months		44
Purchase Obligation, due second year		$31

Stock_Based_Compensation_Stock

Stock Based Compensation - Stock Based Compensation Expenses (Detail) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Non-cash equity compensation	$11.30	$11

StockBased_Compensation_Additi

Stock-Based Compensation - Additional Information (Detail) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015
Restricted stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock available to grant	16,944,983
Fair value at vesting date	$8.60
Unrecognized compensation expense related to non-vested	$115
Unrecognized compensation expense related to non-vested, period for recognition, in years	1 year 9 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
2013 Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock available for issue	19,680,072

Stock_Based_Compensation_Summa

Stock Based Compensation - Summary of Changes in Non Vested Shares of Restricted Stock Outstanding (Detail) (USD $)	3 Months Ended
	Mar. 31, 2015
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	2,678,764
Granted shares	1,233,574
Vested shares	-180,733
Forfeited shares	-54,576
Non-vested shares, ending balance	3,677,029
Non-vested, weighted average grant-date fair value, beginning of period	$49.40
Granted, weighted average grant-date fair value	$47.91
Vested, weighted average grant-date fair value	$51.28
Forfeited, weighted average grant-date fair value	$53.67
Non-vested, weighted average grant-date fair value, end of period	$48.74

Property_Dispositions_Addition

Property Dispositions - Additional Information (Detail) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Property Dispositions (Line Items)
Proceeds from sale of assets	$903,000	$35,433,000
Recognized pre-tax loss		$8,500,000

Accumulated_Other_Comprehensiv1

Accumulated Other Comprehensive Income (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Accumulated Other Comprehensive Income (Loss), Net of Tax	($3,490)		($385)
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Gain (Loss) Arising During Period, Net of Tax	-3,105	0
Translation Adjustment Functional to Reporting Currency, Tax Benefit (Expense)	0
Other Comprehensive Income (Loss), Net of Tax (unaudited)	($3,105)	$0