Chaparral Energy (CHAP) 10-Q 14 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document	9 Months Ended
	Sep. 30, 2013	Nov. 14, 2013	Nov. 14, 2013	Nov. 14, 2013	Nov. 14, 2013	Nov. 14, 2013	Nov. 14, 2013	Nov. 14, 2013
		Common Class A	Common Class B	Common Class C	Common Class D	Common Class E	Common Class F	Common Class G
Entity Information [Line Items]	'	'	'	'	'	'	'	'
Entity Registrant Name	'Chaparral Energy, Inc.	'	'	'	'	'	'	'
Entity Central Index Key	'0001346980	'	'	'	'	'	'	'
Current Fiscal Year End Date	'--12-31	'	'	'	'	'	'	'
Entity Filer Category	'Non-accelerated Filer	'	'	'	'	'	'	'
Document Type	'10-Q	'	'	'	'	'	'	'
Document Period End Date	30-Sep-13	'	'	'	'	'	'	'
Document Fiscal Year Focus	'2013	'	'	'	'	'	'	'
Document Fiscal Period Focus	'Q3	'	'	'	'	'	'	'
Amendment Flag	'false	'	'	'	'	'	'	'
Entity Common Stock, Shares Outstanding	'	70,145	357,882	209,882	279,999	504,276	1	3

Consolidated_balance_sheets

Consolidated balance sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Assets	'	'
Cash and cash equivalents	$37,314	$29,819
Accounts receivable, net	96,463	77,307
Inventories, net	12,069	10,510
Prepaid expenses	2,714	3,465
Derivative instruments	4,449	42,516
Deferred income taxes	989	0
Total current assets	153,998	163,617
Property and equipmentbat cost, net	67,302	65,601
Oil and natural gas properties, using the full cost method:	'	'
Proved	3,062,399	2,860,611
Unevaluated (excluded from the amortization base)	250,026	162,921
Accumulated depreciation, depletion, amortization and impairment	-1,420,348	-1,290,356
Total oil and natural gas properties	1,892,077	1,733,176
Derivative instruments	4,032	517
Assets held for sale	4,599	5,689
Other assets	35,940	38,952
Total assets	2,157,948	2,007,552
Liabilities and stockholders' equity	'	'
Accounts payable and accrued liabilities	116,225	101,598
Accrued payroll and benefits payable	22,293	19,655
Accrued interest payable	33,390	24,131
Revenue distribution payable	23,333	18,152
Current maturities of long-term debt	3,322	3,746
Derivative instruments	6,971	436
Deferred income taxes	0	26,872
Total current liabilities	205,534	194,590
Long-term debt, less current maturities	1,376,736	1,289,656
Derivative instruments	22	2,192
Stock-based compensation	3,133	3,042
Asset retirement obligations, net of current portion	45,349	46,314
Deferred income taxes	45,394	8,901
Commitments and contingencies (Note 10)	'	'
Stockholders' equity:	'	'
Preferred stock, 600,000 shares authorized, none issued and outstanding	0	0
Additional paid in capital	423,993	422,434
Retained earnings	52,328	17,186
Accumulated other comprehensive income, net of taxes	5,445	23,223
Total stockholders' equity	481,780	462,857
Total liabilities and stockholders' equity	2,157,948	2,007,552
Common Class A	'	'
Stockholders' equity:	'	'
Common stock	0	0
Common Class B	'	'
Stockholders' equity:	'	'
Common stock	4	4
Common Class C	'	'
Stockholders' equity:	'	'
Common stock	2	2
Common Class D	'	'
Stockholders' equity:	'	'
Common stock	3	3
Common Class E	'	'
Stockholders' equity:	'	'
Common stock	5	5
Common Class F	'	'
Stockholders' equity:	'	'
Common stock	0	0
Common Class G	'	'
Stockholders' equity:	'	'
Common stock	$0	$0

Consolidated_balance_sheets_Pa

Consolidated balance sheets (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Preferred stock, shares authorized	600,000	600,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Common Class A	'	'
Common stock, par value	0.01	0.01
Common stock, shares authorized	10,000,000	10,000,000
Common stock, shares issued	70,224	67,991
Common stock, shares outstanding	70,224	67,991
Common Class B	'	'
Common stock, par value	0.01	0.01
Common stock, shares authorized	10,000,000	10,000,000
Common stock, shares issued	357,882	357,882
Common stock, shares outstanding	357,882	357,882
Common Class C	'	'
Common stock, par value	0.01	0.01
Common stock, shares authorized	10,000,000	10,000,000
Common stock, shares issued	209,882	209,882
Common stock, shares outstanding	209,882	209,882
Common Class D	'	'
Common stock, par value	0.01	0.01
Common stock, shares authorized	10,000,000	10,000,000
Common stock, shares issued	279,999	279,999
Common stock, shares outstanding	279,999	279,999
Common Class E	'	'
Common stock, par value	0.01	0.01
Common stock, shares authorized	10,000,000	10,000,000
Common stock, shares issued	504,276	504,276
Common stock, shares outstanding	504,276	504,276
Common Class F	'	'
Common stock, par value	0.01	0.01
Common stock, shares authorized	1	1
Common stock, shares issued	1	1
Common stock, shares outstanding	1	1
Common Class G	'	'
Common stock, par value	0.01	0.01
Common stock, shares authorized	3	3
Common stock, shares issued	3	3
Common stock, shares outstanding	3	3

Consolidated_statements_of_ope

Consolidated statements of operations (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Revenues:	'	'	'	'
Oil and natural gas sales	$161,623	$131,215	$433,489	$374,452
Gain from oil hedging activities	9,032	11,468	28,544	35,777
Total revenues	170,655	142,683	462,033	410,229
Costs and expenses:	'	'	'	'
Lease operating	37,306	35,278	104,232	98,946
Production taxes	8,831	8,748	25,299	24,258
Depreciation, depletion & amortization	47,582	44,421	139,439	119,807
Loss on impairment of other assets	1,090	0	1,090	0
General and administrative	13,065	12,878	38,626	39,165
Total costs and expenses	107,874	101,325	308,686	282,176
Operating income	62,781	41,358	153,347	128,053
Non-operating income (expense):	'	'	'	'
Interest expense	-24,074	-24,087	-72,565	-72,666
Non-hedge derivative (losses) gains	-43,830	-25,030	-26,484	37,035
Loss on extinguishment of debt	0	-18	0	-21,714
Other income, net	425	104	837	236
Net non-operating expense	-67,479	-49,031	-98,212	-57,109
(Loss) income before income taxes	-4,698	-7,673	55,135	70,944
Income tax (benefit) expense	-2,130	-2,727	19,993	25,645
Net (loss) income	($2,568)	($4,946)	$35,142	$45,299

Consolidated_statements_of_com

Consolidated statements of comprehensive (loss) income (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Comprehensive income	'	'	'	'
Net (loss) income	($2,568)	($4,946)	$35,142	$45,299
Other comprehensive loss	'	'	'	'
Reclassification adjustment for hedge gains included in gain from oil hedging activities in the consolidated statements of operations	-9,032	-11,468	-28,544	-35,777
Income tax benefit related to other comprehensive loss	3,306	4,129	10,766	14,717
Other comprehensive loss, net of tax	-5,726	-7,339	-17,778	-21,060
Comprehensive (loss) income	($8,294)	($12,285)	$17,364	$24,239

Consolidated_statements_of_cas

Consolidated statements of cash flows (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Cash flows from operating activities	'	'
Net income	$35,142	$45,299
Adjustments to reconcile net income to net cash provided by operating activities	'	'
Depreciation, depletion & amortization	139,439	119,807
Loss on impairment of other assets	1,090	0
Deferred income taxes	19,398	25,540
Gain from oil hedging activities	-28,544	-35,777
Non-hedge derivative losses (gains)	26,484	-37,035
Loss on extinguishment of debt	0	21,714
(Gain) loss on sale of assets	-556	21
Other	1,826	2,167
Change in assets and liabilities	'	'
Accounts receivable	-20,858	-13,140
Inventories	-1,689	-4,599
Prepaid expenses and other assets	2,130	1,763
Accounts payable and accrued liabilities	17,694	13,355
Revenue distribution payable	5,181	-2,215
Stock-based compensation	1,747	2,077
Net cash provided by operating activities	198,484	138,977
Cash flows from investing activities	'	'
Purchase of property and equipment and oil and natural gas properties	-382,167	-379,069
Proceeds from dispositions of property and equipment and oil and natural gas properties	91,788	45,023
Settlement of non-hedge derivative instruments	13,097	24,309
Other	-664	23
Net cash used in investing activities	-277,946	-309,714
Cash flows from financing activities	'	'
Proceeds from long-term debt	133,208	156,457
Repayment of long-term debt and capital lease obligations	-51,416	-37,608
Proceeds from Senior Notes	0	400,000
Repayment of Senior Notes	0	-325,000
Proceeds from capital lease obligations	5,203	0
Principal payments under capital lease obligations	-38	-10
Payment of debt issuance costs and other financing fees	0	-8,867
Payment of debt extinguishment costs	0	-15,827
Net cash provided by financing activities	86,957	169,145
Net increase (decrease) in cash and cash equivalents	7,495	-1,592
Cash and cash equivalents at beginning of period	29,819	34,589
Cash and cash equivalents at end of period	$37,314	$32,997

Nature_of_operations_and_summa

Nature of operations and summary of significant accounting policies	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Nature of operations and summary of significant accounting policies	'
	Nature of operations and summary of significant accounting policies
	Nature of operations
	Chaparral Energy, Inc. and its subsidiaries, (collectively, “we”, “our”, “us”, or the “Company”) are involved in the acquisition, exploration, development, production and operation of oil and natural gas properties. Properties are located primarily in Oklahoma, Texas, New Mexico, Louisiana, Arkansas, and Kansas.
	Interim financial statements
	The accompanying unaudited consolidated interim financial statements of the Company have been prepared in accordance with the rules and regulations of the SEC and do not include all of the financial information and disclosures required by accounting principles generally accepted in the United States of America (“GAAP”) for complete financial statements. These financial statements and the notes thereto should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2012.
	The financial information as of September 30, 2013, and for the three and nine months ended September 30, 2013 and 2012, is unaudited. In management’s opinion, such information contains all adjustments, consisting only of normal recurring accruals, considered necessary for a fair presentation of the results of the interim periods. The results of operations for the three and nine months ended September 30, 2013 are not necessarily indicative of the results of operations that will be realized for the year ended December 31, 2013.
	Cash and cash equivalents
	We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents. We maintain cash and cash equivalents in bank deposit accounts and money market funds which may not be federally insured. As of September 30, 2013, cash with a recorded balance totaling $36,259 was held at JP Morgan Chase Bank, N.A. We have not experienced any losses in such accounts and believe we are not exposed to any significant credit risk on such accounts.
	Accounts receivable
	We have receivables from joint interest owners and oil and natural gas purchasers which are generally uncollateralized. We generally review our oil and natural gas purchasers for credit worthiness and general financial condition. We may have the ability to withhold future revenue disbursements to recover non-payment of joint interest billings on properties of which we are the operator. Accounts receivable from joint interest owners are stated at amounts due, net of an allowance for doubtful accounts. Accounts receivable are generally due within 30 days and accounts outstanding longer than 60 days are considered past due. We determine our allowance by considering the length of time past due, previous loss history, future net revenues of the debtor’s ownership interest in oil and natural gas properties we operate, and the owner’s ability to pay its obligation, among other things.
	We write off accounts receivable when they are determined to be uncollectible. Accounts receivable consisted of the following at September 30, 2013 and December 31, 2012:
		September 30,				December 31,
		2013				2012
	Joint interests	$	35,856			$	19,282
	Accrued oil and natural gas sales	61,380				50,814
	Derivative settlements	317				8,013
	Other	546				472
	Allowance for doubtful accounts	(1,636		)		(1,274		)
		$	96,463			$	77,307
	Inventories
	Inventories are comprised of equipment used in developing oil and natural gas properties and oil and natural gas production inventories. Equipment inventory is carried at the lower of cost or market using the average cost method. Oil and natural gas product inventories are stated at the lower of production cost or market. We regularly review inventory quantities on hand and record provisions for excess or obsolete inventory, if necessary. Inventories at September 30, 2013 and December 31, 2012 consisted of the following:
			September 30,				December 31,
			2013				2012
	Equipment inventory		$	9,688			$	8,047
	Oil and natural gas product		3,087				3,175
	Inventory valuation allowance		(706		)		(712		)
			$	12,069			$	10,510
	Oil and natural gas properties
	We use the full cost method of accounting for oil and natural gas properties and activities. Accordingly, we capitalize all costs incurred in connection with the exploration for and development of oil and natural gas reserves. Proceeds from the disposition of oil and natural gas properties are accounted for as a reduction in capitalized costs, with no gain or loss generally recognized unless such dispositions involve a significant alteration in the depletion rate. We sold certain oil and gas properties for total cash proceeds of approximately $90,530 and $44,523 subject to post-closing adjustments for the nine months ended September 30, 2013 and 2012, respectively, which did not have a significant impact on our depletion rate. After September 30, 2013, we also sold certain additional oil and gas properties for a total price of approximately $12,500 subject to post-closing adjustments.
	On October 11, 2013, we entered into an agreement with Cabot Oil & Gas Corporation to acquire certain oil and gas properties and related assets in the Panhandle Marmaton Play for $160,128 subject to pre- and post-closing adjustments (the “Cabot Acquisition”). We paid $16,013 in earnest money for the Cabot Acquisition with the balance due upon closing, which is expected to occur in the fourth quarter of 2013.
	We capitalize internal costs that can be directly identified with exploration and development activities, but do not include any costs related to production, general corporate overhead or similar activities. Capitalized costs include geological and geophysical work, 3D seismic, delay rentals, drilling and completing and equipping oil and natural gas wells, including salaries, benefits and other internal costs directly attributable to these activities.
	The costs of unevaluated oil and natural gas properties are excluded from amortization until the properties are evaluated. Costs are transferred into the amortization base on an ongoing basis as the properties are evaluated and proved reserves are established or impairment is determined. Work-in-progress costs are included in unevaluated oil and natural gas properties and as of September 30, 2013, include $95,358 of capital costs incurred for undeveloped acreage, $119,181 for the construction of CO2 delivery pipelines and facilities for which there are no reserves, and $35,487 for wells and facilities in progress pending determination. As of December 31, 2012, work-in-progress costs included capital costs incurred for undeveloped acreage of $64,840 and $84,183 for the construction of CO2 delivery pipelines and facilities for which there are no reserves and $13,898 for wells and facilities in progress pending determination.
	In accordance with the full cost method of accounting, the net capitalized costs of oil and natural gas properties are not to exceed their related PV-10 value, net of tax considerations, plus the cost of unproved properties not being amortized. The PV-10 value of our reserves as of September 30, 2013 was estimated based on average first day of the month prices of $95.04 per Bbl of oil and $3.60 per Mcf of natural gas for the twelve months ended September 30, 2013. The cost center ceiling exceeded the net capitalized cost of our oil and natural gas properties as of September 30, 2013, and no impairment was necessary. A decline in oil and natural gas prices subsequent to September 30, 2013 could result in ceiling test write-downs in future periods. The amount of any future impairment is difficult to predict, and will depend on the average oil and natural gas prices during each period, the incremental proved reserves added during each period, and additional capital spent.
	Assets Held for Sale
	In the third quarter of 2013, we reassessed the fair value of certain owned drilling rigs classified as assets held for sale. The accounting for these assets is in accordance with ASC 360-10, Property, Plant and Equipment, which requires assets to be carried on the balance sheet at their carrying value or fair value less cost to sell, whichever is less. In determining current fair value, management performed internal estimates of the value of these assets based on prices that would be received on the sale of each rig in an orderly transaction between market participants. As a result of determining current fair value on certain of the assets held for sale, an impairment loss was recorded in the third quarter of 2013 in the amount of $1,090, which was included in the loss on impairment of other assets in the consolidated statements of operations.
	Stock-based compensation
	Our stock-based compensation programs consist of phantom stock, restricted stock units (“RSU”), and restricted stock awards issued to employees. Generally, we use new shares to grant restricted stock awards, and we cancel restricted shares forfeited or repurchased for tax withholding. Canceled shares are available to be issued as new grants under our 2010 Equity Incentive Plan.
	The estimated fair value of the phantom stock and RSU awards is remeasured at the end of each reporting period until settlement. The estimated fair market value of these awards is calculated based on our total asset value less total liabilities, with both assets and liabilities being adjusted to fair value in accordance with the terms of the Phantom Stock Plan and the Non-Officer Restricted Stock Unit Plan. The primary adjustment required is the adjustment of oil and natural gas properties from net book value to the discounted and risk-adjusted reserve value based on internal reserve reports priced on NYMEX forward strips. Compensation cost associated with the phantom stock and RSU awards is recognized over the vesting period using the straight-line method and the accelerated method, respectively.
	The fair value of our restricted stock awards that include a service condition is based upon the estimated fair market value of our common stock on the date of grant, and is remeasured at the end of each reporting period until settlement. We recognize compensation cost over the requisite service period using the accelerated method for awards with graded vesting.
	We use a Monte Carlo model to estimate the grant date fair value of restricted stock awards that include a market condition. This model includes various significant assumptions, including the expected volatility of the share awards and the probabilities of certain vesting conditions. These assumptions reflect our best estimates, but they involve inherent uncertainties based on market conditions generally outside of our control. As a result, if other assumptions had been used, stock-based compensation expense could have been significantly impacted. Compensation cost associated with restricted stock awards that include a market condition is recognized over the requisite service period using the straight-line method.
	Recently adopted accounting pronouncements
	In December 2011, the Financial Accounting Standards Board (“FASB”) issued authoritative guidance that requires enhanced disclosures that will enable financial statement users to evaluate the effect or potential effect of netting arrangements on an entity’s financial position. In January 2013, additional guidance was issued which narrows the scope of the disclosure requirements to derivatives, securities borrowings, and securities lending transactions that are either offset or subject to a master netting arrangement. This guidance, which was effective and adopted by us in the first quarter of 2013, resulted in additional disclosures but had no financial impact.
	In February 2013, the FASB issued authoritative guidance that requires disclosures of the amounts reclassified out of accumulated other comprehensive income (“AOCI”) by component, including the respective line items of net income if the amount is required to be reclassified to net income in its entirety in the same reporting period. This additional guidance was effective and adopted by us in the first quarter of 2013. As our entire balance in AOCI consists of deferred hedge gains, implementation of the guidance had no significant impact on our financial statement presentation and disclosures.
	Recently issued accounting pronouncements
	In July 2011, the FASB issued authoritative guidance regarding how health insurers should recognize and classify in their income statements the fees mandated by the Health Care and Education Reconciliation Act (“HCERA”). The HCERA imposes an annual fee upon health insurers for each calendar year beginning on or after January 1, 2014. The annual fee will be allocated to individual entities providing health insurance to employees based on a ratio, as provided for in the HCERA, and is not tax deductible. This guidance specifies that once the entity has provided qualifying health insurance in the calendar year in which the fee is payable, the liability for the entity’s fee should be estimated and recorded in full with a corresponding deferred cost that is amortized to expense on a straight line basis, unless another method better allocates the fee over the calendar year that it is payable. This guidance is effective for calendar years beginning after December 15, 2013, once the fee is instituted. We are currently assessing the impact that this fee and the adoption of the related authoritative guidance will have on our financial statements.

Supplemental_disclosures_to_th

Supplemental disclosures to the consolidated statements of cash flows	9 Months Ended
	Sep. 30, 2013
Supplemental Cash Flow Elements [Abstract]	'
Supplemental disclosures to the consolidated statements of cash flows	'
	Supplemental disclosures to the consolidated statements of cash flows
	Supplemental disclosures to the consolidated statements of cash flows are presented below:
		Nine months ended September 30,
		2013			2012
	Net cash provided by operating activities included:
	Cash payments for interest	$	70,735		$	71,475
	Interest capitalized	(11,670		)	(3,311		)
	Cash payments for interest, net of amounts capitalized	$	59,065		$	68,164
	Cash payments for income taxes	$	240		$	100
	Non-cash investing activities included:
	Asset retirement costs capitalized	$	1,036		$	551
	Oil and natural gas properties acquired through increase in accounts payable and accrued liabilities	$	8,298		$	38,184

Longterm_debt

Long-term debt	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Long-term debt	'
	Long-term debt
	Long-term debt at September 30, 2013 and December 31, 2012, consisted of the following:
			September 30, 2013		December 31, 2012
	9.875% Senior Notes due 2020, net of discount of $5,581 and $5,969 at September 30, 2013 and December 31, 2012, respectively		$	294,419	$	294,031
	8.25% Senior Notes due 2021		400,000		400,000
	7.625% Senior Notes due 2022, including premium of $5,942 and $6,631 at September 30, 2013 and December 31, 2012, respectively		555,942		556,631
	Senior secured revolving credit facility		108,000		25,000
	Real estate mortgage notes, principal and interest payable monthly, bearing interest at rates ranging from 2.54% to 5.46%, due August 2021 through December 2028; collateralized by real property		11,322		12,596
	Installment notes payable, principal and interest payable monthly, bearing interest at rates ranging from 2.94% to 6.79%, due November 2013 through February 2018; collateralized by automobiles, machinery and equipment		5,210		5,144
	Capital lease obligations		5,165		—
			1,380,058		1,293,402
	Less current maturities		3,322		3,746
			$	1,376,736	$	1,289,656
	Senior Notes
	The Senior Notes, which, as of September 30, 2013, include our 9.875% Senior Notes due 2020, our 8.25% Senior Notes due 2021, and our 7.625% Senior Notes due 2022, are our senior unsecured obligations, rank equally in right of payment with all our existing and future senior debt, and rank senior to all of our existing and future subordinated debt. The indentures governing our Senior Notes contain certain covenants which limit our ability to:
	•	incur or guarantee additional debt and issue certain types of preferred stock;
	•	pay dividends on capital stock or redeem, repurchase or retire capital stock or subordinated debt;
	•	make investments;
	•	incur liens on assets;
	•	create restrictions on the ability of our restricted subsidiaries to pay dividends or make other payments to us;
	•	engage in transactions with affiliates;
	•	sell assets, including capital stock of our subsidiaries;
	•	consolidate, merge, or transfer assets; and
	•	enter into other lines of business.
	If we experience a change of control (as defined in the indentures governing the Senior Notes), including making certain asset sales, subject to certain conditions, we must give holders of the Senior Notes the opportunity to sell us their Senior Notes at 101% of the principal amount, plus accrued and unpaid interest.
	Chaparral Energy, Inc. is a holding company and owns no operating assets and has no significant operations independent of its subsidiaries. Our obligations under our outstanding Senior Notes have been fully and unconditionally guaranteed, on a joint and several basis, by all of our wholly owned subsidiaries except for Chaparral Biofuels, LLC.
	Senior secured revolving credit facility
	In April 2010, we entered into an Eighth Restated Credit Agreement (our “senior secured revolving credit facility”), which is collateralized by our oil and natural gas properties and, as amended, matures on November 1, 2017. The Thirteenth Amendment, effective October 29, 2013, amended our senior secured revolving credit facility to (a) increase our borrowing base from $500,000 to $550,000, (b) automatically increase the borrowing base to $600,000 upon the consummation of the Cabot Acquisition and (c) allow for the incurrence of $300,000 of unsecured senior or subordinated debt meeting the definition of “Additional Permitted Debt” under our senior secured revolving credit facility, (d) permit entering into swap agreements on production from to-be-acquired properties, including the assets to be acquired in the Cabot Acquisition, in notional amounts up to 80% of anticipated proved developed producing production therefrom if otherwise meeting additional necessary requirements under our senior secured revolving credit facility, and (e) increase permitted other debt from $40,000 to $50,000.
	Amounts borrowed under our senior secured revolving credit facility are subject to varying rates of interest based on (1) the total outstanding borrowings in relation to the borrowing base (the “utilization percentage”) and (2) whether we elect to borrow at the Eurodollar rate or the Alternate Base Rate (“ABR”). The entire balance outstanding at September 30, 2013 was subject to the Eurodollar rate. Subsequent to September 30, 2013, we have drawn down an additional $14,000 under our senior secured revolving credit facility. On November 12, 2013, we committed to borrow an additional $25,000 and will receive the funds on November 15, 2013.
	The Eurodollar rate is computed at the Adjusted LIBO Rate, defined as the rate applicable to dollar deposits in the London interbank market with a maturity comparable to the interest period (one, two, three or six months, selected by us) times a Statutory Reserve Rate multiplier, as defined in our senior secured revolving credit facility, plus a margin that varies depending on our utilization percentage. During the nine months ended September 30, 2013, the applicable margin was 1.50%. Interest payments on Eurodollar borrowings are due the last day of the interest period, if shorter than three months or every three months.
	Interest on loans subject to the ABR is computed as the greater of (1) the Prime Rate, as defined in our senior secured revolving credit facility, (2) the Federal Funds Effective Rate, as defined in our senior secured revolving credit facility, plus 0.50%, or (3) the Adjusted LIBO Rate, as defined in our senior secured revolving credit facility, plus 1%, plus a margin that varies depending on our utilization percentage.
	Commitment fees range from 0.375% to 0.50%, depending on our utilization percentage. During the nine months ended September 30, 2013, commitment fees accrued at the rate of 0.375% on the unused portion of the borrowing base amount, and were included as a component of interest expense. We have the right to make prepayments of the borrowings at any time without penalty or premium.
	Our senior secured revolving credit facility has certain negative and affirmative covenants that require, among other things, maintaining a Current Ratio, as defined in our senior secured revolving credit facility, of not less than 1.0 to 1.0 and a Consolidated Net Debt to Consolidated EBITDAX ratio, as defined in our senior secured revolving credit facility, of not greater than 4.5 to 1.0 for each period of four consecutive fiscal quarters ending on the last day of such applicable fiscal quarter.
	We believe we were in compliance with all covenants under our senior secured revolving credit facility as of September 30, 2013.
	Our senior secured revolving credit facility also specifies events of default, including non-payment, breach of warranty, non-performance of financial covenants, default on other indebtedness, certain adverse judgments, and change of control, among others. In addition, bankruptcy and insolvency events with respect to us or certain of our subsidiaries will result in an automatic acceleration of the indebtedness under our senior secured revolving credit facility. An acceleration of our indebtedness under our senior secured revolving credit facility could in turn result in an event of default under the indentures for our Senior Notes, which in turn could result in the acceleration of the Senior Notes.
	If the outstanding borrowings under our senior secured revolving credit facility were to exceed the borrowing base as a result of a redetermination, we would be required to eliminate this excess. Within 10 days after receiving notice of the new borrowing base, we would be required to make an election: (1) to repay a portion of our bank borrowings in the amount of the excess either in a lump sum within 30 days or in equal monthly installments over a six-month period, (2) to submit within 30 days additional oil and natural gas properties we own for consideration in connection with the determination of the borrowing base sufficient to eliminate the excess or (3) to eliminate the excess through a combination of repayments and the submission of additional oil and natural gas properties within 30 days.
	Capital Leases
	During the third quarter of 2013, we entered into a lease financing agreement with U.S. Bank National Association for approximately $5,200 through the sale and subsequent leaseback of an existing compressor owned by us. The lease financing obligation is for an 84-month term and includes an option to purchase the equipment for a specified price at 72 months as well as an option to purchase the equipment at the end of the lease term for its then-current fair market value. Lease payments related to the equipment are recognized as principal and interest expense based on a weighted average implicit interest rate of 3.4%. Minimum lease payments are approximately $625 annually. In October 2013, we finalized an additional lease financing agreement with U.S. Bank National Association for approximately $11,900 on the sale and subsequent leaseback of compressors.

Derivative_instruments

Derivative instruments	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative instruments	'
	Derivative instruments
	Overview
	Our results of operations, financial condition and capital resources are highly dependent upon the prevailing market prices of, and demand for, oil and natural gas. These commodity prices are subject to wide fluctuations and market uncertainties. To mitigate a portion of this exposure, we enter into various types of derivative instruments, including commodity price swaps, costless collars, put options, and basis protection swaps.
	For commodity price swaps, we receive a fixed price for the hedged commodity and pay a floating market price to the counterparty. The fixed-price payment and the floating-price payment are netted, resulting in a net amount due to or from the counterparty.
	Collars contain a fixed floor price (purchased put) and ceiling price (sold call). If the market price exceeds the call strike price or falls below the put strike price, we receive the fixed price and pay the market price. If the market price is between the call and the put strike price, no payments are due from either party. A three-way collar contract consists of a standard collar contract plus a sold put with a price below the floor price of the collar. The sold put option requires us to make a payment to the counterparty if the market price is below the sold put option price. If the market price is greater than the sold put option price, the result is the same as it would have been with a standard collar contract only. By combining the collar contract with the sold put option, we are entitled to a net payment equal to the difference between the floor price of the standard collar and the sold put option price if the market price falls below the sold put option price. This strategy enables us to increase the floor and the ceiling price of the collar beyond the range of a traditional costless collar utilizing the value associated with the sale of a put option.
	Put options may be purchased from the counterparty by our payment of a cash premium. If the market price is below the put strike price at the settlement date, we will receive a payment from the counterparty. Purchased put options are designed to provide a fixed price floor with the opportunity for upside if commodity prices increase.
	We enhance the value of certain oil swaps by combining them with sold puts or put spread contracts. Sold puts require us to make a payment to the counterparty if the market price is below the put strike price at the settlement date. If the market price is greater than the sold put price, the result is the same as it would have been with a swap contract only. A put spread is a combination of a sold put and a purchased put. If the market price falls below the purchased put option price, we will receive the spread between the sold put option price and the purchased put option price from the counterparty. The use of a sold put allows us to receive an above-market swap price while the purchased put provides a measure of downside protection.
	We use basis protection swaps to reduce basis risk. Basis is the difference between the physical commodity being hedged and the price of the futures contract used for hedging. Basis risk is the risk that an adverse change in the futures market will not be completely offset by an equal and opposite change in the cash price of the commodity being hedged. Basis risk exists in natural gas primarily due to the geographic price differentials between cash market locations and futures contract delivery locations. Natural gas basis protection swaps are arrangements that guarantee a price differential for natural gas from a specified pricing point. We receive a payment from the counterparty if the price differential is greater than the stated terms of the contract and pay the counterparty if the price differential is less than the stated terms of the contract.
	We protect a portion of our natural gas liquids production from price volatility using crude oil derivatives. The following table summarizes our crude oil derivatives outstanding as of September 30, 2013:
						Weighted average fixed price per Bbl
	Period and Type of Contract		Volume			Swaps				Sold puts				Purchased puts				Sold calls
			MBbls
	2013
	Swaps		510			$	95.54			$	—			$	—			$	—
	Three-way collars		900			$	—			$	77.83			$	99.94			$	114.49
	2014
	Swaps		739			$	92.51			$	—			$	—			$	—
	Three-way collars		2,400			$	—			$	75.5			$	93.25			$	101.94
	Enhanced swaps		840			$	98.62			$	80			$	—			$	—
	Put spread enhanced swaps		2,225			$	93.64			$	80			$	60			$	—
	Purchased puts		840			$	—			$	—			$	60			$	—
	2015
	Enhanced swaps		4,918			$	93.35			$	80			$	—			$	—
	The following tables summarize our natural gas derivative instruments outstanding as of September 30, 2013:
	Period and Type of Contract		Volume			Weighted
			BBtu			average
						fixed price
						per MMBtu
	2013
	Natural gas swaps		4,890			$	4.34
	Natural gas basis protection swaps		5,390			$	0.2
	2014
	Natural gas swaps		18,420			$	4.03
	Natural gas basis protection swaps		21,550			$	0.24
	2015
	Natural gas swaps		10,800			$	4.26
	Natural gas basis protection swaps		2,400			$	0.18
	Effect of derivative instruments on the consolidated balance sheets
	All derivative financial instruments are recorded on the balance sheet at fair value. See Note 5 for additional information regarding fair value measurements. The estimated fair values of derivative instruments are provided below. The carrying amounts of these instruments are equal to the estimated fair values.
		As of September 30, 2013												As of December 31, 2012
		Assets				Liabilities				Net value				Assets				Liabilities			Net value
	Natural gas swaps	$	9,180			$	(281	)		$	8,899			$	13,642			$	(1,487	)	$	12,155
	Oil swaps	122				(5,363		)		(5,241		)		4,957				(1,339		)	3,618
	Oil collars	3,974				(538		)		3,436				27,411				(1,180		)	26,231
	Oil enhanced swaps	2,005				(8,229		)		(6,224		)		—				—			—
	Oil purchased puts (1)	185				—				185				—				—			—
	Natural gas basis differential swaps	778				(345		)		433				—				(1,599		)	(1,599		)
	Total derivative instruments	16,244				(14,756		)		1,488				46,010				(5,605		)	40,405
	Less:
	Netting adjustments (2)	7,763				(7,763		)		—				2,977				(2,977		)	—
	Current portion asset (liability)	4,449				(6,971		)		(2,522		)		42,516				(436		)	42,080
		$	4,032			$	(22	)		$	4,010			$	517			$	(2,192	)	$	(1,675	)
	-1	Includes premiums of $664 paid during the second quarter of 2013. No additional premiums have been paid.
	-2	Amounts represent the impact of master netting agreements that allow us to net settle positive and negative positions with the same counterparty.
	We discontinued hedge accounting effective April 1, 2010. Net derivative gains attributable to derivatives previously subject to hedge accounting were deferred through AOCI. As of September 30, 2013 and December 31, 2012, respectively, AOCI consists of deferred gains of $8,590 ($5,445 net of tax) and $37,134 ($23,223 net of tax) that will be recognized as gains from oil hedging activities through December 2013 as the hedged production is sold.
	Derivative settlements outstanding at September 30, 2013 and December 31, 2012 were as follows:
		September 30,				December 31,
		2013				2012
	Derivative settlements receivable included in accounts receivable	$	317			$	8,013
	Derivative settlements payable included in accounts payable and accrued liabilities	$	3,393			$	41
	Effect of derivative instruments on the consolidated statements of operations
	We do not apply hedge accounting to any of our derivative instruments. As a result, all gains and losses associated with our derivative contracts are recognized immediately as non-hedge derivative gains (losses) in the consolidated statements of operations. Gain from oil hedging activities, which is a component of total revenues in the consolidated statements of operations, consists of the reclassification of hedge gains on discontinued oil hedges from AOCI into net income.
	Non-hedge derivative (losses) gains in the consolidated statements of operations are comprised of the following:
		Three months ended								Nine months ended
		September 30,								September 30,
		2013				2012				2013				2012
Change in fair value of commodity price swaps		$	(7,795	)		$	(22,167	)		$	(12,115	)		$	(7,451	)
Change in fair value of collars		(16,057		)		(14,094		)		(22,795		)		20,480
Change in fair value of enhanced swaps and put options		(17,499		)		—				(6,703		)		—
Change in fair value of natural gas basis differential contracts		342				526				2,032				(303		)
(Payments on) receipts from settlement of commodity price swaps		(2,510		)		8,046				2,327				20,022
(Payments on) receipts from settlement of collars		(256		)		3,079				11,300				5,711
Payments on settlement of natural gas basis differential contracts		(55		)		(420		)		(530		)		(1,424		)
		$	(43,830	)		$	(25,030	)		$	(26,484	)		$	37,035
Any premiums paid on derivative contracts will be included in non-hedge derivative gains (losses) as the derivative contracts settle.

Fair_value_measurements

Fair value measurements	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Fair value measurements	'
	Fair value measurements
	Fair value is defined by the FASB as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Where available, fair value is based on observable market prices or parameters or derived from such prices or parameters. Where observable prices or inputs are not available, valuation models are applied. These valuation techniques involve some level of management estimation and judgment, the degree of which is dependent on the price transparency for the instruments or market and the instruments’ complexity.
	Fair value measurements are categorized according to the fair value hierarchy defined by the FASB. The hierarchical levels are based upon the level of judgment associated with the inputs used to measure the fair value of the assets and liabilities as follows:
	•	Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities at the measurement date.
	•	Level 2 inputs include quoted prices for identical or similar instruments in markets that are not active and inputs other than quoted prices that are observable for the asset or liability.
	•	Level 3 inputs are unobservable inputs for the asset or liability, and include situations where there is little, if any, market activity for the asset or liability.
	In certain cases, the inputs used to measure fair value may fall into different levels of the fair value hierarchy. In such cases, the asset or liability is categorized based on the lowest level input that is significant to the fair value measurement in its entirety. Our assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment, and may affect the placement of assets and liabilities within the levels of the fair value hierarchy.
	Recurring fair value measurements
	Our financial instruments recorded at fair value on a recurring basis consist of commodity derivative contracts (see Note 4). We have no Level 1 assets or liabilities as of September 30, 2013 or December 31, 2012. Our derivative contracts classified as Level 2 as of September 30, 2013 and December 31, 2012 consist of commodity price swaps and basis protection swaps, which are valued using an income approach. Future cash flows from the derivatives are estimated based on the difference between the fixed contract price and the underlying published forward market price, and are discounted at the LIBOR swap rate.
	As of September 30, 2013, our derivative contracts classified as Level 3 consisted of three-way collars, enhanced swaps, and purchased puts. As of December 31, 2012, our derivative contracts classified as Level 3 consisted of three-way collars. The fair value of these contracts is developed by a third-party pricing service using a proprietary valuation model, which we believe incorporates the assumptions that market participants would have made at the end of each period. Observable inputs include contractual terms, published forward pricing curves, and yield curves. Significant unobservable inputs are implied volatilities. Significant increases (decreases) in implied volatilities in isolation would result in a significantly higher (lower) fair value measurement. We review these valuations and the changes in the fair value measurements for reasonableness.
	All derivative instruments are discounted further using a rate that incorporates our nonperformance risk for derivative liabilities and our counterparties’ nonperformance risk for derivative assets. If available, we use our counterparties’ credit default swap values or the spread between the risk-free interest rate and the yield on our counterparties’ publicly traded debt having similar maturities to our derivative contracts as the measure of our counterparties’ nonperformance risk. As of September 30, 2013 and December 31, 2012, the rate reflecting our nonperformance risk was 1.50% and 1.50%, respectively. The weighted average rate reflecting our counterparties’ nonperformance risk was approximately 0.44% and 0.32% as of September 30, 2013 and December 31, 2012, respectively.
	The fair value hierarchy for our financial assets and liabilities is shown by the following table:
		As of September 30, 2013												As of December 31, 2012
		Derivative				Derivative				Net assets				Derivative				Derivative				Net assets
		assets				liabilities				(liabilities)				assets				liabilities				(liabilities)
	Significant other observable inputs (Level 2)	$	10,080			$	(5,989	)		$	4,091			$	18,599			$	(4,425	)		$	14,174
	Significant unobservable inputs (Level 3)	6,164				(8,767		)		(2,603		)		27,411				(1,180		)		26,231
	Netting adjustments (1)	(7,763		)		7,763				—				(2,977		)		2,977				—
		$	8,481			$	(6,993	)		$	1,488			$	43,033			$	(2,628	)		$	40,405
	-1	Amounts represent the impact of master netting agreements that allow us to net settle positive and negative positions with the same counterparty.
	Changes in the fair value of our derivative instruments classified as Level 3 in the fair value hierarchy during the nine months ended September 30, 2013 and 2012 were:
			For the nine months ended September 30,
	Net derivative assets (liabilities)		2013				2012
	Beginning balance		$	26,231			$	5,049
	Realized and unrealized (losses) gains included in non-hedge derivative (losses) gains		(18,198		)		26,191
	Purchases		664				—
	Settlements received		(11,300		)		(5,711		)
	Ending balance		$	(2,603	)		$	25,529
	(Losses) gains relating to instruments still held at the reporting date included in non-hedge derivative (losses) gains for the period		$	(8,776	)		$	21,033
	Nonrecurring fair value measurements
	Additions to the asset and liability associated with our asset retirement obligations are measured at fair value on a nonrecurring basis. Our asset retirement obligations consist of the estimated present value of future costs to plug and abandon or otherwise dispose of our oil and natural gas properties and related facilities. Significant inputs used in determining such obligations include estimates of plugging and abandonment costs, inflation rates, discount rates, and well life, all of which are Level 3 inputs according to the fair value hierarchy. The estimated future costs to dispose of properties added during the first nine months of 2013 and 2012 were escalated using an annual inflation rate of 2.95% and 2.95%, respectively, and discounted using our credit-adjusted risk-free interest rate of 6.90% and 6.70%, respectively. These estimates may change based upon future inflation rates and changes in statutory remediation rules. During the nine months ended September 30, 2013 and 2012, additions to our asset retirement obligations were $1,036 and $551, respectively. See Note 6 for additional information regarding our asset retirement obligations.
	Fair value of other financial instruments
	Our significant financial instruments, other than derivatives, consist primarily of cash and cash equivalents, accounts receivable, accounts payable, and long-term debt. We believe the carrying values of cash and cash equivalents, accounts receivable, and accounts payable approximate fair values due to the short-term maturities of these instruments.
	The carrying value and estimated fair value of our long-term debt at September 30, 2013 and December 31, 2012 were as follows:
			September 30, 2013								December 31, 2012
	Level 2		Carrying				Estimated				Carrying				Estimated
			value				fair value				value				fair value
	9.875% Senior Notes due 2020		$	294,419			$	338,625			$	294,031			$	341,250
	8.25% Senior Notes due 2021		400,000				424,000				400,000				434,000
	7.625% Senior Notes due 2022		555,942				566,500				556,631				574,750
	Senior secured revolving credit facility		108,000				108,000				25,000				25,000
	Other secured long-term debt and capital leases		21,697				21,697				17,740				17,740
			$	1,380,058			$	1,458,822			$	1,293,402			$	1,392,740
	The fair value of our Senior Notes was estimated based on quoted market prices. The carrying value of our senior secured revolving credit facility approximates fair value because it has a variable interest rate and incorporates a measure of our credit risk. The carrying value of our other secured long-term debt approximates fair value because the rates are comparable to those at which we could currently borrow under similar terms.
	Counterparty credit risk
	Our derivative contracts are executed with institutions, or affiliates of institutions, that are parties to our senior secured revolving credit facility at the time of execution, and we believe the credit risks associated with all of these institutions are acceptable. We do not require collateral or other security from counterparties to support derivative instruments. Master agreements are in place with each of our derivative counterparties which provide for net settlement in the event of default or termination of the contracts under each respective agreement. As a result of the netting provisions, our maximum amount of loss under derivative transactions due to credit risk is limited to the net amounts due from the counterparties under the derivatives. Our loss is further limited as any amounts due from a defaulting counterparty that is a lender, or an affiliate of a lender, under our senior secured revolving credit facility can be offset against amounts owed to such counterparty lender under our senior secured revolving credit facility. As of September 30, 2013, the counterparties to our open derivative contracts consisted of ten financial institutions, of which nine were subject to our rights of offset under our senior secured revolving credit facility.
	The following table summarizes our derivative assets and liabilities which are offset in the balance sheet under our master netting agreements. It also reflects the amounts outstanding under our senior secured revolving credit facility that are available to offset our net derivative assets due from counterparties that are lenders under our senior secured revolving credit facility.
			Offset in the consolidated balance sheets												Gross amounts not offset in the consolidated balance sheets
			Gross assets (liabilities)				Offsetting assets (liabilities)				Net assets (liabilities)				Amounts outstanding under senior secured revolving credit facility				Net amount
	As of September 30, 2013
	Derivative assets		$	16,244			$	(8,459	)		$	7,785			$	(7,239	)		$	546
	Derivative liabilities		(14,756		)		8,459				(6,297		)		—				(6,297		)
			$	1,488			$	—			$	1,488			$	(7,239	)		$	(5,751	)
	As of December 31, 2012
	Derivative assets		$	46,010			$	(4,721	)		$	41,289			$	(9,180	)		$	32,109
	Derivative liabilities		(5,605		)		4,721				(884		)		—				(884		)
			$	40,405			$	—			$	40,405			$	(9,180	)		$	31,225
	We did not post additional collateral under any of these contracts as all of our counterparties are secured by the collateral under our senior secured revolving credit facility. Payment on our derivative contracts would be accelerated in the event of a default on our senior secured revolving credit facility. The aggregate fair value of our derivative liabilities was $14,756 at September 30, 2013.

Asset_retirement_obligations

Asset retirement obligations	9 Months Ended
	Sep. 30, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Asset retirement obligations	'
	Asset retirement obligations
	The following table provides a summary of our asset retirement obligation activity during the nine months ended September 30, 2013 and 2012.
		For the nine months ended September 30,
		2013			2012
	Beginning balance	$	49,214		$	46,492
	Liabilities incurred in current period	1,036			551
	Liabilities settled and disposed in current period	(4,969		)	(1,484		)
	Accretion expense	2,968			2,962
		48,249			48,521
	Less current portion	2,900			2,900
		$	45,349		$	45,621
	See Note 5 for additional information regarding fair value measurements.

Stockbased_compensation

Stock-based compensation	9 Months Ended
	Sep. 30, 2013
Share-based Compensation [Abstract]	'
Stock-based compensation	'
	Stock-based compensation
	Phantom Stock Plan and Restricted Stock Unit Plan
	Effective January 1, 2004, we implemented a Phantom Unit Plan, which was revised on December 31, 2008 as the Second Amended and Restated Phantom Stock Plan (the “Phantom Plan”), to provide deferred compensation to certain key employees (the “Participants”). Phantom stock may be awarded to Participants in total up to 2% of the fair market value of the Company. No Participant may be granted, in the aggregate, more than 5% of the maximum number of phantom shares available for award. Under the Plan, awards vest on the fifth anniversary of the award date, but may also vest on a pro-rata basis following a Participant’s termination of employment with us due to death, disability, retirement or termination by us without cause. Also, phantom stock will vest if a change of control event occurs. Phantom shares are cash-settled within 120 days of the vesting date.
	Effective March 1, 2012, we implemented a Non-Officer Restricted Stock Unit Plan (the “RSU Plan”) to create incentives to motivate Participants to put forth maximum effort toward the success and growth of the Company and to enable us to attract and retain experienced individuals who by their position, ability and diligence are able to make important contributions to the Company’s success. The RSU Plan is intended to replace the Phantom Plan. Although the Phantom Plan remains in effect, we do not expect to make any further awards under the Phantom Plan.
	Restricted stock units may be awarded to Participants in total up to 2% of the fair market value of the Company. Under the RSU Plan, awards generally vest in equal annual increments over a three-year period. RSU awards may also vest following a Participant’s termination of employment in combination with the occurrence of a change of control event, as specified in the RSU Plan. RSU awards are cash-settled, generally within 120 days of the vesting date.
	A summary of our phantom stock and RSU activity during the nine months ended September 30, 2013 is presented in the following table:
		Phantom Plan										RSU Plan
		Weighted			Phantom			Vest				Weighted				Restricted Stock Units		Vest
		average			shares			date				average						date
		grant date						fair				grant date						fair
		fair value						value				fair value						value
		($ per share)										($ per share)
	Unvested and outstanding at January 1, 2013	$	16.87		84,764							$	17.12			151,909
	Granted	$	—		—							$	12.45			291,253
	Vested	$	16.2		(21,260	)		$	273			$	17.12			(50,246	)	$	626
	Forfeited	$	17.52		(9,388	)						$	14.35			(55,051	)
	Unvested and outstanding at September 30, 2013	$	17.03		54,116							$	13.54			337,865
	Based on an estimated fair value of $10.68 per phantom share and RSU as of September 30, 2013, the aggregate intrinsic value of the unvested phantom shares and RSUs outstanding was $4,186.
	2010 Equity Incentive Plan
	We adopted the Chaparral Energy, Inc. 2010 Equity Incentive Plan (the “2010 Plan”) on April 12, 2010. The 2010 Plan reserves a total of 86,301 shares of our class A common stock for awards issued under the 2010 Plan. All of our or our affiliates’ employees, officers, directors, and consultants, as defined in the 2010 Plan, are eligible to participate in the 2010 Plan.
	These awards consist of shares that are subject to service vesting conditions (the “Time Vested” awards) and shares that are subject to market and performance vesting conditions (the “Performance Vested” awards). The Time Vested awards vest in equal annual installments over the five-year vesting period but may also vest on an accelerated basis in the event of a Transaction (as defined in the 2010 Plan). The Performance Vested awards vest in the event of a Transaction that achieves certain market targets as defined in the 2010 Plan. Any shares of Performance Vested awards not vested on a Separation Date (as defined in the 2010 Plan) will be forfeited as of the Separation Date.
	Effective January 1, 2013, we amended and restated all outstanding Performance Vested awards to reflect that: (i) those shares which would vest if CCMP receives net proceeds from a Transaction that yields a return of at least 400% per share were removed from the initial Performance Vested awards and an equal number of Time Vested shares were granted effective as of January 1, 2013; and (ii) the return on investment targets applicable to the remaining number of Performance Vested shares and to any new grants of Performance Vested shares were set at the following levels:
	Return on Investment Target		Target Shares Vested
	175% per share		20% of shares multiplied by the Vesting Fraction
	200% per share		20% of shares multiplied by the Vesting Fraction
	250% per share		20% of shares multiplied by the Vesting Fraction
	300% per share		20% of shares multiplied by the Vesting Fraction
	350% per share		20% of shares multiplied by the Vesting Fraction
	This modification changed the classification of the canceled and reissued awards from equity to liability instruments and resulted in estimated incremental compensation cost of $4,322, which will be recognized over the five-year requisite service period using the accelerated method. Incremental compensation cost is measured as the excess of the fair value of the modified award over the fair value of the original award immediately before the modification, and will be adjusted for changes in the fair value of the modified awards in each period until the awards are vested or forfeited.
	A summary of our restricted stock activity during the nine months ended September 30, 2013 is presented below:
		Time Vested										Performance Vested
		Weighted			Restricted			Vest				Weighted				Restricted
		average			shares			date				average				shares
		grant date						fair				grant date
		fair value						value				fair value
		($ per share)										($ per share)
	Unvested and outstanding at January 1, 2013	$	651.97		9,481							$	324.48			55,824
	Granted	$	626.02		2,839							$	181.59			5,217
	Vested	$	679.09		(2,030	)		$	1,256			$	—			—
	Forfeited	$	620.01		(1,779	)						$	340.23			(3,171	)
	Modified	$	626		11,169							$	324.47			(11,169	)
	Unvested and total outstanding at September 30, 2013	$	633.58		19,680							$	307.45			46,701
	During the nine months ended September 30, 2013 and 2012, respectively, we repurchased and canceled 873 and 764 vested shares, primarily for tax withholding, and we expect to repurchase approximately 2,000 restricted shares vesting during the next twelve months. Based on an estimated fair value of $626.00 per Time Vested restricted share, the aggregate intrinsic value of the unvested Time Vested restricted shares outstanding was $12,320 as of September 30, 2013.
	Stock-based compensation cost
	Compensation cost is calculated net of forfeitures, which are estimated based on our historical and expected turnover rates. If our actual forfeiture rate is materially different from our estimate, the stock-based compensation cost could be different from what we have recorded in the current period.
	A portion of stock-based compensation cost associated with employees involved in our acquisition, exploration, and development activities has been capitalized as part of our oil and natural gas properties. The remaining cost is reflected in lease operating and general and administrative expenses in the consolidated statements of operations. We recognized stock-based compensation expense as follows for the periods indicated:
		Three months ended							Nine months ended
		September 30,							September 30,
		2013			2012				2013				2012
	Stock-based compensation cost	$	2,045		$	1,725			$	4,620			$	4,773
	Less: stock-based compensation cost capitalized	(505		)	(605		)		(1,440		)		(1,715		)
	Stock-based compensation expense	$	1,540		$	1,120			$	3,180			$	3,058
	Payments for stock-based compensation were $135 and $120 during the third quarters of 2013 and 2012, respectively, and were $1,433 and $981 during the nine months ended September 30, 2013 and 2012, respectively. As of September 30, 2013 and December 31, 2012, accrued payroll and benefits payable included $4,173 and $2,636, respectively, for stock-based compensation costs expected to be settled within the next twelve months. Unrecognized compensation cost of approximately $17,383 is expected to be recognized over a weighted average period of 3.10 years.

Common_stock

Common stock	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
Common stock	'
	Common stock
	The following is a summary of the changes in our common shares outstanding during the nine months ended September 30, 2013:
		Common Stock
		Class A		Class B	Class C	Class D	Class E	Class F	Class G	Total
	Shares outstanding at January 1, 2013	67,991		357,882	209,882	279,999	504,276	1	3	1,420,034
	Restricted stock issuances	8,056		—	—	—	—	—	—	8,056
	Restricted stock repurchased	(873	)	—	—	—	—	—	—	(873	)
	Restricted stock forfeitures	(4,950	)	—	—	—	—	—	—	(4,950	)
	Shares outstanding at September 30, 2013	70,224		357,882	209,882	279,999	504,276	1	3	1,422,267

Related_party_transactions

Related party transactions	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Related party transactions	'
	Related party transactions
	CHK Energy Holdings, Inc., an indirect wholly owned subsidiary of Chesapeake Energy Corporation (“Chesapeake”), owns approximately 20% of our outstanding common stock. We participate in ownership of properties operated by Chesapeake, and we received revenues and incurred joint interest billings on these properties as follows:
		Three months ended September 30,						Nine months ended September 30,
		2013			2012			2013			2012
	Revenues	$	2,449		$	831		$	5,289		$	2,600
	Joint interest billings	$	(453	)	$	(828	)	$	(1,764	)	$	(4,295	)
	In addition, Chesapeake participates in ownership of properties operated by us, and we paid revenues and recorded joint interest billings to Chesapeake on these properties as follows:
		Three months ended September 30,						Nine months ended September 30,
		2013			2012			2013			2012
	Revenues	$	(1,549	)	$	(1,062	)	$	(3,248	)	$	(2,521	)
	Joint interest billings	$	1,084		$	3,093		$	8,969		$	7,737
	Amounts receivable from and payable to Chesapeake at September 30, 2013 and December 31, 2012 were as follows:
			September 30, 2013			December 31, 2012
	Amounts receivable from Chesapeake		$	1,568		$	2,071
	Amounts payable to Chesapeake		$	87		$	864

Commitments_and_contingencies

Commitments and contingencies	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and contingencies	'
	Commitments and contingencies
	Standby letters of credit (“Letters”) available under our senior secured revolving credit facility are used in lieu of surety bonds with various organizations for liabilities relating to the operation of oil and natural gas properties. We had various Letters outstanding totaling $920 as of September 30, 2013 and December 31, 2012. Interest on each Letter accrues at the lender’s prime rate plus applicable margin for all amounts paid by the lenders under the Letters. No amounts were paid by the lenders under the Letters, therefore we paid no interest on the Letters during the nine months ended September 30, 2013 or 2012.
	Naylor Farms, Inc., individually and as class representative on behalf of all similarly situated persons v. Chaparral Energy, L.L.C.
	On June 7, 2011, Naylor Farms, Inc. (the “Plaintiff”), filed a complaint against us, alleging claims on behalf of itself and non-governmental royalty interest owners in oil and natural gas wells we operate in Oklahoma. The Plaintiff asserts class claims seeking recovery for underpayment of royalties, alleging damages in excess of $5,000. The Plaintiff also requests allowable interest, punitive damages, cancellation of leases, other equitable relief, and an award of attorney fees and costs. We have denied liability on the claims and raised arguments and defenses that, if accepted by the Court, will result in no loss to us. The case was stayed on August 9, 2012 to allow the U.S. Court of Appeals for the Tenth Circuit to decide two unrelated cases that had issues similar to this case. The Tenth Circuit issued its opinions in those unrelated cases on July 9, 2013 and mandates were issued July 31, 2013. On or about October 1, 2013, the Court lifted the stay and entered a new scheduling order. The parties are conducting additional discovery and Plaintiff’s Motion for Class Certification is due August 10, 2014. Because a class has not been certified, we are not yet able to estimate a possible loss, or range of possible loss, if any.
	Amanda Dodson, individually and as class representative on behalf of all similarly situated persons v. Chaparral Energy, L.L.C.
	On May 10, 2013, Amanda Dodson (the “Plaintiff”), filed a complaint against us, alleging claims on behalf of herself and all non-governmental Oklahoma citizens who are royalty interest owners in oil and natural gas wells we operate in Oklahoma. The Petition was not served until July 2, 2013. The Plaintiff asserts class claims seeking recovery for underpayment of royalties, alleging entitlement to actual damages in an unspecified amount. The Plaintiff also requests allowable interest, punitive damages, injunctive relief, an accounting, disgorgement damages, and an award of attorney fees and costs. We have denied liability on the claims and raised arguments and defenses that, if accepted by the Court, will result in no loss to us. At this time, a class has not been certified and discovery has yet to begin. As such, we are not yet able to estimate a possible loss, or range of possible loss, if any.
	In our opinion, there are no other material pending legal proceedings to which we are a party or of which any of our property is the subject. However, due to the nature of our business, certain legal or administrative proceedings may arise from time to time in the ordinary course of business. While the outcome of these legal matters cannot be predicted with certainty, we do not expect them to have a material adverse effect on our financial condition, results of operations or cash flows.

Nature_of_operations_and_summa1

Nature of operations and summary of significant accounting policies (Policies)	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Interim financial statements	'
	Interim financial statements
	The accompanying unaudited consolidated interim financial statements of the Company have been prepared in accordance with the rules and regulations of the SEC and do not include all of the financial information and disclosures required by accounting principles generally accepted in the United States of America (“GAAP”) for complete financial statements. These financial statements and the notes thereto should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2012.
	The financial information as of September 30, 2013, and for the three and nine months ended September 30, 2013 and 2012, is unaudited. In management’s opinion, such information contains all adjustments, consisting only of normal recurring accruals, considered necessary for a fair presentation of the results of the interim periods. The results of operations for the three and nine months ended September 30, 2013 are not necessarily indicative of the results of operations that will be realized for the year ended December 31, 2013.
Cash and cash equivalents	'
	Cash and cash equivalents
	We consider all highly liquid investments with an original maturity of three months or less to be cash equivalents. We maintain cash and cash equivalents in bank deposit accounts and money market funds which may not be federally insured.
Accounts receivable	'
	Accounts receivable
	We have receivables from joint interest owners and oil and natural gas purchasers which are generally uncollateralized. We generally review our oil and natural gas purchasers for credit worthiness and general financial condition. We may have the ability to withhold future revenue disbursements to recover non-payment of joint interest billings on properties of which we are the operator. Accounts receivable from joint interest owners are stated at amounts due, net of an allowance for doubtful accounts. Accounts receivable are generally due within 30 days and accounts outstanding longer than 60 days are considered past due. We determine our allowance by considering the length of time past due, previous loss history, future net revenues of the debtor’s ownership interest in oil and natural gas properties we operate, and the owner’s ability to pay its obligation, among other things.
	We write off accounts receivable when they are determined to be uncollectible.
Inventories	'
	Inventories
	Inventories are comprised of equipment used in developing oil and natural gas properties and oil and natural gas production inventories. Equipment inventory is carried at the lower of cost or market using the average cost method. Oil and natural gas product inventories are stated at the lower of production cost or market. We regularly review inventory quantities on hand and record provisions for excess or obsolete inventory, if necessary.
Oil and natural gas properties	'
	Oil and natural gas properties
	We use the full cost method of accounting for oil and natural gas properties and activities. Accordingly, we capitalize all costs incurred in connection with the exploration for and development of oil and natural gas reserves. Proceeds from the disposition of oil and natural gas properties are accounted for as a reduction in capitalized costs, with no gain or loss generally recognized unless such dispositions involve a significant alteration in the depletion rate. We sold certain oil and gas properties for total cash proceeds of approximately $90,530 and $44,523 subject to post-closing adjustments for the nine months ended September 30, 2013 and 2012, respectively, which did not have a significant impact on our depletion rate. After September 30, 2013, we also sold certain additional oil and gas properties for a total price of approximately $12,500 subject to post-closing adjustments.
	On October 11, 2013, we entered into an agreement with Cabot Oil & Gas Corporation to acquire certain oil and gas properties and related assets in the Panhandle Marmaton Play for $160,128 subject to pre- and post-closing adjustments (the “Cabot Acquisition”). We paid $16,013 in earnest money for the Cabot Acquisition with the balance due upon closing, which is expected to occur in the fourth quarter of 2013.
	We capitalize internal costs that can be directly identified with exploration and development activities, but do not include any costs related to production, general corporate overhead or similar activities. Capitalized costs include geological and geophysical work, 3D seismic, delay rentals, drilling and completing and equipping oil and natural gas wells, including salaries, benefits and other internal costs directly attributable to these activities.
	The costs of unevaluated oil and natural gas properties are excluded from amortization until the properties are evaluated. Costs are transferred into the amortization base on an ongoing basis as the properties are evaluated and proved reserves are established or impairment is determined.
Stock-based compensation	'
	Stock-based compensation
	Our stock-based compensation programs consist of phantom stock, restricted stock units (“RSU”), and restricted stock awards issued to employees. Generally, we use new shares to grant restricted stock awards, and we cancel restricted shares forfeited or repurchased for tax withholding. Canceled shares are available to be issued as new grants under our 2010 Equity Incentive Plan.
	The estimated fair value of the phantom stock and RSU awards is remeasured at the end of each reporting period until settlement. The estimated fair market value of these awards is calculated based on our total asset value less total liabilities, with both assets and liabilities being adjusted to fair value in accordance with the terms of the Phantom Stock Plan and the Non-Officer Restricted Stock Unit Plan. The primary adjustment required is the adjustment of oil and natural gas properties from net book value to the discounted and risk-adjusted reserve value based on internal reserve reports priced on NYMEX forward strips. Compensation cost associated with the phantom stock and RSU awards is recognized over the vesting period using the straight-line method and the accelerated method, respectively.
	The fair value of our restricted stock awards that include a service condition is based upon the estimated fair market value of our common stock on the date of grant, and is remeasured at the end of each reporting period until settlement. We recognize compensation cost over the requisite service period using the accelerated method for awards with graded vesting.
	We use a Monte Carlo model to estimate the grant date fair value of restricted stock awards that include a market condition. This model includes various significant assumptions, including the expected volatility of the share awards and the probabilities of certain vesting conditions. These assumptions reflect our best estimates, but they involve inherent uncertainties based on market conditions generally outside of our control. As a result, if other assumptions had been used, stock-based compensation expense could have been significantly impacted. Compensation cost associated with restricted stock awards that include a market condition is recognized over the requisite service period using the straight-line method.
Recently adopted accounting pronouncements	'
	Recently adopted accounting pronouncements
	In December 2011, the Financial Accounting Standards Board (“FASB”) issued authoritative guidance that requires enhanced disclosures that will enable financial statement users to evaluate the effect or potential effect of netting arrangements on an entity’s financial position. In January 2013, additional guidance was issued which narrows the scope of the disclosure requirements to derivatives, securities borrowings, and securities lending transactions that are either offset or subject to a master netting arrangement. This guidance, which was effective and adopted by us in the first quarter of 2013, resulted in additional disclosures but had no financial impact.
	In February 2013, the FASB issued authoritative guidance that requires disclosures of the amounts reclassified out of accumulated other comprehensive income (“AOCI”) by component, including the respective line items of net income if the amount is required to be reclassified to net income in its entirety in the same reporting period. This additional guidance was effective and adopted by us in the first quarter of 2013. As our entire balance in AOCI consists of deferred hedge gains, implementation of the guidance had no significant impact on our financial statement presentation and disclosures.
	Recently issued accounting pronouncements
	In July 2011, the FASB issued authoritative guidance regarding how health insurers should recognize and classify in their income statements the fees mandated by the Health Care and Education Reconciliation Act (“HCERA”). The HCERA imposes an annual fee upon health insurers for each calendar year beginning on or after January 1, 2014. The annual fee will be allocated to individual entities providing health insurance to employees based on a ratio, as provided for in the HCERA, and is not tax deductible. This guidance specifies that once the entity has provided qualifying health insurance in the calendar year in which the fee is payable, the liability for the entity’s fee should be estimated and recorded in full with a corresponding deferred cost that is amortized to expense on a straight line basis, unless another method better allocates the fee over the calendar year that it is payable. This guidance is effective for calendar years beginning after December 15, 2013, once the fee is instituted. We are currently assessing the impact that this fee and the adoption of the related authoritative guidance will have on our financial statements.

Nature_of_operations_and_summa2

Nature of operations and summary of significant accounting policies (Tables)	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Accounts receivable	'
	Accounts receivable consisted of the following at September 30, 2013 and December 31, 2012:
		September 30,				December 31,
		2013				2012
	Joint interests	$	35,856			$	19,282
	Accrued oil and natural gas sales	61,380				50,814
	Derivative settlements	317				8,013
	Other	546				472
	Allowance for doubtful accounts	(1,636		)		(1,274		)
		$	96,463			$	77,307
Inventories	'
	Inventories at September 30, 2013 and December 31, 2012 consisted of the following:
			September 30,				December 31,
			2013				2012
	Equipment inventory		$	9,688			$	8,047
	Oil and natural gas product		3,087				3,175
	Inventory valuation allowance		(706		)		(712		)
			$	12,069			$	10,510

Supplemental_disclosures_to_th1

Supplemental disclosures to the consolidated statements of cash flows (Tables)	9 Months Ended
	Sep. 30, 2013
Supplemental Cash Flow Elements [Abstract]	'
Supplemental disclosures to the consolidated statements of cash flows	'
	Supplemental disclosures to the consolidated statements of cash flows are presented below:
		Nine months ended September 30,
		2013			2012
	Net cash provided by operating activities included:
	Cash payments for interest	$	70,735		$	71,475
	Interest capitalized	(11,670		)	(3,311		)
	Cash payments for interest, net of amounts capitalized	$	59,065		$	68,164
	Cash payments for income taxes	$	240		$	100
	Non-cash investing activities included:
	Asset retirement costs capitalized	$	1,036		$	551
	Oil and natural gas properties acquired through increase in accounts payable and accrued liabilities	$	8,298		$	38,184

Longterm_debt_Tables

Long-term debt (Tables)	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Components of long-term debt	'
	Long-term debt at September 30, 2013 and December 31, 2012, consisted of the following:
		September 30, 2013		December 31, 2012
	9.875% Senior Notes due 2020, net of discount of $5,581 and $5,969 at September 30, 2013 and December 31, 2012, respectively	$	294,419	$	294,031
	8.25% Senior Notes due 2021	400,000		400,000
	7.625% Senior Notes due 2022, including premium of $5,942 and $6,631 at September 30, 2013 and December 31, 2012, respectively	555,942		556,631
	Senior secured revolving credit facility	108,000		25,000
	Real estate mortgage notes, principal and interest payable monthly, bearing interest at rates ranging from 2.54% to 5.46%, due August 2021 through December 2028; collateralized by real property	11,322		12,596
	Installment notes payable, principal and interest payable monthly, bearing interest at rates ranging from 2.94% to 6.79%, due November 2013 through February 2018; collateralized by automobiles, machinery and equipment	5,210		5,144
	Capital lease obligations	5,165		—
		1,380,058		1,293,402
	Less current maturities	3,322		3,746
		$	1,376,736	$	1,289,656

Derivative_instruments_Tables

Derivative instruments (Tables)	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Outstanding derivative instruments	'
	The following table summarizes our crude oil derivatives outstanding as of September 30, 2013:
						Weighted average fixed price per Bbl
	Period and Type of Contract		Volume			Swaps				Sold puts				Purchased puts				Sold calls
			MBbls
	2013
	Swaps		510			$	95.54			$	—			$	—			$	—
	Three-way collars		900			$	—			$	77.83			$	99.94			$	114.49
	2014
	Swaps		739			$	92.51			$	—			$	—			$	—
	Three-way collars		2,400			$	—			$	75.5			$	93.25			$	101.94
	Enhanced swaps		840			$	98.62			$	80			$	—			$	—
	Put spread enhanced swaps		2,225			$	93.64			$	80			$	60			$	—
	Purchased puts		840			$	—			$	—			$	60			$	—
	2015
	Enhanced swaps		4,918			$	93.35			$	80			$	—			$	—
	The following tables summarize our natural gas derivative instruments outstanding as of September 30, 2013:
	Period and Type of Contract		Volume			Weighted
			BBtu			average
						fixed price
						per MMBtu
	2013
	Natural gas swaps		4,890			$	4.34
	Natural gas basis protection swaps		5,390			$	0.2
	2014
	Natural gas swaps		18,420			$	4.03
	Natural gas basis protection swaps		21,550			$	0.24
	2015
	Natural gas swaps		10,800			$	4.26
	Natural gas basis protection swaps		2,400			$	0.18
Derivative instruments recorded on the balance sheet at fair value	'
	The estimated fair values of derivative instruments are provided below. The carrying amounts of these instruments are equal to the estimated fair values.
		As of September 30, 2013												As of December 31, 2012
		Assets				Liabilities				Net value				Assets				Liabilities			Net value
	Natural gas swaps	$	9,180			$	(281	)		$	8,899			$	13,642			$	(1,487	)	$	12,155
	Oil swaps	122				(5,363		)		(5,241		)		4,957				(1,339		)	3,618
	Oil collars	3,974				(538		)		3,436				27,411				(1,180		)	26,231
	Oil enhanced swaps	2,005				(8,229		)		(6,224		)		—				—			—
	Oil purchased puts (1)	185				—				185				—				—			—
	Natural gas basis differential swaps	778				(345		)		433				—				(1,599		)	(1,599		)
	Total derivative instruments	16,244				(14,756		)		1,488				46,010				(5,605		)	40,405
	Less:
	Netting adjustments (2)	7,763				(7,763		)		—				2,977				(2,977		)	—
	Current portion asset (liability)	4,449				(6,971		)		(2,522		)		42,516				(436		)	42,080
		$	4,032			$	(22	)		$	4,010			$	517			$	(2,192	)	$	(1,675	)
	-1	Includes premiums of $664 paid during the second quarter of 2013. No additional premiums have been paid.
	-2	Amounts represent the impact of master netting agreements that allow us to net settle positive and negative positions with the same counterparty.
Derivative settlements outstanding	'
	Derivative settlements outstanding at September 30, 2013 and December 31, 2012 were as follows:
		September 30,				December 31,
		2013				2012
	Derivative settlements receivable included in accounts receivable	$	317			$	8,013
	Derivative settlements payable included in accounts payable and accrued liabilities	$	3,393			$	41
Non-hedge derivative gains (losses) in the consolidated statements of operations	'
	Non-hedge derivative (losses) gains in the consolidated statements of operations are comprised of the following:
			Three months ended								Nine months ended
			September 30,								September 30,
			2013				2012				2013				2012
	Change in fair value of commodity price swaps		$	(7,795	)		$	(22,167	)		$	(12,115	)		$	(7,451	)
	Change in fair value of collars		(16,057		)		(14,094		)		(22,795		)		20,480
	Change in fair value of enhanced swaps and put options		(17,499		)		—				(6,703		)		—
	Change in fair value of natural gas basis differential contracts		342				526				2,032				(303		)
	(Payments on) receipts from settlement of commodity price swaps		(2,510		)		8,046				2,327				20,022
	(Payments on) receipts from settlement of collars		(256		)		3,079				11,300				5,711
	Payments on settlement of natural gas basis differential contracts		(55		)		(420		)		(530		)		(1,424		)
			$	(43,830	)		$	(25,030	)		$	(26,484	)		$	37,035

Fair_value_measurements_Tables

Fair value measurements (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Fair value hierarchy for financial instruments measured at fair value on a recurring basis	'
	The fair value hierarchy for our financial assets and liabilities is shown by the following table:
		As of September 30, 2013												As of December 31, 2012
		Derivative				Derivative				Net assets				Derivative				Derivative				Net assets
		assets				liabilities				(liabilities)				assets				liabilities				(liabilities)
	Significant other observable inputs (Level 2)	$	10,080			$	(5,989	)		$	4,091			$	18,599			$	(4,425	)		$	14,174
	Significant unobservable inputs (Level 3)	6,164				(8,767		)		(2,603		)		27,411				(1,180		)		26,231
	Netting adjustments (1)	(7,763		)		7,763				—				(2,977		)		2,977				—
		$	8,481			$	(6,993	)		$	1,488			$	43,033			$	(2,628	)		$	40,405
	-1	Amounts represent the impact of master netting agreements that allow us to net settle positive and negative positions with the same counterparty.
Level 3 rollforward	'
	Changes in the fair value of our derivative instruments classified as Level 3 in the fair value hierarchy during the nine months ended September 30, 2013 and 2012 were:
			For the nine months ended September 30,
	Net derivative assets (liabilities)		2013				2012
	Beginning balance		$	26,231			$	5,049
	Realized and unrealized (losses) gains included in non-hedge derivative (losses) gains		(18,198		)		26,191
	Purchases		664				—
	Settlements received		(11,300		)		(5,711		)
	Ending balance		$	(2,603	)		$	25,529
	(Losses) gains relating to instruments still held at the reporting date included in non-hedge derivative (losses) gains for the period		$	(8,776	)		$	21,033
Fair value of other financial instruments	'
	The carrying value and estimated fair value of our long-term debt at September 30, 2013 and December 31, 2012 were as follows:
			September 30, 2013								December 31, 2012
	Level 2		Carrying				Estimated				Carrying				Estimated
			value				fair value				value				fair value
	9.875% Senior Notes due 2020		$	294,419			$	338,625			$	294,031			$	341,250
	8.25% Senior Notes due 2021		400,000				424,000				400,000				434,000
	7.625% Senior Notes due 2022		555,942				566,500				556,631				574,750
	Senior secured revolving credit facility		108,000				108,000				25,000				25,000
	Other secured long-term debt and capital leases		21,697				21,697				17,740				17,740
			$	1,380,058			$	1,458,822			$	1,293,402			$	1,392,740
Offsetting Assets and Liabilities	'
	The following table summarizes our derivative assets and liabilities which are offset in the balance sheet under our master netting agreements. It also reflects the amounts outstanding under our senior secured revolving credit facility that are available to offset our net derivative assets due from counterparties that are lenders under our senior secured revolving credit facility.
			Offset in the consolidated balance sheets												Gross amounts not offset in the consolidated balance sheets
			Gross assets (liabilities)				Offsetting assets (liabilities)				Net assets (liabilities)				Amounts outstanding under senior secured revolving credit facility				Net amount
	As of September 30, 2013
	Derivative assets		$	16,244			$	(8,459	)		$	7,785			$	(7,239	)		$	546
	Derivative liabilities		(14,756		)		8,459				(6,297		)		—				(6,297		)
			$	1,488			$	—			$	1,488			$	(7,239	)		$	(5,751	)
	As of December 31, 2012
	Derivative assets		$	46,010			$	(4,721	)		$	41,289			$	(9,180	)		$	32,109
	Derivative liabilities		(5,605		)		4,721				(884		)		—				(884		)
			$	40,405			$	—			$	40,405			$	(9,180	)		$	31,225

Asset_retirement_obligations_T

Asset retirement obligations (Tables)	9 Months Ended
	Sep. 30, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Asset retirement obligations	'
	The following table provides a summary of our asset retirement obligation activity during the nine months ended September 30, 2013 and 2012.
		For the nine months ended September 30,
		2013			2012
	Beginning balance	$	49,214		$	46,492
	Liabilities incurred in current period	1,036			551
	Liabilities settled and disposed in current period	(4,969		)	(1,484		)
	Accretion expense	2,968			2,962
		48,249			48,521
	Less current portion	2,900			2,900
		$	45,349		$	45,621

Stockbased_compensation_Tables

Stock-based compensation (Tables)	9 Months Ended
	Sep. 30, 2013
Share-based Compensation [Abstract]	'
Rollforward of unvested stock-based compensation awards	'
	A summary of our restricted stock activity during the nine months ended September 30, 2013 is presented below:
		Time Vested										Performance Vested
		Weighted			Restricted			Vest				Weighted				Restricted
		average			shares			date				average				shares
		grant date						fair				grant date
		fair value						value				fair value
		($ per share)										($ per share)
	Unvested and outstanding at January 1, 2013	$	651.97		9,481							$	324.48			55,824
	Granted	$	626.02		2,839							$	181.59			5,217
	Vested	$	679.09		(2,030	)		$	1,256			$	—			—
	Forfeited	$	620.01		(1,779	)						$	340.23			(3,171	)
	Modified	$	626		11,169							$	324.47			(11,169	)
	Unvested and total outstanding at September 30, 2013	$	633.58		19,680							$	307.45			46,701
	A summary of our phantom stock and RSU activity during the nine months ended September 30, 2013 is presented in the following table:
		Phantom Plan										RSU Plan
		Weighted			Phantom			Vest				Weighted				Restricted Stock Units		Vest
		average			shares			date				average						date
		grant date						fair				grant date						fair
		fair value						value				fair value						value
		($ per share)										($ per share)
	Unvested and outstanding at January 1, 2013	$	16.87		84,764							$	17.12			151,909
	Granted	$	—		—							$	12.45			291,253
	Vested	$	16.2		(21,260	)		$	273			$	17.12			(50,246	)	$	626
	Forfeited	$	17.52		(9,388	)						$	14.35			(55,051	)
	Unvested and outstanding at September 30, 2013	$	17.03		54,116							$	13.54			337,865
Schedule of Performance Award Vesting and Return on Investment Targets	'
	Effective January 1, 2013, we amended and restated all outstanding Performance Vested awards to reflect that: (i) those shares which would vest if CCMP receives net proceeds from a Transaction that yields a return of at least 400% per share were removed from the initial Performance Vested awards and an equal number of Time Vested shares were granted effective as of January 1, 2013; and (ii) the return on investment targets applicable to the remaining number of Performance Vested shares and to any new grants of Performance Vested shares were set at the following levels:
	Return on Investment Target		Target Shares Vested
	175% per share		20% of shares multiplied by the Vesting Fraction
	200% per share		20% of shares multiplied by the Vesting Fraction
	250% per share		20% of shares multiplied by the Vesting Fraction
	300% per share		20% of shares multiplied by the Vesting Fraction
	350% per share		20% of shares multiplied by the Vesting Fraction
Stock-based compensation cost	'
	We recognized stock-based compensation expense as follows for the periods indicated:
		Three months ended							Nine months ended
		September 30,							September 30,
		2013			2012				2013				2012
	Stock-based compensation cost	$	2,045		$	1,725			$	4,620			$	4,773
	Less: stock-based compensation cost capitalized	(505		)	(605		)		(1,440		)		(1,715		)
	Stock-based compensation expense	$	1,540		$	1,120			$	3,180			$	3,058

Common_stock_Tables

Common stock (Tables)	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
Common stock rollforward	'
	The following is a summary of the changes in our common shares outstanding during the nine months ended September 30, 2013:
		Common Stock
		Class A		Class B	Class C	Class D	Class E	Class F	Class G	Total
	Shares outstanding at January 1, 2013	67,991		357,882	209,882	279,999	504,276	1	3	1,420,034
	Restricted stock issuances	8,056		—	—	—	—	—	—	8,056
	Restricted stock repurchased	(873	)	—	—	—	—	—	—	(873	)
	Restricted stock forfeitures	(4,950	)	—	—	—	—	—	—	(4,950	)
	Shares outstanding at September 30, 2013	70,224		357,882	209,882	279,999	504,276	1	3	1,422,267

Related_party_transactions_Tab

Related party transactions (Tables)	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Related party transactions	'
	We participate in ownership of properties operated by Chesapeake, and we received revenues and incurred joint interest billings on these properties as follows:
		Three months ended September 30,						Nine months ended September 30,
		2013			2012			2013			2012
	Revenues	$	2,449		$	831		$	5,289		$	2,600
	Joint interest billings	$	(453	)	$	(828	)	$	(1,764	)	$	(4,295	)
	In addition, Chesapeake participates in ownership of properties operated by us, and we paid revenues and recorded joint interest billings to Chesapeake on these properties as follows:
		Three months ended September 30,						Nine months ended September 30,
		2013			2012			2013			2012
	Revenues	$	(1,549	)	$	(1,062	)	$	(3,248	)	$	(2,521	)
	Joint interest billings	$	1,084		$	3,093		$	8,969		$	7,737
	Amounts receivable from and payable to Chesapeake at September 30, 2013 and December 31, 2012 were as follows:
			September 30, 2013			December 31, 2012
	Amounts receivable from Chesapeake		$	1,568		$	2,071
	Amounts payable to Chesapeake		$	87		$	864

Nature_of_operations_and_summa3

Nature of operations and summary of significant accounting policies Nature of operations and summary of significant accounting policies (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Accounting Policies [Abstract]	'	'	'
Fair Value, Concentration of Risk, Cash and Cash Equivalents	$36,259	'	'
Receivables [Abstract]	'	'	'
Joint interests	35,856	'	19,282
Accrued oil and natural gas sales	61,380	'	50,814
Derivative settlements	317	'	8,013
Other	546	'	472
Allowance for doubtful accounts	-1,636	'	-1,274
Accounts receivable, net	96,463	'	77,307
Inventory, Gross [Abstract]	'	'	'
Equipment inventory	9,688	'	8,047
Oil and natural gas product	3,087	'	3,175
Inventory valuation allowance	-706	'	-712
Inventories, net	12,069	'	10,510
Proceeds from Sale of Productive Assets [Abstract]	'	'	'
Proceeds from Sale of Oil and Gas Property and Equipment	$90,530	$44,523	'

Nature_of_operations_and_summa4

Nature of operations and summary of significant accounting policies Nature of operations and summary of significant accounting policies (Details 2) (USD $)	9 Months Ended		1 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Nov. 12, 2013	Oct. 11, 2013
			Subsequent Event	Subsequent Event
				Cabot Acquisition
Subsequent Event [Line Items]	'	'	'	'
Proceeds from Sale of Oil and Gas Property and Equipment	$90,530	$44,523	$12,500	'
Significant Acquisitions, Proposed Acquisition Costs	'	'	'	160,128
Significant Acquisitions, Earnest Deposit	'	'	'	$16,013

Nature_of_operations_and_summa5

Nature of operations and summary of significant accounting policies Nature of operations and summary of significant accounting policies (Details 3) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Oil and Gas Property [Abstract]	'	'
Acquisition Costs, Cumulative	$95,358	$64,840
Development Costs, Cumulative	119,181	84,183
Exploration Costs, Cumulative	35,487	13,898
Impairment of Assets Held for Sale	$1,090	'

Nature_of_operations_and_summa6

Nature of operations and summary of significant accounting policies (Details 4)	12 Months Ended
	Sep. 30, 2013
Oil	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'
Price before field differentials used in determining future net revenues	95.04
Natural Gas	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'
Price before field differentials used in determining future net revenues	3.6

Supplemental_disclosures_to_th2

Supplemental disclosures to the consolidated statements of cash flows (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Net cash provided by operating activities included:	'	'
Cash payments for interest	$70,735	$71,475
Interest capitalized	-11,670	-3,311
Cash payments for interest, net of amounts capitalized	59,065	68,164
Cash payments for income taxes	240	100
Non-cash investing activities included:	'	'
Asset retirement costs capitalized	1,036	551
Oil and natural gas properties acquired through increase in accounts payable and accrued liabilities	$8,298	$38,184

Longterm_debt_Details

Long-term debt (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

In Thousands, unless otherwise specified

Senior Notes

Mortgages

Secured Debt

9.875% Senior Notes due 2020

9.875% Senior Notes due 2020

9.875% Senior Notes due 2020

8.25% Senior Notes due 2021

8.25% Senior Notes due 2021

8.25% Senior Notes due 2021

7.625% Senior Notes due 2022

7.625% Senior Notes due 2022

7.625% Senior Notes due 2022

Eurodollar Rate

Minimum

Minimum

Maximum

Maximum

Senior Notes

Senior Notes

Senior Notes

Mortgages

Secured Debt

Mortgages

Secured Debt

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stated interest rate, miminum

'

'

'

2.54%

2.94%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stated interest rate, maximum

'

'

'

5.46%

6.79%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized discount

'

'

'

'

'

$5,581

$5,969

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, unamortized premium

'

'

'

'

'

'

'

'

'

'

'

5,942

6,631

'

'

'

'

'

'

Long-term debt [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior Notes

'

'

'

'

'

294,419

294,031

'

400,000

400,000

'

555,942

556,631

'

'

'

'

'

'

Senior secured revolving credit facility

108,000

25,000

'

'

'

'

'

'

'

'

'

'

'

'

108,000

'

'

'

'

Real estate mortgage notes payable

11,322

12,596

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Installment notes payable

5,210

5,144

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital Lease Obligations

5,165

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt

1,380,058

1,293,402

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Less current maturities

'

3,746

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt, less current maturities

$1,376,736

$1,289,656

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior Notes [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stated interest rate

'

'

'

'

'

'

'

9.88%

'

'

8.25%

'

'

7.63%

'

'

'

'

'

Debt instrument, maturity date

'

'

'

'

'

'

'

'2020

'

'

'2021

'

'

'2022

'

'08/2021

'11/2013

'12/2028

'02/2018

Debt instrument redemption price at Change of Control event as percentage of principal amount

'

'

101.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Longterm_debt_Senior_Secured_R

Long-term debt - Senior Secured Revolving Credit Facility (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Oct. 29, 2013

Sep. 30, 2013

Sep. 30, 2013

Oct. 29, 2013

Oct. 29, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Nov. 12, 2013

Nov. 12, 2013

Oct. 29, 2013

Sep. 30, 2013

Oct. 31, 2013

Sep. 30, 2013

Maximum

Eurodollar Rate

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Revolving Credit Facility

Revolving Credit Facility

Unsecured Senior or Subordinated Debt

Capital Lease Obligations

Capital Lease Obligations

Capital Lease Obligations

Subsequent Event

Subsequent Event

Subsequent Event

Election One

Election Two

Election Three

Minimum

Maximum

Eurodollar Rate

Prime Rate

Federal Funds Effective Rate

Adjusted LIBO Rate

Subsequent Event

Subsequent Event

Subsequent Event

U.S. Bank National Association

Subsequent Event

Minimum

Cabot Acquisition

Sale Leaseback, Compressor

U.S. Bank National Association

U.S. Bank National Association

Sale Leaseback, Compressor

Sale Leaseback, Compressor

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, maturity date

'

'

'

'

1-Nov-17

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base amount

'

'

'

'

$500,000,000

$550,000,000

$600,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Unused Borrowing Capacity, Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000,000

'

'

'

Derivative, Nonmonetary Notional Amount, Percent of Required Need, Coverage

'

'

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other Long-term Debt

'

'

'

'

40,000,000

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Lines of Credit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

14,000,000

'

'

'

'

Proceeds from Lines of Credit, Commitments For Additional Borrowings

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25,000,000

'

'

'

'

'

Senior secured revolving credit facility

108,000,000

25,000,000

'

108,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

One month interest period

'

'

'

'

'

'

'

'

'

'

'

'

'1 month

'

'

'

'

'

'

'

'

'

Two month interest period

'

'

'

'

'

'

'

'

'

'

'

'

'2 months

'

'

'

'

'

'

'

'

'

Three month interest period

'

'

'

'

'

'

'

'

'

'

'

'

'3 months

'

'

'

'

'

'

'

'

'

Six month interest period

'

'

'

'

'

'

'

'

'

'

'

'

'6 months

'

'

'

'

'

'

'

'

'

Basis spread on variable rate

'

'

'

'

'

'

'

'

'

'

'

'

1.50%

'

0.50%

1.00%

'

'

'

'

'

'

Description of variable rate basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'the Prime Rate

'the Federal Funds Effective Rate

'the Adjusted LIBO Rate

'

'

'

'

'

'

Commitment fee on unused portion of the borrowing base

'

'

'

'

0.38%

'

'

'

'

'

0.38%

0.50%

'

'

'

'

'

'

'

'

'

'

Current Ratio covenant

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ratio Of Consolidated Net Debt To Consolidated EBITDAX covenant

'

'

'

'

4.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Days to elect method to eliminate borrowings in excess of borrowing base

'

'

'

'

'10 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Days to eliminate borrowings in excess of borrowing base

'

'

'

'

'

'

'

'30 days

'30 days

'30 days

'

'

'

'

'

'

'

'

'

'

'

'

Months over which borrowings in excess of borrowing base may be repaid in equal monthly installments

'

'

'

'

'

'

'

'6 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital Leases

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Sale Leaseback Transaction Arrangement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,200,000

11,900,000

'

Sale Leaseback Transaction, Lease Term

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'84 months

'

'

Sale Leaseback Transaction, Lease, Option Purchase Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'72 months

'

'

Sale Leaseback Transaction, Imputed Interest Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.40%

'

'

Sale Leaseback Transaction, Annual Rental Payments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$625,000

Derivative_instruments_Outstan

Derivative instruments - Outstanding Derivatives (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

In Thousands, unless otherwise specified

Derivatives maturing in 2015

Swaps

Swaps

Swaps

Swaps

Swaps

Costless Collars

Costless Collars

Enhanced Swap

Enhanced Swap

Put Spread Enhanced Swap

Put Options Purchased

Put Options Purchased

Basis Protection Swaps

Basis Protection Swaps

Natural Gas Derivative

Derivatives Maturing In 2013

Derivatives Maturing In 2013

Derivatives Maturing In 2014

Derivatives Maturing In 2014

Derivatives maturing in 2015

Derivatives Maturing In 2013

Derivatives Maturing In 2014

Derivatives Maturing In 2014

Derivatives maturing in 2015

Derivatives Maturing In 2014

Oil Derivative

Derivatives Maturing In 2014

Derivatives Maturing In 2013

Derivatives Maturing In 2014

MMBTU

Oil Derivative

Natural Gas Derivative

Oil Derivative

Natural Gas Derivative

Natural Gas Derivative

Oil Derivative

Oil Derivative

Oil Derivative

Oil Derivative

Oil Derivative

Oil Derivative

Natural Gas Derivative

Natural Gas Derivative

bbl

MMBTU

bbl

MMBTU

MMBTU

bbl

bbl

bbl

bbl

bbl

bbl

MMBTU

MMBTU

Derivative [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Volume of derivative instruments held

'

'

2,400,000

510,000

4,890,000

739,000

18,420,000

10,800,000

900,000

2,400,000

840,000

4,918,000

2,225,000

'

840,000

5,390,000

21,550,000

Weighted average fixed price per unit, swaps

'

'

0.18

95.54

4.34

92.51

4.03

4.26

'

'

98.62

93.35

93.64

'

'

0.2

0.24

Weighted average fixed price per Bbl, sold puts

'

'

'

'

'

'

'

'

77.83

75.5

80

80

80

'

'

'

'

Weighted average fixed price per Bbl, purchased puts

'

'

'

'

'

'

'

'

99.94

93.25

'

'

60

'

60

'

'

Weighted average fixed price per Bbl, sold calls

'

'

'

'

'

'

'

'

114.49

101.94

'

'

'

'

'

'

'

Premium paid for put options on commodity derivative contracts

'

'

'

'

'

'

'

'

'

'

'

'

'

$664

'

'

'

Derivative settlements

317

8,013

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative settlements payable

3,393

41

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash flow hedge gains deferred through AOCI [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accumulated other comprehensive income, before tax

8,590

37,134

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accumulated other comprehensive income, net of taxes

$5,445

$23,223

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative_instruments_Estimat

Derivative instruments - Estimated Fair Value of Derivative Instruments (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'		'
Derivative assets, gross	$16,244		$46,010
Current derivative assets, net	4,449		42,516
Long-term derivative assets, net	4,032		517
Derivative liabilities, gross	-14,756		-5,605
Current derivative liabilities, net	-6,971		-436
Long-term derivative liabilities, net	-22		-2,192
Derivative assets (liabilities), net	1,488		40,405
Current derivative assets (liabilities), net	-2,522		42,080
Long-term derivative assets (liabilities), net	4,010		-1,675
Oil Derivative | Swaps	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative assets, gross	122		4,957
Derivative liabilities, gross	-5,363		-1,339
Derivative assets (liabilities), net	-5,241		3,618
Oil Derivative | Enhanced Swap	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative assets, gross	2,005		'
Derivative liabilities, gross	-8,229		'
Derivative assets (liabilities), net	-6,224		'
Oil Derivative | Put Options Purchased	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative assets, gross	185	[1]	'
Derivative liabilities, gross	0	[1]	'
Derivative assets (liabilities), net	185	[1]	'
Oil Derivative | Costless Collars	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative assets, gross	3,974		27,411
Derivative liabilities, gross	-538		-1,180
Derivative assets (liabilities), net	3,436		26,231
Natural Gas Derivative | Swaps	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative assets, gross	9,180		13,642
Derivative liabilities, gross	-281		-1,487
Derivative assets (liabilities), net	8,899		12,155
Natural Gas Derivative | Basis Protection Swaps	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative assets, gross	778		0
Derivative liabilities, gross	-345		-1,599
Derivative assets (liabilities), net	433		-1,599
Netting adjustments	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative assets, gross	-7,763	[2]	-2,977	[2]
Derivative liabilities, gross	$7,763	[2]	$2,977	[2]
[1]	Includes premiums of $664 paid during the second quarter of 2013.
[2]	Amounts represent the impact of master netting agreements that allow us to net settle positive and negative positions with the same counterparty.

Derivative_instruments_NonHedg

Derivative instruments - Non-Hedge Derivative Gains (Losses) in the Consolidated Statements of Operations (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Non-Hedge Derivative Gains (Losses) [Line Items]	'	'	'	'
Receipts from (payments on) settlement of non-hedge derivative instruments	'	'	($13,097)	($24,309)
Non-hedge derivative (losses) gains	-43,830	-25,030	-26,484	37,035
Swaps	'	'	'	'
Non-Hedge Derivative Gains (Losses) [Line Items]	'	'	'	'
Change in fair value of non-hedge derivatives	-7,795	-22,167	-12,115	-7,451
Receipts from (payments on) settlement of non-hedge derivative instruments	-2,510	8,046	2,327	20,022
Costless Collars	'	'	'	'
Non-Hedge Derivative Gains (Losses) [Line Items]	'	'	'	'
Change in fair value of non-hedge derivatives	-16,057	-14,094	-22,795	20,480
Receipts from (payments on) settlement of non-hedge derivative instruments	-256	3,079	11,300	5,711
Enhanced Swaps and Put Options	'	'	'	'
Non-Hedge Derivative Gains (Losses) [Line Items]	'	'	'	'
Change in fair value of non-hedge derivatives	-17,499	0	-6,703	0
Basis Protection Swaps	'	'	'	'
Non-Hedge Derivative Gains (Losses) [Line Items]	'	'	'	'
Change in fair value of non-hedge derivatives	342	526	2,032	-303
Receipts from (payments on) settlement of non-hedge derivative instruments	($55)	($420)	($530)	($1,424)

Fair_value_measurements_Inputs

Fair value measurements - Inputs (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
Fair Value Disclosures [Abstract]	'	'
Rate reflecting our nonperformance risk	1.50%	1.50%
Weighted-average rate reflecting our counterparties' nonperformance risk	0.44%	0.32%

Fair_value_measurements_Fair_V

Fair value measurements - Fair Value Hierachy (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value Hierarchy for Financial Instruments Measured at Fair Value on a Recurring Basis [Line Items]	'		'
Derivative assets, gross	$16,244		$46,010
Derivative liabilities, gross	-14,756		-5,605
Derivative assets (liabilities), net	1,488		40,405
Total derivative assets (liabilities), net	1,488		40,405
Netting adjustments	'		'
Fair Value Hierarchy for Financial Instruments Measured at Fair Value on a Recurring Basis [Line Items]	'		'
Derivative assets, gross	-7,763	[1]	-2,977	[1]
Derivative liabilities, gross	7,763	[1]	2,977	[1]
Recurring Fair Value Measurements	'		'
Fair Value Hierarchy for Financial Instruments Measured at Fair Value on a Recurring Basis [Line Items]	'		'
Derivative assets, net	8,481		43,033
Derivative liabilities, net	-6,993		-2,628
Total derivative assets (liabilities), net	1,488		40,405
Recurring Fair Value Measurements | Significant other observable inputs (Level 2)	'		'
Fair Value Hierarchy for Financial Instruments Measured at Fair Value on a Recurring Basis [Line Items]	'		'
Derivative assets, gross	10,080		18,599
Derivative liabilities, gross	-5,989		-4,425
Derivative assets (liabilities), net	4,091		14,174
Recurring Fair Value Measurements | Significant unobservable inputs (Level 3)	'		'
Fair Value Hierarchy for Financial Instruments Measured at Fair Value on a Recurring Basis [Line Items]	'		'
Derivative assets, gross	6,164		27,411
Derivative liabilities, gross	-8,767		-1,180
Derivative assets (liabilities), net	-2,603		26,231
Recurring Fair Value Measurements | Netting adjustments	'		'
Fair Value Hierarchy for Financial Instruments Measured at Fair Value on a Recurring Basis [Line Items]	'		'
Derivative assets, gross	-7,763	[1]	-2,977	[1]
Derivative liabilities, gross	7,763	[1]	2,977	[1]
Derivative assets (liabilities), net	$0	[1]	$0	[1]
[1]	Amounts represent the impact of master netting agreements that allow us to net settle positive and negative positions with the same counterparty.

Fair_value_measurements_Level_

Fair value measurements - Level 3 Rollforward (Details) (Significant unobservable inputs (Level 3), Derivative, USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Significant unobservable inputs (Level 3) | Derivative	'	'
Level 3 Rollforward	'	'
Level 3 net derivative assets at beginning of period	$26,231	$5,049
Realized and unrealized (losses) gains included in non-hedge derivative (losses) gains	-18,198	26,191
Purchases	664	0
Settlements received	-11,300	-5,711
Level 3 net derivative assets at end of period	-2,603	25,529
(Losses) gains relating to instruments still held at the reporting date included in non-hedge derivative (losses) gains for the period	($8,776)	$21,033

Fair_value_measurements_Nonrec

Fair value measurements - Nonrecurring Fair Value Measurements (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Nonrecurring Fair Value Measurements [Line Items]	'	'
Liabilities incurred in current period	$1,036	$551
Significant unobservable inputs (Level 3) | Nonrecurring fair value measurements	'	'
Nonrecurring Fair Value Measurements [Line Items]	'	'
Annual inflation rate	2.95%	2.95%
Credit-adjusted risk-free interest rate	6.90%	6.70%
Liabilities incurred in current period	$1,036	$551

Fair_value_measurements_Carryi

Fair value measurements - Carrying Value and Estimated Fair Value of Long-Term Debt (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior secured revolving credit facility	$108,000	$25,000
Total long-term debt	1,380,058	1,293,402
9.875% Senior Notes due 2020	'	'
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior Notes	294,419	294,031
8.25% Senior Notes due 2021	'	'
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior Notes	400,000	400,000
7.625% Senior Notes due 2022	'	'
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior Notes	555,942	556,631
Significant other observable inputs (Level 2) | Carrying value	'	'
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior secured revolving credit facility	108,000	25,000
Other secured long-term debt	21,697	17,740
Total long-term debt	1,380,058	1,293,402
Significant other observable inputs (Level 2) | Carrying value | 9.875% Senior Notes due 2020	'	'
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior Notes	294,419	294,031
Significant other observable inputs (Level 2) | Carrying value | 8.25% Senior Notes due 2021	'	'
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior Notes	400,000	400,000
Significant other observable inputs (Level 2) | Carrying value | 7.625% Senior Notes due 2022	'	'
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior Notes	555,942	556,631
Significant other observable inputs (Level 2) | Estimated fair value	'	'
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior secured revolving credit facility	108,000	25,000
Other secured long-term debt	21,697	17,740
Total long-term debt	1,458,822	1,392,740
Significant other observable inputs (Level 2) | Estimated fair value | 9.875% Senior Notes due 2020	'	'
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior Notes	338,625	341,250
Significant other observable inputs (Level 2) | Estimated fair value | 8.25% Senior Notes due 2021	'	'
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior Notes	424,000	434,000
Significant other observable inputs (Level 2) | Estimated fair value | 7.625% Senior Notes due 2022	'	'
Fair Value of Other Financial Instruments [Line Items]	'	'
Senior Notes	$566,500	$574,750

Fair_value_measurements_Counte

Fair value measurements - Counterparty Credit Risk (Details) (Concentration of Counterparty Credit Risk)	Sep. 30, 2013
	financial_institutions
Concentration of Counterparty Credit Risk	'
Concentration Risk [Line Items]	'
Derivative contracts, number of counterparties	10
Derivative contracts, number of counterparties subject to offset under credit facility	9

Recovered_Sheet1

Fair value measurements Fair value measurements - Schedule of Derivatives Offset in the Consolidated Balance Sheet (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value Disclosures [Abstract]	'	'
Derivative assets, gross	$16,244	$46,010
Derivative assets, amounts offset	-8,459	-4,721
Derivative assets, net	7,785	41,289
Derivative assets, net, credit facility balance subject to right of offset	-7,239	-9,180
Derivative assets, net of offsetting amounts	546	32,109
Derivative liabilities, gross	-14,756	-5,605
Derivative liabilities, amounts offset	8,459	4,721
Derivative liabilities, net of offsetting amounts	-6,297	-884
Derivative assets (liabilities), net	1,488	40,405
Total derivative assets (liabilities), net	1,488	40,405
Derivative assets (liabilities), net of offsetting amounts	($5,751)	$31,225

Asset_retirement_obligations_D

Asset retirement obligations (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'	'
Beginning balance	$49,214	$46,492	'
Liabilities incurred in current period	1,036	551	'
Liabilities settled in current period	-4,969	-1,484	'
Accretion expense	2,968	2,962	'
Ending balance	48,249	48,521	'
Less current portion	2,900	2,900	'
Asset retirement obligations, net of current portion	$45,349	$45,621	$46,314

Stockbased_compensation_Detail

Stock-based compensation (Details) (USD $)	9 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Stock-Based Compensation Arrangement Rollforward	'	'
Restricted stock used for tax withholding	873	'
Common Class A	'	'
Stock-Based Compensation Arrangement Rollforward	'	'
Restricted stock used for tax withholding	873	'
Phantom Shares | Phantom Stock Plan	'	'
Stock-Based Compensation [Line Items]	'	'
Maximum percentage of fair market value of the Company available for share-based awards	2.00%	'
Maximum individual award as a percentage of shares available for award	5.00%	'
Days from vesting date to cash settlement	'120 days	'
Stock-Based Compensation Arrangement Rollforward	'	'
Unvested and outstanding at beginning of period	16.87	'
Unvested and outstanding at beginning of period (in shares)	84,764	'
Granted	0	'
Granted (in shares)	0	'
Vested	16.2	'
Vested (in shares)	-21,260	'
Vest Date Fair Value	273	'
Forfeited	17.52	'
Forfeited (in shares)	-9,388	'
Unvested and outstanding at end of period	17.03	'
Unvested and outstanding at end of period (in shares)	54,116	'
Phantom Shares | Time Vested | Phantom Stock Plan	'	'
Stock-Based Compensation [Line Items]	'	'
Award vesting period	'5 years	'
Restricted Stock Units (RSU)	'	'
Stock-Based Compensation [Line Items]	'	'
Award vesting period	'3 years	'
Restricted Stock Units (RSU) | Non-Officer Restricted Stock Unit Plan	'	'
Stock-Based Compensation [Line Items]	'	'
Maximum percentage of fair market value of the Company available for share-based awards	2.00%	'
Days from vesting date to cash settlement	'120 days	'
Stock-Based Compensation Arrangement Rollforward	'	'
Unvested and outstanding at beginning of period	17.12	'
Unvested and outstanding at beginning of period (in shares)	151,909	'
Granted	12.45	'
Granted (in shares)	291,253	'
Vested	17.12	'
Vested (in shares)	-50,246	'
Vest Date Fair Value	626	'
Forfeited	14.35	'
Forfeited (in shares)	-55,051	'
Unvested and outstanding at end of period	13.54	'
Unvested and outstanding at end of period (in shares)	337,865	'
Phantom Stock and RSU | Phantom Stock Plan And Restricted Stock Unit Plan	'	'
Stock-Based Compensation Arrangement Rollforward	'	'
Estimated fair value per share at end of period	10.68	'
Aggregate intrinisc value of unvested Time Vested restricted shares	4,186	'
Restricted Stock | 2010 Equity Incentive Plan | Common Class A	'	'
Stock-Based Compensation Arrangement Rollforward	'	'
Shares reserved for issuance under the 2010 Plan	86,301	'
Restricted stock used for tax withholding	873	764
Shares expected to be repurchased during the next twelve months	2,000	'
Restricted Stock | Time Vested | 2010 Equity Incentive Plan | Common Class A	'	'
Stock-Based Compensation Arrangement Rollforward	'	'
Unvested and outstanding at beginning of period	651.97	'
Unvested and outstanding at beginning of period (in shares)	9,481	'
Granted	626.02	'
Granted (in shares)	2,839	'
Vested	679.09	'
Vested (in shares)	-2,030	'
Vest Date Fair Value	1,256	'
Forfeited	620.01	'
Forfeited (in shares)	-1,779	'
Modified	626	'
Modified (in Shares)	11,169	'
Unvested and outstanding at end of period	633.58	'
Unvested and outstanding at end of period (in shares)	19,680	'
Estimated fair value per share at end of period	626	'
Aggregate intrinisc value of unvested Time Vested restricted shares	12,320	'
Restricted Stock | Market and Performance Vesting Conditions | 2010 Equity Incentive Plan | Common Class A	'	'
Stock-Based Compensation Arrangement Rollforward	'	'
Unvested and outstanding at beginning of period	324.48	'
Unvested and outstanding at beginning of period (in shares)	55,824	'
Granted	181.59	'
Granted (in shares)	5,217	'
Vested	0	'
Vested (in shares)	0	'
Forfeited	340.23	'
Forfeited (in shares)	-3,171	'
Modified	324.47	'
Modified (in Shares)	-11,169	'
Unvested and outstanding at end of period	307.45	'
Unvested and outstanding at end of period (in shares)	46,701	'
Maximum | Restricted Stock Units (RSU)	'	'
Stock-Based Compensation [Line Items]	'	'
Award vesting period	'3 years	'
Maximum | Restricted Stock | Time Vested | 2010 Equity Incentive Plan	'	'
Stock-Based Compensation [Line Items]	'	'
Award vesting period	'5 years	'
Maximum | Restricted Stock | Performance Vested | 2010 Equity Incentive Plan	'	'
Stock-Based Compensation [Line Items]	'	'
Award vesting period	'5 years	'

Stockbased_compensation_Perfor

Stock-based compensation (Performance Vested Awards Return on Investment Targets) (Details) (2010 Equity Incentive Plan, Restricted Stock, USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013
Performance Vested	'
Stock-Based Compensation [Line Items]	'
Incremental compensation cost	$4,322
Return On Investment Target One | Performance Vested	'
Stock-Based Compensation [Line Items]	'
Return On Investment Target Percentage	175.00%
Vesting Percentage	20.00%
Return On Investment Target Two | Performance Vested	'
Stock-Based Compensation [Line Items]	'
Return On Investment Target Percentage	200.00%
Vesting Percentage	20.00%
Return On Investment Target Three | Performance Vested	'
Stock-Based Compensation [Line Items]	'
Return On Investment Target Percentage	250.00%
Vesting Percentage	20.00%
Return On Investment Target Four | Performance Vested	'
Stock-Based Compensation [Line Items]	'
Return On Investment Target Percentage	300.00%
Vesting Percentage	20.00%
Return On Investment Target Five | Market and Performance Vesting Conditions	'
Stock-Based Compensation [Line Items]	'
Return On Investment Target Percentage	400.00%
Return On Investment Target Five | Performance Vested	'
Stock-Based Compensation [Line Items]	'
Return On Investment Target Percentage	350.00%
Vesting Percentage	20.00%
Maximum | Performance Vested	'
Stock-Based Compensation [Line Items]	'
Award vesting period	'5 years
Maximum | Time Vested	'
Stock-Based Compensation [Line Items]	'
Award vesting period	'5 years

Stockbased_compensation_cost_D

Stock-based compensation cost (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Stock-Based Compensation Expense [Abstract]	'	'	'	'	'
Stock-based compensation cost	$2,045	$1,725	$4,620	$4,773	'
Less: stock-based compensation cost capitalized	-505	-605	-1,440	-1,715	'
Stock-based compensation expense	1,540	1,120	3,180	3,058	'
Payments for stock-based compensation	135	120	1,433	981	'
Stock-based compensation costs included in accrued payroll and benefits payable	4,173	'	4,173	'	2,636
Unrecognized compensation cost	$17,383	'	$17,383	'	'
Years over which unrecognized compensation cost is expected to be recognized	'	'	'3 years 1 month 6 days	'	'

Common_stock_Details

Common stock (Details)

9 Months Ended

9 Months Ended

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Common Stock

Common Stock

Common Class A

Common Class B

Common Class B

Common Class C

Common Class C

Common Class D

Common Class D

Common Class E

Common Class E

Common Class F

Common Class F

Common Class G

Common Class G

Common stock rollforward

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares outstanding at January 1, 2013

'

1,422,267

1,420,034

67,991

357,882

357,882

209,882

209,882

279,999

279,999

504,276

504,276

1

1

3

3

Restricted stock issuances

8,056

'

'

8,056

'

'

'

'

'

'

'

'

'

'

'

'

Restricted stock repurchased

-873

'

'

-873

'

'

'

'

'

'

'

'

'

'

'

'

Restricted stock forfeitures

-4,950

'

'

-4,950

'

'

'

'

'

'

'

'

'

'

'

'

Shares outstanding at September 30, 2013

'

1,422,267

1,420,034

70,224

357,882

357,882

209,882

209,882

279,999

279,999

504,276

504,276

1

1

3

3

Related_party_transactions_Det

Related party transactions (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
In Thousands, unless otherwise specified	Chesapeake	Chesapeake	Chesapeake Holdings Corporation	Properties Operated by Chesapeake	Properties Operated by Chesapeake	Properties Operated by Chesapeake	Properties Operated by Chesapeake	Properties Operated by Chaparral	Properties Operated by Chaparral	Properties Operated by Chaparral	Properties Operated by Chaparral
Related Party Transaction [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Chaparral common stock owned by Chesapeake	'	'	20.00%	'	'	'	'	'	'	'	'
Revenue from jointly owned properties	'	'	'	$2,449	$831	$5,289	$2,600	($1,549)	($1,062)	($3,248)	($2,521)
Joint interest billings	'	'	'	-453	-828	-1,764	-4,295	1,084	3,093	8,969	7,737
Amounts receivable from Chesapeake	1,568	2,071	'	'	'	'	'	'	'	'	'
Amounts payable to Chesapeake	$87	$864	'	'	'	'	'	'	'	'	'

Commitments_and_contingencies_

Commitments and contingencies (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Jun. 30, 2011
In Thousands, unless otherwise specified			Pending Litigation
			Minimum
Loss Contingencies [Line Items]	'	'	'
Letters of credit outstanding	$920	$920	'
Damages sought	'	'	$5,000