PostRock Energy (PSTR) 10-K 31 Mar 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Mar. 02, 2015	Jun. 30, 2014
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Trading Symbol	PSTR
Entity Registrant Name	PostRock Energy Corp
Entity Central Index Key	1473061
Current Fiscal Year End Date	-19
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding		6,372,054
Entity Public Float			$29.40
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets
Cash and equivalents	$46	$37
Accounts receivable-trade, net	9,080	7,722
Other receivables	515	194
Inventory	1,042	886
Other	1,031	820
Derivative financial instruments	11,151	54
Total	22,865	9,713
Oil and natural gas properties, full cost method of accounting, net	153,240	141,911
Other property and equipment, net	11,829	14,180
Equity investment		14,588
Derivative financial instruments	6,162	652
Other, net	1,579	2,038
Total assets	195,675	183,082
Current liabilities
Accounts payable	9,278	7,406
Revenue payable	4,051	4,397
Accrued expenses and other	3,283	4,055
Derivative financial instruments		1,937
Total	16,612	17,795
Derivative financial instruments		1,796
Long-term debt	83,000	92,000
Mandatorily redeemable preferred stock, $0.01 par value; 7,250 and 5,075 shares issued and outstanding at December 31, 2013 and 2014, respectively		83,994
Asset retirement obligations	13,884	13,099
Other	1	75
Total liabilities	177,451	208,759
Commitments and contingencies
Stockholders’ equity (deficit)
Common stock, $0.01 par value; 100,000,000 authorized shares; issued—2,991,595 and 6,523,811; outstanding—2,955,627 and 6,336,728 at December 31, 2013 and 2014, respectively	65	30
Additional paid-in capital	481,050	439,114
Treasury stock, at cost	-2,432	-512
Accumulated deficit	-460,459	-464,309
Total stockholders’ equity (deficit)	18,224	-25,677
Total liabilities and stockholders’ equity (deficit)	195,675	183,082
Series A Preferred Stock [Member]
Current liabilities
Mandatorily redeemable preferred stock, $0.01 par value; 7,250 and 5,075 shares issued and outstanding at December 31, 2013 and 2014, respectively	63,954	83,994
Series B Preferred Stock [Member]
Stockholders’ equity (deficit)
Preferred stock, $0.01 par value; 5,000,000 authorized shares; 11,352 and 23,098 shares of Series B Voting Preferred Stock issued and outstanding at December 31, 2013 and 2014, respectively

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Common stock, par value	$0.01	$0.01
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares issued	6,523,811	2,991,595
Common stock, shares outstanding	6,336,728	2,955,627
Series A Preferred Stock [Member]
Mandatorily redeemable preferred stock, shares	7,250	5,075
Preferred stock, par value	$0.01	$0.01
Preferred stock, shares outstanding	5,075	7,250
Series B Preferred Stock [Member]
Preferred stock, par value	$0.01	$0.01
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, shares issued	23,098	11,352
Preferred stock, shares outstanding	23,098	11,352

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Revenues
Natural gas sales	$56,273		$51,489		$43,911
Crude oil sales	24,532		18,200		8,640
Gathering	2,700		2,611		2,444
Total	83,505		72,300		54,995
Costs and expenses
Production expense	40,885		40,085		42,213
General and administrative	13,889		15,990		14,810
Depreciation, depletion and amortization	28,895		27,369		27,669
Impairment of oil and gas properties	0		0		5,919
(Gain) loss on disposal of assets	-144		-194		295
Acquisition costs	47		348
Total	83,572		83,598		90,906
Operating loss	-67		-11,298		-35,911
Other income (expense)
Gain (loss) from derivative financial instruments	16,396		-599		6,454
Gain (loss) on investment	7,214		6,768		-5,174
Gain on forgiveness of debt					255
Other income (expense), net	-17		12		111
Interest expense, net	-19,664		-18,069		-21,773
Total	3,929		-11,888		-20,127
Income (loss) from continuing operations before income taxes	3,862		-23,186		-56,038
Income taxes	12		180		0
Income (loss) from continuing operations	3,850		-23,366		-56,038
Loss from discontinued operations					-2,855
Net income (loss)	$3,850		($23,366)		($58,893)
Net income (loss) per common share
Basic income (loss) per share—continuing operations	$0.98		($9.32)		($41.20)
Basic income (loss) per share—discontinued operations					($2.10)
Basic income (loss) per share	$0.98		($9.32)		($43.30)
Diluted income (loss) per share—continuing operations	$0.98		($9.32)		($41.20)
Diluted income (loss) per share—discontinued operations					($2.10)
Diluted income (loss) per share	$0.98		($9.32)		($43.30)
Weighted average common shares outstanding
Basic	3,915,578	[1]	2,506,857	[1]	1,359,584	[1]
Diluted	3,947,917		2,506,857		1,359,584
[1]	Includes vested common shares in the Company’s deferred compensation plan and vested deferred restricted stock units, both of which will deliver shares to participants at a later date. Although shares have not been delivered on these awards, all conditions for issuance and delivery have been met. Pursuant to FASB ASC 260-10-45-13, such shares are to be included in the denominator in calculating basic earnings per share.

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash flows from operating activities
Net income (loss)	$3,850	($23,366)	($58,893)
Adjustments to reconcile net income (loss) to net cash flows from operating activities
Depreciation, depletion and amortization	28,895	27,369	30,206
Impairment of oil and gas properties	0	0	5,919
Share-based and other compensation	3,158	4,268	2,224
Amortization of deferred loan costs	524	461	2,820
Change in fair value of derivative financial instruments	-20,340	-1,672	67,186
Loss (gain) on disposal of assets	-144	-194	5,735
Gain on forgiveness of debt			-255
Loss (gain) from investment	-7,214	-6,768	5,174
Non-cash interest expense	16,106	14,827	11,321
Other non-cash changes to items affecting net loss			409
Changes in operating assets and liabilities
Receivables	-1,679	-529	1,519
Payables	-2,946	-3,606	-9,248
Other	-577	453	5,002
Net cash flows from operating activities	19,633	11,243	69,119
Cash flows from investing activities
Restricted cash		1,500	-1,500
Proceeds from sale of equity securities	21,802
Expenditures for equipment, development, leasehold and pipeline	-32,973	-52,283	-16,759
Proceeds from sale of discontinued pipeline			53,397
Proceeds from sale of assets	649	1,111	496
Net cash flows from (used in) investing activities	-10,522	-49,672	35,634
Cash flows from financing activities
Proceeds from debt	63,000	98,500	57,500
Repayments of debt	-72,000	-64,000	-193,000
Debt and equity financing costs	-102	-635	-2,301
Proceeds from issuance of common stock		4,076	20,724
Proceeds from issuance of preferred stock and warrants			12,500
Net cash flows from (used in) financing activities	-9,102	37,941	-104,577
Net increase (decrease) in cash and cash equivalents	9	-488	176
Cash and equivalents beginning of period	37	525	349
Cash and equivalents end of period	$46	$37	$525

Consolidated_Statement_of_Stoc

Consolidated Statement of Stockholders' Equity (Deficit) (USD $)	Preferred Stock [Member]	Preferred Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Additional Paid-in Capital [Member]	Treasury Stock [Member]	Accumulated Deficit [Member]	Series B Preferred Stock [Member]	Total
In Thousands, except Share data	Series B Preferred Stock [Member]		USD ($)	Series B Preferred Stock [Member]	USD ($)	USD ($)	USD ($)	USD ($)	USD ($)
				USD ($)
Beginning balance at Dec. 31, 2011			$10		$389,850		($382,050)		$7,810
Beginning balance, common shares at Dec. 31, 2011			993,534
Beginning balance, preferred shares at Dec. 31, 2011		21,566
Stock-based compensation					2,223				2,223
Restricted stock grants, net			1						1
Restricted stock grants, net, shares			108,510
Issuance of stock			10	1	20,435			1	20,445
Issuance of stock, shares	4,944		1,028,072
Issuance of warrants					7,405				7,405
Net loss							-58,893		-58,893
Ending balance at Dec. 31, 2012			21		419,914		-440,943		-21,008
Ending balance, common shares at Dec. 31, 2012			2,130,116
Beginning balance, preferred shares at Dec. 31, 2012		26,510
Stock-based compensation					3,209				3,209
Restricted stock grants, net						-39			-39
Restricted stock grants, net, shares			-39,376			3,517
Funding of 401K and deferred comp. plans			1		1,403	-473			931
Funding of 401K and deferred comp. plans, shares			64,953			32,452			32,501
Warrant exchange (see Note 12)			1		-2				-1
Warrant exchange (see Note 12), shares		-22,242	112,398
Issuance of stock			7	1	10,605			1	10,612
Issuance of stock, shares	7,084		723,504
Issuance of warrants					3,984				3,984
Net loss							-23,366		-23,366
Ending balance at Dec. 31, 2013			30		439,114	-512	-464,309		-25,677
Ending balance, common shares at Dec. 31, 2013			2,991,595			35,969			2,955,627
Ending balance, preferred shares at Dec. 31, 2013		11,352						11,352
Stock-based compensation					922				922
Restricted stock grants, net						-121			-121
Restricted stock grants, net, shares			34,436			9,733
Funding of 401K and deferred comp. plans			2		4,033	-1,799			2,236
Funding of 401K and deferred comp. plans, shares			213,821			141,381			58,513
Preferred exchange (see Note 12)			32		32,000				32,032
Preferred exchange (See Note 12), shares			3,211,378
Issuance of stock			1		892				893
Issuance of stock, shares	11,746		72,581
Issuance of warrants					4,089				4,089
Net loss							3,850		3,850
Ending balance at Dec. 31, 2014			$65		$481,050	($2,432)	($460,459)		$18,224
Ending balance, common shares at Dec. 31, 2014			6,523,811			187,083			6,336,728
Ending balance, preferred shares at Dec. 31, 2014		23,098						23,098

Business_Organization

Business Organization	12 Months Ended
	Dec. 31, 2014
Business of Presentation [Abstract]
Business Organization	Note 1—Business Organization
	PostRock Energy Corporation (“PostRock”) is an independent oil and gas company engaged in the acquisition, exploration, development, production and gathering of crude oil and natural gas. It manages its business in one segment, oil and gas production. Its primary production activity is focused in the Cherokee Basin, a 15-county region in southeastern Kansas and northeastern Oklahoma, and central Oklahoma. It also has minor oil and gas producing properties in the Appalachian Basin. Unless the context requires otherwise, any reference to “the Company”, “we”, “us”, and “our” is to PostRock and subsidiaries.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Summary of Significant Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Note 2—Summary of Significant Accounting Policies
	Principles of Consolidation—These consolidated financial statements include PostRock’s and its subsidiaries’ accounts. Subsidiaries in which PostRock directly or indirectly owns more than 50% of the outstanding voting securities or those in which PostRock has effective control over are generally accounted for under the consolidation method of accounting. Under this method, a subsidiaries’ balance sheet and results of operations are reflected within the Company’s consolidated financial statements. All significant intercompany accounts and transactions have been eliminated.
	Use of Estimates in the Preparation of Financial Statements—The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company’s most significant recurring estimates are based on remaining proved oil and gas reserves. Estimates of proved reserves are key components of the Company’s depletion rate for oil and gas properties and its full cost ceiling test limitation. In addition, estimates are used in computing fair value of impaired assets, taxes, asset retirement obligations, fair value of derivative contracts and other items. Actual results could differ from these estimates.
	Cash and Cash Equivalents—The Company considers all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents. Cash balances are maintained at a few financial institutions that are insured by the Federal Deposit Insurance Corporation although such balances at times are in excess of the insured amount; however, no losses have been recognized as a result of this circumstance. During 2011, the Company began utilizing a controlled disbursement cash account which is funded when outstanding checks and electronic payments are presented for payment and an overdraft is the normal book balance. The Company’s policy has been to fund these outstanding checks and electronic payments as they clear through the banking system with customer receipts and borrowings under its Borrowing Base Credit Facility (as defined below). The Company accounts for such book overdrafts by reporting them in accounts and revenue payable in its consolidated balance sheets and including the change in such amounts in cash flows from operating activities in its consolidated statements of cash flows. Outstanding checks and electronic payments included in accounts and revenue payable at December 31, 2013 and 2014, amounted to $4.5 million and $2.0 million, respectively.
	Accounts Receivable—The Company conducts the majority of its operations in Kansas and Oklahoma and operates exclusively in the oil and gas industry. Receivables are generally unsecured; however, the Company has not experienced any significant losses to date. Receivables are recorded at the estimate of amounts due based upon the terms of the related agreements. Management periodically assesses the accounts receivable and establishes an allowance for estimated uncollectible amounts. Accounts estimated to be uncollectible are charged to operations in the period the reserve is established. The allowance for doubtful accounts was approximately $194,000 at December 31, 2013 and 2014.
	Inventory—Inventory includes tubular goods and other lease and well equipment which the Company plans to utilize in its ongoing exploration and development activities and is carried at the lower of cost or market using the specific identification method.
	Oil and Natural Gas Properties—The Company uses the full cost method of accounting for oil and gas properties. Under the full cost method, all direct costs and certain indirect costs associated with the acquisition, exploration, and development of its oil and gas properties are capitalized.
	Oil and gas properties are depleted using the units-of-production method. The depletion expense is significantly affected by the unamortized historical and future development costs and the estimated proved oil and gas reserves. Estimation of proved oil and gas reserves relies on professional judgment and use of factors that cannot be precisely determined. Subsequent proved reserve estimates that are materially different from those reported would change the depletion expense recognized during the future reporting period. No gains or losses are recognized upon the sale or disposition of oil and gas properties such will result in an amortization rate materially different from the amortization rate calculated upon recognition of gains or losses.
	Under the full cost accounting rules, total capitalized costs are limited to a ceiling equal to the present value of future net revenues, discounted at 10% per annum less income tax effects (the “ceiling limitation”). The Company performs a quarterly ceiling test to evaluate whether the net book value of its full cost pool exceeds the ceiling limitation. If capitalized costs (net of accumulated depreciation, depletion, and amortization) less related deferred taxes are greater than the discounted future net revenues or ceiling limitation, a write-down or impairment of the full cost pool is required. A write-down of the carrying value of the full cost pool is a non-cash charge that reduces earnings and impacts stockholders’ (deficit) equity in the period of occurrence and typically results in lower depreciation, depletion, and amortization expense in future periods. Once incurred, a write-down is not reversible at a later date. The risk that the Company will be required to write down the carrying value of its oil and gas properties increases when oil and gas prices are depressed. This is partially mitigated by the use of an unweighted arithmetic average of first day of the month price for trailing twelve-month market prices to determine the ceiling. In addition, a write-down may occur if estimates of proved reserves are substantially reduced or estimates of future development costs increase significantly.
	Unevaluated Properties—The costs directly associated with unevaluated oil and gas properties and properties under development are not initially included in the amortization base and relate to unproved leasehold acreage, seismic data, wells and production facilities in progress and wells pending determination. Unevaluated leasehold costs are transferred to the amortization base once determination has been made or upon expiration of a lease. Geological and geophysical costs and cumulative drilling costs to date associated with a specific unevaluated property are transferred to the amortization base with the associated leasehold costs on a specific project basis. Costs associated with wells in progress and wells pending determination are transferred to the amortization base once a determination is made whether or not proved reserves can be assigned to the property. All items included in the Company’s unevaluated property balance are assessed on a quarterly basis for possible impairment or reduction in value. The assessment includes consideration of numerous factors, including intent to drill, remaining lease term, geological and geophysical evaluations, drilling results and activity, assignment of proved reserves and economic viability of development if proved reserves are assigned. Any impairments of unevaluated properties are transferred to the amortization base.
	Capitalized General and Administrative Expenses—Under the full cost method of accounting, a portion of general and administrative expenses that are directly attributable to acquisition, exploration, and development activities are capitalized to the full cost pool. The capitalized costs include salaries, related fringe benefits, cost of consulting services and other costs directly associated with those activities. In addition to costs related to acquisition, exploration, and development activities, the Company has also capitalized certain software costs. The Company’s capitalized general and administrative costs, including software costs, were $904,000, $1.3 million and $960,000 for the years ended December 31, 2012, 2013 and 2014, respectively.
	Capitalized Interest Costs—The Company capitalizes interest based on the cost of major development projects. Capitalized interest was $11,000 for the year ended December 31, 2012 and nil for the years ended December 31, 2013 and 2014.
	Other Property and Equipment—The cost of other property and equipment is depreciated over the estimated useful lives of the related assets. The cost of leasehold improvements is depreciated over the lesser of the length of the related leases or the estimated useful lives of the assets.
	Upon disposition or retirement of property and equipment, other than oil and gas properties, the cost and related accumulated depreciation are removed from the accounts and the gain or loss thereon, if any, is recognized in the statement of operations in the period of sale or disposition. Maintenance and repair costs are charged to operating expense as incurred.
	Impairment—Long-lived assets such as property and equipment are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of such assets to estimated undiscounted future cash flows expected to be generated by the assets. If the carrying amount of such assets exceeds their undiscounted estimated future cash flows, an impairment charge is recognized in the amount by which the carrying amount of such assets exceeds the fair value of the assets.
	Investment—The Company elected to measure its investment in Constellation Energy Partners LLC, now named Sanchez Production Partners LLC (“SPP”), at fair value with changes in fair value included in the consolidated statements of operations. If the Company had not elected the fair value method, the investment would have previously qualified for the equity method of accounting, under which the Company’s proportionate share of the investee’s income would have been reported in the consolidated statements of operations.
	Asset Retirement Obligations—Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 410, Asset Retirement and Environmental Obligations (ASC 410) requires that the fair value of an asset retirement cost and the corresponding liability should be recorded as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method. The Company records asset retirement obligations to reflect the Company’s legal obligations related to future plugging and abandonment of its natural gas and oil wells. Asset retirement obligations associated with the retirement of a tangible long-lived asset are recognized as a liability in the period incurred or when it becomes determinable that there is a legal or contractual obligation to dismantle or dispose of the asset and reclaim or remediate any related property at the end of its useful life, with an associated increase in the carrying amount of the related long-lived asset. The cost of the tangible asset, including the asset retirement cost, is depreciated over the useful life of the asset. The asset retirement obligation is recorded at its estimated fair value, measured by reference to the expected future cash outflows required to satisfy the retirement obligation discounted at the Company’s credit-adjusted risk-free interest rate. Accretion expense is recognized over time as the discounted liability is accreted to its expected settlement value and is recorded within “Depreciation, depletion, and amortization” on the Statement of Operations. If the estimated future cost of the asset retirement obligation changes, an adjustment is recorded to both the asset retirement obligation and the long-lived asset. Revisions to estimated asset retirement obligations can result from changes in retirement cost estimates, revisions to estimated inflation rates and changes in the estimated timing of abandonment. The Company has not recorded an asset retirement obligation relating to its gathering system because it does not have any legal or constructive obligations relative to asset retirements of the gathering system.
	Derivative Instruments—The Company utilizes derivative instruments in conjunction with marketing and trading activities to manage price risk attributable to its forecasted sales of oil and gas production.
	The Company does not designate its oil and natural gas derivative contracts as hedges under ASC 815 Derivatives and Hedging although it believes that such contracts are effective hedges of its commodity price exposure. These contracts are accounted for using the mark-to-market accounting method. Using this method, the contracts are carried at their fair value on the Company’s consolidated balance sheets under the caption “Derivative financial instruments.” Changes in the fair value of these derivative financial instruments are recorded in earnings. The Company recognizes all unrealized and realized gains and losses related to these contracts on its consolidated statements of operations under the caption “Gain (loss) from derivative instruments” which is a component of “Other income (expense)”.
	The Company has exposure to credit risk to the extent a counterparty to a derivative instrument is unable to meet its settlement commitment. It actively monitors the creditworthiness of each counterparty and assesses the impact, if any, on its derivative positions.
	Legal—The Company is subject to certain legal proceedings, claims and liabilities which arise in the ordinary course of its business. It accrues for losses associated with legal claims when such losses are probable and can be reasonably estimated. These estimates are adjusted as additional information becomes available or circumstances change.
	Revenue Recognition—Revenue from the Company’s oil and gas operations is derived from the sale of produced oil and natural gas. The Company uses the sales method of accounting for the recognition of oil and gas revenue. Because there is a ready market for oil and gas, the Company sells its oil and gas shortly after production at various pipeline receipt points at which time title and risk of loss transfers to the buyer. Revenue is recorded when title and risk of loss is transferred based on the Company’s net revenue interests. Gathering revenue is recognized at the time the gas is gathered or transported through the system and delivered to a third party as evidenced by a contract.
	Environmental Costs—Environmental expenditures are expensed or capitalized, as appropriate, depending on future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed. Liabilities related to future costs are recorded on an undiscounted basis when environmental assessments and/or remediation activities are probable and costs can be reasonably estimated. The Company has no environmental costs accrued for the periods presented.
	Stock-Based Compensation—The Company grants various types of stock-based awards including stock options, restricted stock and restricted stock units to its employees and non-employee directors. The Company accounts for stock-based compensation in accordance with FASB ASC 718 Compensation – Stock Compensation where the awards are measured at fair value on the date of grant and are generally recognized as a component of general and administrative expenses in the consolidated statement of operations over the applicable requisite service periods. The fair value of stock option awards is determined using a Black-Scholes pricing model where volatility is derived from a peer group of companies.
	Deferred compensation plan—The Company’s deferred compensation plan permits selected employees and members of its board of directors to defer part or all of their eligible compensation. The Company accounts for this deferred compensation in accordance with FASB ASC 710 Compensation – General. The Company issues common stock into a rabbi trust created to hold the assets associated with the plan. A participant’s deferred compensation is credited with earnings, gains and losses based on the Company’s common stock, the only investment option currently available under the plan. The Company may also make discretionary employer credits in an amount it determines each plan year. Distributions to participants will be made in shares of the Company’s common stock. Company shares held in the rabbi trust are recorded as treasury stock in the consolidated balance sheets. Since the deferred compensation arrangement currently does not permit diversification and only allows for settlement by delivery of Company common stock, the obligation is recorded as a component of paid-in-capital and changes in the fair value of the obligation are not recognized.
	Income Taxes—The Company records its income taxes using an asset and liability approach in accordance with the provisions of the FASB ASC 740 Income Taxes. This results in the recognition of deferred tax assets and liabilities for the expected future tax consequences of temporary differences (primarily property and equipment and the net operating loss carry forward) between the book carrying amounts and the tax bases of assets and liabilities using enacted tax rates at the end of the period. Under FASB ASC 740, the effect of a change in tax rates of deferred tax assets and liabilities is recognized in the year of the enacted change. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. At December 31, 2013 and 2014, a full valuation allowance was recorded against the Company’s net deferred tax assets.
	The Company regularly analyzes tax positions taken or expected to be taken in a tax return based on the threshold condition prescribed under FASB ASC 740. Tax positions that do not meet or exceed this threshold condition are considered uncertain tax positions. The Company accrues interest and penalties related to uncertain tax positions as income tax expense.
	Net Income (Loss) per Common Share—Basic earnings (loss) per share is calculated by dividing net income (loss) available to common stockholders by the weighted average number of shares of common stock outstanding during the period. The Company also includes contingently issuable shares in basic earnings (loss) per share when there is no circumstance under which those shares would not be issued. These include vested shares under the Company’s deferred compensation plan and vested deferred restricted stock units as all necessary conditions have been satisfied for the issuance of those shares other than the passage of time. Diluted earnings (loss) per share assumes the conversion of all potentially dilutive securities (warrants, stock options and restricted stock awards) and is calculated by dividing net income (loss) by the sum of the weighted average number of shares of common stock outstanding plus potentially dilutive securities under the treasury stock method.
	Reverse Stock Split—All common stock, options, warrants, shares and per share amounts with respect to PostRock stock, excluding Series A Preferred Stock, have been retroactively adjusted in the accompanying consolidated financial statements and related notes to reflect the 1-for-10 reverse stock split, effective January 2, 2015.
	Reclassifications—Certain reclassifications have been made to the prior periods’ financial statements to conform to the current period’s presentation. These reclassifications had no effect on the financial position, results of operations or cash flows of the Company.
	Concentrations of Market Risk—The Company’s future results will be affected by the market price of oil and gas. The availability of a ready market for oil and gas will depend on numerous factors beyond the Company’s control, including weather, production of oil and gas, imports, marketing, competitive fuels, proximity of oil and gas pipelines and other transportation facilities, any oversupply or undersupply of oil and gas, the regulatory environment, and other regional and political events, none of which can be predicted with certainty.
	Concentrations of Credit Risk—Financial instruments, which subject the Company to concentrations of credit risk, consist primarily of cash and accounts receivable. Risk with respect to receivables at December 31, 2013 and 2014, arise substantially from the sales of oil and gas. The following table discloses the percentage of consolidated revenues from our major customers:
		Year Ended December 31,
		2013		2014
	British Petroleum Energy Company	56	%	64	%
	ONEOK Energy and Marketing and Trading Company	11	%	—	%
	Sunoco	11	%	21	%
	Fair Value—The Company applies the provisions of FASB ASC 820 Fair Value Measurements and Disclosures. Fair value is the exit price that we would receive to sell an asset or pay to transfer a liability in an orderly transaction between market participants at the measurement date.
	FASB ASC 820 also establishes a hierarchy that prioritizes the inputs used to measure fair value. The three levels of the fair value hierarchy are as follows:
	•Level 1—Quoted prices available in active markets for identical assets or liabilities at the reporting date.
	•Level 2—Pricing inputs other than quoted prices in active markets included in Level 1 which are either directly or indirectly observable at the reporting date. Level 2 consists primarily of non-exchange traded commodity derivatives.
	•Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources.
	The Company classifies assets and liabilities within the fair value hierarchy based on the lowest level of input that is significant to the fair value measurement of each individual asset and liability taken as a whole. Transfers of assets and liabilities between Level 1 and Level 2 are recognized at the end of a reporting period. The Company prioritizes the use of the highest level inputs available in determining fair value.
	Recent Accounting Pronouncements Not Yet Adopted
	In May 2014, the Financial Accounting Standards Board issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). The update provides guidance concerning the recognition and measurement of revenue from contracts with customers. Its objective is to increase the usefulness of information in the financial statements regarding the nature, timing and uncertainty of revenues. The update is effective for PostRock beginning on January 1, 2017. The standard permits the use of either the retrospective or cumulative effect transition method. PostRock has not yet selected a transition method and is evaluating the impact this standard will have on its consolidated financial statements and related disclosures.
	In August 2014, the Financial Accounting Standards Board issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Topic 205). The update provides guidance on management’s responsibility in evaluating whether there is a substantial doubt about a company’s ability to continue as a going concern. Its objective is to define management’s responsibility to evaluate going concern and to provide related footnote disclosures. The update is effective for PostRock beginning on January 1, 2017. PostRock has not yet determined whether early application of this accounting standard will be adopted.

Acquisitions_and_Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2014
Acquisitions and Divestitures [Abstract]
Acquisitions and Divestitures	Note 3—Acquisitions and Divestitures
	Acquisitions
	During January 2014, the Company acquired additional interests in the assets purchased in Pottawatomie, Cleveland, and McClain Counties in central Oklahoma in November 2013, discussed below. The total purchase price of the acquired interests after closing adjustments was approximately $1.7 million which was paid in cash of approximately $800,000 and 72,581 shares of the Company’s common stock.
	During May 2013, we acquired leasehold interests in 4,300 acres located in Lincoln and Payne Counties in Oklahoma. The total purchase price of the acquired interests was $1.9 million which was paid in cash of $1.7 million and 12,661 shares of the Company’s common stock.
	During November 2013, we acquired a 50% working interest in 110 operated acres and three producing wells in Seminole County, Oklahoma, for $750,000 in cash.
	During November 2013, the Company closed on an acquisition of oil and natural gas assets located in Pottawatomie, Cleveland and McClain Counties in central Oklahoma. The acquisition included approximately 22,000 net acres of leasehold mineral interests, including certain producing oil and gas properties and related wells. The total purchase price of the acquired assets was approximately $10.0 million and was paid in cash and 451,613 shares of the Company’s common stock. The Company estimated the fair value of the assets and liabilities acquired as of the acquisition date. The following table discloses the fair value of consideration transferred to the sellers as well as the purchase price allocation of the assets and liabilities assumed:
	Consideration given (in thousands)
	Cash	$	3,440
	Common stock		6,548
	Total consideration given	$	9,988
	Amounts recognized for fair value of assets acquired and liabilities assumed
	Proved oil and natural gas properties	$	7,081
	Unproved oil and natural gas properties		3,253
	Crude oil inventory		177
	Accounts receivable		167
	Asset retirement obligations		-538
	Accounts payable		-152
	Total fair value of oil and gas properties acquired	$	9,988
	To estimate the fair values of the properties as of the acquisition date, the Company utilized a discounted cash flow model that took into account the following inputs to arrive at estimates of future net cash flows: (i) estimated ultimate recovery of crude oil and natural gas as prepared by a third party reservoir engineering consultant; (ii) estimated future commodity prices based on NYMEX crude oil and gas futures prices as of the acquisition date and adjusted for estimated location and quality differentials; (iii) estimated future production rates; and (iv) estimated timing and amounts of future operating and development costs. To estimate the fair value of proved properties, the Company discounted the future net cash flows using a market-based rate that the Company determined appropriate at the acquisition date for the various proved reserve categories. The valuation of the assets and liabilities received is a Level 3 valuation under the fair value hierarchy. The Company has not presented pro forma information for the acquired businesses because the revenues and expenses from the acquired properties were not material to the results of operations of the Company.
	Divestitures
	During June 2014, the Company entered into a joint venture (“JV”) agreement with Silver Creek Oil and Gas, LLC (“Silver Creek”) covering approximately 17,900 gross unproved acres in Cleveland and Pottawatomie Counties in central Oklahoma. The JV included an acre for acre swap of approximately 3,800 total net acres. After the swap, the ownership split in the development area is 30% PostRock and 70% Silver Creek, with Silver Creek serving as the operator. The Company also sold approximately 1,150 net acres to Silver Creek for $466,000 in cash.
	KPC Sale—In September 2012, the Company sold PostRock KPC Pipeline, LLC (“KPC”) subsidiary to MV Pipelines, LLC (“MV”) for $53.4 million in cash after a working capital adjustment. Details of the transaction are discussed further in Note 16 — Discontinued Operations.
	Appalachia Basin Sale—  On December 24, 2010, the Company entered into an agreement with Magnum Hunter Resources Corporation (“MHR”) to sell certain oil and gas properties and related assets in West Virginia. The sale closed in three phases for a total of $44.6 million.
	Of the total proceeds received from all three phases of the sale, $6.4 million was set aside in escrow to cover potential claims for indemnity and title defects. During 2012, $5.7 million of escrowed funds relating to the first and second closing was released after net claims of $219,000 were paid. Of the $5.7 million released to the Company, $1.3 million was retained by the Company while $4.4 million was paid to Royal Bank of Canada (“RBC”) under the asset sale agreement discussed in Note 10. The $219,000 of net claims paid out of escrow effectively reduced the net proceeds received from the sale, and along with certain post-closing adjustments, resulted in a $266,000 reduction in the gain on sale recognized in 2012.

Other_Balance_Sheet_Items

Other Balance Sheet Items	12 Months Ended
	Dec. 31, 2014
Other Balance Sheet Items [Abstract]
Other Balance Sheet Items	Note 4—Other Balance Sheet Items
	The following describes the components of the following consolidated balance sheet items at December 31, 2013 and 2014:
		December 31,
		2013		2014
		(in thousands)
	Other current assets
	Prepaid fees and deposits	$	820	$	975
	Other		—		56
	Total	$	820	$	1,031
	Other noncurrent assets, net
	Deferred financing costs	$	1,547	$	1,126
	Noncurrent deposits and other		491		453
	Total	$	2,038	$	1,579
	Accrued expenses and other
	Interest	$	39	$	26
	Employee-related costs and benefits		1,062		1,870
	Non-income related taxes		72		40
	Fees for services		1,127		316
	Asset retirement obligations		129		134
	Current income taxes		80		—
	Other		1,546		897
	Total	$	4,055	$	3,283
	Other noncurrent liabilities
	Lease termination costs	$	75	$	—
	Other		—		1
	Total	$	75	$	1
	Deferred Financing Costs—The Company’s expense related to amortizing or writing off deferred financing costs was $2.8 million, $461,000 and $524,000 for the years ended December 31, 2012, 2013 and 2014, respectively. These costs are included in interest expense. Included in the amounts above was a $1.2 million write-off of unamortized debt issuance costs for the year ended December 31, 2012, made in connection with the refinancing of the Company’s credit facility that year.

Property

Property	12 Months Ended
	Dec. 31, 2014
Property [Abstract]
Property	Note 5—Property
	Oil and gas properties, and other property and equipment were comprised of the following at December 31, 2013 and 2014:
		December 31,
		2013		2014
		(in thousands)
	Oil and gas properties under the full cost method of accounting
	Properties being amortized	$	405,895	$	440,333
	Properties not being amortized		4,862		6,150
	Total oil and gas properties, at cost		410,757		446,483
	Less accumulated depletion, depreciation and amortization		-268,846		-293,243
	Oil and gas properties, net	$	141,911	$	153,240
	Other property and equipment at cost	$	30,019	$	30,629
	Less accumulated depreciation		-15,839		-18,800
	Other property and equipment, net	$	14,180	$	11,829
	Depreciation on other property and equipment is computed on the straight-line basis over the following estimated useful lives:
	Buildings	25 years
	Machinery and equipment	10 years
	Software and computer equipment	3 years
	Furniture and fixtures	10 years
	Vehicles	5 years
	For the years ended December 31, 2012, 2013 and 2014, depletion, depreciation and amortization expense on oil and gas properties amounted to $23.3 million, $23.3 million and $24.3 million, respectively. For the years ended December 31, 2012, 2013 and 2014, depreciation expense on other property and equipment amounted to $3.6 million, $3.2 million and $3.6 million, respectively. Depreciation and amortization expense on the Company’s interstate pipeline, sold in September 2012, is disclosed in Note 16.

Derivative_Financial_Instrumen

Derivative Financial Instruments	12 Months Ended
	Dec. 31, 2014
Derivative Financial Instruments [Abstract]
Derivative Financial Instruments	Note 6—Derivative Financial Instruments
	The Company is exposed to commodity price risk and management believes it prudent to periodically reduce exposure to cash-flow variability resulting from this volatility. Accordingly, the Company enters into certain derivative financial instruments in order to manage exposure to commodity price risk inherent in its oil and gas production. Derivative financial instruments are also used to manage commodity price risk inherent in customer pricing requirements and to fix margins on the future sale of oil and natural gas. Specifically, the Company may utilize futures, swaps and options.
	Derivative instruments expose the Company to counterparty credit risk. The Company’s commodity derivative instruments are currently with two counterparties. The Company generally executes commodity derivative instruments under master agreements which allow it, in the event of default, to elect early termination of all contracts with the defaulting counterparty. If the Company chooses to elect early termination, all asset and liability positions with the defaulting counterparty would be net cash settled at the time of election.
	The Company monitors the creditworthiness of its counterparties; however, it is not able to predict sudden changes in counterparties’ creditworthiness. In addition, even if such changes are not sudden, it may be limited in its ability to mitigate an increase in counterparty credit risk. Possible actions would be to transfer its position to another counterparty or request a voluntary termination of the derivative contracts resulting in a cash settlement. Should one of these counterparties not perform, the Company may not realize the benefit of some of its derivative instruments under lower commodity prices as well as incur a loss. The Company includes a measure of counterparty credit risk in its estimates of the fair values of derivative instruments in an asset position.
	The Company entered into an International Swap Dealers Association Master Agreement (“ISDA”) with each of its two counterparties for which it holds derivative contracts. The ISDA is a standard contract that governs all derivative contracts entered into between the Company and the respective counterparty. The ISDA allows for offsetting of amounts payable or receivable between the Company and the counterparty, at the election of both parties, for transactions that occur on the same date and in the same currency. The Company has multiple oil swap contracts that could be offset under these provisions but has elected not to offset the fair values of its derivative assets against the fair value of its derivative liabilities on its consolidated balance sheets. The ISDA also includes a master netting arrangement in the event of early termination or default.
	The Company does not designate its derivative financial instruments as hedging instruments for financial accounting purposes and, as a result, it recognizes the change in the respective instruments’ fair value currently in earnings. The tables below outline the classification of derivative financial instruments on the consolidated balance sheet:
				December 31,
				2013			2014
	Derivative Financial Instruments		Balance Sheet Location	(in thousands)
	Commodity contracts		Current derivative financial instrument asset	$	54		$	11,151
	Commodity contracts		Long-term derivative financial instrument asset		652			6,162
	Commodity contracts		Current derivative financial instrument liability		-1,937			—
	Commodity contracts		Long-term derivative financial instrument liability		-1,796			—
				$	-3,027		$	17,313
	Gains and losses associated with derivative financial instruments related to oil and gas production were as follows for the periods indicated:
		Year Ended December 31,
		2012			2013			2014
		(in thousands)
	Realized gains (losses)(1)	$	73,162		$	-2,271		$	-3,944
	Unrealized gains (losses)		-66,708			1,672			20,340
	Total gain (loss) from derivative financial instruments	$	6,454		$	-599		$	16,396
	___________
	(1)2012 includes $30.2 million received from exiting above market natural gas swap contracts originally scheduled for delivery in 2013.
	The following table summarizes the estimated volumes, fixed prices and fair values attributable to all of the Company’s oil and gas derivative contracts at December 31, 2014.
		Year Ending December 31,
		2015			2016			Total
		($ in thousands, except per unit data)
	Natural Gas Swaps
	Contract volumes (MMBtu)		8,983,560			7,814,028			16,797,588
	Weighted-average fixed price per MMBtu	$	4.01		$	4.01		$	4.01
	Fair value, net	$	8,778		$	4,218		$	12,996
	Crude Oil Swaps
	Contract volumes (Bbl)		71,568			65,568			137,136
	Weighted-average fixed price per Bbl	$	92.73		$	90.33		$	91.58
	Fair value, net	$	2,566		$	1,751		$	4,317
	Total fair value, net	$	11,344		$	5,969		$	17,313
	The following table summarizes the estimated volumes, fixed prices and fair values attributable to all of the Company’s oil and gas derivative contracts at December 31, 2013:
		Year Ending December 31,
		2014			2015			2016		Total
		($ in thousands, except per unit data)
	Natural Gas Swaps
	Contract volumes (MMBtu)		10,327,572			8,983,560			7,814,028		27,125,160
	Weighted-average fixed price per MMBtu	$	4.01		$	4.01		$	4.01	$	4.01
	Fair value, net	$	-1,800		$	-1,076		$	-719	$	-3,595
	Crude Oil Swaps
	Contract volumes (Bbl)		116,076			71,568			65,568		253,212
	Weighted-average fixed price per Bbl	$	95.19		$	92.73		$	90.33	$	93.23
	Fair value, net	$	-53		$	281		$	340	$	568
	Total fair value, net	$	-1,853		$	-795		$	-379	$	-3,027
	The following table discloses and reconciles the gross amounts as presented in the consolidated balance sheets to the net amounts allowed under a master netting arrangement. Amounts not offset on the condensed consolidated balance sheets represent positions that do not meet all the conditions for "a right of offset" or positions for which the Company has elected not to offset.
		December 31,
		2013			2014
		(in thousands)
	Derivative Assets
	Gross amounts of recognized assets	$	706		$	17,313
	Gross amounts offset in the balance sheet		—			—
	Net amounts of assets presented in the balance sheet		706			17,313
	Gross amounts not offset in the balance sheet		-706			—
	Net amount	$	—		$	17,313
	Derivative Liabilities
	Gross amounts of recognized liabilities	$	3,733		$	—
	Gross amounts offset in the balance sheet		—			—
	Net amounts of liabilities presented in the balance sheet		3,733			—
	Gross amounts not offset in the balance sheet		-706			—
Net amount	$	3,027		$	—

Financial_Instruments

Financial Instruments	12 Months Ended
	Dec. 31, 2014
Financial Instruments [Abstract]
Fair Value Measurements	Note 7—Financial Instruments
	The Company’s financial instruments include commodity derivatives, debt, cash, receivables, payables, redeemable preferred stock and equity securities. The carrying amount of cash, receivables and payables approximates fair value because of the short-term nature of those instruments.
	The Company classifies assets and liabilities within the fair value hierarchy based on the lowest level of input that is significant to the fair value measurement of each individual asset and liability taken as a whole. The Company did not own any Level 3 assets or liabilities during 2013 or 2014 and there were no movements between Levels 1 and 2 for the respective time periods.
	Assets and Liabilities Measured at Fair Value on a Recurring Basis—The following table sets forth, by level within the fair value hierarchy, our assets and liabilities that were measured at fair value on a recurring basis at December 31, 2013 and 2014:
								Total Net Fair
		Level 1		Level 2		Level 3		Value
		(in thousands)
	At December 31, 2013
	Investment, gross	$	14,205	$	383	$	—	$	14,588
	Derivative financial instruments—assets		—		706		—		706
	Derivative financial instruments—liabilities		—		-3,733		—		-3,733
	Total	$	14,205	$	-2,644	$	—	$	11,561
	At December 31, 2014
	Investment, gross	$	315	$	—	$	—	$	315
	Derivative financial instruments—assets		—		17,313		—		17,313
	Derivative financial instruments—liabilities		—		—		—		—
	Total	$	315	$	17,313	$	—	$	17,628
	Commodity Derivative Instruments—The Company’s oil and gas derivative instruments may consist of variable to fixed price swaps, collars and basis swaps. When possible, the Company estimates the fair values of these instruments based on published forward commodity price curves as of the date of the estimate. The discount rate used in the discounted cash flow projections is based on published LIBOR rates adjusted for counterparty credit risk. Counterparty credit risk is incorporated into derivative assets while the Company’s own credit risk is incorporated into derivative liabilities. Both are based on current published credit default swap rates.
	Investment—The Company continues to hold an investment in SPP that was purchased in 2011 (see Note 8—Investment). At December 31, 2014, the investment included 224,850 Class B units. Fair value for the Class B units, which are publicly traded, is based on market price and classified as a Level 1 measurement under the fair value hierarchy. At December 31, 2014, the market price of a Class B unit was $1.40. At December 31, 2013, the Company held 484,505 Class A units, which were classified as a Level 2 measurement. Fair value for the Class A units was based on the market price of the publicly traded Class B units and a liquidity discount, as the Class A units were not publicly traded. All Class A units were disposed of in the first quarter of 2014.
	Additional Fair Value Disclosures—The Company has 5,075 outstanding shares of Series A Cumulative Redeemable Preferred Stock (see Note 12—Redeemable Preferred Stock). At December 31, 2014, the obligation to redeem the preferred shares is reflected as debt (“Mandatorily redeemable preferred stock”) in the balance sheet (see Note 12—Redeemable Preferred Stock). The fair value and the carrying value of these securities at December 31, 2013, were $102.8 million and $84.0 million, respectively. The fair value and the carrying value of these securities at December 31, 2014, were $79.8 million and $64.0 million, respectively. The fair value was determined by discounting the cash flows over the remaining life of the securities utilizing a LIBOR interest rate and a risk premium of approximately 12.9% and 10.0% at December 31, 2013 and 2014, respectively, which was based on companies with similar leverage ratios to PostRock. The Company has classified the valuation of these securities under Level 2 of the fair value hierarchy.
	The Company’s long term debt consists entirely of floating-rate facilities. The carrying amount of floating-rate debt approximates fair value because the interest rates paid on such debt are generally set for periods of six months or shorter.

Investment

Investment	12 Months Ended
	Dec. 31, 2014
Investment [Abstract]
Investment	Note 8—Investment
	The Company elected the fair value option to account for its interest in SPP. The fair value option was chosen as the Company determined that the market price of SPP’s publicly traded interests provided a more accurate fair value measure of the Company’s investment in SPP. The Company has not elected the fair value option for any of its other assets and liabilities. While the Company did not have the ability to exercise significant influence over SPP after March 31, 2014 (the settlement date of the SPP lawsuit discussed in more detail below), it continued to use the fair value option to account for the investment as that election is irrevocable. See further discussion below on the sale of SPP units.
	The following table presents the mark-to-market gains (losses) and realized gains on the Company’s investment (recorded as a component of other income in the consolidated statements of operations):
		Year ended December 31,
		2012			2013		2014
		(in thousands)
	Mark to market gains (losses) on equity investment	$	-5,174		$	6,768	$	1,770
	Realized gain	$	—		$	—	$	5,444
	The following table presents the Company’s investment in SPP at gross fair value, and the valuation allowance on SPP investment, which includes certain proceeds received from the settlement agreement as described below (presented net in the consolidated balance sheets):
		Year ended December 31,
		2013			2014
		(in thousands)
	Investment, at gross fair value	$	14,588		$	315
	Valuation allowance on investment		—			-315
	The following table presents summarized condensed financial information of SPP for the years ended December 31, 2012 and 2013. As of March 31, 2014 the investment no longer qualified as an equity method investment as mentioned above therefore December 31, 2014 condensed financial information is not included.
		Year ended December 31,
		2012			2013
		(in thousands)
	Gross revenues	$	59,335		$	46,381
	Gross profit (loss)(1)		-80,964			-25,589
	Net income (loss) from continuing operations		-9,462			-25,857
	Net income (loss)		-86,543			-28,543
	____________
		-1		Equals revenues less operating expenses
	On March 31, 2014, PostRock Energy Corporation and its wholly owned subsidiary, Constellation Energy Partners Management, LLC (“CEPM”), entered into a settlement agreement fully resolving all claims associated with the lawsuit filed August 30, 2013, against SPP, SPP’s Chief Executive Officer, members of SPP’s Board of Managers, Sanchez Oil & Gas Corporation and Sanchez Energy Partners I, LP (“SEPI”).
	Under the settlement agreement, CEPM was to recover a target amount of $21.6 million (the “Target Amount”). In the initial phase of the settlement, CEPM transferred 484,505 Class A units of SPP, representing 100% of the Class A units owned by CEPM, to SEPI, and received the sum of $817,767 from SEPI and an initial payment in the sum of $6,516,103 from SPP. The $6.5 million was recorded as a valuation allowance related to the SPP investment in accordance with the principles of cost recovery. When the value of the Company’s net investment reached zero resulting from periodic sale of the investment, the Company started realizing gains/losses in net income. In addition, CEPM transferred 414,938 SPP Class B units to SEPI in exchange for $1 million from SEPI. In the first quarter after the Company’s mark-to-market adjustment for the B units, a loss of $78,839 was recorded in the investment valuation allowance.
	During 2014, the Company sold 5,054,255 Class B units at a weighted average price of $2.72 per unit. The value of the Company’s investment in SPP reached zero in the fourth quarter; therefore, the Company recorded a realized gain of approximately $5.4 million in 2014.
	As of December 15, 2014, the final settlement date, CEPM had recovered approximately $22.1 million of the Target Amount. At such time, per the settlement agreement, CEPM paid SEPI 50% of the surplus over the Target Amount, approximately $240,000, and transferred half of the remaining units held, or 224,850 Class B units, to SEPI. As of December 31, 2014, CEPM owned 224,850 Class B units, which were disposed of in February 2015 for approximately $290,000.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligations [Abstract]
Asset Retirement Obligations	Note 9—Asset Retirement Obligations
	The following table reflects the changes to asset retirement obligations for the periods indicated:
		Year Ended December 31,
		2013		2014
		(in thousands)
	Asset retirement obligations at beginning of period	$	10,868	$	13,228
	Liabilities incurred		533		146
	Liabilities settled		-88		-282
	Acquisitions		538		—
	Accretion		811		926
	Revision of estimates		566		—
	Asset retirement obligations at end of period	$	13,228	$	14,018
	Current portion of asset retirement obligations	$	129	$	134
	Noncurrent portion of asset retirement obligations at end of period	$	13,099	$	13,884
	During 2013, revisions to the Company's asset retirement obligations totaled $566,000. The increase was due to higher estimated cost to plug an oil/gas well, salt water disposal (“SWD”) well, as well as a tank battery remediation costs. During 2014, there were no changes to the Company’s revisions as costs have remained consistent from the prior year.

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2014
Long-Term Debt [Abstract]
Long-Term Debt	Note 10—Long-Term Debt
	The following is a summary of long-term debt at the dates indicated:
		December 31,
		2013		2014
		(in thousands)
	Borrowing Base Facility	$	92,000	$	83,000
	Less current maturities		—		—
	Total long-term debt	$	92,000	$	83,000
	Borrowing Base Facility
	The Company’s sole credit facility is the Third Amended and Restated Credit Agreement, dated as of December 20, 2012 (the “Borrowing Base Facility”), among PostRock Energy Services Corporation (“PESC”) and PostRock MidContinent Production, LLC (“MidContinent”), as borrowers, Citibank, N.A., as administrative and collateral agent, and the lenders and other loan parties party thereto. The Borrowing Base Facility is a $200 million senior secured revolving facility guaranteed by the Company and its subsidiaries other than Constellation Energy Partners Management, LLC (the “Excluded Subsidiary”). At December 31, 2014, the borrowing base under the Borrowing Base Facility remained at $115.0 million which was the same borrowing base at December 31, 2013. With outstanding borrowings of $83.0 million and letters of credit of $1.4 million, $30.6 million was available for additional borrowings at December 31, 2014.
	Material terms of the Borrowing Base Facility include the following:
	Covenants. The Borrowing Base Facility contains affirmative and negative covenants that are customary for transactions of this type, including financial covenants that prohibit the Company and any of its subsidiaries (other than the Excluded Subsidiary) from:
	•permitting the ratio of consolidated current assets of the Company and its subsidiaries (excluding the Excluded Subsidiary) to consolidated current liabilities, after certain adjustment, at any fiscal quarter-end to be less than or equal to 1.0 to 1.0;
	•permitting the Company’s interest coverage ratio (ratio of consolidated EBITDAX (as defined in the Borrowing Base Facility) to consolidated interest charges) at any fiscal quarter-end to be less than or equal to 3.0 to 1.0 measured on a trailing four quarter basis; and
	•permitting the Company’s leverage ratio (ratio of consolidated funded debt to consolidated EBITDAX for the four fiscal quarters ending on the applicable fiscal quarter-end) to be greater than to 3.5 to 1.0.
	Interest Rate. LIBOR plus 2.50% to 3.25% or, at the borrowers’ option, Base Rate (as defined) plus 1.5% to 2.25%, in each case depending on utilization. The interest rate on outstanding borrowings on December 31, 2014 was 3.04%.
	Maturity Date. December 20, 2016.
	Borrowing Base Redetermination. Borrowing base redeterminations by the lenders will be effective every May 1st and November 1st until maturity taking into account the value of MidContinent’s proved reserves. In addition, during each period between scheduled redeterminations of the borrowing base, the borrowers and the administrative agent, respectively, have the right to initiate a redetermination of the borrowing base between each scheduled redetermination, provided that no more than two such redeterminations may occur in a 12-month period. In addition, upon a material disposition of assets and a material acquisition of oil and gas properties, and in certain other limited circumstances, the borrowing base will or may be redetermined. If the borrowing base is reduced in connection with a redetermination, the borrowers can elect to either repay the entire deficiency within 30 days, repay the deficiency in six equal monthly installments, or contribute additional properties to increase the value of the collateral to support the prior borrowing base.
	Payments. The aggregate principal amount of all outstanding revolving loans is required to be repaid on the maturity date. The borrowers are required to make a mandatory prepayment upon the occurrence of any of the following events: (a) a material disposition of oil and gas properties; (b) a change of control; (c) the existence of a borrowing base deficiency; (d) a sale of assets whose proceeds exceed 5% of the borrowing base then in effect; (e) the issuance or incurrence of indebtedness by any loan party not otherwise permitted under the Borrowing Base Facility; and (f) certain equity issuances. Interest payments are due (i) at the end of each LIBOR interest period, but in no event less frequently than quarterly in the case of LIBOR loans or (ii) quarterly in the case of Base Rate loans.
	Security Interest. The Borrowing Base Facility is secured by a first lien on substantially all of the assets of the Company and its subsidiaries other than the Excluded Subsidiary and its assets.
	Events of Default. Events of default are customary for transactions of this type and include, without limitation, non-payment of principal when due, non-payment of interest, fees and other amounts within three business days after the due date, failure to perform or observe covenants and agreements (subject to a 30-day cure period in certain cases), representations and warranties not being correct in any material respect when made, certain acts of bankruptcy or insolvency, cross defaults to other material indebtedness, non-appealable judgment in a material amount is entered against a borrower or its affiliate, ERISA violations, invalidity of loan documents, dissolution, collateral impairment, existence of any borrowing base deficiency beyond any permitted grace periods, and change of control.
	The Company was in compliance with all of its financial covenants under the Borrowing Base Facility at December 31, 2014.
	QER Loan
	The QER Loan was a former credit facility collateralized by a first priority lien on all the assets of PostRock Eastern Production, LLC, formerly named Quest Eastern Resource LLC (“QER”). In connection with the restructuring of the Company’s credit facilities in 2010, the Company entered into an asset sale agreement with Royal Bank of Canada (“RBC”) that allowed the Company to sell QER, or its assets and, in the event the proceeds were not adequate to repay the QER Loan in full, the Company agreed to pay a portion of such shortfall in cash, stock or a combination thereof.
	As discussed in Note 3, the Company sold certain Appalachian Basin oil and gas properties to MHR in three phases that closed in December 2010, January 2011 and June 2011. Included in the $44.6 million total was approximately $41.6 million representing the purchase price of assets owned by QER pledged as collateral under the QER Loan. From the sale proceeds, QER made payments to the lender, RBC, in the amount of $21.2 million in December 2010, $9.3 million in January 2011 and $4.3 million in June 2011. Concurrent with the June 2011 payment and pursuant to the terms of the asset sale agreement with RBC, the Company fully settled the outstanding balance of the QER Loan of approximately $843,000 by issuing 141,186 shares of its common stock with a fair value of $744,000 to RBC. The settlement also included the future remittance of a portion of the sale proceeds scheduled to be released from the escrow in June 2012. In June 2012, $5.7 million of the escrowed proceeds was released to the Company, of which $1.3 million was retained by the Company while $4.4 million was paid to RBC, representing the final payment in connection with the QER Loan. Included in the amount released to the Company was a recovery by the Company of the $843,000 payment to RBC made in June 2011.
	The settlement of the QER Loan was facilitated by the restructuring of a prior loan that met the criteria under accounting guidance to be classified as a troubled debt restructuring. The Company had previously recorded gains on debt restructuring related to the QER Loan of $2.9 million in 2010 and $1.6 million in 2011. The gain in 2011 included $799,000 of accrued interest that was forgiven at the time the balance of the loan was settled. As a result of the Company’s final evaluation of all payments made to RBC in connection with the QER Loan, an additional gain on debt restructuring of $255,000 was recorded in 2012. These gains are reflected as a “gain on forgiveness of debt” in the consolidated statement of operations.
	Deferred Financing Costs
	In connection with the closing of the Borrowing Base Facility on December 20, 2012, the Company incurred $1.7 million in financing costs that were capitalized and will be amortized over the four-year life of the facility. In conjunction with the closing of the Borrowing Base Facility, the Company’s prior credit facility was settled and $1.2 million in remaining unamortized deferred financing costs associated with the prior facility were written off.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Taxes [Abstract]
Income Taxes	Note 11—Income Taxes
	The Company did not record any provision or benefit for income taxes for the year ended December 31, 2012. During 2013, the Company recorded a tax expense of $180,000. The IRS recently completed an examination of the Company’s 2012 income tax return, resulting in no changes to the 2012 federal taxable income. For 2014, the Company has recorded $12,022 of tax expense related to the previous tax year.
	A reconciliation of federal income taxes at the statutory federal rates to our actual provision for income taxes is as follows:
		Year Ended December 31,
		2012		2013
		(Restated)		(Restated)		2014
		(in thousands)
	Income tax expense (benefit) at statutory rate	$	-20,612	$	-8,115	$	1,353
	State income tax expense, net of federal		958		19		573
	2011 IRS Settlement		—		30		—
	Interest expense - preferred stock dividend		3,962		5,189		5,637
	Other		1,650		322		-4
	IRC Section 382 limitation		30,491		2,575		2,085
	Change in valuation allowance		-16,449		160		-9,632
	Total tax expense	$	—	$	180	$	12
	Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax reporting. Deferred tax assets are reduced by a valuation allowance if it is deemed more likely than not that some or all of the deferred assets will not be realized based on the weight of all available evidence. Based on the negative evidence that existed at each reporting period, the Company recorded a full valuation allowance against its net deferred tax asset at December 31, 2012, 2013, and 2014.
	Deferred tax assets and liabilities at December 31, 2013 and 2014 were as follows:
		Year Ended December 31,
		2013		2014
		(in thousands)
	Current deferred income tax assets
	Unrealized loss for commodity derivative recorded for book, not for tax	$	722	$	—
	Accrued liabilities		1,038		477
	Allowance for bad debts		72		72
	Other		277		510
	Total current deferred income tax assets		2,109		1,059
	Noncurrent deferred income tax assets
	Unrealized loss for commodity derivative recorded for book, not for tax		669		—
	Partnership basis differences		6,287		478
	Property and equipment		37,849		33,161
	Asset retirement obligations		2,173		2,504
	Net operating loss carryforwards		14,943		23,379
	Other carryforwards		2,264		2,273
	Total noncurrent deferred income tax assets		64,185		61,795
	Total deferred income tax assets		66,294		62,854
	Current deferred income tax liabilities
	Unrealized gain for commodity derivative recorded for book, not for tax		-20		-4,157
	Total current deferred income tax liabilities		-20		-4,157
	Noncurrent deferred income tax liabilities
	Unrealized gain for commodity derivative recorded for book, not for tax		-420		-2,474
	Total noncurrent deferred income tax liabilities		-420		-2,474
	Total deferred income tax liabilities		-440		-6,631
	Net deferred income tax assets		65,854		56,223
	Valuation allowance		-65,854		-56,223
	Total deferred tax asset (liability)	$	—	$	—
	The Company has net operating loss (“NOL”) carryforwards that are available to reduce future U.S. taxable income. If not utilized, such carryforwards will expire from 2019 through 2034.
	The Company’s ability to utilize NOL carryforwards to reduce future federal taxable income and federal income tax of the Company is subject to various limitations under Internal Revenue Code (“IRC”) Section 382. The utilization of such carryforwards may be limited upon the occurrence of certain ownership changes, including the issuance or exercise of rights to acquire stock, the purchase or sale of stock by 5% stockholders, as defined in the Treasury regulations, and the offering of stock of PostRock during any three-year period resulting in an aggregate change of more than 50% in the beneficial ownership of PostRock. The Company experienced ownership changes within the meaning of IRC Section 382 on November 14, 2005, March 5, 2010, and September 21, 2010. The Company has NOL carryforwards of approximately $261 million at December 31, 2014 that are available to reduce future U.S. taxable income in certain circumstances. At December 31, 2014, $228 million of federal NOL carryforwards are subject to the IRC Section 382 limitation and it is anticipated that $211 million of these federal NOL carryforwards will expire unused due to the IRC Section 382 limitation. As a result, only $50 million of federal NOL carryforwards have been recorded as a deferred tax asset. The limitation does not result in a current federal tax liability for the period ended December 31, 2014.
	In addition to the restrictions imposed on the Company’s NOL carryforwards under IRC Section 382, the Company also had a net unrealized built-in loss in its assets at the date of the ownership changes. IRC Section 382 generally restricts the Company’s ability to utilize any recognized built-in losses (“RBILs”) which are recognized during the 5-year period following an ownership change. The Company has recognized tax depreciation and depletion and tax losses on the disposition of its built-in loss assets during 2010, 2011, 2012, 2013 and 2014 of approximately $103.6 million. Of this amount, only $4.6 million was allowed to be deducted in the year incurred. The remaining RBILs of $99.0 million are allowed to be carried forward in a manner similar to NOLs, subject to limitation under IRC Section 382. It is anticipated that approximately $94.7 million of these RBIL carryforwards will expire unused due to the IRC Section 382 limitation. As a result, only $4.3 million of RBILs have been recorded as a deferred tax asset.
	FASB ASC 740-10 provides guidance for recognizing and measuring uncertain tax positions. Based upon the provision of FASB ASC 740-10, the Company did not record any amounts for uncertain tax benefits upon adoption of the standard and has no amounts recorded for uncertain tax benefits at December 31, 2014. Accordingly, there has been no change in unrecognized tax benefits during the year. The Company files income tax returns in the U.S. federal jurisdiction and various state and local jurisdictions. Tax year ended December 31, 2013 remains open for examination by the relevant taxing authorities. In addition, the Company’s tax returns for the tax years ended May 31, 2000, through December 31, 2010, can be examined and adjustments made to the amount of net operating losses flowing from those years into an open tax year. However, no assessment of income tax may generally be made for those years on which the statute has closed. The Company’s policy is to recognize interest and penalties, if any, related to unrecognized tax benefits as income tax expense.

Redeemable_Preferred_Stock_and

Redeemable Preferred Stock and Warrants	12 Months Ended
	Dec. 31, 2014
Redeemable Preferred Stock and Warrants [Abstract]
Redeemable Preferred Stock and Warrants	Note 12—Redeemable Preferred Stock and Warrants
	On September 21, 2010, the Company issued to White Deer Energy L.P. and its affiliates (“White Deer”) 6,000 shares of the Company’s Series A Cumulative Redeemable Preferred Stock (the “Series A Preferred Stock”), 19,047.62 shares of its Series B Voting Preferred Stock (the “Series B Preferred Stock”) and warrants to purchase 1,904,762 shares of the Company’s common stock. The preferred stock and warrants were issued in exchange for $60 million. During 2012, the Company issued additional shares of Series A Preferred Stock and warrants to White Deer in two separate transactions. The first transaction, which closed in August 2012, included 600 shares of Series A Preferred Stock with $6.0 million initial liquidation preference along with warrants to purchase 307,693 shares of common stock at an exercise price of $19.50 a share. These securities were issued for proceeds of $6.0 million. The second transaction, which closed in December 2012, included 650 shares of Series A Preferred Stock with $6.5 million initial liquidation preference along with warrants to purchase 457,746 shares of common stock at an exercise price of $14.20 a share. These securities were issued for proceeds of $6.5 million. The terms of the Series A Preferred Stock and warrants issued in 2012 are substantially the same as those in White Deer’s original September 2010 investment except as discussed below.
	The investments discussed above were recognized on the Company’s consolidated balance sheets based on the relative fair values of the Series A Preferred Stock and the warrants allocated to the proceeds. The allocation resulted in an increase to the Company’s long-term liability related to the Series A Preferred Stock and an increase to additional paid in capital related to the warrants issued.
	The Series A Preferred Stock is entitled to a cumulative dividend of 12% per year on its liquidation preference, compounded quarterly. The liquidation preference will increase by the amount of dividends paid in kind. Changes in the liquidation value are disclosed in the table below. The Company is not required to pay cash dividends until June 30, 2016. Any dividends prior to that time not paid in cash will accrue as additional liquidation preference. Subsequent to June 30, 2016, dividends are required to be paid in cash, subject to the legal availability of funds for the declaration and payment thereof, and any payment default after that date will increase the accrual of the additional liquidation preference during the default period to 14%. The Company is required to redeem the Series A Preferred Stock on March 21, 2018, at 100% of the liquidation preference. From and after one year from the issuance date until such mandatory redemption date, the Company will have the option to redeem all or a specified minimum portion of the Series A Preferred Stock at 110% of the liquidation preference. The holders of the Series A Preferred Stock have the right to require the Company to purchase their shares on the occurrence of specified change in control events at 110% of the liquidation preference. In the case of specified defaults by the Company, including the failure to pay dividends for any quarterly period after June 30, 2016 and until the defaults are cured, the holders of the Series A Preferred Stock have the right to appoint two additional directors to the Board of Directors. The Series A Preferred Stock does not vote generally with the common stock, but has specified approval rights with respect to, among other things, changes to the Company’s certificate of incorporation that affect the Series A Preferred Stock, cash dividends on the common stock or other junior stock, redemptions or repurchases of common stock or other capital stock, increases in the size of the Board of Directors, changes to specified debt agreements and changes to the Company’s business.
	With respect to the Series A Preferred Stock issued on September 21, 2010, prior to June 30, 2016, if dividends are not paid in cash on a dividend payment date, the Company will issue additional warrants exercisable for a number of shares of common stock equal to the amount of dividends that are not paid on that dividend payment date divided by the closing price of the common stock on the trading date immediately preceding the dividend payment date. The exercise price of the warrants will be such closing price. The warrants, including any additional warrants, are exercisable for 90 months following the applicable issuance date. Each warrant is coupled, and may only be transferred as a unit, with a number of one one-hundredths of a share, or a “fractional share,” of Series B Preferred Stock equal to the number of shares of common stock purchasable upon exercise of the warrant. The warrants and the Series B Preferred Stock may not be transferred separately. If and when the warrant is exercised, the holder of the warrant will be required to deliver to the Company, as part of the payment of the exercise price, a number of fractional shares of Series B Preferred Stock equal to the number of shares of common stock purchased upon such exercise. The holders of the warrants have the right to pay the exercise price in cash, by electing a cashless exercise (whereby the holder will receive the excess of the market price of the common stock over the exercise price in shares of common stock valued at the market price) or by tendering shares of Series A Preferred Stock with a liquidation preference equal to the exercise price. If the market price of the common stock exceeds 300% of the exercise price for a specified period of time and other conditions are satisfied, the Company may require the holders of the warrants to exercise warrants to purchase up to 50% of shares covered thereby, but in the aggregate not less than 75,000 shares or more than 50% of the trading volume of the common stock over the preceding 20 trading days.
	With respect to the warrants issued in conjunction with the Series A Preferred Stock in August 2012 and December 2012, including those that may be issued on future pay-in-kind dividends on this preferred stock, the terms are otherwise similar to those issued in September 2010 except they are not coupled with a fractional share of Series B Preferred Stock (and therefore have no voting right attached) and all of those warrants will have an exercise price of $19.50 a share and $14.20 a share, respectively, rather than the market price at the time of issuance.
	The holders of Series B Preferred Stock are entitled to vote in the election of directors and on all other matters submitted to a vote of the holders of common stock of the Company, with the holders of Series B Preferred Stock and the holders of common stock voting together as a single class. Each fractional share of Series B Preferred Stock has one vote. The voting rights of each share of Series B Preferred Stock may not be exercised by any person other than the holder of the warrant that is part of the unit with such share or fractional share and will expire on the expiration date of such warrant. The Series B Preferred Stock has no dividend rights and a nominal liquidation preference. With respect to the votes applicable to the Series B Preferred Stock, the holders of the Series B Preferred Stock and their affiliates are limited to 45% of the votes applicable to all outstanding voting stock; such holders and their affiliates may vote any shares of common stock held by them without regard to that limit.
	When the Company accrues dividends on its Series A Preferred Stock on a quarterly dividend payment date, it records the increase in liquidation preference and the issuance of additional warrants by allocating their relative fair values to the amount of accrued dividends. The allocation results in an increase to the Company’s long-term liability related to the Series A Preferred Stock and an increase to additional paid in capital related to the additional warrants issued.
	The Series A Preferred Stock has been recorded as a non-current liability, in the Company’s consolidated balance sheet as it meets the definition of mandatorily redeemable preferred stock under FASB ASC 480 Distinguishing Liabilities from Equity. Dividends and accretion related to the Series A Preferred Stock are recorded as non-cash interest expense for which $14.8 million and $16.1 million was recognized for the years ended December 31, 2013 and 2014, respectively.
	In December 2013, the Company closed on a Warrant Exchange Agreement with White Deer pursuant to which the Company issued to White Deer  112,398 shares of its common stock with a fair value of $1.5 million in exchange for the following securities of the Company held by White Deer: warrants exercisable for 2,224,135 shares of common stock (the “Warrants”) together with a like number of one one-hundredths of a share of Series B Voting Preferred Stock that were issued as a unit with the Warrants (collectively, the “Warrant Exchange”). The Warrants had exercise prices ranging from $28.00 to $63.90 per share, with a weighted average exercise price of $32.30 per share. The number of shares issued was calculated based on the Black-Scholes model.
	In October 2014, the Company closed on a Preferred Stock Exchange Agreement with White Deer pursuant to which PostRock issued 3,211,378 shares of its common stock to White Deer in exchange for 2,175 shares of Series A Preferred Stock issued to White Deer on September 21, 2010 (collectively, the “Preferred Exchange”). The Series A Preferred Stock had an aggregate liquidation preference of $35.0 million and a carrying value of $32.1 million. No gain or loss was recognized as a result of the transaction.
	The following table summarizes changes in the Series A Preferred Stock and associated warrants.
		Carrying Value		Number of
		of Series A		Outstanding		Liquidation Value			Number of	Weighted Average
		Preferred Stock		Series A		of Series A			Outstanding	Exercise Price of
		(Restated)		Preferred Shares		Preferred Stock			Warrants	Warrants
		(in thousands except share, warrant and per unit data)
	31-Dec-11	$	56,736	6,000		$	69,759		2,156,626	$	32.35
	Issuance		8,428	1,250			12,500		765,439		16.33
	Accrued dividends recorded as interest		5,750	—			9,083		511,581		17.75
	Accretion recorded as interest		2,238	—			—		—		—
	31-Dec-12		73,152	7,250			91,342		3,433,646		26.60
	Accrued dividends recorded as interest		7,479	—			11,464		806,633		14.21
	Warrant Exchange		—	—			—		-2,224,135		32.31
	Accretion recorded as interest		3,363	—			—		—		—
	31-Dec-13		83,994	7,250			102,806		2,016,144		15.35
	Accrued dividends recorded as interest		7,868	—			11,958		1,285,105		9.31
	Preferred Exchange		-32,056	-2,175			-35,004		—		—
	Accretion recorded as interest		4,148	—			—		—		—
	31-Dec-14	$	63,954	5,075		$	79,760		3,301,249	$	13.00
	The following table summarizes changes to additional paid in capital (“APIC”) as a result of warrants issued to White Deer:
		Year Ended December 31,
		2012		2013			2014
		(in thousands)
	Warrants issued in conjunction with issuance of Series A Preferred Stock	$	4,071	$	—		$	—
	Warrants issued in conjunction with paid-in-kind dividends		3,334		3,984			4,089
	Total change in APIC due to warrants issued	$	7,405	$	3,984		$	4,089

Equity_and_Earnings_Per_Share

Equity and Earnings Per Share	12 Months Ended
	Dec. 31, 2014
Equity And Earnings Per Share [Abstract]
Equity and Earnings Per Share	Note 13—Equity and Earnings per Share
	Restricted share and stock option grants to employees and non-employee directors is governed by PostRock’s 2010 Long-Term Incentive Plan (the “LTIP”) of which 1,085,000 shares have been authorized for awards.
	The Company’s employee share based grants, including restricted shares and options, have generally vested 33% a year for three years or have vested in one year when awarded in conjunction with the Company’s annual bonus program. Share based grants to non-employee directors have generally vested immediately or in one year.
	A summary of changes in the non-vested restricted shares or share units for PostRock and its Predecessors for the periods presented is below.
		Number of Non-Vested		Weighted Average Grant
		Restricted Shares		Date Fair Value
	Non-vested restricted shares at December 31, 2011	57,921		$	33.30
	Granted	129,512			20.10
	Vested	-27,590			32.34
	Forfeited	-11,886			37.58
	Non-vested restricted shares at December 31, 2012	147,957			21.58
	Granted	64,191			17.49
	Vested	-45,253			27.95
	Cancelled/Forfeited (1)	-105,368			17.92
	Non-vested restricted shares at December 31, 2013	61,527			18.86
	Granted	39,760			13.33
	Vested	-41,373			18.30
	Forfeited	-10,533			17.55
	Non-vested restricted shares at December 31, 2014	49,381		$	15.16
	____________
	(1) 78,742 shares were cancelled with an associated accelerated stock compensation expense of approximately $500,000.
	At December 31, 2014, total unrecognized stock-based compensation expense related to non-vested restricted shares was $328,000, which is expected to be recognized over a weighted average period of approximately 1.28 years while 669,119 shares (adjusted for the reverse split) were available under the LTIP for future stock awards and options.
	Stock Options—The LTIP also provides for the granting of options to purchase shares of PostRock’s common stock. The Company has in the past granted stock options to employees and non-employees. Option grants under the LTIP expire 5-6 years following the date of grant.
	A summary of changes in stock options outstanding for PostRock and its Predecessors is presented below.
				Weighted Average			Weighted Average
				Exercise Price per			Grant Date Fair
		Stock Options		Option			Value per Option
	Options outstanding at December 31, 2011	105,685		$	35.89
	Granted	130,366			18.01		$	10.68
	Forfeited or expired	-19,022			42.95
	Options outstanding at December 31, 2012	217,029			24.53
	Granted	58,495			17.73			8.89
	Forfeited or expired	-44,882			19.30
	Options outstanding at December 31, 2013	230,642			23.81
	Granted	92,451			13.08			7.14
	Forfeited or expired	-56,298			19.91
	Options outstanding at December 31, 2014	266,795			20.92
	Exercisable
	Options exercisable at December 31, 2012	46,719		$	41.03
	Options exercisable at December 31, 2013	98,904			30.34
	Options exercisable at December 31, 2014	129,589			27.32
	The weighted average remaining term of options outstanding and options exercisable at December 31, 2014, was 3.09 and 2.30 years, respectively. Both options outstanding and options exercisable at December 31, 2014, had aggregate intrinsic values of nil.
	The Company determines the fair value of stock option awards using the Black-Scholes option pricing model. As the Company does not have sufficient historical exercise or post-vesting termination experience, the Company currently uses an expected option term of four years, which is the average of the vesting term and the original contractual term. The expected forfeiture rate was estimated based upon historical forfeiture experience. The volatility assumption was estimated based upon expectations of volatility over the life of the option as measured by historical and implied volatility of peer companies. The risk-free interest rate was based on the U.S. Treasury rate for a term commensurate with the expected life of the option. The dividend yield was based upon a 12-month average dividend yield.
	The Company used the following assumptions to estimate the fair value of stock options granted during the years ending December 31, 2012, 2013 and 2014.
		2012				2013			2014
	Expected option life-years		5				4			4
	Volatility		74.3 - 76.1	%			64.0 - 82.7	%		66.0 - 74.6	%
	Risk-free interest rate		0.9 - 1.3	%			0.6 - 1.4	%		1.2 - 1.4	%
	Dividend yield		—				—			—
	Fair value per share	$	8.70 - 18.80			$	8.20 - 10.30		$	5.60 - 8.50
	At December 31, 2014, there was $492,000 of total unrecognized compensation cost related to stock options which is expected to be recognized over a weighted average period of 1.29 years.
	Total share-based compensation covering stock awards and options is included in general and administrative expense on the consolidated statement of operations and is disclosed below for the periods presented:
		Total Share
		Based
		Compensation
		Expense
		(in thousands)
	Year Ended December 31, 2012	$	2,224
	Year Ended December 31, 2013		3,177
	Year Ended December 31, 2014		922
	Income/(Loss) per Share — A reconciliation of the denominator (number of shares) used in the basic and diluted per share calculations for the periods indicated is as follows:
		Year Ended December 31,
		2012		2013		2014
	Denominator for basic earnings per share (1)	1,359,584		2,506,857		3,915,578
Effect of potentially dilutive securities
Warrants	—		—		32,327
Stock options	—		—		12
Denominator for diluted earnings per share	1,359,584		2,506,857		3,947,917
Securities excluded from earnings per share calculation
Unvested share-based awards	14,999		—		—
Antidilutive stock options	217,028		230,642		251,917
Antidilutive warrants	3,308,662		1,792,951		2,275,368
____________
(1)Includes vested common shares in the Company’s deferred compensation plan and vested deferred restricted stock units, both of which will deliver shares to participants at a later date. Although shares have not been delivered on these awards, all conditions for issuance and delivery have been met. Pursuant to FASB ASC 260-10-45-13, such shares are to be included in the denominator in calculating basic earnings per share.
Common Stock Issuance—During 2013 and 2014, the Company issued common stock to generate capital, fund its 401K and deferred compensation plans (Note 18), fund property acquisitions (Note 3) and to retire outstanding warrants and Series A Preferred Stock (Note 12). Equity issuances intended to raise capital are discussed below. Proceeds from these transactions were used for debt repayment and for other general corporate purposes.
The Company has an effective $100 million universal shelf registration statement under which it can sell common shares pursuant to an at-the-market issuance sales agreement.
	Year Ended December 31,
	2013			2014
Gross proceeds (in thousands)	$	4,076		$	—
Common shares sold		259,232			—

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies [Abstract]
Commitments and Contingencies	Note 14—Commitments and Contingencies
	Litigation—The Company is subject, from time to time, to certain legal proceedings and claims in the ordinary course of conducting its business. It records a liability related to its legal proceedings and claims when it has been determined that it is probable that it will be obligated to pay and the related amount can be reasonably estimated. The Company currently believes that there are no pending legal proceedings in which it is currently involved which have a reasonable possibility of materially affecting its financial position, results of operations or cash flows in an adverse manner.
	The Company had been sued in royalty owner lawsuits filed in Kansas. The lawsuit was a putative class action filed in the United States District Court for the District of Kansas, brought on behalf of all the Company’s royalty owners in that state. Plaintiffs generally alleged that the Company failed to properly make royalty payments by, among other things, charging post-production costs to royalty owners in violation of the underlying lease contracts, paying royalties based on sale point volumes rather than wellhead volumes, allocating expenses in excess of the actual and reasonable post-production costs incurred, allocating production costs and marketing costs to royalty owners, and making royalty payments after the statutorily prescribed time for doing so without paying interest thereon. We denied plaintiffs’ claims. The parties reached a settlement and on December 30, 2011, the Court entered an order certifying a class for settlement purposes consisting of all current and former PostRock royalty and overriding royalty owners, approving the parties’ settlement and dismissing the action. The settlement included a payment of $3.0 million that was made in January 2012, and a payment of $4.5 million which was made in December 2012, for a total of $7.5 million.
	In connection with their criminal convictions, in November 2010, Jerry Cash and David Grose, former CEO and CFO of predecessor, respectively, were ordered to pay the Company restitution in the sums of $5 million and $1 million, respectively. During 2014 the Company received approximately $23,000 from Jerry Cash in restitution. Additionally, in early March 2015 the Company received approximately $300,000 from David Grose in restitution. The Company intends to continue to pursue recovery of the restitution obligations.
	Additionally, see Note 8 – Investment for discussion on settlement of the SPP lawsuit.
	Environmental Matters—At December 31, 2013 and 2014, there were no known environmental or regulatory matters related to our operations which are reasonably expected to result in a material liability to us. Like other oil and gas producers and marketers, our operations are subject to extensive and rapidly changing federal and state environmental regulations governing air emissions, wastewater discharges, and solid and hazardous waste management activities. Therefore, it is difficult to reasonably quantify future environmental related expenditures.
	Operating Lease Commitments—The Company has lease agreements to obtain natural gas compressors as and when required. Terms of the leases on the gas compressors call for a minimum obligation of one year and are month to month thereafter. In addition, the Company also has operating leases for office space, warehouse facilities, and office equipment expiring in various years through 2018.
	Future minimum rental payments under all non-cancelable operating leases at December 31, 2014, were as follows:
	Year ending December 31,	(in thousands)
	2015	$	4,570
	2016		2,945
	2017		1,760
	2018		414
	2019		—
	Thereafter		—
	Total minimum lease obligations	$	9,689
	Total rental expense under cancelable and non-cancelable operating leases was $12.4 million, $10.8 million and $9.1 million for the years ended December 31, 2012, 2013 and 2014, respectively.

Impairment_of_Oil_and_Gas_Prop

Impairment of Oil and Gas Properties	12 Months Ended
	Dec. 31, 2014
Impairment of Oil and Gas Properties [Abstract]
Impairment of Oil and Gas Properties	Note 15—Impairment of Oil and Gas Properties
	At the end of each quarterly period, the unamortized cost of oil and natural gas properties, net of related deferred income taxes, is limited to the full cost ceiling, computed as the sum of the estimated future net revenues from proved reserves using twelve-month average prices discounted at 10%, and adjusted for related income tax effects (“ceiling test”). Under full cost accounting rules, any ceiling test write-down of oil and natural gas properties may not be reversed in subsequent periods. Since the Company does not designate its derivative financial instruments as hedges, it is not allowed to use the impacts of the derivative financial instruments in its ceiling test computation. As a result, decreases in commodity prices which contribute to ceiling test write-downs may be offset by mark-to-market gains which are not reflected in the Company’s ceiling test results.
	The base for the Company’s spot prices for natural gas is Henry Hub and for oil is Cushing, Oklahoma. At the end of the third and fourth quarters of 2012, the ceiling test computation resulted in the carrying costs of the Company’s unamortized proved oil and natural gas properties, net of deferred taxes, exceeding the present value of future net revenues. As a result of this difference, the Company recorded ceiling test impairments of its oil and gas properties of $5.9 million for the year ended December 31, 2012. There were no ceiling test impairments for the years ended December 31, 2013 and 2014. The Company may face further ceiling test write-downs in future periods, depending on the level of commodity prices, drilling results and well performance.
	The calculation of the ceiling test is based upon estimates of proved reserves. There are numerous uncertainties inherent in estimating quantities of proved reserves, in projecting the future rates of production and in the timing of development activities. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing, production and changes in economics related to the properties subsequent to the date of the estimate may justify revision of such estimate. Accordingly, reserve estimates are often different from the quantities of oil and natural gas that are ultimately recovered.

Discontinued_Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2014
Discontinued Operations [Abstract]
Discontinued Operations	Note 16—Discontinued Operations
	The Company previously owned an interstate natural gas pipeline in its PostRock KPC Pipeline, LLC (“KPC”) subsidiary. On September 28, 2012, the Company, PostRock Energy Services Corporation, a wholly owned subsidiary of the Company (“Seller”), and KPC entered into and simultaneously closed a Purchase Agreement (the “Purchase Agreement”) with MV pursuant to which the Seller sold all the equity of KPC to MV for a gross purchase price of $53.5 million. After an adjustment for working capital as set forth in the Purchase Agreement, the Company received $53.4 million in proceeds at closing. MV also agreed to make additional payments of $1.0 million for each of the next four years if qualified EBITDA (as defined in the Purchase Agreement) of KPC for that year exceeds a target amount. Determination of qualified EBITDA for the first year was due from MV no later than May 30, 2014. Qualified EBITDA did not meet the target amount in 2014; therefore, no payment was received by the Company. KPC owns a 1,120 mile interstate natural gas pipeline that transports natural gas from northern Oklahoma and western Kansas to Wichita and Kansas City, which formerly comprised the Company’s pipeline segment.
	The carrying value of KPC’s net assets sold was $57.0 million which resulted in a loss on sale of $5.4 million. The loss on sale included $1.9 million in closing-related costs comprised of $1.0 million in legal, professional, and investment banking fees, $505,000 of severance and $350,000 in site cleanup costs. The operating results of KPC are classified as discontinued operations and are presented in a separate line in the consolidated statement of operations for all periods presented. Prior to the classification as a discontinued operation, the Company had reported this business as a separate segment under the heading “Pipeline.”
	The following table discloses the results of discontinued operations related to KPC:
		Year Ended
		December 31,
		2012
		(in thousands)
	Interstate pipeline revenue	$	8,934
	Pipeline expense		-2,825
	Depreciation and amortization		-2,537
	Gain (loss) on disposal of assets (1)		-5,437
	General and administrative expenses		-945
	Interest expense		-45
	Income from discontinued operations before income taxes		-2,855
	Income taxes		—
	Total income (loss) from discontinued operations	$	-2,855
	____________
	(1)Includes a loss of $5.4 million from the disposal of KPC.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Note 17—Supplemental Cash Flow Information
	The following discloses certain cash and noncash transactions for the periods indicated:
		Year Ended December 31,
		2012		2013		2014
		(in thousands)
	Cash paid for interest	$	7,292	$	2,780	$	3,033
	Cash paid for income taxes		—		100		12
	Non-cash investing activity
	Common stock issued for purchase of oil and gas properties		—		6,728		893
	Property additions financed through accounts payable and accrued liabilities		239		1,010		3,597
	Additions to property and equipment by recognizing asset retirement obligations		159		1,099		146
	Non-cash financing activity
	Common stock issued to fund 401K and deferred compensation plans		—		931		2,596
	Common stock issued to repurchase and retire outstanding warrants		—		1,528		—
	Common stock issued to repurchase and retire Series A preferred stock		—		—		32,435

Profit_Sharing_And_Deferred_Co

Profit Sharing And Deferred Compensation Plans	12 Months Ended
	Dec. 31, 2014
Profit Sharing And Deferred Compensation Plans [Abstract]
Profit Sharing And Deferred Compensation Plans	Note 18—Profit Sharing and Deferred Compensation Plan
	401K plan — Substantially all of the Company’s employees are eligible to participate in a profit sharing plan under Section 401(k) of the Internal Revenue Code (the “401K plan”). In 2014, the Company contributed three percent of employees’ annual compensation regardless whether contributions were made by the employee. The Company would also match 100% of employee contributions in excess of three percent up to a total of six percent of annual compensation. Employees vest 33% in Company contributions in their first year of service, 67% in their second year of service and 100% in their third year of service. Prior to 2013, employer matching contributions to the 401K plan were made in cash. Beginning in 2013, employer matching contributions to the 401K plan may be made in Company common stock. In general, the Company issues common stock to fund its matching contributions although, from time to time, purchases of common stock on the open market by the 401K plan trust may occur if funds are available as a result of forfeitures. During the year ended December 31, 2013, 40,481 shares of common stock were contributed to the 401K plan, of which 32,501 shares were issued by the Company, and 7,980 shares were purchased by the 401K plan trust on the open market. During the year ended December 31, 2014, 58,805 shares of common stock were contributed to the 401K plan, of which 58,513 shares were issued by the Company, and 292 shares were funded with forfeited shares already in the plan.
	The following table presents the expense incurred by the Company related to the 401K plan which is reflected in the consolidated statements of operations as a component of general and administrative expense:
		Year Ended December 31,
		2012		2013		2014
		(in thousands)
	401(k) profit sharing plan cost	$	235	$	662	$	597
	Deferred compensation plan — Effective January 1, 2013, the Company established a deferred compensation plan that permits selected employees and members of its board to defer part or all of their eligible compensation. The Company may also give awards to select employees via the deferred compensation plan. The following table presents the number of shares and the related fair values of common stock contributed by the Company to the deferred compensation plan for the years ended December 31, 2013 and 2014. The fair value of common stock is based on the market price of the stock on the preceding day that the stock is transferred and thus deemed to be a Level 1 measurement under the fair value hierarchy. Contributions were not made in 2012 as the plan was not in effect during that time.
		Year Ended December 31,
		2013		2014
		($ in thousands)
	Shares of common stock contributed		32,452		155,308
	Fair value of common stock contributed	$	473	$	1,997

Supplemental_Financial_Informa

Supplemental Financial Information-Quarterly Financial Data	12 Months Ended
	Dec. 31, 2014
Supplemental Financial Information-Quarterly Financial Data [Abstract]
Supplemental Financial Information-Quarterly Financial Data	Note 19—Supplemental Financial Information—Quarterly Financial Data (Unaudited)
	Summarized unaudited quarterly financial data for 2013 and 2014 are as follows (the information below has been restated where noted to give effect to the restatement discussed in Note 20):
		Quarters Ended
		March 31,		June 30,		September 30,		December 31,
		(Restated)		(Restated)		(Restated)		(Restated)
		(in thousands, except per share data)
	2013
	Total revenues	$	16,053	$	19,594	$	18,614	$	18,039
	Operating loss (1)		-3,727		-2,019		-1,679		-3,873
	Net income (loss)		-11,412		3,231		-4,429		-10,756
	Net income (loss) per common share
	Basic	$	-5.01	$	1.32	$	-1.77	$	-3.84
	Diluted	$	-5.01	$	1.32	$	-1.77	$	-3.84
		Quarters Ended
		March 31,		June 30,		September 30,
		(Restated)		(Restated)		(Restated)		December 31,
		(in thousands, except per share data)
	2014
	Total revenues	$	21,803	$	21,596	$	21,299	$	18,807
	Operating loss (1)		703		222		80		-1,072
	Net income (loss)		-7,622		-7,445		4,376		14,541
	Net income (loss) per common share
	Basic	$	-2.46	$	-2.34	$	1.36	$	2.37
	Diluted	$	-2.46	$	-2.34	$	1.35	$	2.37
	____________
	(1) Total revenue less total costs and expenses.
		Quarters Ended
		March 31,		June 30,		September 30,		December 31,
		(As Reported)		(As Reported)		(As Reported)		(As Reported)
		(in thousands, except per share data)
	2013
	Total revenues	$	16,053	$	19,594	$	18,614	$	18,039
	Operating loss (1)		-3,727		-2,019		-1,679		-3,873
	Net income (loss)		-7,894		6,880		-645		-7,377
	Net income (loss) per common share
	Basic	$	-5.01	$	1.32	$	-1.77	$	-3.84
	Diluted	$	-5.01	$	1.32	$	-1.77	$	-3.84
		Quarters Ended
		March 31,		June 30,		September 30,
		(As Reported)		(As Reported)		(As Reported)
		(in thousands, except per share data)
	2014
	Total revenues	$	21,803	$	21,596	$	21,299
	Operating income (loss) (1)		703		222		80
	Net income (loss)		-6,323		-5,988		5,997
	Net income (loss) per common share
	Basic	$	-2.46	$	-2.34	$	1.36
	Diluted	$	-2.46	$	-2.34	$	1.35
	____________
	(1)Total revenue less total costs and expenses.

Restatement_Of_Previously_Issu

Restatement Of Previously Issued Consolidated Financial Statements	12 Months Ended
	Dec. 31, 2014
Restatement Of Previously Issued Consolidated Financial Statements [Abstract]
Restatement Of Previously Issued Consolidated Financial Statements	Note 20—Restatement of Previously Issued Consolidated Financial Statements
	Prior to the issuance of the Company’s 2014 consolidated financial statements, the Company concluded that its previously issued 2010, 2011, 2012 and 2013 consolidated financial statements should be restated because of a misinterpretation of the guidance around accounting for its Series A Preferred Stock issued in September 2010.
	Background of Restatement – As discussed further in Note 12, on September 21, 2010 and from time to time thereafter, the Company issued to White Deer Series A Preferred Stock, Series B Preferred Stock and warrants to purchase shares of the Company’s common stock in exchange for cash. The Series A Preferred Stock was recorded outside of permanent equity and liabilities, in the Company’s consolidated balance sheet because the settlement provisions of the warrants allowed White Deer to “net exercise” the warrants by permitting White Deer to pay the exercise price of the warrant by delivering the Series A Preferred Stock with a liquidation preference equal to the exercise price that would otherwise be due from White Deer in cash. Although the terms of the Series A Preferred Stock has a mandatory redemption date attributed to it, the Company believed this provision associated with the warrants excluded the Series A Preferred Stock from the definition of mandatorily redeemable preferred stock under FASB ASC 480, “Distinguishing Liabilities from Equity.”  The Company now believes that under U.S. generally accepted accounting principles, because the warrants are detachable, and thus are separate from the Series A Preferred Stock, the features of the warrants cannot be considered when evaluating the classification of the Series A Preferred Stock, and the Company therefore believes that the Series A Preferred Stock should have been classified as a liability for all periods from its issuance date.
	Impact of the Restatement - The effect of the restatement on the Company’s consolidated balance sheets for each quarter and annual period end, beginning with September 30, 2010, consists of reclassifications of the Series A Preferred Stock from temporary equity to a liability.  Additionally, dividends and accretion, originally taken to additional paid-in capital, have been reclassified to interest expense on the statement of operations. While these non-cash reclassifications have the effect of reducing net income (or increasing the net loss) in each period, they have no material impact on total stockholders’ equity, net income (loss) attributable to common stockholders, net income (loss) per common share or cash flows. Details of the restatement for 2013 and 2012 are as follows:
		As of December 31, 2013
		As Reported		Adjustment		Restated
		(in thousands)
	Total Assets	$	183,082	$	—	$	183,082
	Total Current Liabilities		17,795		—		17,795
	Derivative financial instruments		1,796		—		1,796
	Long-term debt		92,000		—		92,000
	Mandatorily redeemable preferred stock		64,523		19,471		83,994
	Asset retirement obligations		13,099		—		13,099
	Other		75		—		75
	Total liabilities		189,288		19,471		208,759
	Commitments and contingencies
	Series A Cumulative Redeemable Preferred Stock		23,828		-23,828		—
	Stockholders’ equity (deficit)
	Preferred stock		—		—		—
	Common stock		30		—		30
	Additional paid-in capital		397,440		41,674		439,114
	Treasury stock, at cost		-512		—		-512
	Accumulated deficit		-426,992		-37,317		-464,309
	Total stockholders’ equity (deficit)		-30,034		4,357		-25,677
	Total liabilities and stockholders’ equity (deficit)	$	183,082	$	—	$	183,082
		Year Ended December 31, 2013
		As Reported		Adjustment		Restated
		(in thousands, except per share data)
	Operating loss	$	-11,298	$	—	$	-11,298
	Other income (expense)
	Realized gains (losses) from derivative financial instruments		-2,271		—		-2,271
	Unrealized gains (losses) from derivative financial instruments		1,672		—		1,672
	Gain (loss) from equity investment		6,768		—		6,768
	Other income (expense), net		12		—		12
	Interest expense, net		-3,739		-14,330		-18,069
	Total		2,442		-14,330		-11,888
	Income (loss) before income taxes		-8,856		-14,330		-23,186
	Income taxes		180		—		180
	Net income (loss)		-9,036		-14,330		-23,366
	Preferred stock dividends		-11,047		11,047		—
	Accretion of redeemable preferred stock		-3,283		3,283		—
	Net income (loss) attributable to common stockholders	$	-23,366	$	—	$	-23,366
	Net income (loss) per common share
	Basic	$	-9.32	$	—	$	-9.32
	Diluted	$	-9.32	$	—	$	-9.32
	Weighted average common shares outstanding
	Basic		2,507		—		2,507
	Diluted		2,507		—		2,507
		Year Ended December 31, 2012
		As Reported		Adjustment		Restated
		(in thousands, except per share data)
	Operating loss	$	-35,911	$	—	$	-35,911
	Other income (expense)
	Realized gains (losses) from derivative financial instruments		73,162		—		73,162
	Unrealized gains (losses) from derivative financial instruments		-66,708		—		-66,708
	Gain on investment		-5,174		—		-5,174
	Gain on forgiveness of debt		255		—		255
	Other income (expense), net		111		—		111
	Interest expense, net		-10,452		-11,321		-21,773
	Total		-8,806		-11,321		-20,127
	Income (loss) from continuing operations before income taxes		-44,717		-11,321		-56,038
	Income taxes		—		—		—
	Income (loss) from continuing operations		-44,717		-11,321		-56,038
	Income (loss) from discontinued operations		-2,855		—		-2,855
Net income (loss)		-47,572		-11,321		-58,893
Preferred stock dividends		-9,083		9,083		—
Accretion of redeemable preferred stock		-2,238		2,238		—
Net income (loss) attributable to common stockholders	$	-58,893	$	—	$	-58,893
Net income (loss) per common share
Basic	$	-43.3	$	—	$	-43.3
Diluted	$	-43.3	$	—	$	-43.3
Weighted average common shares outstanding
Basic		1,360		—		1,360
Diluted		1,360		—		1,360

Supplemental_Information_on_Oi

Supplemental Information on Oil and Gas Producing Activities	12 Months Ended
	Dec. 31, 2014
Supplemental Information on Oil and Gas Producing Activities [Abstract]
Supplemental Information on Oil and Gas Producing Activities	Note 21—Supplemental Information on Oil and Gas Producing Activities (Unaudited)
	The supplementary oil and gas data that follows is presented in accordance with FASB ASC 932 Extractive Activities—Oil and Gas (“FASB ASC 932”),  and includes (1) capitalized costs, costs incurred and results of operations related to oil and gas producing activities, (2) net proved oil and gas reserves, and (3) a standardized measure of discounted future net cash flows relating to proved oil and gas reserves.
	Investment—At December 31, 2014, the Company owns less than 20.0% voting interest in SPP, a publicly traded oil and gas exploration and production company. Since the Company no longer has significant influence over SPP, December 31, 2014 amounts for SPP are not included (see Note 8 – Investment for further discussion). The Company’s equity interest in SPP was 26.5% and 21.3% at December 31, 2012 and 2013, respectively. SPP utilizes the successful efforts method of accounting for its oil and gas activities. Where applicable, the disclosures required under FASB ASC 932 are made below based on the Company’s proportionate share of SPP’s oil and gas activities according to the percentages described above. Information utilized to prepare disclosures on the Company’s proportionate share of SPP is based on publicly available data. The Company has updated previously filed amounts for December 31, 2012 related to SPP as discontinued operations have now been presented in their current public filing.
	Net Capitalized Costs
	Aggregate capitalized costs related to oil and gas producing activities of the Company at December 31, 2013 and 2014, are summarized as follows:
		2013			2014
		(in thousands)
	Oil and gas properties and related leasehold costs
	Proved	$	405,895		$	440,333
	Unproved		4,862			6,150
			410,757			446,483
	Accumulated depreciation, depletion and amortization		-268,846			-293,243
	Net capitalized costs	$	141,911		$	153,240
	Unproved properties not subject to amortization consisted mainly of leaseholds acquired through acquisitions. The Company will continue to evaluate its unproved properties; however, the timing of the ultimate evaluation and disposition of the properties has not been determined.
	Aggregate capitalized costs related to oil and gas producing activities of the Company’s proportionate investment in SPP at December 31, 2013, are summarized as follows:
		2013
		(in thousands)
	Oil and gas properties and related equipment (successful efforts method)
	Proved	$	135,642
	Unproved		338
	Materials, supplies and land		385
			136,365
	Accumulated depreciation, depletion and amortization		-105,481
	Net capitalized costs	$	30,884
	Costs Incurred
	Costs incurred for oil and gas property acquisition, exploration and development activities that have been capitalized for the years ended December 31, 2012, 2013, and 2014 are summarized as follows:
		Consolidated Entities							SPP (1)
		2012			2013		2014		2012		2013
		(in thousands)
	Proved property acquisition costs	$	151		$	8,023	$	2,274	$	20	$	4,262
	Unproved property acquisition costs		52			8,567		1,722		47		45
	Exploration costs		—			—		—		—		—
	Development Costs		12,506			40,004		32,197		4,064		3,343
		$	12,709		$	56,594	$	36,193	$	4,131	$	7,650
	____________
	(1)Based on the Company’s pro-rata interest in SPP (disclosed above) assuming that the Company’s investment was made at the beginning of the period. 2014 is not shown as the Company no longer has significant influence over SPP.
	Results of Operations
	The revenues and expenses associated directly with the Company’s oil and natural gas producing activities are reflected in the consolidated statement of operations. All of our ongoing operations are oil and natural gas producing activities located in the United States.
	The table below presents the pro-rata results of oil and gas producing activities of the Company’s investment in SPP for the years ended December 31, 2012, and 2013 assuming that the Company’s investment was made at the beginning of the period presented.
		2012			2013
		(in thousands)
	Revenues	$	12,330		$	9,388
	Lease operating expense		5,144			4,017
	Cost of sales and production taxes		780			864
	Exploration costs		—			—
	Impairment of oil and gas properties		29			502
	Depreciation, depletion and amortization		3,109			4,041
	Oil and Gas Reserve Quantities
	The following reserve schedule was developed by the Company’s reserve engineers and sets forth the changes in estimated quantities for its proved reserves, all of which are located in the United States. Cawley, Gillespie & Associates, Inc., independent reserve engineering firm, was retained to perform the annual year-end independent evaluation of the Company’s proved reserves.
	Users of this information should be aware that the process of estimating quantities of “proved,” “proved developed” and “proved undeveloped” oil and gas reserves is very complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to, additional development activity, evolving production history, and continual reassessment of the viability of production under varying economic conditions. Consequently, material revisions (upwards or downward) to existing reserve estimates may occur from time to time. Although every reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the significance of the subjective decisions required and variances in available data for various reservoirs make these estimates generally less precise than other estimates presented in connection with financial statement disclosures.
	The table below presents changes in proved developed and undeveloped reserves of our consolidated entities.
		Gas - Mcf		Oil - Bbls
	Proved reserves
	Balance, December 31, 2011	118,220,188		1,073,921
	Purchase of reserves in place	—		—
	Extensions, discoveries, and other additions	1,867,365		617,854
	Sale of reserves	—		—
	Revisions of previous estimates	-34,037,402		1,095,656
	Production	-16,388,878		-95,863
	Balance, December 31, 2012	69,661,273		2,691,568
	Purchase of reserves in place	98,822		554,892
	Extensions, discoveries, and other additions	1,122,511		1,911,959
	Sale of reserves	—		—
	Revisions of previous estimates	30,246,006		-585,342
Production	-14,521,385		-192,474
Balance, December 31, 2013	86,607,227		4,380,603
Purchase of reserves in place	8,257		130,569
Extensions, discoveries, and other additions	924,218		533,124
Sale of reserves	-349,615		—
Revisions of previous estimates	45,171,999		-635,313
Production	-13,228,274		-274,919
Balance, December 31, 2014	119,133,812		4,134,064
Proved developed reserves
Balance, December 31, 2012	69,661,273		1,804,057
Balance, December 31, 2013	85,006,592		2,705,664
Balance, December 31, 2014	83,420,930		2,532,821
The table below presents the Company’s pro-rata share of changes in reserves and the amounts of proved developed reserves of SPP.
	Mcfe
Proved reserves
Balance, December 31, 2011	53,151,000
Purchase of reserves in place	—
Extensions, discoveries, and other additions	543,000
Sale of reserves	-68,000
Revisions of previous estimates	-25,551,000
Production	-3,435,000
Balance, December 31, 2012	24,640,000
Decrease in pro rata ownership	-4,835,000
Purchase of reserves in place	1,523,000
Extensions, discoveries, and other additions	1,028,000
Sale of reserves	-10,519,000
Revisions of previous estimates	9,527,000
Production	-1,927,000
Balance, December 31, 2013	19,437,000
Proved developed reserves
Balance, December 31, 2012	23,850,000
Balance, December 31, 2013	16,748,000
Standardized Measure of Discounted Future Net Cash Flows
The following information is based on the Company’s best estimate of the required data for the Standardized Measure of Discounted Future Net Cash Flows at December 31, 2012, 2013 and 2014 in accordance with FASB ASC 932 which requires the use of a 10% discount rate. Future income taxes are based on year-end statutory rates. This information is not the fair market value, nor does it represent the expected present value of future cash flows of Company’s proved oil and gas reserves.
	Consolidated Entities							SPP (1)
	2012			2013		2014		2012		2013
	(in thousands)
Future cash inflows	$	438,356		$	720,924	$	899,127	$	95,619	$	107,103
Future production costs		218,707			315,079		431,769		51,462		48,418
Future development costs		31,051			49,590		96,472		2,948		8,668
Future income tax expense		—			30,149		29,830		—		—
Future net cash flows		188,598			326,106		341,056		41,209		50,017
10% annual discount for estimated timing of cash flows		86,516			156,977		161,095		17,446		19,406
Standardized measure of discounted future net cash flows related to proved reserves	$	102,082		$	169,129	$	179,961	$	23,763	$	30,611
Standardized measure from continuing operations	$	102,082		$	169,129	$	179,961	$	16,021	$	30,611
Standardized measure from discontinued operations		—			—		—		7,742		—
Standardized measure of discounted future net cash flows related to proved gas reserves	$	102,082		$	169,129	$	179,961	$	23,763	$	30,611
____________
(1)Represents the Company’s pro-rata share of its investment in SPP. 2014 is not shown as the Company no longer has significant influence over SPP.
Future cash inflows are computed by applying a first-day-of-month, twelve-month average price, adjusted for location and quality differentials on a property-by-property basis, to year-end quantities of proved reserves, except in those instances where fixed and determinable price changes are provided by contractual arrangements at year-end. The discounted future cash flow estimates do not include the effects of our derivative instruments. See the following table for average oil and gas prices as of the periods indicated.
	2012			2013		2014
Crude oil price per Bbl	$	95.05		$	96.94	$	94.99
Natural gas price per MMBtu	$	2.76		$	3.67	$	4.35
The principal changes in the standardized measure of discounted future net cash flows relating to proven oil and gas properties were as follows:
	Consolidated Entities							SPP (1)
	2012			2013		2014		2012		2013
	(in thousands)
Present value, beginning of period	$	175,520		$	102,082	$	169,129	$	42,423	$	23,763
Net changes in prices and production costs		18,071			37,826		-18,101		-5,095		10,741
Decrease in pro rata ownership		—			—		—		—		-4,664
Net changes in future development costs		-18,008			-30,462		-41,958		—		—
Previously estimated development costs incurred		12,743			40,196		32,635		4,987		1,196
Sales of oil and gas produced, net		-10,338			-29,604		-39,919		-10,520		-4,525
Extensions and discoveries		7,724			23,514		7,070		3,336		6,069
Purchases of reserves in-place		—			6,401		1,358		—		—
Sales of reserves in-place		—			—		-600		-391		-489
Revisions of previous quantity estimates		-38,064			49,926		70,928		-22,034		4,570
Net change in income taxes		—			-7,769		-1,674		—		—
Accretion of discount		16,730			8,975		16,618		4,258		1,910
Timing differences and other (2)		-62,296			-31,956		-15,525		6,799		-7,960
Present value, end of period	$	102,082		$	169,129	$	179,961	$	23,763	$	30,611
Standardized measure from continuing operations	$	102,082		$	169,129	$	179,961	$	16,021	$	30,611
Standardized measure from discontinued operations		—			—		—		7,742		—
Standardized measure of discounted future net cash flows related to proved gas reserves	$	102,082		$	169,129	$	179,961	$	23,763	$	30,611
____________
(1)Represents the Company’s pro-rata share of its investment in SPP assuming that the Company’s investment was made at the beginning of each period presented. 2014 is not shown as the Company no longer has significant influence over SPP.
(2)The change in timing differences and other are related to revisions in the Company’s estimated time of production and development and the impact of changes in the relative proportion of oil versus natural gas in the Company’s total reserves.
During 2014, the Company continued to focus its development activities on oil related projects. The proportion of oil reserves to total reserves increased from 19% at December 31, 2012, to 23% at December 31, 2013 and 17% as of December 31, 2014.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2014
Summary of Significant Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation—These consolidated financial statements include PostRock’s and its subsidiaries’ accounts. Subsidiaries in which PostRock directly or indirectly owns more than 50% of the outstanding voting securities or those in which PostRock has effective control over are generally accounted for under the consolidation method of accounting. Under this method, a subsidiaries’ balance sheet and results of operations are reflected within the Company’s consolidated financial statements. All significant intercompany accounts and transactions have been eliminated.
Use of Estimates in the Preparation of Financial Statements	Use of Estimates in the Preparation of Financial Statements—The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company’s most significant recurring estimates are based on remaining proved oil and gas reserves. Estimates of proved reserves are key components of the Company’s depletion rate for oil and gas properties and its full cost ceiling test limitation. In addition, estimates are used in computing fair value of impaired assets, taxes, asset retirement obligations, fair value of derivative contracts and other items. Actual results could differ from these estimates.
Cash and Cash Equivalents	Cash and Cash Equivalents—The Company considers all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents. Cash balances are maintained at a few financial institutions that are insured by the Federal Deposit Insurance Corporation although such balances at times are in excess of the insured amount; however, no losses have been recognized as a result of this circumstance. During 2011, the Company began utilizing a controlled disbursement cash account which is funded when outstanding checks and electronic payments are presented for payment and an overdraft is the normal book balance. The Company’s policy has been to fund these outstanding checks and electronic payments as they clear through the banking system with customer receipts and borrowings under its Borrowing Base Credit Facility (as defined below). The Company accounts for such book overdrafts by reporting them in accounts and revenue payable in its consolidated balance sheets and including the change in such amounts in cash flows from operating activities in its consolidated statements of cash flows. Outstanding checks and electronic payments included in accounts and revenue payable at December 31, 2013 and 2014, amounted to $4.5 million and $2.0 million, respectively.
Accounts Receivable	Accounts Receivable—The Company conducts the majority of its operations in Kansas and Oklahoma and operates exclusively in the oil and gas industry. Receivables are generally unsecured; however, the Company has not experienced any significant losses to date. Receivables are recorded at the estimate of amounts due based upon the terms of the related agreements. Management periodically assesses the accounts receivable and establishes an allowance for estimated uncollectible amounts. Accounts estimated to be uncollectible are charged to operations in the period the reserve is established. The allowance for doubtful accounts was approximately $194,000 at December 31, 2013 and 2014.
Inventory	Inventory—Inventory includes tubular goods and other lease and well equipment which the Company plans to utilize in its ongoing exploration and development activities and is carried at the lower of cost or market using the specific identification method.
Oil and Natural Gas Properties	Oil and Natural Gas Properties—The Company uses the full cost method of accounting for oil and gas properties. Under the full cost method, all direct costs and certain indirect costs associated with the acquisition, exploration, and development of its oil and gas properties are capitalized.
	Oil and gas properties are depleted using the units-of-production method. The depletion expense is significantly affected by the unamortized historical and future development costs and the estimated proved oil and gas reserves. Estimation of proved oil and gas reserves relies on professional judgment and use of factors that cannot be precisely determined. Subsequent proved reserve estimates that are materially different from those reported would change the depletion expense recognized during the future reporting period. No gains or losses are recognized upon the sale or disposition of oil and gas properties such will result in an amortization rate materially different from the amortization rate calculated upon recognition of gains or losses.
	Under the full cost accounting rules, total capitalized costs are limited to a ceiling equal to the present value of future net revenues, discounted at 10% per annum less income tax effects (the “ceiling limitation”). The Company performs a quarterly ceiling test to evaluate whether the net book value of its full cost pool exceeds the ceiling limitation. If capitalized costs (net of accumulated depreciation, depletion, and amortization) less related deferred taxes are greater than the discounted future net revenues or ceiling limitation, a write-down or impairment of the full cost pool is required. A write-down of the carrying value of the full cost pool is a non-cash charge that reduces earnings and impacts stockholders’ (deficit) equity in the period of occurrence and typically results in lower depreciation, depletion, and amortization expense in future periods. Once incurred, a write-down is not reversible at a later date. The risk that the Company will be required to write down the carrying value of its oil and gas properties increases when oil and gas prices are depressed. This is partially mitigated by the use of an unweighted arithmetic average of first day of the month price for trailing twelve-month market prices to determine the ceiling. In addition, a write-down may occur if estimates of proved reserves are substantially reduced or estimates of future development costs increase significantly.
Unevaluated Properties	Unevaluated Properties—The costs directly associated with unevaluated oil and gas properties and properties under development are not initially included in the amortization base and relate to unproved leasehold acreage, seismic data, wells and production facilities in progress and wells pending determination. Unevaluated leasehold costs are transferred to the amortization base once determination has been made or upon expiration of a lease. Geological and geophysical costs and cumulative drilling costs to date associated with a specific unevaluated property are transferred to the amortization base with the associated leasehold costs on a specific project basis. Costs associated with wells in progress and wells pending determination are transferred to the amortization base once a determination is made whether or not proved reserves can be assigned to the property. All items included in the Company’s unevaluated property balance are assessed on a quarterly basis for possible impairment or reduction in value. The assessment includes consideration of numerous factors, including intent to drill, remaining lease term, geological and geophysical evaluations, drilling results and activity, assignment of proved reserves and economic viability of development if proved reserves are assigned. Any impairments of unevaluated properties are transferred to the amortization base.
Capitalized General and Administrative Expenses	Capitalized General and Administrative Expenses—Under the full cost method of accounting, a portion of general and administrative expenses that are directly attributable to acquisition, exploration, and development activities are capitalized to the full cost pool. The capitalized costs include salaries, related fringe benefits, cost of consulting services and other costs directly associated with those activities. In addition to costs related to acquisition, exploration, and development activities, the Company has also capitalized certain software costs. The Company’s capitalized general and administrative costs, including software costs, were $904,000, $1.3 million and $960,000 for the years ended December 31, 2012, 2013 and 2014, respectively.
Capitalized Interest Costs	Capitalized Interest Costs—The Company capitalizes interest based on the cost of major development projects. Capitalized interest was $11,000 for the year ended December 31, 2012 and nil for the years ended December 31, 2013 and 2014.
Other Property and Equipment	Other Property and Equipment—The cost of other property and equipment is depreciated over the estimated useful lives of the related assets. The cost of leasehold improvements is depreciated over the lesser of the length of the related leases or the estimated useful lives of the assets.
	Upon disposition or retirement of property and equipment, other than oil and gas properties, the cost and related accumulated depreciation are removed from the accounts and the gain or loss thereon, if any, is recognized in the statement of operations in the period of sale or disposition. Maintenance and repair costs are charged to operating expense as incurred.
Impairment	Impairment—Long-lived assets such as property and equipment are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of such assets to estimated undiscounted future cash flows expected to be generated by the assets. If the carrying amount of such assets exceeds their undiscounted estimated future cash flows, an impairment charge is recognized in the amount by which the carrying amount of such assets exceeds the fair value of the assets.
Investment	Investment—The Company elected to measure its investment in Constellation Energy Partners LLC, now named Sanchez Production Partners LLC (“SPP”), at fair value with changes in fair value included in the consolidated statements of operations. If the Company had not elected the fair value method, the investment would have previously qualified for the equity method of accounting, under which the Company’s proportionate share of the investee’s income would have been reported in the consolidated statements of operations.
Asset Retirement Obligations	Asset Retirement Obligations—Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 410, Asset Retirement and Environmental Obligations (ASC 410) requires that the fair value of an asset retirement cost and the corresponding liability should be recorded as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method. The Company records asset retirement obligations to reflect the Company’s legal obligations related to future plugging and abandonment of its natural gas and oil wells. Asset retirement obligations associated with the retirement of a tangible long-lived asset are recognized as a liability in the period incurred or when it becomes determinable that there is a legal or contractual obligation to dismantle or dispose of the asset and reclaim or remediate any related property at the end of its useful life, with an associated increase in the carrying amount of the related long-lived asset. The cost of the tangible asset, including the asset retirement cost, is depreciated over the useful life of the asset. The asset retirement obligation is recorded at its estimated fair value, measured by reference to the expected future cash outflows required to satisfy the retirement obligation discounted at the Company’s credit-adjusted risk-free interest rate. Accretion expense is recognized over time as the discounted liability is accreted to its expected settlement value and is recorded within “Depreciation, depletion, and amortization” on the Statement of Operations. If the estimated future cost of the asset retirement obligation changes, an adjustment is recorded to both the asset retirement obligation and the long-lived asset. Revisions to estimated asset retirement obligations can result from changes in retirement cost estimates, revisions to estimated inflation rates and changes in the estimated timing of abandonment. The Company has not recorded an asset retirement obligation relating to its gathering system because it does not have any legal or constructive obligations relative to asset retirements of the gathering system.
Derivative Instruments
	Derivative Instruments—The Company utilizes derivative instruments in conjunction with marketing and trading activities to manage price risk attributable to its forecasted sales of oil and gas production.
	The Company does not designate its oil and natural gas derivative contracts as hedges under ASC 815 Derivatives and Hedging although it believes that such contracts are effective hedges of its commodity price exposure. These contracts are accounted for using the mark-to-market accounting method. Using this method, the contracts are carried at their fair value on the Company’s consolidated balance sheets under the caption “Derivative financial instruments.” Changes in the fair value of these derivative financial instruments are recorded in earnings. The Company recognizes all unrealized and realized gains and losses related to these contracts on its consolidated statements of operations under the caption “Gain (loss) from derivative instruments” which is a component of “Other income (expense)”.
	The Company has exposure to credit risk to the extent a counterparty to a derivative instrument is unable to meet its settlement commitment. It actively monitors the creditworthiness of each counterparty and assesses the impact, if any, on its derivative positions.
Legal	Legal—The Company is subject to certain legal proceedings, claims and liabilities which arise in the ordinary course of its business. It accrues for losses associated with legal claims when such losses are probable and can be reasonably estimated. These estimates are adjusted as additional information becomes available or circumstances change.
Revenue Recognition	Revenue Recognition—Revenue from the Company’s oil and gas operations is derived from the sale of produced oil and natural gas. The Company uses the sales method of accounting for the recognition of oil and gas revenue. Because there is a ready market for oil and gas, the Company sells its oil and gas shortly after production at various pipeline receipt points at which time title and risk of loss transfers to the buyer. Revenue is recorded when title and risk of loss is transferred based on the Company’s net revenue interests. Gathering revenue is recognized at the time the gas is gathered or transported through the system and delivered to a third party as evidenced by a contract.
Environmental Costs	Environmental Costs—Environmental expenditures are expensed or capitalized, as appropriate, depending on future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed. Liabilities related to future costs are recorded on an undiscounted basis when environmental assessments and/or remediation activities are probable and costs can be reasonably estimated. The Company has no environmental costs accrued for the periods presented.
Stock-Based Compensation	Stock-Based Compensation—The Company grants various types of stock-based awards including stock options, restricted stock and restricted stock units to its employees and non-employee directors. The Company accounts for stock-based compensation in accordance with FASB ASC 718 Compensation – Stock Compensation where the awards are measured at fair value on the date of grant and are generally recognized as a component of general and administrative expenses in the consolidated statement of operations over the applicable requisite service periods. The fair value of stock option awards is determined using a Black-Scholes pricing model where volatility is derived from a peer group of companies.
Deferred Compensation Plan	Deferred compensation plan—The Company’s deferred compensation plan permits selected employees and members of its board of directors to defer part or all of their eligible compensation. The Company accounts for this deferred compensation in accordance with FASB ASC 710 Compensation – General. The Company issues common stock into a rabbi trust created to hold the assets associated with the plan. A participant’s deferred compensation is credited with earnings, gains and losses based on the Company’s common stock, the only investment option currently available under the plan. The Company may also make discretionary employer credits in an amount it determines each plan year. Distributions to participants will be made in shares of the Company’s common stock. Company shares held in the rabbi trust are recorded as treasury stock in the consolidated balance sheets. Since the deferred compensation arrangement currently does not permit diversification and only allows for settlement by delivery of Company common stock, the obligation is recorded as a component of paid-in-capital and changes in the fair value of the obligation are not recognized.
Income Taxes	Income Taxes—The Company records its income taxes using an asset and liability approach in accordance with the provisions of the FASB ASC 740 Income Taxes. This results in the recognition of deferred tax assets and liabilities for the expected future tax consequences of temporary differences (primarily property and equipment and the net operating loss carry forward) between the book carrying amounts and the tax bases of assets and liabilities using enacted tax rates at the end of the period. Under FASB ASC 740, the effect of a change in tax rates of deferred tax assets and liabilities is recognized in the year of the enacted change. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. At December 31, 2013 and 2014, a full valuation allowance was recorded against the Company’s net deferred tax assets.
	The Company regularly analyzes tax positions taken or expected to be taken in a tax return based on the threshold condition prescribed under FASB ASC 740. Tax positions that do not meet or exceed this threshold condition are considered uncertain tax positions. The Company accrues interest and penalties related to uncertain tax positions as income tax expense.
Net Income (Loss) per Common Share	Net Income (Loss) per Common Share—Basic earnings (loss) per share is calculated by dividing net income (loss) available to common stockholders by the weighted average number of shares of common stock outstanding during the period. The Company also includes contingently issuable shares in basic earnings (loss) per share when there is no circumstance under which those shares would not be issued. These include vested shares under the Company’s deferred compensation plan and vested deferred restricted stock units as all necessary conditions have been satisfied for the issuance of those shares other than the passage of time. Diluted earnings (loss) per share assumes the conversion of all potentially dilutive securities (warrants, stock options and restricted stock awards) and is calculated by dividing net income (loss) by the sum of the weighted average number of shares of common stock outstanding plus potentially dilutive securities under the treasury stock method.
Reverse Stock Split	Reverse Stock Split—All common stock, options, warrants, shares and per share amounts with respect to PostRock stock, excluding Series A Preferred Stock, have been retroactively adjusted in the accompanying consolidated financial statements and related notes to reflect the 1-for-10 reverse stock split, effective January 2, 2015.
Reclassifications	Reclassifications—Certain reclassifications have been made to the prior periods’ financial statements to conform to the current period’s presentation. These reclassifications had no effect on the financial position, results of operations or cash flows of the Company.
Concentrations of Market Risk	Concentrations of Market Risk—The Company’s future results will be affected by the market price of oil and gas. The availability of a ready market for oil and gas will depend on numerous factors beyond the Company’s control, including weather, production of oil and gas, imports, marketing, competitive fuels, proximity of oil and gas pipelines and other transportation facilities, any oversupply or undersupply of oil and gas, the regulatory environment, and other regional and political events, none of which can be predicted with certainty.
Concentrations of Credit Risk	Concentrations of Credit Risk—Financial instruments, which subject the Company to concentrations of credit risk, consist primarily of cash and accounts receivable. Risk with respect to receivables at December 31, 2013 and 2014, arise substantially from the sales of oil and gas. The following table discloses the percentage of consolidated revenues from our major customers:
		Year Ended December 31,
		2013		2014
	British Petroleum Energy Company	56	%	64	%
	ONEOK Energy and Marketing and Trading Company	11	%	—	%
	Sunoco	11	%	21	%
Fair Value	Fair Value—The Company applies the provisions of FASB ASC 820 Fair Value Measurements and Disclosures. Fair value is the exit price that we would receive to sell an asset or pay to transfer a liability in an orderly transaction between market participants at the measurement date.
	FASB ASC 820 also establishes a hierarchy that prioritizes the inputs used to measure fair value. The three levels of the fair value hierarchy are as follows:
	•Level 1—Quoted prices available in active markets for identical assets or liabilities at the reporting date.
	•Level 2—Pricing inputs other than quoted prices in active markets included in Level 1 which are either directly or indirectly observable at the reporting date. Level 2 consists primarily of non-exchange traded commodity derivatives.
	•Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources.
	The Company classifies assets and liabilities within the fair value hierarchy based on the lowest level of input that is significant to the fair value measurement of each individual asset and liability taken as a whole. Transfers of assets and liabilities between Level 1 and Level 2 are recognized at the end of a reporting period. The Company prioritizes the use of the highest level inputs available in determining fair value.
Recent Accounting Pronouncements Not Yet Adopted	Recent Accounting Pronouncements Not Yet Adopted
	In May 2014, the Financial Accounting Standards Board issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). The update provides guidance concerning the recognition and measurement of revenue from contracts with customers. Its objective is to increase the usefulness of information in the financial statements regarding the nature, timing and uncertainty of revenues. The update is effective for PostRock beginning on January 1, 2017. The standard permits the use of either the retrospective or cumulative effect transition method. PostRock has not yet selected a transition method and is evaluating the impact this standard will have on its consolidated financial statements and related disclosures.
	In August 2014, the Financial Accounting Standards Board issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Topic 205). The update provides guidance on management’s responsibility in evaluating whether there is a substantial doubt about a company’s ability to continue as a going concern. Its objective is to define management’s responsibility to evaluate going concern and to provide related footnote disclosures. The update is effective for PostRock beginning on January 1, 2017. PostRock has not yet determined whether early application of this accounting standard will be adopted.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Summary of Significant Accounting Policies [Abstract]
Summary of Percentage of Consolidated Revenue from Major Customers
		Year Ended December 31,
		2013		2014
	British Petroleum Energy Company	56	%	64	%
	ONEOK Energy and Marketing and Trading Company	11	%	—	%
	Sunoco	11	%	21	%

Acquisitions_and_Divestitures_

Acquisitions and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2014
Acquisitions and Divestitures [Abstract]
Schedule of Fair Value of Consideration Given and Purchase Price Allocation of Assets and Liabilities Assumed
	Consideration given (in thousands)
	Cash	$	3,440
	Common stock		6,548
	Total consideration given	$	9,988
	Amounts recognized for fair value of assets acquired and liabilities assumed
	Proved oil and natural gas properties	$	7,081
	Unproved oil and natural gas properties		3,253
	Crude oil inventory		177
	Accounts receivable		167
	Asset retirement obligations		-538
	Accounts payable		-152
	Total fair value of oil and gas properties acquired	$	9,988

Other_Balance_Sheet_Items_Tabl

Other Balance Sheet Items (Tables)	12 Months Ended
	Dec. 31, 2014
Other Balance Sheet Items [Abstract]
Other Balance Sheet Items
		December 31,
		2013		2014
		(in thousands)
	Other current assets
	Prepaid fees and deposits	$	820	$	975
	Other		—		56
	Total	$	820	$	1,031
	Other noncurrent assets, net
	Deferred financing costs	$	1,547	$	1,126
	Noncurrent deposits and other		491		453
	Total	$	2,038	$	1,579
	Accrued expenses and other
	Interest	$	39	$	26
	Employee-related costs and benefits		1,062		1,870
	Non-income related taxes		72		40
	Fees for services		1,127		316
	Asset retirement obligations		129		134
	Current income taxes		80		—
	Other		1,546		897
	Total	$	4,055	$	3,283
	Other noncurrent liabilities
	Lease termination costs	$	75	$	—
	Other		—		1
	Total	$	75	$	1

Property_Tables

Property (Tables)	12 Months Ended
	Dec. 31, 2014
Property [Abstract]
Schedule of Oil and Gas Properties and Other Property and Equipment
		December 31,
		2013		2014
		(in thousands)
	Oil and gas properties under the full cost method of accounting
	Properties being amortized	$	405,895	$	440,333
	Properties not being amortized		4,862		6,150
	Total oil and gas properties, at cost		410,757		446,483
	Less accumulated depletion, depreciation and amortization		-268,846		-293,243
	Oil and gas properties, net	$	141,911	$	153,240
	Other property and equipment at cost	$	30,019	$	30,629
	Less accumulated depreciation		-15,839		-18,800
	Other property and equipment, net	$	14,180	$	11,829
Schedule of Estimated Useful Lives of Other Property and Equipment
	Buildings	25 years
	Machinery and equipment	10 years
	Software and computer equipment	3 years
	Furniture and fixtures	10 years
	Vehicles	5 years

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Financial Instruments [Abstract]
Derivative Financial Instruments on Consolidated Balance Sheets
				December 31,
				2013			2014
	Derivative Financial Instruments		Balance Sheet Location	(in thousands)
	Commodity contracts		Current derivative financial instrument asset	$	54		$	11,151
	Commodity contracts		Long-term derivative financial instrument asset		652			6,162
	Commodity contracts		Current derivative financial instrument liability		-1,937			—
	Commodity contracts		Long-term derivative financial instrument liability		-1,796			—
				$	-3,027		$	17,313
Gains and Losses Associated with Derivative Financial Instruments
		Year Ended December 31,
		2012			2013			2014
		(in thousands)
	Realized gains (losses)(1)	$	73,162		$	-2,271		$	-3,944
	Unrealized gains (losses)		-66,708			1,672			20,340
	Total gain (loss) from derivative financial instruments	$	6,454		$	-599		$	16,396
	___________
	(1)2012 includes $30.2 million received from exiting above market natural gas swap contracts originally scheduled for delivery in 2013.
Reconciliation Of Gross Amounts To Net Amounts
		December 31,
		2013			2014
		(in thousands)
	Derivative Assets
	Gross amounts of recognized assets	$	706		$	17,313
	Gross amounts offset in the balance sheet		—			—
	Net amounts of assets presented in the balance sheet		706			17,313
	Gross amounts not offset in the balance sheet		-706			—
	Net amount	$	—		$	17,313
	Derivative Liabilities
	Gross amounts of recognized liabilities	$	3,733		$	—
	Gross amounts offset in the balance sheet		—			—
	Net amounts of liabilities presented in the balance sheet		3,733			—
	Gross amounts not offset in the balance sheet		-706			—
	Net amount	$	3,027		$	—
Estimated Volumes, Fixed Prices and Fair Values Attributable to All of Company Oil and Gas Derivative Contracts	The following table summarizes the estimated volumes, fixed prices and fair values attributable to all of the Company’s oil and gas derivative contracts at December 31, 2014.
		Year Ending December 31,
		2015			2016			Total
		($ in thousands, except per unit data)
	Natural Gas Swaps
	Contract volumes (MMBtu)		8,983,560			7,814,028			16,797,588
	Weighted-average fixed price per MMBtu	$	4.01		$	4.01		$	4.01
	Fair value, net	$	8,778		$	4,218		$	12,996
	Crude Oil Swaps
	Contract volumes (Bbl)		71,568			65,568			137,136
	Weighted-average fixed price per Bbl	$	92.73		$	90.33		$	91.58
	Fair value, net	$	2,566		$	1,751		$	4,317
	Total fair value, net	$	11,344		$	5,969		$	17,313
	The following table summarizes the estimated volumes, fixed prices and fair values attributable to all of the Company’s oil and gas derivative contracts at December 31, 2013:
		Year Ending December 31,
		2014			2015			2016		Total
		($ in thousands, except per unit data)
	Natural Gas Swaps
	Contract volumes (MMBtu)		10,327,572			8,983,560			7,814,028		27,125,160
	Weighted-average fixed price per MMBtu	$	4.01		$	4.01		$	4.01	$	4.01
	Fair value, net	$	-1,800		$	-1,076		$	-719	$	-3,595
	Crude Oil Swaps
	Contract volumes (Bbl)		116,076			71,568			65,568		253,212
	Weighted-average fixed price per Bbl	$	95.19		$	92.73		$	90.33	$	93.23
	Fair value, net	$	-53		$	281		$	340	$	568
	Total fair value, net	$	-1,853		$	-795		$	-379	$	-3,027

Financial_Instruments_Tables

Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2014
Financial Instruments [Abstract]
Assets and Liabilities Measured at Fair Value on Recurring Basis
								Total Net Fair
		Level 1		Level 2		Level 3		Value
		(in thousands)
	At December 31, 2013
	Investment, gross	$	14,205	$	383	$	—	$	14,588
	Derivative financial instruments—assets		—		706		—		706
	Derivative financial instruments—liabilities		—		-3,733		—		-3,733
	Total	$	14,205	$	-2,644	$	—	$	11,561
	At December 31, 2014
	Investment, gross	$	315	$	—	$	—	$	315
	Derivative financial instruments—assets		—		17,313		—		17,313
	Derivative financial instruments—liabilities		—		—		—		—
	Total	$	315	$	17,313	$	—	$	17,628

Investment_Tables

Investment (Tables)	12 Months Ended
	Dec. 31, 2014
Investment [Abstract]
Effect of Mark to Market Gains on Investment
		Year ended December 31,
		2012			2013		2014
		(in thousands)
	Mark to market gains (losses) on equity investment	$	-5,174		$	6,768	$	1,770
	Realized gain	$	—		$	—	$	5,444
Investment in SPP
		Year ended December 31,
		2013			2014
		(in thousands)
	Investment, at gross fair value	$	14,588		$	315
	Valuation allowance on investment		—			-315
Summarized Condensed Financial Information of SPP
		Year ended December 31,
		2012			2013
		(in thousands)
	Gross revenues	$	59,335		$	46,381
	Gross profit (loss)(1)		-80,964			-25,589
	Net income (loss) from continuing operations		-9,462			-25,857
	Net income (loss)		-86,543			-28,543
	____________
		-1		Equals revenues less operating expenses

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligations [Abstract]
Schedule of Changes in Asset Retirement Obligations
		Year Ended December 31,
		2013		2014
		(in thousands)
	Asset retirement obligations at beginning of period	$	10,868	$	13,228
	Liabilities incurred		533		146
	Liabilities settled		-88		-282
	Acquisitions		538		—
	Accretion		811		926
	Revision of estimates		566		—
	Asset retirement obligations at end of period	$	13,228	$	14,018
	Current portion of asset retirement obligations	$	129	$	134
	Noncurrent portion of asset retirement obligations at end of period	$	13,099	$	13,884

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Long-Term Debt [Abstract]
Summary of Long-Term Debt
		December 31,
		2013		2014
		(in thousands)
	Borrowing Base Facility	$	92,000	$	83,000
	Less current maturities		—		—
	Total long-term debt	$	92,000	$	83,000

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Taxes [Abstract]
Reconciliation of Federal Income Taxes at Federal Rates to Actual Provision for Income Taxes
		Year Ended December 31,
		2012		2013
		(Restated)		(Restated)		2014
		(in thousands)
	Income tax expense (benefit) at statutory rate	$	-20,612	$	-8,115	$	1,353
	State income tax expense, net of federal		958		19		573
	2011 IRS Settlement		—		30		—
	Interest expense - preferred stock dividend		3,962		5,189		5,637
	Other		1,650		322		-4
	IRC Section 382 limitation		30,491		2,575		2,085
	Change in valuation allowance		-16,449		160		-9,632
	Total tax expense	$	—	$	180	$	12
Summary of Deferred Tax Assets and Liabilities
		Year Ended December 31,
		2013		2014
		(in thousands)
	Current deferred income tax assets
	Unrealized loss for commodity derivative recorded for book, not for tax	$	722	$	—
	Accrued liabilities		1,038		477
	Allowance for bad debts		72		72
	Other		277		510
	Total current deferred income tax assets		2,109		1,059
	Noncurrent deferred income tax assets
	Unrealized loss for commodity derivative recorded for book, not for tax		669		—
	Partnership basis differences		6,287		478
	Property and equipment		37,849		33,161
	Asset retirement obligations		2,173		2,504
	Net operating loss carryforwards		14,943		23,379
	Other carryforwards		2,264		2,273
	Total noncurrent deferred income tax assets		64,185		61,795
	Total deferred income tax assets		66,294		62,854
	Current deferred income tax liabilities
	Unrealized gain for commodity derivative recorded for book, not for tax		-20		-4,157
	Total current deferred income tax liabilities		-20		-4,157
	Noncurrent deferred income tax liabilities
	Unrealized gain for commodity derivative recorded for book, not for tax		-420		-2,474
	Total noncurrent deferred income tax liabilities		-420		-2,474
	Total deferred income tax liabilities		-440		-6,631
	Net deferred income tax assets		65,854		56,223
	Valuation allowance		-65,854		-56,223
	Total deferred tax asset (liability)	$	—	$	—

Redeemable_Preferred_Stock_and1

Redeemable Preferred Stock and Warrants (Tables)	12 Months Ended
	Dec. 31, 2014
Redeemable Preferred Stock and Warrants [Abstract]
Changes in Series A Preferred Stock and Associated Warrants
		Carrying Value		Number of
		of Series A		Outstanding		Liquidation Value			Number of	Weighted Average
		Preferred Stock		Series A		of Series A			Outstanding	Exercise Price of
		(Restated)		Preferred Shares		Preferred Stock			Warrants	Warrants
		(in thousands except share, warrant and per unit data)
	31-Dec-11	$	56,736	6,000		$	69,759		2,156,626	$	32.35
	Issuance		8,428	1,250			12,500		765,439		16.33
	Accrued dividends recorded as interest		5,750	—			9,083		511,581		17.75
	Accretion recorded as interest		2,238	—			—		—		—
	31-Dec-12		73,152	7,250			91,342		3,433,646		26.60
	Accrued dividends recorded as interest		7,479	—			11,464		806,633		14.21
	Warrant Exchange		—	—			—		-2,224,135		32.31
	Accretion recorded as interest		3,363	—			—		—		—
	31-Dec-13		83,994	7,250			102,806		2,016,144		15.35
	Accrued dividends recorded as interest		7,868	—			11,958		1,285,105		9.31
	Preferred Exchange		-32,056	-2,175			-35,004		—		—
	Accretion recorded as interest		4,148	—			—		—		—
	31-Dec-14	$	63,954	5,075		$	79,760		3,301,249	$	13.00
Changes to Additional Paid in Capital as a Result of Warrants Issued
		Year Ended December 31,
		2012		2013			2014
		(in thousands)
	Warrants issued in conjunction with issuance of Series A Preferred Stock	$	4,071	$	—		$	—
	Warrants issued in conjunction with paid-in-kind dividends		3,334		3,984			4,089
	Total change in APIC due to warrants issued	$	7,405	$	3,984		$	4,089

Equity_And_Earnings_Per_Share_

Equity And Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2014
Equity And Earnings Per Share [Line Items]
Summary of Changes in the Non-Vested Restricted Shares	the periods presented is below.
		Number of Non-Vested		Weighted Average Grant
		Restricted Shares		Date Fair Value
	Non-vested restricted shares at December 31, 2011	57,921		$	33.30
	Granted	129,512			20.10
	Vested	-27,590			32.34
	Forfeited	-11,886			37.58
	Non-vested restricted shares at December 31, 2012	147,957			21.58
	Granted	64,191			17.49
	Vested	-45,253			27.95
	Cancelled/Forfeited (1)	-105,368			17.92
	Non-vested restricted shares at December 31, 2013	61,527			18.86
	Granted	39,760			13.33
	Vested	-41,373			18.30
	Forfeited	-10,533			17.55
	Non-vested restricted shares at December 31, 2014	49,381		$	15.16
	____________
	(1) 78,742 shares were cancelled with an associated accelerated stock compensation expense of approximately $500,000.
Summary of Changes in Stock Options Outstanding
				Weighted Average			Weighted Average
				Exercise Price per			Grant Date Fair
		Stock Options		Option			Value per Option
	Options outstanding at December 31, 2011	105,685		$	35.89
	Granted	130,366			18.01		$	10.68
	Forfeited or expired	-19,022			42.95
	Options outstanding at December 31, 2012	217,029			24.53
	Granted	58,495			17.73			8.89
	Forfeited or expired	-44,882			19.30
	Options outstanding at December 31, 2013	230,642			23.81
	Granted	92,451			13.08			7.14
	Forfeited or expired	-56,298			19.91
	Options outstanding at December 31, 2014	266,795			20.92
	Exercisable
	Options exercisable at December 31, 2012	46,719		$	41.03
	Options exercisable at December 31, 2013	98,904			30.34
	Options exercisable at December 31, 2014	129,589			27.32
Weighted-Average Assumptions to Estimate the Fair Value of Stock Options Granted
		2012				2013			2014
	Expected option life-years		5				4			4
	Volatility		74.3 - 76.1	%			64.0 - 82.7	%		66.0 - 74.6	%
	Risk-free interest rate		0.9 - 1.3	%			0.6 - 1.4	%		1.2 - 1.4	%
	Dividend yield		—				—			—
	Fair value per share	$	8.70 - 18.80			$	8.20 - 10.30		$	5.60 - 8.50
Total Share-Based Compensation Covering Stock Awards and Options
		Total Share
		Based
		Compensation
		Expense
		(in thousands)
	Year Ended December 31, 2012	$	2,224
	Year Ended December 31, 2013		3,177
	Year Ended December 31, 2014		922
Reconciliation of Numerator and Denominator Used in Basic and Diluted Per Share Calculations
		Year Ended December 31,
		2012		2013		2014
	Denominator for basic earnings per share (1)	1,359,584		2,506,857		3,915,578
	Effect of potentially dilutive securities
	Warrants	—		—		32,327
	Stock options	—		—		12
	Denominator for diluted earnings per share	1,359,584		2,506,857		3,947,917
	Securities excluded from earnings per share calculation
	Unvested share-based awards	14,999		—		—
	Antidilutive stock options	217,028		230,642		251,917
	Antidilutive warrants	3,308,662		1,792,951		2,275,368
	____________
	(1)Includes vested common shares in the Company’s deferred compensation plan and vested deferred restricted stock units, both of which will deliver shares to participants at a later date. Although shares have not been delivered on these awards, all conditions for issuance and delivery have been met. Pursuant to FASB ASC 260-10-45-13, such shares are to be included in the denominator in calculating basic earnings per share.
Universal Shelf Registration Statement [Member]
Equity And Earnings Per Share [Line Items]
Schedule of Common Stock Issuance
		Year Ended December 31,
		2013			2014
	Gross proceeds (in thousands)	$	4,076		$	—
	Common shares sold		259,232			—

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies [Abstract]
Future Minimum Rental Payments Under All Non-Cancelable Operating Leases
	Year ending December 31,	(in thousands)
	2015	$	4,570
	2016		2,945
	2017		1,760
	2018		414
	2019		—
	Thereafter		—
	Total minimum lease obligations	$	9,689

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2014
Discontinued Operations [Abstract]
Results of Discontinued Operations
		Year Ended
		December 31,
		2012
		(in thousands)
	Interstate pipeline revenue	$	8,934
	Pipeline expense		-2,825
	Depreciation and amortization		-2,537
	Gain (loss) on disposal of assets (1)		-5,437
	General and administrative expenses		-945
	Interest expense		-45
	Income from discontinued operations before income taxes		-2,855
	Income taxes		—
	Total income (loss) from discontinued operations	$	-2,855
	____________
	(1)Includes a loss of $5.4 million from the disposal of KPC.

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Summary of Supplemental Cash Flow Information
		Year Ended December 31,
		2012		2013		2014
		(in thousands)
	Cash paid for interest	$	7,292	$	2,780	$	3,033
	Cash paid for income taxes		—		100		12
	Non-cash investing activity
	Common stock issued for purchase of oil and gas properties		—		6,728		893
	Property additions financed through accounts payable and accrued liabilities		239		1,010		3,597
	Additions to property and equipment by recognizing asset retirement obligations		159		1,099		146
	Non-cash financing activity
	Common stock issued to fund 401K and deferred compensation plans		—		931		2,596
	Common stock issued to repurchase and retire outstanding warrants		—		1,528		—
	Common stock issued to repurchase and retire Series A preferred stock		—		—		32,435

Profit_Sharing_And_Deferred_Co1

Profit Sharing And Deferred Compensation Plans (Tables)	12 Months Ended
	Dec. 31, 2014
Profit Sharing And Deferred Compensation Plans [Abstract]
Schedule of Profit Sharing Plan
		Year Ended December 31,
		2012		2013		2014
		(in thousands)
	401(k) profit sharing plan cost	$	235	$	662	$	597
Schedule Of Deferred Compensation
		Year Ended December 31,
		2013		2014
		($ in thousands)
	Shares of common stock contributed		32,452		155,308
	Fair value of common stock contributed	$	473	$	1,997

Supplemental_Financial_Informa1

Supplemental Financial Information-Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2014
Supplemental Financial Information-Quarterly Financial Data [Abstract]
Schedule of Quarterly Financial Information
		Quarters Ended
		March 31,		June 30,		September 30,		December 31,
		(Restated)		(Restated)		(Restated)		(Restated)
		(in thousands, except per share data)
	2013
	Total revenues	$	16,053	$	19,594	$	18,614	$	18,039
	Operating loss (1)		-3,727		-2,019		-1,679		-3,873
	Net income (loss)		-11,412		3,231		-4,429		-10,756
	Net income (loss) per common share
	Basic	$	-5.01	$	1.32	$	-1.77	$	-3.84
	Diluted	$	-5.01	$	1.32	$	-1.77	$	-3.84
		Quarters Ended
		March 31,		June 30,		September 30,
		(Restated)		(Restated)		(Restated)		December 31,
		(in thousands, except per share data)
	2014
	Total revenues	$	21,803	$	21,596	$	21,299	$	18,807
	Operating loss (1)		703		222		80		-1,072
	Net income (loss)		-7,622		-7,445		4,376		14,541
	Net income (loss) per common share
	Basic	$	-2.46	$	-2.34	$	1.36	$	2.37
	Diluted	$	-2.46	$	-2.34	$	1.35	$	2.37
	____________
	(1) Total revenue less total costs and expenses.
		Quarters Ended
		March 31,		June 30,		September 30,		December 31,
		(As Reported)		(As Reported)		(As Reported)		(As Reported)
		(in thousands, except per share data)
	2013
	Total revenues	$	16,053	$	19,594	$	18,614	$	18,039
	Operating loss (1)		-3,727		-2,019		-1,679		-3,873
	Net income (loss)		-7,894		6,880		-645		-7,377
	Net income (loss) per common share
	Basic	$	-5.01	$	1.32	$	-1.77	$	-3.84
	Diluted	$	-5.01	$	1.32	$	-1.77	$	-3.84
		Quarters Ended
		March 31,		June 30,		September 30,
		(As Reported)		(As Reported)		(As Reported)
		(in thousands, except per share data)
	2014
	Total revenues	$	21,803	$	21,596	$	21,299
	Operating income (loss) (1)		703		222		80
	Net income (loss)		-6,323		-5,988		5,997
	Net income (loss) per common share
	Basic	$	-2.46	$	-2.34	$	1.36
	Diluted	$	-2.46	$	-2.34	$	1.35
	____________
	(1)Total revenue less total costs and expenses.

Restatement_Of_Previously_Issu1

Restatement Of Previously Issued Consolidated Financial Statements (Tables)	12 Months Ended
	Dec. 31, 2014
Restatement Of Previously Issued Consolidated Financial Statements [Abstract]
Schedule Of Impact Of Restatement
		As of December 31, 2013
		As Reported		Adjustment		Restated
		(in thousands)
	Total Assets	$	183,082	$	—	$	183,082
	Total Current Liabilities		17,795		—		17,795
	Derivative financial instruments		1,796		—		1,796
	Long-term debt		92,000		—		92,000
	Mandatorily redeemable preferred stock		64,523		19,471		83,994
	Asset retirement obligations		13,099		—		13,099
	Other		75		—		75
	Total liabilities		189,288		19,471		208,759
	Commitments and contingencies
	Series A Cumulative Redeemable Preferred Stock		23,828		-23,828		—
	Stockholders’ equity (deficit)
	Preferred stock		—		—		—
	Common stock		30		—		30
	Additional paid-in capital		397,440		41,674		439,114
	Treasury stock, at cost		-512		—		-512
	Accumulated deficit		-426,992		-37,317		-464,309
	Total stockholders’ equity (deficit)		-30,034		4,357		-25,677
	Total liabilities and stockholders’ equity (deficit)	$	183,082	$	—	$	183,082
		Year Ended December 31, 2013
		As Reported		Adjustment		Restated
		(in thousands, except per share data)
	Operating loss	$	-11,298	$	—	$	-11,298
	Other income (expense)
	Realized gains (losses) from derivative financial instruments		-2,271		—		-2,271
	Unrealized gains (losses) from derivative financial instruments		1,672		—		1,672
	Gain (loss) from equity investment		6,768		—		6,768
	Other income (expense), net		12		—		12
	Interest expense, net		-3,739		-14,330		-18,069
	Total		2,442		-14,330		-11,888
	Income (loss) before income taxes		-8,856		-14,330		-23,186
	Income taxes		180		—		180
	Net income (loss)		-9,036		-14,330		-23,366
	Preferred stock dividends		-11,047		11,047		—
	Accretion of redeemable preferred stock		-3,283		3,283		—
	Net income (loss) attributable to common stockholders	$	-23,366	$	—	$	-23,366
	Net income (loss) per common share
	Basic	$	-9.32	$	—	$	-9.32
	Diluted	$	-9.32	$	—	$	-9.32
	Weighted average common shares outstanding
	Basic		2,507		—		2,507
	Diluted		2,507		—		2,507
		Year Ended December 31, 2012
		As Reported		Adjustment		Restated
		(in thousands, except per share data)
	Operating loss	$	-35,911	$	—	$	-35,911
	Other income (expense)
	Realized gains (losses) from derivative financial instruments		73,162		—		73,162
	Unrealized gains (losses) from derivative financial instruments		-66,708		—		-66,708
	Gain on investment		-5,174		—		-5,174
	Gain on forgiveness of debt		255		—		255
	Other income (expense), net		111		—		111
	Interest expense, net		-10,452		-11,321		-21,773
	Total		-8,806		-11,321		-20,127
	Income (loss) from continuing operations before income taxes		-44,717		-11,321		-56,038
	Income taxes		—		—		—
	Income (loss) from continuing operations		-44,717		-11,321		-56,038
	Income (loss) from discontinued operations		-2,855		—		-2,855
	Net income (loss)		-47,572		-11,321		-58,893
	Preferred stock dividends		-9,083		9,083		—
	Accretion of redeemable preferred stock		-2,238		2,238		—
Net income (loss) attributable to common stockholders	$	-58,893	$	—	$	-58,893
Net income (loss) per common share
Basic	$	-43.3	$	—	$	-43.3
Diluted	$	-43.3	$	—	$	-43.3
Weighted average common shares outstanding
Basic		1,360		—		1,360
Diluted		1,360		—		1,360

Supplemental_Information_on_Oi1

Supplemental Information on Oil and Gas Producing Activities (Tables)	12 Months Ended
	Dec. 31, 2014
Aggregate Capitalized Costs Related to Oil and Gas Producing Activities
		2013			2014
		(in thousands)
	Oil and gas properties and related leasehold costs
	Proved	$	405,895		$	440,333
	Unproved		4,862			6,150
			410,757			446,483
	Accumulated depreciation, depletion and amortization		-268,846			-293,243
	Net capitalized costs	$	141,911		$	153,240
Costs Incurred for Oil and Gas Property Acquisition, Exploration and Development Activities
		Consolidated Entities							SPP (1)
		2012			2013		2014		2012		2013
		(in thousands)
	Proved property acquisition costs	$	151		$	8,023	$	2,274	$	20	$	4,262
	Unproved property acquisition costs		52			8,567		1,722		47		45
	Exploration costs		—			—		—		—		—
	Development Costs		12,506			40,004		32,197		4,064		3,343
		$	12,709		$	56,594	$	36,193	$	4,131	$	7,650
	____________
	(1)Based on the Company’s pro-rata interest in SPP (disclosed above) assuming that the Company’s investment was made at the beginning of the period.
Changes in Proved Developed and Undeveloped Reserves
		Gas - Mcf		Oil - Bbls
	Proved reserves
	Balance, December 31, 2011	118,220,188		1,073,921
	Purchase of reserves in place	—		—
	Extensions, discoveries, and other additions	1,867,365		617,854
	Sale of reserves	—		—
	Revisions of previous estimates	-34,037,402		1,095,656
	Production	-16,388,878		-95,863
	Balance, December 31, 2012	69,661,273		2,691,568
	Purchase of reserves in place	98,822		554,892
	Extensions, discoveries, and other additions	1,122,511		1,911,959
	Sale of reserves	—		—
	Revisions of previous estimates	30,246,006		-585,342
	Production	-14,521,385		-192,474
	Balance, December 31, 2013	86,607,227		4,380,603
	Purchase of reserves in place	8,257		130,569
	Extensions, discoveries, and other additions	924,218		533,124
	Sale of reserves	-349,615		—
	Revisions of previous estimates	45,171,999		-635,313
	Production	-13,228,274		-274,919
	Balance, December 31, 2014	119,133,812		4,134,064
	Proved developed reserves
	Balance, December 31, 2012	69,661,273		1,804,057
	Balance, December 31, 2013	85,006,592		2,705,664
	Balance, December 31, 2014	83,420,930		2,532,821
Best Estimate of Required Data for Standardized Measure of Discounted Future Net Cash Flows
		Consolidated Entities							SPP (1)
		2012			2013		2014		2012		2013
		(in thousands)
	Future cash inflows	$	438,356		$	720,924	$	899,127	$	95,619	$	107,103
	Future production costs		218,707			315,079		431,769		51,462		48,418
	Future development costs		31,051			49,590		96,472		2,948		8,668
	Future income tax expense		—			30,149		29,830		—		—
	Future net cash flows		188,598			326,106		341,056		41,209		50,017
	10% annual discount for estimated timing of cash flows		86,516			156,977		161,095		17,446		19,406
	Standardized measure of discounted future net cash flows related to proved reserves	$	102,082		$	169,129	$	179,961	$	23,763	$	30,611
	Standardized measure from continuing operations	$	102,082		$	169,129	$	179,961	$	16,021	$	30,611
	Standardized measure from discontinued operations		—			—		—		7,742		—
	Standardized measure of discounted future net cash flows related to proved gas reserves	$	102,082		$	169,129	$	179,961	$	23,763	$	30,611
	____________
	(1)Represents the Company’s pro-rata share of its investment in SPP. 2014 is not shown as the Company no longer has significant influence over SPP.
Discounted Future Cash Flow Estimates do not Include the Effects of Derivative Instruments
		2012			2013		2014
	Crude oil price per Bbl	$	95.05		$	96.94	$	94.99
	Natural gas price per MMBtu	$	2.76		$	3.67	$	4.35
Principal Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proven Oil and Gas Properties
		Consolidated Entities							SPP (1)
		2012			2013		2014		2012		2013
		(in thousands)
	Present value, beginning of period	$	175,520		$	102,082	$	169,129	$	42,423	$	23,763
	Net changes in prices and production costs		18,071			37,826		-18,101		-5,095		10,741
	Decrease in pro rata ownership		—			—		—		—		-4,664
	Net changes in future development costs		-18,008			-30,462		-41,958		—		—
	Previously estimated development costs incurred		12,743			40,196		32,635		4,987		1,196
	Sales of oil and gas produced, net		-10,338			-29,604		-39,919		-10,520		-4,525
	Extensions and discoveries		7,724			23,514		7,070		3,336		6,069
	Purchases of reserves in-place		—			6,401		1,358		—		—
	Sales of reserves in-place		—			—		-600		-391		-489
	Revisions of previous quantity estimates		-38,064			49,926		70,928		-22,034		4,570
	Net change in income taxes		—			-7,769		-1,674		—		—
	Accretion of discount		16,730			8,975		16,618		4,258		1,910
	Timing differences and other (2)		-62,296			-31,956		-15,525		6,799		-7,960
	Present value, end of period	$	102,082		$	169,129	$	179,961	$	23,763	$	30,611
	Standardized measure from continuing operations	$	102,082		$	169,129	$	179,961	$	16,021	$	30,611
	Standardized measure from discontinued operations		—			—		—		7,742		—
	Standardized measure of discounted future net cash flows related to proved gas reserves	$	102,082		$	169,129	$	179,961	$	23,763	$	30,611
	____________
	(1)Represents the Company’s pro-rata share of its investment in SPP assuming that the Company’s investment was made at the beginning of each period presented. 2014 is not shown as the Company no longer has significant influence over SPP.
	(2)The change in timing differences and other are related to revisions in the Company’s estimated time of production and development and the impact of changes in the relative proportion of oil versus natural gas in the Company’s total reserves.
SPP [Member]
Aggregate Capitalized Costs Related to Oil and Gas Producing Activities
		2013
		(in thousands)
	Oil and gas properties and related equipment (successful efforts method)
	Proved	$	135,642
	Unproved		338
	Materials, supplies and land		385
			136,365
	Accumulated depreciation, depletion and amortization		-105,481
	Net capitalized costs	$	30,884
Pro-Rata Results of Oil and Gas Producing Activities of Investment in SPP
		2012			2013
		(in thousands)
	Revenues	$	12,330		$	9,388
	Lease operating expense		5,144			4,017
	Cost of sales and production taxes		780			864
	Exploration costs		—			—
	Impairment of oil and gas properties		29			502
	Depreciation, depletion and amortization		3,109			4,041
Changes in Proved Developed and Undeveloped Reserves
		Mcfe
	Proved reserves
	Balance, December 31, 2011	53,151,000
	Purchase of reserves in place	—
	Extensions, discoveries, and other additions	543,000
	Sale of reserves	-68,000
	Revisions of previous estimates	-25,551,000
	Production	-3,435,000
	Balance, December 31, 2012	24,640,000
	Decrease in pro rata ownership	-4,835,000
	Purchase of reserves in place	1,523,000
	Extensions, discoveries, and other additions	1,028,000
	Sale of reserves	-10,519,000
	Revisions of previous estimates	9,527,000
	Production	-1,927,000
	Balance, December 31, 2013	19,437,000
	Proved developed reserves
	Balance, December 31, 2012	23,850,000
	Balance, December 31, 2013	16,748,000

Business_Organization_Narrativ

Business Organization (Narrative) (Details)	12 Months Ended
	Dec. 31, 2014
	county
	segment
Business of Presentation [Abstract]
Number of segments	1
Number of counties	15

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Summary Of Significant Accounting Policies [Line Items]
Ownership of the outstanding voting stock of subsidiaries	50.00%
Accounts payable and revenue payable	$9,278,000	$7,406,000
Allowance for doubtful accounts	194,000	194,000
Capitalized general and administrative costs	960,000	1,300,000	904,000
Interest cost capitalized	0	0	11,000
Reverse stock split	0.1
Outstanding checks [Member]
Summary Of Significant Accounting Policies [Line Items]
Accounts payable and revenue payable	$2,000,000	$4,500,000

Summary_of_Significant_Account4

Summary of Significant Accounting Policies (Summary Of Percentage Of Consolidated Revenue From Major Customer) (Details) (Sales [Member])	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
British Petroleum Energy Company [Member]
Concentration Risk [Line Items]
Percentage of revenue	64.00%	56.00%
Oneok Energy Marketing And Trading Company [Member]
Concentration Risk [Line Items]
Percentage of revenue		11.00%
Sunoco [Member]
Concentration Risk [Line Items]
Percentage of revenue	21.00%	11.00%

Acquisitions_and_Divestitures_1

Acquisitions and Divestitures (Narrative) (Details) (USD $)	1 Months Ended	7 Months Ended	12 Months Ended			1 Months Ended
	Jun. 30, 2014	Jun. 30, 2011	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jan. 31, 2014	Nov. 30, 2013	31-May-13
									acre
Business Acquisition And Divestiture [Line Items]
Payments to acquire oil and gas property and equipment			$32,973,000	$52,283,000	$16,759,000
Ownership interest in the development area	30.00%
Sale of oil and gas properties		44,600,000
Reduction in oil and gas full cost					266,000
Escrow to cover potential claims					6,400,000
Escrowed funds released					5,700,000
Escrowed funds paid from second and third closing					219,000
Escrow deposit of first and second closing retained by company					1,300,000
Escrow deposit of first and second closing payment to lender					4,400,000
Silver Creek Oil and Gas [Member]
Business Acquisition And Divestiture [Line Items]
Acres acquired	17,900
Acre for acre swap	3,800
Ownership interest in the development area	70.00%
Area sold	1,150
Disposal group purchase price, received	466,000
KPC Pipeline [Member]
Business Acquisition And Divestiture [Line Items]
Disposal group purchase price, received						53,400,000
Pottawatomie, Cleveland and McClain Counties in Central Oklahoma [Member]
Business Acquisition And Divestiture [Line Items]
Aggregate purchase price							1,700,000	9,988,000
Payments to acquire oil and gas property and equipment							800,000
Shares of common stock							72,581
Pottawatomie, Cleveland and McClain Counties in Central Oklahoma [Member] | Oil and gas properties [Member]
Business Acquisition And Divestiture [Line Items]
Acres acquired								22,000
Shares of common stock								451,613
Lincoln and Payne Counties in Oklahoma [Member] | Oil and gas properties [Member]
Business Acquisition And Divestiture [Line Items]
Acres acquired									4,300
Aggregate purchase price									1,900,000
Payments to acquire oil and gas property and equipment									1,700,000
Shares of common stock									12,661
Seminole County, Oklahoma [Member] | Oil and gas properties [Member]
Business Acquisition And Divestiture [Line Items]
Acres acquired								110
Payments to acquire oil and gas property and equipment								$750,000
Voting interest acquired								50.00%
Number of producing wells acquired								3

Acquisitions_and_Divestitures_2

Acquisitions and Divestitures (Schedule of Fair Value of Consideration Given and Purchase Price Allocation of Assets and Liabilities Assumed) (Details) (Pottawatomie, Cleveland and McClain Counties in Central Oklahoma [Member], USD $)	1 Months Ended
In Thousands, unless otherwise specified	Jan. 31, 2014	Nov. 30, 2013
Pottawatomie, Cleveland and McClain Counties in Central Oklahoma [Member]
Business Acquisition [Line Items]
Cash		$3,440
Common stock		6,548
Total consideration given	1,700	9,988
Proved oil and natural gas properties		7,081
Unproved oil and natural gas properties		3,253
Crude oil inventory		177
Accounts receivable		167
Asset retirement obligations		-538
Accounts payable		-152
Total fair value of oil and gas properties acquired		$9,988

Other_Balance_Sheet_Items_Narr

Other Balance Sheet Items (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Other Balance Sheet Items [Abstract]
Amortization or write off expenses related to deferred financing costs	$524,000	$461,000	$2,820,000
Write-off expense of unamortized debt issuance costs			$1,200,000

Other_Balance_Sheet_Items_Othe

Other Balance Sheet Items (Other Balance Sheet Items) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Other current assets
Prepaid fees and deposits	$975	$820
Other	56
Total	1,031	820
Other noncurrent assets, net
Deferred financing costs	1,126	1,547
Noncurrent deposits and other	453	491
Total	1,579	2,038
Accrued expenses and other
Interest	26	39
Employee-related costs and benefits	1,870	1,062
Non-income related taxes	40	72
Fees for services	316	1,127
Asset retirement obligations	134	129
Current income taxes		80
Other	897	1,546
Total	3,283	4,055
Other noncurrent liabilities
Lease termination costs		75
Other	1
Total	$1	$75

Property_Narrative_Details

Property (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	$28,895,000	$27,369,000	$27,669,000
Oil and gas properties [Member]
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	24,300,000	23,300,000	23,300,000
Other property plant and equipment [Member]
Property, Plant and Equipment [Line Items]
Depreciation expense	$3,600,000	$3,200,000	$3,600,000

Property_Schedule_Of_Oil_And_G

Property (Schedule Of Oil And Gas Properties And Other Property And Equipment) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Property [Abstract]
Properties being amortized (Proved)	$440,333	$405,895
Properties not being amortized (Unproved)	6,150	4,862
Total oil and gas properties, at cost	446,483	410,757
Accumulated depreciation, depletion and amortization	-293,243	-268,846
Oil and gas properties, net	153,240	141,911
Other property and equipment at cost	30,629	30,019
Less accumulated depreciation	-18,800	-15,839
Other property and equipment, net	$11,829	$14,180

Property_Schedule_Of_Estimated

Property (Schedule Of Estimated Useful Lives Of Other Property And Equipment (Details)	12 Months Ended
	Dec. 31, 2014
Buildings [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives of property and equipment	25 years
Machinery and equipment [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives of property and equipment	10 years
Software and computer equipment [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives of property and equipment	3 years
Furniture and fixtures [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives of property and equipment	10 years
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives of property and equipment	5 years

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Derivative Financial Instruments on Consolidated Balance Sheets) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative [Line Items]
Current derivative financial instrument asset	$11,151	$54
Long-term derivative financial instrument asset	6,162	652
Current derivative financial instrument liability		-1,937
Long-term derivative financial instrument liability		-1,796
Derivative financial instruments, fair value	17,313	-3,027
Commodity Contracts [Member]
Derivative [Line Items]
Current derivative financial instrument asset	11,151	54
Long-term derivative financial instrument asset	6,162	652
Current derivative financial instrument liability		-1,937
Long-term derivative financial instrument liability		($1,796)

Derivative_Financial_Instrumen3

Derivative Financial Instruments (Gains and Losses Associated with Derivative Financial Instruments) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Derivative Financial Instruments [Abstract]
Realized losses	($3,944,000)	[1]	($2,271,000)	[1]	$73,162,000	[1]
Unrealized gains	20,340,000		1,672,000		-66,708,000
Total gain (loss) from derivative financial instruments	16,396,000		-599,000		6,454,000
Realized gain from early monetization of derivative instrument					$30,200,000
[1]	2012 includes $30.2 million received from exiting above market natural gas swap contracts originally scheduled for delivery in 2013.

Derivative_Financial_Instrumen4

Derivative Financial Instruments (Estimated Volumes, Fixed Prices and Fair Values Attributable to All of Company Oil and Gas Derivative Contracts) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
	MMBTU	MMBTU
Derivatives, Fair Value [Line Items]
Fair value, net	$17,313	($3,027)
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Fair value, net	17,313	-3,027
NYMEX Swap – Natural Gas 2014 [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Contract volumes (MMbtu-gas)		10,327,572
Weighted-average fixed price per MMBtu		4.01
Fair value, net		-1,800
NYMEX Swap – Natural Gas 2015 [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Contract volumes (MMbtu-gas)	8,983,560	8,983,560
Weighted-average fixed price per MMBtu	4.01	4.01
Fair value, net	8,778	-1,076
NYMEX Swap – Natural Gas 2016 [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Contract volumes (MMbtu-gas)	7,814,028	7,814,028
Weighted-average fixed price per MMBtu	4.01	4.01
Fair value, net	4,218	-719
NYMEX Swap – Oil 2014 [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Contract volumes (Bbl-oil)		116,076
Weighted-average fixed price per Bbl		95.19
Fair value, net		-53
NYMEX Swap – Oil 2015 [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Contract volumes (Bbl-oil)	71,568	71,568
Weighted-average fixed price per Bbl	92.73	92.73
Fair value, net	2,566	281
NYMEX Swap – Oil 2016 [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Contract volumes (Bbl-oil)	65,568	65,568
Weighted-average fixed price per Bbl	90.33	90.33
Fair value, net	1,751	340
2014 [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Fair value, net		-1,853
2015 [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Fair value, net	11,344	-795
2016 [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Fair value, net	5,969	-379
Natural Gas Swaps [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Contract volumes (MMbtu-gas)	16,797,588	27,125,160
Weighted-average fixed price per MMBtu	4.01	4.01
Fair value, net	12,996	-3,595
Crude Oil Swaps [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Contract volumes (Bbl-oil)	137,136	253,212
Weighted-average fixed price per Bbl	91.58	93.23
Fair value, net	$4,317	$568

Derivative_Financial_Instrumen5

Derivative Financial Instruments (Reconciliation Of Gross Amounts To Net Amounts) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative Financial Instruments [Abstract]
Gross amounts of recognized assets	$17,313	$706
Gross amounts offset in the balance sheet
Net amounts of assets presented in the balance sheet	17,313	706
Gross amounts not offset in the balance sheet		-706
Net amount	17,313
Gross amounts of recognized liabilities		3,733
Gross amounts offset in the balance sheet
Net amounts of liabilities presented in the balance sheet		3,733
Gross amounts not offset in the balance sheet		-706
Net amount		$3,027

Financial_Instruments_Narrativ

Financial Instruments (Narrative) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Fair Value Measurements [Line Items]
Mandatorily redeemable preferred stock, carrying value		$83,994,000
Common Class B [Member]
Fair Value Measurements [Line Items]
Fair value, per unit	$1.40
Series A Preferred Stock [Member]
Fair Value Measurements [Line Items]
Preferred stock, shares outstanding	5,075	7,250	7,250	6,000
Mandatorily redeemable preferred stock, fair value	79,800,000	102,800,000
Mandatorily redeemable preferred stock, carrying value	$63,954,000	$83,994,000	$73,152,000	$56,736,000
LIBOR interest rate and risk premium used to discount cash flows for determining fair value	10.00%	12.90%
Class B Units [Member]
Fair Value Measurements [Line Items]
Equity investment member interest number	224,850
Class A Units [Member]
Fair Value Measurements [Line Items]
Equity investment member interest number		484,505

Financial_Instruments_Assets_a

Financial Instruments (Assets and Liabilities Measured at Fair Value on Recurring Basis) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative financial instruments-assets	$17,313	$706
Derivative financial instruments-liabilities		-3,733
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment, gross	315	14,588
Derivative financial instruments-assets	17,313	706
Derivative financial instruments-liabilities		-3,733
Assets and liabilities fair value, Total	17,628	11,561
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment, gross	315	14,205
Assets and liabilities fair value, Total	315	14,205
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment, gross		383
Derivative financial instruments-assets	17,313	706
Derivative financial instruments-liabilities		-3,733
Assets and liabilities fair value, Total	$17,313	($2,644)

Investment_Narrative_Details

Investment (Narrative) (Details) (USD $)	3 Months Ended	12 Months Ended	1 Months Ended
	Mar. 31, 2014	Dec. 31, 2014	Feb. 28, 2015
Business Acquisition [Line Items]
Value received from units transferred	$817,767
Recovered amount		22,100,000
Surplus percentage		50.00%
SPP [Member]
Business Acquisition [Line Items]
Settlement amount recorded as valuation allowance related to cost recovery of investment	6,516,103
CEPM [Member]
Business Acquisition [Line Items]
Target recovery amount	21,600,000
Surplus amount		240,000
Class A Units [Member]
Business Acquisition [Line Items]
Percentage of units transferred	100.00%
Class A Units [Member] | SPP [Member]
Business Acquisition [Line Items]
Units transferred	484,505
Class B Units [Member]
Business Acquisition [Line Items]
Value received from units transferred	1,000,000
Gain (loss) recorded in valuation allowance	-78,839
Number of units sold		5,054,255
Average price of units sold		$2.72
Class B Units [Member] | SPP [Member]
Business Acquisition [Line Items]
Units transferred	414,938
Class B Units [Member] | CEPM [Member]
Business Acquisition [Line Items]
Units transferred		224,850
Number of units owned		224,850
Class B Units [Member] | CEPM [Member] | Subsequent Events [Member]
Business Acquisition [Line Items]
Sale of stock, value			$290,000

Investment_Effect_of_Mark_to_M

Investment (Effect of Mark to Market Gains (Losses) on Investment) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Option, Quantitative Disclosures [Line Items]
Mark to market gains (losses) on equity investment	$7,214	$6,768	($5,174)
Equity Method Investments [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Mark to market gains (losses) on equity investment	1,770	6,768	-5,174
Realized gain	$5,444

Investment_Investment_at_Gross

Investment (Investment at Gross Fair Value and Valuation Allowance) (Details) (Equity Method Investments [Member], USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Equity Method Investments [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Investment, at gross value	$315	$14,588
Valuation allowance on investment	($315)

Investment_Summarized_Condense

Investment (Summarized Condensed Financial Information of CEP) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Schedule Of Summarized Financial Information Of Equity Investee [Line Items]
Gross revenues	$18,807	$21,299	$21,596	$21,803	$18,039	$18,614	$19,594	$16,053	$83,505	$72,300		$54,995
Net income (loss)	14,541	4,376	-7,445	-7,622	-10,756	-4,429	3,231	-11,412	3,850	-23,366		-58,893
SPP [Member]
Schedule Of Summarized Financial Information Of Equity Investee [Line Items]
Gross revenues										46,381		59,335
Gross profit (loss)										-25,589	[1]	-80,964	[1]
Net income (loss) from continuing operations										-25,857		-9,462
Net income (loss)										($28,543)		($86,543)
[1]	Equals revenues less operating expenses

Asset_Retirement_Obligations_S

Asset Retirement Obligations (Schedule of Changes in Asset Retirement Obligations) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligations [Abstract]
Asset retirement obligations at beginning of period	$13,228	$10,868
Liabilities incurred	146	533
Liabilities settled	-282	-88
Acquistions		538
Accretion	926	811
Revision of estimates		566
Asset retirement obligations at end of period	14,018	13,228
Current portion of asset retirement obligations	134	129
Noncurrent portion of asset retirement obligations at end of period	$13,884	$13,099

LongTerm_Debt_Narrative_Detail

Long-Term Debt (Narrative) (Details) (USD $)	7 Months Ended	12 Months Ended				1 Months Ended
	Jun. 30, 2011	Dec. 31, 2014	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Jun. 30, 2012	Jun. 30, 2011	Jan. 31, 2011	Dec. 31, 2013
		item
Debt Instrument [Line Items]
Ratio of current assets to current liabilities		1
Ratio of consolidated EBITDAX to consolidated interest charges		3
Rato of consolidated funded debt to consolidated EBITDAX		3.5
Repayment of deficiency under option one		30 days
Repayment of deficiency under option two		6
Minimum percentage of sale of assets		5.00%
Proceeds from sale of oil and gas properties	$44,600,000
Common stock, shares issued		6,523,811							2,991,595
Common stock fair value		65,000							30,000
Escrowed funds released			5,700,000
Escrow deposit retained by Company			1,300,000
Gain on forgiveness of debt			255,000	1,600,000	2,900,000
Deferred finance costs		1,700,000
Deferred financing costs amortization period		4 years
Unamortized deferred financing costs		1,200,000
Quest Eastern Resource LLC [Member]
Debt Instrument [Line Items]
Proceeds from sale of oil and gas properties			44,600,000
Purchase price of assets			41,600,000
Payments made from sale proceeds					21,200,000		4,300,000	9,300,000
Repayments of long-term lines of credit stock value			843,000
Common stock, shares issued			141,186
Common stock fair value			744,000
Escrowed funds released						5,700,000
Escrow deposit retained by Company						1,300,000
Repayments of long-term debt						4,400,000
Accrued interest forgiven				799,000
Citibank, N.A. [Member]
Debt Instrument [Line Items]
Interest rate at period end		3.04%
Minimum [Member] | London Interbank Offered Rate (LIBOR) [Member] | Citibank, N.A. [Member]
Debt Instrument [Line Items]
Basis spread on variable rate		2.50%
Minimum [Member] | Base Rate [Member] | Citibank, N.A. [Member]
Debt Instrument [Line Items]
Basis spread on variable rate		1.50%
Maximum [Member] | London Interbank Offered Rate (LIBOR) [Member] | Citibank, N.A. [Member]
Debt Instrument [Line Items]
Basis spread on variable rate		3.25%
Maximum [Member] | Base Rate [Member] | Citibank, N.A. [Member]
Debt Instrument [Line Items]
Basis spread on variable rate		2.25%
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Credit facility, borrowing base		115,000,000
Revolving Credit Facility [Member] | Citibank, N.A. [Member]
Debt Instrument [Line Items]
Credit facility, outstanding borrowings		83,000,000
Credit facility, amount available for additional borrowings		30,600,000
Line of credit facility, maximum borrowing capacity		200,000,000
Secured Debt [Member]
Debt Instrument [Line Items]
Credit facility, outstanding borrowings		83,000,000							92,000,000
Letter of Credit [Member] | Citibank, N.A. [Member]
Debt Instrument [Line Items]
Credit facility, outstanding borrowings		$1,400,000

LongTerm_Debt_Summary_of_LongT

Long-Term Debt (Summary of Long-Term Debt) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Line of Credit Facility [Line Items]
Total long-term debt	$83,000	$92,000
Secured Debt [Member]
Line of Credit Facility [Line Items]
Borrowing Base Facility	83,000	92,000
Total long-term debt	$83,000	$92,000

Income_Taxes_Narrative_Details

Income Taxes (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Abstract]
Provision (benefit) for income taxes	$12,000	$180,000	$0
2011 IRS Settlement		30,000
Current tax expense	12,022
Operating loss carry forwards	261,000,000
Federal NOL carryforwards 382 limit	228,000,000
Federal NOL carryforwards that will expire	211,000,000
Recognized built in loss ownership change recognized period	5 years
Recognized built-in-loss	103,600,000	103,600,000	103,600,000
Operating loss carry forward deducted	4,600,000
NOL carryforwards recorded as deferred tax asset	50,000,000
Recognized built-in-losses that will carryforward	99,000,000
Recognized built-in-loss that will expire	94,700,000
Operating loss carry forwards deferred tax asset	$4,300,000

Income_Taxes_Reconciliation_Of

Income Taxes (Reconciliation Of Federal Income Taxes At Federal Rates To Actual Provision For Income Taxes) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Abstract]
Income tax expense (benefit) at statutory rate	$1,353	($8,115)	($20,612)
State income tax expense, net of federal	573	19	958
2011 IRS Settlement		30
Interest expense - preferred stock dividend	5,637	5,189	3,962
Other	-4	322	1,650
IRC Section 382 limitation	2,085	2,575	30,491
Change in valuation allowance	-9,632	160	-16,449
Total tax expense	$12	$180	$0

Income_Taxes_Summary_Of_Deferr

Income Taxes (Summary Of Deferred Tax Assets and Liabilities) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current deferred income tax assets
Unrealized loss for commodity derivative recorded for book, not for tax		$722
Accrued liabilities	477	1,038
Allowance for bad debts	72	72
Other	510	277
Total current deferred income tax assets	1,059	2,109
Noncurrent deferred income tax assets
Unrealized loss for commodity derivative recorded for book, not for tax		669
Partnership basis differences	478	6,287
Property and equipment	33,161	37,849
Asset retirement obligations	2,504	2,173
Net operating loss carryforwards	23,379	14,943
Other carryforwards	2,273	2,264
Total noncurrent deferred income tax assets	61,795	64,185
Total deferred income tax assets	62,854	66,294
Current deferred income tax liabilities
Unrealized gain for commodity derivative recorded for book, not for tax	-4,157	-20
Total current deferred income tax liabilities	-4,157	-20
Noncurrent deferred income tax liabilities
Unrealized gain for commodity derivative recorded for book, not for tax	-2,474	-420
Total noncurrent deferred income tax liabilities	-2,474	-420
Total deferred income tax liabilities	-6,631	-440
Net deferred income tax assets	56,223	65,854
Valuation allowance	-56,223	-65,854
Total deferred tax asset (liability)

Redeemable_Preferred_Stock_and2

Redeemable Preferred Stock and Warrants (Narrative) (Details) (USD $)	1 Months Ended			12 Months Ended			1 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2012	Aug. 31, 2012	Sep. 21, 2010	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Oct. 31, 2014	Dec. 31, 2011	Sep. 30, 2010
Summary Activity [Line Items]
Warrants issued to purchase common stock	457,746	307,693	1,904,762
Proceeds from issuance of preferred stock and warrants	$6,500	$6,000	$60,000			$12,500
Warrant exercise price	$14.20	$19.50			$32.30	$14.20	$32.30
Percentage of additional liquidation preference rate						14.00%
Warrant exercisable period						90 months
Percentage of market price of common stock exceeds exercise price				300.00%
Maximum percentage of warrants can be exercised to purchase shares				50.00%
Maximum number of shares can be issued upon exercise of warrants				75,000
Common stock trading days				20 days
Issuance of stock				893	10,612	20,445
Warrants exercisable for common stock					2,224,135		2,224,135
Series B Voting Preferred Stock shares issued per unit					0.01		0.01
Interest expense				19,664	18,069	21,773
Mandatorily redeemable preferred stock, carrying value					83,994		83,994
Minimum [Member]
Summary Activity [Line Items]
Warrant exercise price					$28		$28
Maximum [Member]
Summary Activity [Line Items]
Warrant exercise price					$63.90		$63.90
Antidilutive warrants [Member]
Summary Activity [Line Items]
Issuance of stock, shares							112,398
Issuance of stock							1,500
Series A Preferred Stock [Member]
Summary Activity [Line Items]
Issuance of cumulative preferred stock			6,000
Liquidation Value of Series A Preferred Stock, Issuance	6,500					12,500
Preferred stock, cumulative dividend rate	12.00%
Redemption date of preferred stock				21-Mar-18
Redemption rate on mandatory date					100.00%		100.00%
Redemption rate before mandatory date					110.00%		110.00%
Issuance of stock, shares	650	600				1,250,000
Issuance of stock		6,000
Aggregate liquidation preference	91,342			79,760	102,806	91,342	102,806		69,759
Mandatorily redeemable preferred stock, carrying value	73,152			63,954	83,994	73,152	83,994		56,736
Series B Preferred Stock [Member]
Summary Activity [Line Items]
Issuance of cumulative preferred stock			19,047.62	23,098	11,352		11,352
Maximum voting stock applicable for Series B Preferred Stock holder		45.00%
Issuance of stock					1	1
White Deer [Member] | Series A Preferred Stock [Member]
Summary Activity [Line Items]
Issuance of cumulative preferred stock										2,175
Issuance of stock, shares								3,211,378
Aggregate liquidation preference				35,000
Mandatorily redeemable preferred stock, carrying value				$32,100

Redeemable_Preferred_Stock_and3

Redeemable Preferred Stock and Warrants (Changes in Series A Preferred Stock and Associated Warrants) (Details) (USD $)	1 Months Ended		12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2012	Aug. 31, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Class of Stock [Line Items]
Carrying Value of Series A Preferred Stock, beginning balance			$83,994
Carrying Value of Series A Preferred Stock, ending balance				83,994
Number of Outstanding Warrants, beginning balance			2,016,144	3,433,646	2,156,626
Number of Outstanding Warrants, Issuance					765,439
Number of Outstanding Warrants, Accrued dividends recorded as interest			1,285,105	806,633	511,581
Number of Outstanding Warrants, Warrant Exchange				-2,224,135
Number of Outstanding Warrants, Ending Balance	3,433,646		3,301,249	2,016,144	3,433,646
Weighted Average Exercise Price of Warrants, Beginning Balance			$32.30	$14.20
Weighted Average Exercise Price of Warrants, Ending Balance	$14.20	19.5		$32.30	$14.20
Weighted Average [Member]
Class of Stock [Line Items]
Weighted Average Exercise Price of Warrants, Beginning Balance			$15.35	$26.60	$32.35
Weighted Average Exercise Price of Warrants, Issuance					$16.33
Weighted Average Exercise Price of Warrants, Accrued dividends recorded as interest			$9.31	$14.21	$17.75
Weighted Average Exercise Price of Warrants, Warrant Exchange				$32.31
Weighted Average Exercise Price of Warrants, Ending Balance	$26.60		$13	$15.35	$26.60
Series A Preferred Stock [Member]
Class of Stock [Line Items]
Carrying Value of Series A Preferred Stock, beginning balance			83,994	73,152	56,736
Carrying Value of Series A Preferred Stock, Issuance					8,428
Carrying Value of Series A Preferred Stock, Accrued dividends recorded as interest			7,868	7,479	5,750
Carrying Value of Series A Preferred Stock, Preferred Exchange			-32,056
Carrying Value of Series A Preferred Stock, Accretion recorded as interest			4,148	3,363	2,238
Carrying Value of Series A Preferred Stock, ending balance	73,152		63,954	83,994	73,152
Beginning balance, preferred shares			7,250	7,250	6,000
Issuance of stock, shares	650	600			1,250,000
Preferred exchange, shares			-2,175
Ending balance, preferred shares	7,250		5,075	7,250	7,250
Liquidation Value of Series A Preferred Stock, beginning balance			102,806	91,342	69,759
Liquidation Value of Series A Preferred Stock, Issuance	6,500				12,500
Liquidation Value of Series A Preferred Stock, Accrued dividends recorded as interest			11,958	11,464	9,083
Liquidation Value of Series A Preferred Stock, Preferred Exchange			-35,004
Liquidation Value of Series A Preferred Stock, ending balance	$91,342		$79,760	$102,806	$91,342

Redeemable_Preferred_Stock_and4

Redeemable Preferred Stock and Warrants (Changes to Additional Paid in Capital as Result of Warrants Issued) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Summary Activity [Line Items]
Total change in APIC due to warrants issued	$4,089	$3,984	$7,405
White Deer [Member]
Summary Activity [Line Items]
Warrants issued in conjunction with issuance of Series A Preferred Stock			4,071
Warrants issued in conjunction with paid-in-kind dividends	4,089	3,984	3,334
Total change in APIC due to warrants issued	$4,089	$3,984	$7,405

Recovered_Sheet1

Equity and Earnings Per Share (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Equity And Earnings Per Share [Line Items]
Common shares pursuant to an at-the-market issuance sales	$100,000,000
Long -Term Incentive Plan [Member]
Equity And Earnings Per Share [Line Items]
Shares authorized for future stock and option awards	1,085,000
Vesting percentage	33.00%
Award vesting period	3 years
Award vesting period in conjunction with Company's annual bonus program	1 year
Award vesting period for non-employee directors	1 year
Shares available under plan for future stock awards and options	669,119
Expected option life-years	4 years
Long -Term Incentive Plan [Member] | Minimum [Member]
Equity And Earnings Per Share [Line Items]
Expiration period for options granted	5 years
Long -Term Incentive Plan [Member] | Maximum [Member]
Equity And Earnings Per Share [Line Items]
Expiration period for options granted	6 years
Long -Term Incentive Plan [Member] | Restricted Shares [Member]
Equity And Earnings Per Share [Line Items]
Unrecognized compensation expense for non-vested awards	328,000
Weighted average period of recognition for unrecognized compensation expense	1 year 3 months 11 days
Long -Term Incentive Plan [Member] | Stock options [Member]
Equity And Earnings Per Share [Line Items]
Weighted average period of recognition for unrecognized compensation expense	1 year 3 months 15 days
Weighted average remaining term of options outstanding	3 years 1 month 2 days
Weighted average remaining term of options exercisable	2 years 3 months 18 days
Aggregate intrinsic value of options outstanding
Aggregate intrinsic value of options exercisable
Expected option life-years	4 years	4 years	5 years
Unrecognized compensation expense for stock options	$492,000
Long -Term Incentive Plan [Member] | Stock options [Member] | Minimum [Member]
Equity And Earnings Per Share [Line Items]
Expected option life-years			5 years

Recovered_Sheet2

Equity and Earnings per Share (Summary of Changes in Non-Vested Restricted Shares) (Details) (Long -Term Incentive Plan [Member], Restricted Shares [Member], USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Long -Term Incentive Plan [Member] | Restricted Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of Non-Vested Restricted Shares, Beginning balance	61,527	147,957		57,921
Number of Non-Vested Restricted Shares, Granted	39,760	64,191		129,512
Number of Non-Vested Restricted Shares, Vested	-41,373	-45,253		-27,590
Number of Non-Vested Restricted Shares, Cancelled/Forfeited	-10,533	-105,368	[1]	-11,886
Number of Non-Vested Restricted Shares, Ending balance	49,381	61,527		147,957
Weighted Average Grant-Date Fair Value, Beginning Balance	$18.86	$21.58		$33.30
Weighted Average Grant-Date Fair Value, Granted	$13.33	$17.49		$20.10
Weighted Average Grant-Date Fair Value, Vested	$18.30	$27.95		$32.34
Weighted Average Grant-Date Fair Value, Cancelled/Forfeited	$17.55	$17.92	[1]	$37.58
Weighted Average Grant-Date Fair Value, Ending Balance	$15.16	$18.86		$21.58
Shares cancelled	78,742
Restricted stock compensation expense	$500
[1]	78,742 shares were cancelled with an associated accelerated stock compensation expense of approximately $500,000.

Equity_and_Earnings_per_Share_1

Equity and Earnings per Share (Summary of Changes in the Stock Options Outstanding) (Details) (Long -Term Incentive Plan [Member], Stock options [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Long -Term Incentive Plan [Member] | Stock options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Options, Beginning Balance	230,642	217,029	105,685
Stock Options, Granted	92,451	58,495	130,366
Stock Options, Forfeited or expired	-56,298	-44,882	-19,022
Stock Options, Ending Balance	266,795	230,642	217,029
Stock Options, Options exercisable	129,589	98,904	46,719
Weighted Average Exercise Price per Share, Options outstanding	$23.81	$24.53	$35.89
Weighted Average Exercise Price per Share, Granted	$13.08	$17.73	$18.01
Weighted Average Exercise Price per Share, Forfeited or expired	$19.91	$19.30	$42.95
Weighted Average Exercise Price per Share, Option outstanding	$20.92	$23.81	$24.53
Weighted Average Exercise Price per Share, Options exercisable	$27.32	$30.34	$41.03
Weighted Average Grant Date Fair Value per Option	$7.14	$8.89	$10.68

Equity_and_Earnings_per_Share_2

Equity and Earnings per Share (Weighted-Average Assumptions to Estimate the Fair Value of Stock Options Granted) (Details) (Long -Term Incentive Plan [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected option life-years	4 years
Stock options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected option life-years	4 years	4 years	5 years
Volatility, Minimum	66.00%	64.00%	74.30%
Volatility, Maximum	74.60%	82.70%	76.10%
Risk-free interest rate, Minimum	1.20%	0.60%	0.90%
Risk-free interest rate, Maximum	1.40%	1.40%	1.30%
Dividend yield
Stock options [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected option life-years			5 years
Fair value per option	$5.60	$8.20	$8.70
Stock options [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair value per option	$8.50	$10.30	$18.80

Equity_and_Earnings_per_Share_3

Equity and Earnings per Share (Total Share-Based Compensation Covering Stock Awards and Options) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Equity And Earnings Per Share [Abstract]
Stock-based compensation	$922	$3,177	$2,224

Equity_and_Earnings_per_Share_4

Equity and Earnings per Share (Summary of Reconciliation of Denominator (Number of Shares) Used in Basic and Diluted Per Share Calculations) (Details)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Earnings Per Common Share [Line Items]
Denominator for basic earnings per share	3,915,578	[1]	2,506,857	[1]	1,359,584	[1]
Warrants	32,327
Stock options	12
Denominator for diluted earnings per share	3,947,917		2,506,857		1,359,584
Securities excluded from earnings per share calculation
Securities excluded from earnings per share calculation					14,999
Stock options [Member]
Securities excluded from earnings per share calculation
Securities excluded from earnings per share calculation	251,917		230,642		217,028
Antidilutive warrants [Member]
Securities excluded from earnings per share calculation
Securities excluded from earnings per share calculation	2,275,368		1,792,951		3,308,662
[1]	Includes vested common shares in the Company’s deferred compensation plan and vested deferred restricted stock units, both of which will deliver shares to participants at a later date. Although shares have not been delivered on these awards, all conditions for issuance and delivery have been met. Pursuant to FASB ASC 260-10-45-13, such shares are to be included in the denominator in calculating basic earnings per share.

Equity_and_Earnings_per_Share_5

Equity and Earnings per Share (Schedule of Common Stock Issuance) (Details) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Equity And Earnings Per Share [Line Items]
Gross proceeds	$4,076	$20,724
Universal Shelf Registration Statement [Member]
Equity And Earnings Per Share [Line Items]
Gross proceeds	$4,076
Common shares sold	259,232

Commitments_and_Contingencies_1

Commitments and Contingencies (Narrative) (Details) (USD $)	1 Months Ended		12 Months Ended			1 Months Ended	0 Months Ended
	Dec. 31, 2012	Jan. 31, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Nov. 30, 2010	Mar. 05, 2015
Commitment And Contingencies [Line Items]
Funded settlements	$4,500,000	$3,000,000
Total settlement (against) awarded to amount					-7,500,000
Rental expense			9,100,000	10,800,000	12,400,000
Jerry Cash [Member]
Commitment And Contingencies [Line Items]
Total settlement (against) awarded to amount						5,000,000
Litigation restitution payment			23,000
David Grose [Member]
Commitment And Contingencies [Line Items]
Total settlement (against) awarded to amount						1,000,000
David Grose [Member] | Subsequent Events [Member]
Commitment And Contingencies [Line Items]
Litigation restitution payment							$300,000

Commitments_and_Contingencies_2

Commitments and Contingencies (Future Minimum Rental Payments Under All Non-Cancelable Operating Leases) (Details) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified
Commitments and Contingencies [Abstract]
2015	$4,570
2016	2,945
2017	1,760
2018	414
2019
Thereafter
Total minimum lease obligations	$9,689

Impairment_of_Oil_and_Gas_Prop1

Impairment of Oil and Gas Properties (Narrative) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Impairment of Oil and Gas Properties [Abstract]
Impairment of oil and gas properties	$0	$0	$5,919

Discontinued_Operations_Narrat

Discontinued Operations (Narrative) (Details) (USD $)	12 Months Ended	1 Months Ended	12 Months Ended
	Dec. 31, 2014	Sep. 28, 2012	Dec. 31, 2012
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Purchase and sale agreement date	28-Sep-12
Interstate natural gas pipeline, length			1,120
KPC Pipeline [Member] | Discontinued Operations [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal group Purchase Price		$53,500,000
Disposal group purchase price, received		53,400,000
Additional payment to be received			1,000,000
Carrying value of the net assets sold		57,000,000
Gain (loss) on disposal of assets			-5,437,000	[1]
Closing-related costs			1,900,000
Legal, professional, and investment banking fees			1,000,000
Severance costs			505,000
Site cleanup costs			$350,000
[1]	Includes a loss of $5.4 million from the disposal of KPC.

Discontinued_Operations_Result

Discontinued Operations (Results of Discontinued Operations) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total income from discontinued operations	($2,855)
KPC Pipeline [Member] | Discontinued Operations [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Interstate pipeline revenue	8,934
Pipeline expense	-2,825
Depreciation and amortization	-2,537
Gain (loss) on disposal of assets	-5,437	[1]
General and administrative expenses	-945
Interest expense	-45
Income from discontinued operations before income taxes	-2,855
Income taxes
Total income from discontinued operations	($2,855)
[1]	Includes a loss of $5.4 million from the disposal of KPC.

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Disclosure Supplemental Cash Flow Information Summary Of Supplemental Cash Flow Information [Abstract]
Cash paid for interest	$3,033	$2,780	$7,292
Cash paid for income taxes	12	100
Non-cash investing activity
Common stock issued for purchase of oil and gas properties	893	6,728
Property additions financed through accounts payable and accrued liabilities	3,597	1,010	239
Additions to property and equipment by recognizing asset retirement obligations	146	1,099	159
Non-cash financing activity
Common stock issued to fund 401K and deferred compensation plans	2,596	931
Common stock issued to repurchase and retire outstanding warrants		1,528
Common stock issued to repurchase and retire Series A preferred stock	$32,435

Recovered_Sheet3

Profit Sharing and Deferred Compensation Plans (Narrative) (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Defined Contribution Plan Disclosure [Line Items]
Maximum percentage of employee contribution to company	100.00%
Number of shares transferred to profit sharing plan	58,805	40,481
Shares issued to 401(k) plan	58,513	32,501
Forfeited shares already in the plan	292
Shares purchased on the open market		7,980
Year 1 [Member]
Defined Contribution Plan Disclosure [Line Items]
Vesting percentage of company contributions	33.00%
Year 2 [Member]
Defined Contribution Plan Disclosure [Line Items]
Vesting percentage of company contributions	67.00%
Year 3 [Member]
Defined Contribution Plan Disclosure [Line Items]
Vesting percentage of company contributions	100.00%
Minimum [Member]
Defined Contribution Plan Disclosure [Line Items]
Percentage of employee contribution to company	3.00%
Maximum [Member]
Defined Contribution Plan Disclosure [Line Items]
Percentage of employee contribution to company	6.00%

Profit_Sharing_And_Deferred_Co2

Profit Sharing And Deferred Compensation Plans (Profit Sharing Plan Expense) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Profit Sharing And Deferred Compensation Plans [Abstract]
401(k) profit sharing plan cost	$597	$662	$235

Profit_Sharing_And_Deferred_Co3

Profit Sharing And Deferred Compensation Plans (Schedule Of Deferred Compensation) (Details) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Profit Sharing And Deferred Compensation Plans [Abstract]
Shares of common stock contributed	155,308	32,452
Fair value of common stock contributed	$1,997	$473

Supplemental_Financial_Informa2

Supplemental Financial Information - Quarterly Financial Data (Schedule of Quarterly Financial Information) (Details) (USD $)	3 Months Ended															12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Total revenues	$18,807	$21,299		$21,596		$21,803		$18,039		$18,614		$19,594		$16,053		$83,505	$72,300	$54,995
Operating income (loss)	-1,072	80		222		703		-3,873	[1]	-1,679	[1]	-2,019	[1]	-3,727	[1]	-67	-11,298	-35,911
Net income (loss)	14,541	4,376		-7,445		-7,622		-10,756		-4,429		3,231		-11,412		3,850	-23,366	-58,893
Net income (loss) per common share
Basic	$2.37	$1.36		($2.34)		($2.46)		($3.84)		($1.77)		$1.32		($5.01)		$0.98	($9.32)	($43.30)
Diluted	$2.37	$1.35		($2.34)		($2.46)		($3.84)		($1.77)		$1.32		($5.01)		$0.98	($9.32)	($43.30)
As Reported [Member]
Total revenues		21,299		21,596		21,803		18,039		18,614		19,594		16,053
Operating income (loss)		80	[1]	222	[1]	703	[1]	-3,873	[1]	-1,679	[1]	-2,019	[1]	-3,727	[1]		-11,298	-35,911
Net income (loss)		$5,997		($5,988)		($6,323)		($7,377)		($645)		$6,880		($7,894)			($9,036)	($47,572)
Net income (loss) per common share
Basic		$1.36		($2.34)		($2.46)		($3.84)		($1.77)		$1.32		($5.01)			($9.32)	($43.30)
Diluted		$1.35		($2.34)		($2.46)		($3.84)		($1.77)		$1.32		($5.01)			($9.32)	($43.30)
[1]	Total revenue less total costs and expenses.

Restatement_Of_Previously_Issu2

Restatement Of Previously Issued Consolidated Financial Statements (Schedule Of Impact Of Restatement On Consolidated Balance Sheets) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Thousands, unless otherwise specified
Total Assets	$195,675	$183,082
Total Current Liabilities	16,612	17,795
Derivative financial instruments		1,796
Long-term debt	83,000	92,000
Mandatorily redeemable preferred stock, carrying value		83,994
Asset retirement obligations	13,884	13,099
Other	1	75
Total liabilities	177,451	208,759
Commitments and contingencies
Common stock	65	30
Additional paid-in capital	481,050	439,114
Treasury stock, at cost	-2,432	-512
Accumulated deficit	-460,459	-464,309
Total stockholders’ equity (deficit)	18,224	-25,677	-21,008	7,810
Total liabilities and stockholders’ equity (deficit)	195,675	183,082
As Reported [Member]
Total Assets		183,082
Total Current Liabilities		17,795
Derivative financial instruments		1,796
Long-term debt		92,000
Mandatorily redeemable preferred stock, carrying value		64,523
Asset retirement obligations		13,099
Other		75
Total liabilities		189,288
Commitments and contingencies
Series A Cumulative Redeemable Preferred Stock		23,828
Common stock		30
Additional paid-in capital		397,440
Treasury stock, at cost		-512
Accumulated deficit		-426,992
Total stockholders’ equity (deficit)		-30,034
Total liabilities and stockholders’ equity (deficit)		183,082
Adjustment [Member]
Mandatorily redeemable preferred stock, carrying value		19,471
Total liabilities		19,471
Commitments and contingencies
Series A Cumulative Redeemable Preferred Stock		-23,828
Additional paid-in capital		41,674
Accumulated deficit		-37,317
Total stockholders’ equity (deficit)		$4,357

Restatement_Of_Previously_Issu3

Restatement Of Previously Issued Consolidated Financial Statements (Schedule Of Impact Of Restatement On Consolidated Statements Of Operations) (Details) (USD $)	3 Months Ended															12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011	Dec. 31, 2010
Operating loss	($1,072)	$80		$222		$703		($3,873)	[1]	($1,679)	[1]	($2,019)	[1]	($3,727)	[1]	($67)		($11,298)		($35,911)
Other income (expense)
Realized gains (losses) from derivative financial instruments																-3,944	[2]	-2,271	[2]	73,162	[2]
Unrealized gains (loss) from derivative financial instruments																20,340		1,672		-66,708
Gain (loss) on investment																7,214		6,768		-5,174
Gain on forgiveness of debt																				255		1,600	2,900
Other income (expense), net																-17		12		111
Interest expense, net																-19,664		-18,069		-21,773
Total																3,929		-11,888		-20,127
Income (loss) from continuing operations before income taxes																3,862		-23,186		-56,038
Income taxes																12		180		0
Income (loss) from continuing operations																3,850		-23,366		-56,038
Income (loss) fromm discontinued operations																				-2,855
Net income (loss)	14,541	4,376		-7,445		-7,622		-10,756		-4,429		3,231		-11,412		3,850		-23,366		-58,893
Net income (loss) attributable to common stockholders																		-23,366		-58,893
Net income (loss) per common share
Basic income (loss) per share	$2.37	$1.36		($2.34)		($2.46)		($3.84)		($1.77)		$1.32		($5.01)		$0.98		($9.32)		($43.30)
Diluted income (loss) per share	$2.37	$1.35		($2.34)		($2.46)		($3.84)		($1.77)		$1.32		($5.01)		$0.98		($9.32)		($43.30)
Weighted average common shares outstanding
Basic																3,915,578	[3]	2,506,857	[3]	1,359,584	[3]
Diluted																3,947,917		2,506,857		1,359,584
As Reported [Member]
Operating loss		80	[1]	222	[1]	703	[1]	-3,873	[1]	-1,679	[1]	-2,019	[1]	-3,727	[1]			-11,298		-35,911
Other income (expense)
Realized gains (losses) from derivative financial instruments																		-2,271		73,162
Unrealized gains (loss) from derivative financial instruments																		1,672		-66,708
Gain (loss) on investment																		6,768		-5,174
Gain on forgiveness of debt																				255
Other income (expense), net																		12		111
Interest expense, net																		-3,739		-10,452
Total																		2,442		-8,806
Income (loss) from continuing operations before income taxes																		-8,856		-44,717
Income taxes																		180
Income (loss) from continuing operations																				-44,717
Income (loss) fromm discontinued operations																				-2,855
Net income (loss)		5,997		-5,988		-6,323		-7,377		-645		6,880		-7,894				-9,036		-47,572
Preferred stock dividends																		-11,047		-9,083
Accretion of redeemable preferred stock																		-3,283		-2,238
Net income (loss) attributable to common stockholders																		-23,366		-58,893
Net income (loss) per common share
Basic income (loss) per share		$1.36		($2.34)		($2.46)		($3.84)		($1.77)		$1.32		($5.01)				($9.32)		($43.30)
Diluted income (loss) per share		$1.35		($2.34)		($2.46)		($3.84)		($1.77)		$1.32		($5.01)				($9.32)		($43.30)
Weighted average common shares outstanding
Basic																		2,507,000		1,360,000
Diluted																		2,507,000		1,360,000
Adjustment [Member]
Other income (expense)
Interest expense, net																		-14,330		-11,321
Total																		-14,330		-11,321
Income (loss) from continuing operations before income taxes																		-14,330		-11,321
Income (loss) from continuing operations																				-11,321
Net income (loss)																		-14,330		-11,321
Preferred stock dividends																		11,047		9,083
Accretion of redeemable preferred stock																		$3,283		$2,238
[1]	Total revenue less total costs and expenses.
[2]	2012 includes $30.2 million received from exiting above market natural gas swap contracts originally scheduled for delivery in 2013.
[3]	Includes vested common shares in the Company’s deferred compensation plan and vested deferred restricted stock units, both of which will deliver shares to participants at a later date. Although shares have not been delivered on these awards, all conditions for issuance and delivery have been met. Pursuant to FASB ASC 260-10-45-13, such shares are to be included in the denominator in calculating basic earnings per share.

Supplemental_Information_on_Oi2

Supplemental Information on Oil and Gas Producing Activities (Narrative) (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Oil reserve portion percent reported	17.00%	23.00%	19.00%
SPP [Member]
Voting interest	20.00%	21.30%	26.50%

Supplemental_Information_on_Oi3

Supplemental Information on Oil and Gas Producing Activities (Aggregate Capitalized Costs Related to Oil and Gas Producing Activities) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Oil and gas properties and related equipment (successful efforts method)
Proved	$440,333	$405,895
Unproved	6,150	4,862
Net capitalized costs, gross	446,483	410,757
Accumulated depreciation, depletion and amortization	-293,243	-268,846
Net capitalized costs	153,240	141,911
SPP [Member]
Oil and gas properties and related equipment (successful efforts method)
Proved		135,642
Unproved		338
Materials, supplies and land		385
Net capitalized costs, gross		136,365
Accumulated depreciation, depletion and amortization		-105,481
Net capitalized costs		$30,884

Supplemental_Information_on_Oi4

Supplemental Information on Oil and Gas Producing Activities (Costs Incurred for Oil and Gas Property Acquisition, Exploration and Development Activities) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Proved property acquisition costs	$2,274	$8,023		$151
Unproved property acquisition costs	1,722	8,567		52
Exploration costs
Development costs	32,197	40,004		12,506
Costs incurred for oil and gas property acquisition, exploration and development activities that have been capitalized	36,193	56,594		12,709
SPP [Member]
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Proved property acquisition costs		4,262	[1]	20	[1]
Unproved property acquisition costs		45	[1]	47	[1]
Exploration costs			[1]		[1]
Development costs		3,343	[1]	4,064	[1]
Costs incurred for oil and gas property acquisition, exploration and development activities that have been capitalized		$7,650	[1]	$4,131	[1]
[1]	Based on the Company’s pro-rata interest in SPP (disclosed above) assuming that the Company’s investment was made at the beginning of the period. 2014 is not shown as the Company no longer has significant influence over SPP.

Supplemental_Information_on_Oi5

Supplemental Information on Oil and Gas Producing Activities (Pro-Rata Results of Oil and Gas Producing Activities of Investment in CEP) (Details) (SPP [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
SPP [Member]
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Revenues	$9,388	$12,330
Lease operating expense	4,017	5,144
Cost of sales and production taxes	864	780
Impairment of oil and gas properties	502	29
Depreciation, depletion and amortization	$4,041	$3,109

Supplemental_Information_on_Oi6

Supplemental Information on Oil and Gas Producing Activities (Changes in Proved Developed and Undeveloped Reserves) (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	Mcf	Mcf	Mcf
Natural Gas [Member]
Proved reserves
Beginning Balance	86,607,227	69,661,273	118,220,188
Purchase of reserves in place	8,257	98,822
Extensions, discoveries, and other additions	924,218	1,122,511	1,867,365
Sale of reserves	-349,615
Revisions of previous estimates	45,171,999	30,246,006	-34,037,402
Production	-13,228,274	-14,521,385	-16,388,878
Ending Balance	119,133,812	86,607,227	69,661,273
Proved developed reserves
Ending Balance	83,420,930	85,006,592	69,661,273
Oil [Member]
Proved reserves
Beginning Balance	4,380,603	2,691,568	1,073,921
Purchase of reserves in place	130,569	554,892
Extensions, discoveries, and other additions	533,124	1,911,959	617,854
Revisions of previous estimates	-635,313	-585,342	1,095,656
Production	-274,919	-192,474	-95,863
Ending Balance	4,134,064	4,380,603	2,691,568
Proved developed reserves
Ending Balance	2,532,821	2,705,664	1,804,057

Supplemental_Information_on_Oi7

Supplemental Information on Oil and Gas Producing Activities (Changes in Proved Developed and Undeveloped Reserves of SPP) (Details) (Natural Gas and Oil [Member], SPP [Member])	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
	Mcf	Mcf
Natural Gas and Oil [Member] | SPP [Member]
Reserve Quantities [Line Items]
Beginning Balance	24,640,000	53,151,000
Decrease in pro rata ownership	-4,835,000
Purchase of reserves in place	1,523,000
Extensions, discoveries, and other additions	1,028,000	543,000
Sale of reserves	-10,519,000	-68,000
Revisions of previous estimates	9,527,000	-25,551,000
Production	-1,927,000	-3,435,000
Ending Balance	19,437,000	24,640,000
Proved developed reserves
Ending Balance	16,748,000	23,850,000

Supplemental_Information_on_Oi8

Supplemental Information on Oil and Gas Producing Activities (Best Estimate of Required Data for Standardized Measure of Discounted Future Net Cash Flows) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
In Thousands, unless otherwise specified
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future cash inflows	$899,127	$720,924		$438,356
Future production costs	431,769	315,079		218,707
Future development costs.	96,472	49,590		31,051
Future income tax expense	29,830	30,149
Future net cash flows	341,056	326,106		188,598
10% annual discount for estimated timing of cash flows	161,095	156,977		86,516
Standardized measure of discounted future net cash flows related to proved gas reserves	179,961	169,129		102,082		175,520
SPP [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future cash inflows		107,103	[1]	95,619	[1]
Future production costs		48,418	[1]	51,462	[1]
Future development costs.		8,668	[1]	2,948	[1]
Future net cash flows		50,017	[1]	41,209	[1]
10% annual discount for estimated timing of cash flows		19,406	[1]	17,446	[1]
Standardized measure of discounted future net cash flows related to proved gas reserves		30,611	[1],[2]	23,763	[1],[2]	42,423	[2]
Continuing Operations [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Standardized measure of discounted future net cash flows related to proved gas reserves	179,961	169,129		102,082
Continuing Operations [Member] | SPP [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Standardized measure of discounted future net cash flows related to proved gas reserves		30,611	[1],[2]	16,021	[1],[2]
Discontinued Operations [Member] | SPP [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Standardized measure of discounted future net cash flows related to proved gas reserves				$7,742	[1],[2]
[1]	Represents the Company’s pro-rata share of its investment in SPP. 2014 is not shown as the Company no longer has significant influence over SPP.
[2]	Represents the Company’s pro-rata share of its investment in SPP assuming that the Company’s investment was made at the beginning of each period presented.

Supplemental_Information_on_Oi9

Supplemental Information on Oil and Gas Producing Activities (Discounted Future Cash Flow Estimates do not Include Effects of Derivative Instruments) (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Crude Oil and NGL [Member]
Average Sales Price and Production Costs Per Unit of Production [Line Items]
Average sales price	94.99	96.94	95.05
Natural Gas, Per Thousand Cubic Feet [Member]
Average Sales Price and Production Costs Per Unit of Production [Line Items]
Average sales price	4.35	3.67	2.76

Recovered_Sheet4

Supplemental Information on Oil and Gas Producing Activities (Principal Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proven Oil and Gas Properties) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Beginning balance	$169,129		$102,082		$175,520
Net changes in prices and production costs	-18,101		37,826		18,071
Net changes in future development costs.	-41,958		-30,462		-18,008
Previously estimated development costs incurred	32,635		40,196		12,743
Sales of oil and gas produced, net	-39,919		-29,604		-10,338
Extensions and discoveries	7,070		23,514		7,724
Purchases of reserves in-place	1,358		6,401
Sales of reserves in-place	-600
Revisions of previous quantity estimates	70,928		49,926		-38,064
Net change in income taxes	-1,674		-7,769
Accretion of discount	16,618		8,975		16,730
Timing differences and other	-15,525	[1]	-31,956	[1]	-62,296	[1]
Ending balance	179,961		169,129		102,082
Standardized measure of discounted future net cash flows related to proved gas reserves	179,961		169,129		102,082
SPP [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Beginning balance			23,763	[2],[3]	42,423	[2]
Net changes in prices and production costs			10,741	[2]	-5,095	[2]
Decrease in pro rata ownership			-4,664	[2]
Previously estimated development costs incurred			1,196	[2]	4,987	[2]
Sales of oil and gas produced, net			-4,525	[2]	-10,520	[2]
Extensions and discoveries			6,069	[2]	3,336	[2]
Sales of reserves in-place			-489	[2]	-391	[2]
Revisions of previous quantity estimates			4,570	[2]	-22,034	[2]
Accretion of discount			1,910	[2]	4,258	[2]
Timing differences and other			-7,960	[1],[2]	6,799	[1],[2]
Ending balance			30,611	[2],[3]	23,763	[2],[3]
Standardized measure of discounted future net cash flows related to proved gas reserves			30,611	[2],[3]	23,763	[2],[3]
Continuing Operations [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Ending balance	179,961		169,129		102,082
Standardized measure of discounted future net cash flows related to proved gas reserves	179,961		169,129		102,082
Continuing Operations [Member] | SPP [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Ending balance			30,611	[2],[3]	16,021	[2],[3]
Standardized measure of discounted future net cash flows related to proved gas reserves			30,611	[2],[3]	16,021	[2],[3]
Discontinued Operations [Member] | SPP [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Ending balance					7,742	[2],[3]
Standardized measure of discounted future net cash flows related to proved gas reserves					$7,742	[2],[3]
[1]	The change in timing differences and other are related to revisions in the Company’s estimated time of production and development and the impact of changes in the relative proportion of oil versus natural gas in the Company’s total reserves.
[2]	Represents the Company’s pro-rata share of its investment in SPP assuming that the Company’s investment was made at the beginning of each period presented.
[3]	Represents the Company’s pro-rata share of its investment in SPP. 2014 is not shown as the Company no longer has significant influence over SPP.