GeoMet 10-K 17 Feb 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	Feb. 01, 2015	Jun. 30, 2014
Document and Entity Information
Entity Registrant Name	GeoMet, Inc.
Entity Central Index Key	1352302
Document Type	10-K
Document Period End Date	31-Dec-14
Amendment Flag	FALSE
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Smaller Reporting Company
Entity Public Float			$0.50
Entity Common Stock, Shares Outstanding		40,513,373
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2014	Dec. 31, 2013
Current Assets:
Cash and cash equivalents	$22,894,405	$8,108,272
Accounts receivable, net of allowance of $0 and $14,744 at December 31, 2014 and December 31, 2013, respectively		2,900,807
Other current assets	148,302	692,740
Total current assets	23,042,707	11,701,819
Natural gas properties-utilizing the full cost method of accounting:
Proved natural gas properties		333,109,974
Other property and equipment		3,158,701
Total property and equipment		336,268,675
Less accumulated depreciation, depletion, amortization and impairment of gas properties		-293,939,624
Property and equipment-net		42,329,051
Other noncurrent assets		769,384
TOTAL ASSETS	23,042,707	54,800,254
Current Liabilities:
Accounts payable	152,258	3,541,770
Royalties payable		3,656,272
Accrued liabilities	123,092	1,073,653
Income tax payable	2,543
Derivative liability-natural gas contracts		834,151
Asset retirement obligations		265,470
Current portion of long-term debt		71,550,000
Total current liabilities	277,893	80,921,316
Asset retirement obligations		8,915,407
Derivative liability-natural gas contracts		709,571
Other long-term accrued liabilities		113,434
TOTAL LIABILITIES	277,893	90,659,728
Mezzanine equity:
Series A Convertible Redeemable Preferred Stock-net of offering costs of $1,660,435; redemption amount $67,863,340; $.001 par value; 7,401,832 shares authorized, 6,786,334 and 6,000,571 shares were issued and outstanding at December 31, 2014 and December 31, 2013, respectively	48,676,221	43,404,993
Stockholders' Deficit:
Preferred stock, $0.001 par value-2,598,168 shares authorized, none issued
Common stock, $0.001 par value-authorized 125,000,000 shares; 40,523,805 issued and 40,513,373 outstanding at September 30, 2014 and 40,662,749 issued and 40,652,317 outstanding at December 31, 2013	40,524	40,663
Treasury stock, at cost-10,432 shares at December 31, 2014 and December 31, 2013	-94,424	-94,424
Paid-in capital	182,275,243	187,527,716
Retained deficit	-208,132,750	-266,738,422
Balance	-25,911,407	-79,264,467
TOTAL LIABILITIES, MEZZANINE AND STOCKHOLDERS' DEFICIT	$23,042,707	$54,800,254

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
CONSOLIDATED BALANCE SHEETS
Accounts receivable, allowance (in dollars)	$0	$14,744
Series A Convertible Redeemable Preferred Stock, offering costs (in dollars)	1,660,435	1,660,435
Series A Convertible Redeemable Preferred Stock, redemption amount (in dollars)	$67,863,340	$67,863,340
Series A Convertible Redeemable Preferred Stock, par value (in dollars per share)	$0.00	$0.00
Series A Convertible Redeemable Preferred Stock, shares authorized	7,401,832	7,401,832
Series A Convertible Redeemable Preferred Stock, shares issued	6,786,334	6,000,571
Series A Convertible Redeemable Preferred Stock, shares outstanding	6,786,334	6,000,571
Preferred stock, par value (in dollars per share)	$0.00	$0.00
Preferred stock, shares authorized	2,598,168	2,598,168
Preferred stock, shares issued	0	0
Common stock, par value (in dollars per share)	$0.00	$0.00
Common stock, shares authorized	125,000,000	125,000,000
Common stock, shares issued	40,523,805	40,662,749
Common stock, shares outstanding	40,513,373	40,652,317
Treasury stock, shares	10,432	10,432

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Expenses:
Depreciation, depletion and amortization	$113,817	$125,897
General and administrative	3,846,142	5,011,645
Lease termination costs	427,722
Restructuring costs		93,584
Total operating expenses	4,387,681	5,231,126
Operating loss	-4,387,681	-5,231,126
Other expense	-14,966	-227,082
Loss before income taxes from continuing operations	-4,402,647	-5,458,208
Income tax expense	25,000	25,000
Loss from continuing operations	-4,427,647	-5,483,208
Discontinued operations, net of tax expense of $652,543 and $0 for the years ended December 31, 2014 and 2013, respectively	63,033,319	40,802,282
Net income	58,605,672	35,319,074
Accretion of Series A Convertible Redeemable Preferred Stock	-2,964,762	-2,257,968
PIK dividends on Series A Convertible Redeemable Preferred Stock	-2,306,466	-5,295,138
Cash dividends paid on Series A Convertible Redeemable Preferred Stock	-1,960	-2,572
Net income available to common stockholders	$53,332,484	$27,763,396
Net (loss) income per common share-basic:
Net loss per common share from continuing operations (in dollars per share)	($0.24)	($0.32)
Net income per common share from discontinued operations (in dollars per share)	$1.56	$1.01
Net (loss) income per common share-basic (in dollars per share)	$1.32	$0.69
Net (loss) income per common share-diluted:
Net loss per common share from continuing operations (in dollars per share)	($0.24)	($0.32)
Net income per common share from discontinued operations (in dollars per share)	$1.56	$1.01
Net (loss) income per common share-diluted (in dollars per share)	$1.32	$0.69
Weighted average number of common shares:
Basic	40,513,373	40,481,330
Diluted (in shares)	40,513,373	40,481,330

CONSOLIDATED_STATEMENT_OF_OPER

CONSOLIDATED STATEMENT OF OPERATIONS (parenthetical) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
CONSOLIDATED STATEMENTS OF OPERATIONS
Discontinued Operation, Tax Effect of Discontinued Operation	$652,543	$0

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
Net income	$58,605,672	$35,319,074
Foreign currency translation adjustment		-10,182
Reclassification adjustment for loss on foreign currency translation included in net income		1,541
Unrealized loss on available for sale securities		-90,567
Reclassification adjustment for impairment of variable for sale securities included in net income		152,228
Other comprehensive income	$58,605,672	$35,372,094

CONSOLIDATED_STATEMENTS_OF_STO

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (USD $)	Common Stock [Member]	Treasury Stock [Member]	Additional Paid In Capital [Member]	Accumulated Other Comprehensive Income [Member]	Retained Earnings [Member]	Notes Receivable [Member]	Total
Balance at Dec. 31, 2012	$40,690	($94,424)	$195,033,585	($53,020)	($302,057,496)	($182,924)	($107,313,589)
Balance (in shares) at Dec. 31, 2012	40,690,077
Activity related to common stock (Number of Shares)
Stock-based compensation			232,760				232,760
Stock-based compensation (in shares)	121
Purchase and cancellation of common stock			-27				-27
Shares of restricted stock forfeited upon termination of employment	-3						-3
Shares of restricted stock forfeited upon termination of employment (in shares)	-2,779
Dividends paid in-kind			-5,295,138				-5,295,138
Dividends paid in cash			-2,572				-2,572
Accretion of Series A Convertible Redeemable Preferred Stock			-2,257,968				-2,257,968
Write-off of notes receivable	-24		-183,208			183,208	-24
Write-off of notes receivable (in shares)	24,428
Accrued interest on notes receivable			284			-284
Net income (loss)					35,319,074		35,319,074
Unrealized loss on available for sale securities				-90,567			-90,567
Foreign currency translation adjustment, net of income taxes of $0				-10,182			-10,182
Reclassification adjustment for loss on foreign currency translation				1,541			1,541
Reclassification adjustment for impairment of variable for sale securities				-152,228			-152,228
Balance at Dec. 31, 2013	40,663	-94,424	187,527,716		-266,738,422		-79,264,467
Balance (in shares) at Dec. 31, 2013	40,662,749
Activity related to common stock (Number of Shares)
Stock-based compensation			20,576				20,576
Shares of restricted stock forfeited upon termination of employment	-139		139
Shares of restricted stock forfeited upon termination of employment (in shares)	-138,944
Dividends paid in-kind			-2,306,466				-2,306,466
Dividends paid in cash			-1,960				-1,960
Accretion of Series A Convertible Redeemable Preferred Stock			-2,964,762				-2,964,762
Net income (loss)					58,605,672		58,605,672
Balance at Dec. 31, 2014	$40,524	($94,424)	$182,275,243		($208,132,750)		($25,911,407)
Balance (in shares) at Dec. 31, 2014	40,523,805

CONSOLIDATED_STATEMENTS_OF_STO1

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) (USD $)	12 Months Ended
	Dec. 31, 2013
Income tax (benefit) expense	$25,000
Available For Sale Securities [Member]
Income tax (benefit) expense	0
Foreign Currency Translation Adjustment [Member]
Income tax (benefit) expense	$0

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Cash flows (used in) provided by operating activities:
Loss from continuing operations	($4,427,647)	($5,483,208)
Adjustments to reconcile loss from continuing operations to net cash flows used in continuing operating activities:
Depreciation, depletion and amortization	113,817	125,897
Impairment of available for sale securities		153,769
Stock-based compensation	20,576	232,760
Changes in operating assets and liabilities:
Other current assets	273,858	-41,677
Accounts payable	-547,942	-116,884
Other accrued liabilities	-171,564	-26,881
Net cash used in continuing operating activities	-4,738,894	-5,156,224
Income from discontinued operations	63,033,311	40,802,282
Adjustments to reconcile Income from discontinued operations to net cash flows (used in) provided by discontinued operating activities:
Depreciation, depletion and amortization	715,892	4,468,196
Amortization of debt issuance costs	218,357	912,481
Unrealized losses from the change in market value of open derivative contracts	-1,543,722	2,917,569
Gain on the sale of gas properties	-62,455,861	-36,948,313
Loss on sale of other assets	22,706	107,519
Accretion expense	298,130	1,035,717
Changes in operating assets and liabilities:
Accounts receivable	3,191,408	3,732,313
Other current assets	617,790	-234,441
Accounts payable	-6,333,487	-2,174,456
Income taxes payable	2,543
Other accrued liabilities	-3,808,084	-664,835
Net cash (used in) provided by discontinued operating activities	-6,041,017	13,954,032
Net cash (used in) provided by operating activities	-10,779,911	8,797,808
Continuing operations:
Proceeds from the sale of other assets	140,000
Net cash provided by investing activities- continuing operations	140,000
Discontinued operations:
Capital expenditures	-108,597	-919,412
Proceeds from the sale of gas properties	97,061,090	60,732,775
Proceeds from sale of other assets	25,511	19,276
Net cash provided by investing activities - discontinued operations	96,978,004	59,832,639
Net cash provided by investing activities	97,118,004	59,832,639
Continuing operation:
Dividends paid	-1,960	-2,572
Treasury stock		-27
Net cash used in financing activities- continuing operations	-1,960	-2,599
Discontinued operations:
Repayment of borrowings under Credit Agreement	-71,550,000	-67,750,000
Deferred financing costs		-3,801
Net cash used in financing activities - discontinued operations	-71,550,000	-67,753,801
Net cash used in financing activities	-71,551,960	-67,756,400
Increase in cash and cash equivalents	14,786,133	874,047
Cash and cash equivalents at beginning of period	8,108,272	7,234,225
Cash and cash equivalents at end of period	22,894,405	8,108,272
Supplemental disclosure of cash flow information:
Interest expense	1,448,385	5,208,800
Income taxes	675,000	25,000
Significant noncash investing and financing activities:
Accrued capital expenditures		26,546
Increase in estimated asset retirement obligations	($5,789)	$453,660

Organization_and_Our_Business

Organization and Our Business	12 Months Ended
	Dec. 31, 2014
Organization and Our Business
Organization and Our Business
	Note 1—Organization and Our Business
	GeoMet, Inc. (the “Company,” “GeoMet,” “we,” “us” or “our”) (formerly GeoMet Resources, Inc.) was incorporated under the laws of the state of Delaware on November 9, 2000.
	Prior to the completion of the sale of substantially all of our remaining assets on May 12, 2014, we were engaged in the exploration, development and production of natural gas from coal seams (“coalbed methane” or “CBM”). All of our production was CBM, which is a dry natural gas containing no hydrocarbon liquids. We were originally founded as a consulting company to the coalbed methane industry in 1985 and were active as an operator, developer and producer of coalbed methane properties since 1993. Our principal operations and producing properties were located in the Central Appalachian Basin in Virginia and West Virginia.
	From May 13, 2014 through August 15, 2014, we provided transition services to ARP Mountaineer Production, LLC, a Delaware limited liability company (the “Buyer”), purchaser of certain of our assets, while simultaneously working toward the completion of the final purchase price adjustment described in Note 4—Sale of our Central Appalachian Assets and Termination of Credit Agreement. On August 15, 2014, we became a “shell company” as defined by Rule 12b-2 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), because we no longer had operations and our assets consisted of cash and nominal other assets.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Summary of Significant Accounting Policies
Summary of Significant Accounting Policies
	Note 2—Summary of Significant Accounting Policies
	Principles of Consolidation—The accompanying Consolidated Financial Statements are presented in conformity with accounting principles generally accepted in the United States of America (“GAAP”) and include our accounts and the accounts of our wholly-owned subsidiaries, GeoMet Operating Company, Inc., an Alabama corporation, and GeoMet Gathering Company LLC, an Alabama limited liability company. All inter-company accounts and transactions have been eliminated in consolidation.
	Use of Estimates in the Preparation of Financial Statements—The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Our most significant financial estimates are related to computing taxes. Actual results could differ from these estimates.
	Cash and Cash Equivalents—For purposes of these statements, short-term investments, which have an original maturity of three months or less, are considered cash equivalents.
	Income Taxes—We record our income taxes using an asset and liability approach in accordance with GAAP. This results in the recognition of deferred tax assets and liabilities for the expected future tax consequences of temporary differences between the book carrying amounts and the tax basis of assets and liabilities using enacted tax rates at the end of the period. Under GAAP, 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. As of December 31, 2014, a full valuation allowance has been recorded against our net deferred tax asset.
	Estimating the amount of valuation allowance is dependent on estimates of future taxable income, alternative minimum tax income, and changes in stockholder ownership that could trigger limits on use of net operating losses under Section 382 of the Internal Revenue Code of 1986, as amended (the “Code”). We have a significant deferred tax asset associated with net operating loss carryforwards (“NOLs”).
	GAAP also clarifies the accounting for uncertainty in income taxes recognized in an entity’s financial statements and prescribes a consistent threshold and measurement attribute for financial statement recognition and disclosure of tax positions taken, or expected to be taken, on a tax return.
	Revenue Recognition and Gas Balancing—Through May 12, 2014, we derived revenue primarily from the sale of produced natural gas. We used the sales method of accounting for the recognition of gas revenue whereby revenues, net of royalties, were recognized as the production was sold to a purchaser. The amount of gas sold may have differed from the amount to which the Company was entitled based on its working interest or net revenue interest in the properties. In instances where we had wellhead imbalances, we used the entitlements method. A ready market for natural gas allowed us to sell our natural gas shortly after production at various pipeline receipt points at which time title and risk of loss transferred to the buyer. Revenue was recorded when title was transferred based on our nominations and net revenue interests. Pipeline imbalances occurred when our production delivered into the pipeline varied from the gas we nominated for sale. Depending on the agreement in place, imbalances may have been made up in future production or settled with cash approximately 30 days from date of production. Imbalances were recorded as either a reduction or increase of revenue depending upon whether we are over-delivered or under-delivered.
	Settlements of gas sales occurred after the month in which the gas was produced. We estimated and accrued for the value of the sales using information available at the time financial statements were generated. Differences were reflected in the accounting period during which payments were received from the purchaser.
	Industry Segment and Geographic Information— On August 15, 2014, we became a “shell company” as defined by Rule 12b-2 of the Exchange Act because we no longer had operations.
	Concentration of Credit Risk—The Company maintains deposits in financial institutions which are insured by the Federal Deposit Insurance Corporation (“FDIC”). At various times, the Company has deposits in these financial institutions in excess of the amount insured by the FDIC.
	Mezzanine Equity—Our Series A Convertible Redeemable Preferred Stock has been classified within the mezzanine (temporary) equity section of the Consolidated Balance Sheets because the shares are redeemable at the option of the holder and therefore do not qualify for permanent equity.
	Fair Value Measurement—The fair value of cash and cash equivalents, current assets and payables, approximate book value because of the short maturity of these accounts.

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncement	12 Months Ended
	Dec. 31, 2014
Recent Pronouncement
Recent Pronouncement
	Note 3—Recent Accounting Pronouncement
	In April 2014, the Financial Accounting Standards Board (“FASB”), issued Accounting Standards Update (“ASU”), No. 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The ASU changes the requirements for reporting discontinued operations in Subtopic 205-20. A discontinued operation may include a component of an entity or a group of components of an entity. A disposal of a component of an entity or a group of components of an entity is required to be reported in discontinued operations if the disposal represents a strategic shift that has (or will have) a major effect on an entity’s operations and financial results when an entity meets the criteria to be classified as held for sale, the component of an entity or group of components of an entity is disposed of by sale, or the component of an entity or group of components of an entity is disposed of other than by sale. ASU 2014-08 should be applied when any of these occur within annual periods beginning on or after December 15, 2014. Early adoption is permitted; however, the Company elected not to early adopt the ASU. The ASU requires entities to separately present assets and liabilities of a discontinued operation for all periods presented in the balance sheet. The impact of adopting the ASU would be the reclassification of all of the assets related to our operations as Assets held for sale and all related liabilities as Liabilities held for sale, both in our Consolidated Balance Sheet (Unaudited) as of December 31, 2013.
	In August 2014, the FASB issued ASU, No. 2014-15, Presentation of Financial Statements—Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. The ASU provides guidance on determining when and how reporting entities must disclose going-concern uncertainties in their financial statements. The new standard requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date of issuance of the entity’s financial statements (or within one year after the date on which the financial statements are available to be issued, when applicable). Further, an entity must provide certain disclosures if there is “substantial doubt about the entity’s ability to continue as a going concern.” The ASU is effective for annual periods ending after December 15, 2016, and interim periods thereafter and early adoption is permitted. The Company does not expect the adoption of this amendment to have a material impact on its consolidated financial statements.

Sale_of_our_Central_Appalachia

Sale of our Central Appalachian Assets and Termination of Credit Agreement	12 Months Ended
	Dec. 31, 2014
Sale of our Central Appalachian Assets and Termination of Credit Agreement
Sale of our Central Appalachian Assets and Termination of Credit Agreement
	Note 4—Sale of our Central Appalachian Assets and Termination of Credit Agreement
	On May 12, 2014, we closed the sale of substantially all of our remaining assets which consisted of coalbed methane interests and other assets located in the Appalachian Basin in McDowell, Harrison, Wyoming, Raleigh, Barbour and Taylor Counties, West Virginia and Buchanan County, Virginia (the “Asset Sale”) to the Buyer, a wholly-owned subsidiary of Atlas Resource Partners, L.P., a Delaware limited partnership. The purchase price of $107.0 million was adjusted downward $9.7 million to account for purchase price adjustments, resulting in net proceeds of $97.3 million.
	Immediately following the closing of the Asset Sale, GeoMet, Bank of America, N.A., as administrative agent (the “Administrative Agent”), and the financial institutions party thereto terminated the Fifth Amended and Restated Credit Agreement, dated as of October 14, 2011, by and among GeoMet, the Administrative Agent, the financial institutions party thereto as lenders and the other agents party thereto (as amended, restated, supplemented or otherwise modified from time to time, the “Credit Agreement”). Immediately prior to termination of the Credit Agreement, we repaid all amounts owed to the lenders party to the Credit Agreement, which amounts totaled $69.1 million. As a result, we satisfied all of our obligations under the Credit Agreement. We were not required to pay a termination penalty or other fee in connection with the termination of the Credit Agreement.
	Additionally, we settled all of our remaining outstanding natural gas hedge positions for approximately $3.1 million.

Results_of_Discontinued_Operat

Results of Discontinued Operations	12 Months Ended
	Dec. 31, 2014
Results of Discontinued Operations
Results of Discontinued Operations	Note 5—Results of Discontinued Operations
	As a result of the Asset Sale, all operating activities are presented as discontinued operations in the Consolidated Statements of Operations (Unaudited) for the year ended December 3, 2014 and 2013 as follows:
		2014			2013
	Revenues:
	Gas sales	$	13,645,825		$	38,086,539
	Other	27,505			122,844
	Total revenues	13,673,330			38,209,383
	Expenses:
	Lease operating expense	3,924,356			13,131,855
	Compression and transportation expense	2,713,296			7,716,864
	Production taxes	817,531			2,096,598
	Lease termination costs	300,000			—
	Depreciation, depletion and amortization	715,892			4,468,196
	Losses on natural gas derivatives	2,753,190			1,811,191
	Total operating expenses	11,224,265			29,224,704
	Gain on the sale of assets	62,455,861			36,948,313
	Operating income	64,904,926			45,932,992
	Interest income	4,284			1,714
	Interest expense	(1,223,348		)	(5,132,424		)
	Income tax expense	(652,543		)	—
	Income from discontinued operations	$	63,033,319		$	40,802,282

Gain_on_the_Sale_of_Assets

Gain on the Sale of Assets	12 Months Ended
	Dec. 31, 2014
Gain on the Sale of Assets
Gain on the Sale of Assets	Note 6— Gain on the Sale of Assets
	The total gain on sale of assets for the year ended December 31, 2014 as presented above includes the following:
			Sale to ARP			Other Sales			Total Gain
			Mountaineer
			Productions, LLC
	Cash proceeds		$	97,307,961		$	(246,871	)	$	97,061,090
	Buyer’s assumption of asset retirement obligations		8,027,899			1,253,198			9,281,097
	Buyer’s assumption of other liabilities		3,628,304			104,934			3,733,238
	Net book value of sold gas properties		(41,332,191		)	—			(41,332,191		)
	Net book value of sold equipment		(198,875		)	—			(198,875		)
	Transaction costs		(6,085,348		)	(3,150		)	(6,088,498		)
	Total gain on sale		$	61,347,750		$	1,108,111		$	62,455,861
	Current year operating losses generated in the normal course of business are less than the estimated taxable gain from the Asset Sale.  However, no regular income tax is expected to result from the Asset Sale as we estimate sufficient net operating losses will be available from prior years to offset the estimated taxable gain, resulting in a reduction of our deferred tax asset and the related valuation allowance of $23.2 million. We are subject to a federal alternative minimum tax and have estimated that amount to be $652,543 for 2014. In 2014, we made estimated payments of $650,000 and $2,543 remains as a payable recorded in the Consolidated Balance Sheet as of December 31, 2014.
	On June 14, 2013, the Company closed the sale of all of its coalbed methane properties located in the state of Alabama. The sale resulted in proceeds of approximately $62.0 million after purchase price adjustments of $1.2 million to account for net cash flows from the effective date to the closing date. Approximately $58.8 million was used to repay outstanding borrowings under our Credit Agreement and $3.2 million was used to pay transaction related costs and expenses, including the liquidation of certain natural gas hedge positions.
	The total gain on sale of assets for the year ended December 31, 2013 as presented above includes the following:
	Cash proceeds		$	62,007,639
	Buyer’s assumption of asset retirement obligations		4,411,201
	Buyer’s assumption of other liabilities		164,108
	Net book value of sold natural gas properties		(27,998,835		)
	Net book value of sold inventory		(133,732		)
	Net book value of sold equipment		(108,642		)
	Transaction costs		(1,120,654		)
	Post-closing purchase price adjustments (1)		(272,772		)
	Total gain on sale		$	36,948,313
		-1		Post-closing purchase price adjustments results from actual operating revenues and expenses realized related to properties sold that differed from the amounts estimated at the time of closing.
	No federal or state income taxes payable were recorded in conjunction with the sale of the Alabama properties which was the result of 2013 tax basis operating losses generated in the normal course of business that were available to offset the taxable gain.

Pro_Forma_Financial_Informatio

Pro Forma Financial Information	12 Months Ended
	Dec. 31, 2014
Pro Forma Financial Information
Pro Forma Financial Information
	Note 7— Pro Forma Financial Information
	Pro forma adjustments related to the unaudited pro forma financial information presented below were computed assuming the asset sales completed in June 2013 and May 2014 were both consummated on January 1, 2013 and include adjustments which give effect to events that are (i) directly attributable to the asset sales, (ii) expected to have a continuing impact on the registrant and (iii) factually supportable. As such, included in Net income (loss), Net income (loss) available to common stockholders and Net income (loss) per common share (basic and diluted) for the year ended December 31, 2013 are the gains on the asset sales completed in June 2013 and May 2014 of $36,948,313 and $62,455,853, respectively.
		2014			2013
	Revenue	$	—		$	—
	Loss from continuing operations	$	(4,427,647	)	$	(5,483,208	)
	Net (loss) income	$	(4,427,647	)	$	93,268,423
	Net (loss) income available to common stockholders	$	(9,700,835	)	$	85,712,745
	Net (loss) income per common share—basic	$	(0.24	)	$	2.12
	Net (loss) income per common share—diluted	$	(0.24	)	$	2.12

Net_Income_Per_Common_Share

Net Income Per Common Share	12 Months Ended
	Dec. 31, 2014
Net (Loss) Income Per Common Share
Net (Loss) Income Per Common Share
	Note 8—Net Income Per Common Share
	Net income per common share—basic is calculated by dividing Net income available to common stockholders by the weighted average number of shares of Common Stock, par value $0.001 per share (the “Common Stock”), outstanding during the period. Net income per common share—diluted assumes the conversion of all potentially dilutive securities and is calculated by dividing Net income available to common stockholders by the sum of the weighted average number of shares of Common Stock outstanding plus potentially dilutive securities. Net income per common share—diluted considers the impact of potentially dilutive securities except in periods in which there is a loss because the inclusion of the potential shares of Common Stock would have an anti-dilutive effect. A reconciliation of Net income per common share for the years ended December 31, 2014 and 2013 is as follows:
		2014			2013
	Net income	$	58,605,672		$	35,319,074
	Accretion of Series A Convertible Redeemable Preferred Stock	(2,964,762		)	(2,257,968
	PIK dividends on Series A Convertible Redeemable Preferred Stock	(2,306,466		)	(5,295,138
	Cash dividends paid on Series A Convertible Redeemable Preferred Stock	(1,960		)	(2,572
	Net income available to common stockholders —basic and diluted	$	53,332,484		$	27,763,396
	Net income per common share—basic and diluted:
	Net loss per common share from continuing operations	$	(0.24	)	$	(0.32	)
	Net income per common share from discontinued operations	1.56			1.01
	Net income per common share—basic and diluted	$	1.32		$	0.69
	Weighted average number of common shares:
	Basic and diluted	40,513,373			40,481,330
	Net income per common share—diluted for the year ended December 31, 2014 excluded the effect of 6,291,671 weighted average shares of Preferred Stock, par value $0.001 per share (“Preferred Stock”) (48,397,468 in dilutive shares, as converted, which assumes conversion on the later of the first day of the period or date of issuance), because we reported Loss from continuing operations which caused the options, restricted shares and the Preferred Stock to be anti-dilutive. Additionally, in computing the dilutive effect of convertible securities, Net income available to common stockholders is also adjusted to add back any convertible preferred dividends and accretion unless the shares of Preferred Stock are anti-dilutive. As such, there was no add back to Net income available to common stockholders for the year ended December 31, 2014 for accretion of and dividends paid for Preferred Stock of $2,964,762 and $2,306,466, respectively, in computing Net income per common share—diluted as the shares of Preferred Stock were anti-dilutive.
	Net income per common share—diluted for the year ended December 31, 2013 excluded the effect of outstanding options exercisable to purchase 1,574,198 shares, 116,553 weighted average restricted stock units for which common shares are distributed upon achievement of certain performance targets, 193,045 weighted average restricted shares outstanding, and 5,562,319 weighted average shares of Preferred Stock 42,787,068 in dilutive shares, as converted, which assumes conversion on the later of the first day of the period or date of issuance) because we reported Loss from continuing operations which caused the options, restricted shares and the Preferred Stock to be anti-dilutive. Additionally, in computing the dilutive effect of convertible securities, Net income available to common stockholders is also adjusted to add back any convertible preferred dividends and accretion unless the shares of Preferred Stock are anti-dilutive. As such, there was no add back to Net income available to common stockholders for the year ended December 31, 2013 for accretion of and dividends paid for Preferred Stock of $2,257,968 and $5,295,138, respectively, in computing Net income per common share—diluted as the shares of Preferred Stock were anti-dilutive.

Gas_Properties

Gas Properties	12 Months Ended
	Dec. 31, 2014
Gas Properties
Gas Properties
	Note 9—Gas Properties
	As described in Note 4—Sale of our Central Appalachian Assets and Termination of Credit Agreement, on May 12, 2014, we sold substantially all of our remaining assets. Prior to the Asset Sale, the method of accounting for oil and gas producing activities determines what costs are capitalized and how these costs are ultimately matched with revenues and expenses. We use the full cost method of accounting for natural gas properties as prescribed by the SEC. Under this method, all direct costs and certain indirect costs associated with the acquisition, exploration, and development of our natural gas properties are capitalized.
	Natural 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 gas reserves.
	Estimation of proved gas reserves involves professional judgment and use of factors that cannot be precisely determined. Subsequent proved reserve estimates materially different from those reported would change the depletion expense recognized during future reporting periods. No gains or losses are recognized upon the sale or disposition of natural gas properties unless the sale or disposition represents a significant quantity of gas reserves, which would have a significant impact on the depreciation, depletion and amortization rate.
	Under full cost accounting rules, total capitalized costs are limited to a ceiling equal to the present value of estimated future net revenues, discounted at 10% per annum, plus cost of properties not being amortized plus the lower of cost or fair value of unevaluated properties less income tax effects (the “ceiling limitation”). We perform a quarterly ceiling test to evaluate whether the net book value of our 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 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 ceiling test is calculated using the unweighted arithmetic average of the natural gas price on the first day of each month within the twelve-month period prior to the end of the reporting period, unless prices are defined by contractual arrangements, excluding escalations based on future conditions, as allowed by the guidelines of the SEC. In addition, subsequent to the adoption of ASC 410-20-25, the future cash outflows associated with settling asset retirement obligations were not included in the computation of the discounted present value of future net revenues for the purposes of the ceiling test calculation.
	For the year ended December 31, 2014, no ceiling test calculation was required. For the year ended December 31, 2013, the unweighted arithmetic average of the Henry Hub spot market price on the first day of each month was $3.69 per Mcf, resulting in a natural gas price of $3.75 per Mcf when adjusted for regional price differentials. For the year ended December 31, 2013, no write-downs of the carrying value of our full cost pool were recorded.
	The following table provides a summary of the capitalized cost of our natural gas properties as of December 31, 2014 and 2013, by the year in which the costs were incurred.
		2014		2013
	Subject to depletion	$	—	$	333,109,974
	Total not subject to depletion	—		—
	Gross natural gas properties	—		333,109,974
	Less impairment of natural gas properties	—		(241,964,803		)
	Less accumulated depletion	—		(49,161,150		)
	Net natural gas properties	$	—	$	41,984,021

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligations
Asset Retirement Obligations
	Note 10—Asset Retirement Obligations
	We record an asset retirement obligation (“ARO”) on the consolidated balance sheet and capitalize the asset retirement costs in natural gas properties in the period in which the retirement obligation is incurred. The amount of the ARO and the costs capitalized are equal to the estimated future costs to satisfy the obligation using current prices that are escalated by an assumed inflation factor up to the estimated settlement date, which is then discounted back to the date the abandonment obligation was incurred using an assumed cost of funds for GeoMet. Once the ARO is recorded, it is then accreted to its estimated future value using the same assumed cost of funds. Periodically, we update the cost assumptions resulting from market changes and revise the liability recorded accordingly.
	The following table describes the changes to our asset retirement obligations for the years ending December 31, 2014 and 2013:
		2014			2013
	Current portion of asset retirement obligation at beginning of year	$	265,470		$	73,706
	Add: Long-term portion of asset retirement obligation at beginning of year	8,915,407			13,235,318
	Asset retirement obligation at beginning of year	9,180,877			13,309,024
	Buyer’s assumption of liabilities	(9,394,507		)	(5,509,401		)
	Liabilities settled	(78,711		)	(108,123		)
	Accretion of discount	298,130			1,035,717
	Revisions in estimates	(5,789		)	453,660
	Asset retirement obligation at end of year	—			9,180,877
	Less: current portion of obligation	—			265,470
	Long-term asset retirement obligation	$	—		$	8,915,407

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities
Derivative Instruments and Hedging Activities
	Note 11—Derivative Instruments and Hedging Activities
	In connection with the closing of the Asset Sale described in Note 4—Sale of our Central Appalachian Assets and Termination of Credit Agreement, we settled all of our outstanding natural gas hedge positions for approximately $3.1 million.
	Prior to the closing of the Asset Sale, in an effort to reduce the effects of the volatility of the price of natural gas on our operations, management had historically hedged natural gas prices primarily using derivative instruments in the form of three-way collars, traditional collars and swaps. While the use of these hedging arrangements limited the downside risk of adverse price movements, it also limited future gains from favorable movements. We entered into hedging transactions, generally for forward periods up to two years or more, which increased the probability of achieving our targeted level of cash flows. Our price risk management policy strictly prohibited the use of derivatives for speculative positions.
	Swaps exchange floating price risk in the future for a fixed price at the time of the hedge. Costless collars set both a maximum ceiling (a sold ceiling) and a minimum floor (a bought floor) future price. We have accounted for these transactions using the mark-to-market accounting method. Generally, we incurred accounting losses on derivatives during periods where prices were rising and gains during periods where prices were falling which caused significant fluctuations in our Consolidated Balance Sheets and Consolidated Statements of Operations.
	Commodity Price Risk and Related Hedging Activities
	As of December 31, 2014, we had no natural gas derivative contracts.
	As of December 31, 2013, we had the following natural gas derivative contracts:
	Contract	Period	Volume		Fixed Price or		Derivative			Derivative			Total Fair
	Type		(MMBtu)		Sold Ceiling/		liability—			liability—			Value of
					Bought Floor		current			non-current			Contract
	Swap	January 2014 through March 2014	360,000		$3.82		$	(164,121	)	$	—		$	(164,121	)
	Collar	January 2014 through December 2015	3,650,000		$ 4.30/$3.60		(280,392		)	(296,436		)	(576,828		)
	Collar	January 2014 through December 2015	3,650,000		$ 4.20/$3.50		(389,638		)	(413,135		)	(802,773		)
			7,660,000				$	(834,151	)	$	(709,571	)	$	(1,543,722	)
	We reviewed the financial strength of our hedge counterparties and believed our credit risk was minimal. Our hedge counterparties were participants or affiliates of the participants in the Credit Agreement and the collateral for the outstanding borrowings under the Credit Agreement was used as collateral for our hedges. We did not have rights to collateral from our counterparties, nor did we have rights of offset against borrowings under the Credit Agreement.
	We estimated the fair value of our natural gas derivative contracts using the income approach. The income approach uses valuation techniques that convert future cash flows to a single discounted value. In order to estimate the fair value of our natural gas derivative contracts, a forward price curve and volatility estimates were compiled from sources that include NYMEX settlements and observed trading activity in the Over-the-Counter markets. Pricing estimates for the theoretical market value of hedge positions were developed using analytical models accepted and employed by a broad cross-section of industry participants. To extrapolate future cash flows, discount factors incorporating our counterparties’ and our credit standing were used to discount future cash flows. The estimated fair value of our natural gas derivative contracts also reflected its nonperformance risk, the risk that the obligation would not be fulfilled. Because nonperformance risk included our counterparties’ and our credit risk, we had considered the effect of credit risk on the fair value of our natural gas derivative contracts. The consideration for discounting our counterparties’ liabilities (our assets) was based on the difference between the S&P credit rating of a comparable company to our counterparties and the 1-Year Treasury bill rate, both at the reporting date. The consideration for discounting our liabilities was based on the difference between the market weighted average cost of debt capital plus a premium over the capital asset pricing model and the 1-Year Treasury bill rate.
	We did not have any derivative assets or derivative liabilities as of December 31, 2014 and there were no transfers of assets and liabilities between Level 1 and Level 2 of the fair value measurement hierarchy during the year ended December 31, 2014. Based on the use of observable market inputs, we had designated these types of instruments designated below as Level 2. The fair value of our Level 2 derivative instruments were as follows:
		Asset Derivatives									Liability Derivatives
		December 31, 2014				December 31, 2013					December 31, 2014					December 31, 2013
		Balance Sheet	Fair			Balance Sheet		Fair			Balance Sheet		Fair			Balance Sheet	Fair
		Location	Value			Location		Value			Location		Value			Location	Value
	Derivatives not designated as hedging instruments
	Natural gas hedge positions	Derivative asset (current)	$	—		Derivative asset (current)		$	—		Derivative liability (current)		$	—		Derivative liability (current)	$	834,151
	Natural gas hedge positions	Derivative asset (non- current)	—			Derivative asset (non- current)		—			Derivative liability (non- current)		—			Derivative liability (non-current)	709,571
	Total derivatives not designated as hedging instruments		$	—				$	—				$	—			$	1,543,722
	The following losses on our hedging instruments included in the consolidated statements of operations are as follows:
		Location of (Gain) or Loss Recognized in	Amount of (Gain) or Loss
			Recognized in Income on
			Derivative
	Derivatives not designated as hedging instruments under ASC 815-20-25	Income on Derivative	2014			2013
	Natural gas collar/swap settled positions	Discontinued operations	$	4,296,912		$	(1,106,378	)
	Natural gas collar/swap unsettled positions	Discontinued operations	(1,543,722		)	2,917,569
	Total loss		$	2,753,190		$	1,811,191

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2014
Long-Term Debt
Long-Term Debt
	Note 12—Long-Term Debt
	As described in Note 4—Sale of our Central Appalachian Assets and Termination of Credit Agreement, on May 12, 2014, we sold substantially all of our remaining assets. Immediately following the closing of the Asset Sale, we repaid all outstanding borrowings under the Credit Agreement of $69.1 million.
	During 2012, the amounts borrowed under the Credit Agreement exceeded the borrowing base. Borrowings under the Credit Agreement as of August 8, 2012 totaled $148.6 million. On August 8, 2012, in connection with the excess of borrowings over the borrowing base, we amended the Credit Agreement to provide for a tranche A loan in the amount of our borrowing base and a tranche B loan in the amount of the borrowing base deficiency.
	On June 14, 2013, we closed the sale of all of our coalbed methane properties located in the state of Alabama. Simultaneously with the close of the property sale, approximately $57.0 million was used to repay outstanding borrowings under the Credit Agreement, which eliminated the borrowing base deficiency. After this repayment, borrowings outstanding under the Credit Agreement totaled $77.0 million.
	For the year ended December 31, 2014, we had no borrowings and made payments of $71.6 million under the Credit Agreement. For the period January 1, 2014 through May 12, 2014, interest on the borrowings averaged 5.00% per annum. For the year ended December 31, 2013, we had no borrowings and made payments of $67.8 million under our Credit Agreement and interest on the borrowings averaged 4.10% per annum.
	The following is a summary of our long-term debt as of December 31, 2014 and 2013:
		December 31,		December 31,
		2014		2013
	Borrowings under the Credit Agreement	$	—	$	71,550,000
	Less current maturities included in current liabilities	—		(71,550,000		)
	Total long-term debt	$	—	$	—
	We record our debt instruments based on contractual terms. We did not elect to apply the fair value option for recording financial assets and financial liabilities. We measure the fair value of our debt instruments using discounted cash flow analyses based on our current borrowing rates for similar types of borrowing arrangements (categorized as level 3). We do not have any debt instruments with fair value measurements categorized as level 1 or 2 within the fair value hierarchy. Fair value measurement for an asset or liability reflects its nonperformance risk, the risk that the obligation will not be fulfilled. Because nonperformance risk includes our credit risk, we have considered the effect of our credit risk on the fair value of the long-term debt. This consideration involved discounting our long-term debt based on the difference between the market weighted average cost of equity capital plus a premium over the capital asset pricing model and the stated interest rates of the debt instruments included in our long-term debt. The fair value of long-term debt as of December 31, 2013 was estimated to be approximately $70.1 million.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Taxes
Income Taxes
	Note 13—Income Taxes
	We record our income taxes using an asset and liability approach. This results in the recognition of deferred tax assets and liabilities for the expected future tax consequences of temporary differences between the book carrying amounts and the tax basis of assets and liabilities using enacted tax rates at the end of the period. The effect of a change in tax rates of deferred tax assets and liabilities is recognized in the year of the enacted change.
	For tax reporting purposes, we have federal and state NOLs of approximately $119.4 million and $133.3 million, respectively, as of December 31, 2014 that are available to reduce future taxable income. For tax reporting purposes, we had federal and state NOLs of approximately $156.0 million and $162.3 million, respectively, as of December 31, 2013 that were available to reduce future taxable income. Our first material federal NOL carryforward expires in 2024 and the last one expires in 2033.
	Additionally, for tax reporting purposes, we have a federal capital loss carryforward generated by the sale of Hudson’s Hope Gas, Ltd. in 2012, of approximately $33.9 million as of December 31, 2014 that is available to reduce future taxable capital gains and expires in 2017. Additionally, we have a federal capital loss carryforward of $0.2 million generated by the sale of other assets in 2014.
	As of December 31, 2014, we have a valuation allowance of $60.9 million recorded against our net deferred tax asset which includes $48.0 million related to our United States operations and $12.9 million related to the capital loss carryforward generated by the sale of Hudson’s Hope Gas, Ltd. in 2012 and other assets in 2014.
	An analysis of our deferred tax assets and liabilities as of December 31, 2014 and 2013:
		2014			2013
	Current deferred tax asset:
	Compensation expense and other	$	—		$	43,161
	Tax basis in excess of book basis of derivative contracts	—			318,645
	Valuation allowance	—			(361,806		)
	Total current deferred tax asset	—			—
	Net current deferred tax asset	$	—		$	—
	Long-term deferred tax asset:
	Net operating loss carryforward	$	46,316,857		$	60,233,320
	Compensation expense and other	872,852			1,084,474
	Accrued asset retirement obligations	—			2,187,078
	Tax basis in excess of book basis of derivative contracts	—			1,156,475
	Tax basis of natural gas properties in excess of book basis	—			5,502,048
	Tax basis of other fixed assets in excess of book basis	65,258			—
	Alternative minimum tax credit carryforward	652,543			—
	Capital loss on sale of Canadian properties	12,989,411			12,936,668
	Valuation allowance	(60,896,921		)	(83,100,063		)
	Net long-term deferred tax asset	$	—		$	—
	A reconciliation of the effective tax rates to the statutory rate are as follows:
		2014					2013
	Amount computed using statutory rates	$	20,156,293		34	%	$	12,016,985		34	%
	State income taxes—net of federal benefit	2,233,125			3.77	%	591,595			1.67	%
	Valuation Allowance	(21,928,834		)	-36.99	%	(13,179,253		)	-37.29	%
	Nondeductible items and other	216,959			0.36	%	595,673			1.69	%
	Income tax (benefit) expense	$	677,543		1.14	%	$	25,000		1.16	%
	Income tax benefit (expense)—discontinued operations	(652,543		)			—
	Income tax expense—continuing operations	$	25,000				$	25,000
	The following components of the income tax expense for the years ended December 31, 2014 and 2013 are as follows:
		2014			2013
	Current:
	State	$	25,000		$	25,000
	Federal	652,543			—
	Deferred:
	State	2,208,125			566,595
	State valuation allowance	(2,208,125		)	(566,595		)
	Federal	19,720,709			12,612,658
	Federal valuation allowance	(19,720,709		)	(12,612,658		)
	Income tax provision	$	677,543		$	25,000
	Current year operating losses generated in the normal course of business are less than the estimated taxable gain from the Asset Sale.  However, no regular income tax is expected to result from the Asset Sale as we estimate sufficient net operating losses will be available from prior years to offset the estimated taxable gain, resulting in a reduction of our deferred tax asset and the related valuation allowance of $23.2 million. We are subject to a federal alternative minimum tax and have estimated that amount to be $652,543 for 2014. In 2014, we made estimated payments of $650,000 and $2,543 remains as a payable recorded in the Consolidated Balance Sheet as of December 31, 2014.

Common_Stock

Common Stock	12 Months Ended
	Dec. 31, 2014
Common Stock
Common Stock
	Note 14—Common Stock
	As of December 31, 2014, shares of the Common Stock issued and outstanding were 40,523,805 and 40,513,373, respectively. As of December 31, 2013, shares of our Common Stock issued and outstanding were 40,662,749 and 40,652,317, respectively. Included in shares of our Common Stock issued as of December 31, 2014 and December 31, 2013 were 10,432 shares of treasury stock held by the Company. Included in our Common Stock both issued and outstanding as of December 31, 2013 were 158,065 shares of restricted stock. During the year ended December 31, 2014, 153 shares of restricted stock were forfeited and canceled upon the termination of an employee by the Company, 2,724 shares of restricted stock expired unvested and were canceled, and 136,067 shares of restricted stock were cancelled in conjunction with the termination of the employment agreements with certain of our executive officers.

Series_A_Convertible_Redeemabl

Series A Convertible Redeemable Preferred Stock	12 Months Ended
	Dec. 31, 2014
Series A Convertible Redeemable Preferred Stock
Series A Convertible Redeemable Preferred Stock
	Note 15—Series A Convertible Redeemable Preferred Stock
	As of December 31, 2014 and 2013, 6,786,334 and 6,000,571 shares of Preferred Stock were issued and outstanding, respectively. As of December 31, 2014, an additional 821,106 shares of the Preferred Stock were reserved exclusively for the payment of paid-in-kind dividends (“PIK dividends”). We measure the fair value of PIK dividends using the closing quoted NASDAQ market price on the dividend date (categorized as level 1) with the exception of the dividend issued on December 31, 2014 which was measured using the closing quoted OTC market price on the dividend date. The following table details the activity related to the Preferred Stock for the years ended December 31, 2014 and 2013:
		Dividend Period	Date Issued	Number of Shares	Balance
		(Three Months Ended)
	Balance on January 1, 2013			5,305,865	$	35,851,887
	Accretion of discount on Preferred Stock				2,257,968
	PIK Dividends Issued for Preferred Stock :	3/31/13	4/1/13	165,745	1,075,685
		6/30/13	7/1/13	170,931	1,367,488
		9/30/13	9/30/13	176,266	1,277,889
		12/31/13	12/31/13	181,764	1,574,076
	Balance on December 31, 2013			6,000,571	$	43,404,993
	Accretion of discount on Preferred Stock				2,964,762
	PIK Dividends Issued for Preferred Stock :	3/31/14	3/31/14	187,461	599,875
		6/30/14	6/30/14	193,327	552,915
		9/30/14	9/30/14	199,367	649,937
		12/31/14	12/31/14	205,608	503,739
	Balance on December 31, 2014			6,786,334	$	48,676,221
	As of December 31, 2014, the 6,786,334 shares of Preferred Stock were issued and outstanding were convertible into 52,202,569 shares of our Common Stock.

Profit_Sharing_Plan

Profit Sharing Plan	12 Months Ended
	Dec. 31, 2014
Profit Sharing Plan
Profit Sharing Plan
	Note 16—Profit Sharing Plan
	Substantially all of the employees were covered by our profit sharing plan under Section 401(k) of the Code through July 31, 2014 at which time the plan was terminated. Eligible employees were able to make contributions to the plan by electing to defer some of their compensation. We were required to match 100% of the first 3% of their annual compensation contributed and 50% of the following 2% of their annual compensation contributed. Our matching contributions vested immediately.  Our contributions to the Plan for the years ended December 31, 2014 and 2013 were $86,122 and $174,958, respectively. We elected a Safe Harbor 401(k) plan for the years ended December 31, 2014 and 2013. A Safe Harbor 401(k) plan generally satisfies the non-discrimination rules for elective deferrals and employer matching contributions. For a 401(k) plan to be considered a Safe Harbor plan, employers must satisfy certain contribution, vesting, and notice requirements. Under Safe Harbor, the matching contributions vest immediately.

Investment_in_Canada_Energy_Pa

Investment in Canada Energy Partners	12 Months Ended
	Dec. 31, 2014
Investment in Canada Energy Partners
Investment in Canada Energy Partners
	Note 17—Investment in Canada Energy Partners
	As of December 31, 2013, we owned two million shares of Canada Energy Partners (“CEP”). In December 2013, we were offered $140,000 for our CEP shares and completed the sale of those shares for that amount in January 2014. As such, we classified those shares as available for sale and recorded at fair value in Other current assets on the Consolidated Balance Sheet as of December 31, 2013. Additionally, the gains or losses related to both market price fluctuation and currency translation adjustment on the shares of CEP that were held in Accumulated other comprehensive loss in the Consolidated Balance Sheets were reclassified to net income as the recorded value of the CEP shares was considered to be permanently impaired as of December 31, 2013. As of December 31, 2013, the value of the shares recorded in Other noncurrent assets was $240,749 using a Level 1 input (the closing price of the shares on the TSX Venture Exchange). Accumulated other comprehensive loss of $53,020 in the Consolidated Balance Sheets as of December 31, 2013 consisted of a $61,661 decrease in market value offset by a $8,641 gain related to currency translation on the CEP shares.

ShareBased_Awards

Share-Based Awards	12 Months Ended
	Dec. 31, 2014
Share-Based Awards
Share-Based Awards
	Note 18—Share-Based Awards
	Our 2006 Long-Term Incentive Plan (the “2006 Plan”) authorized the granting of incentive stock options, non-qualified stock options, stock appreciation rights, stock awards, restricted stock, restricted stock units and performance awards. On May 12, 2014, all remaining awards under the 2006 Plan were forfeited and a $40,560 reduction in General and administrative expenses was recorded in the Consolidated Statements of Operations (Unaudited) resulting from forfeiture reversals.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies
Commitments and Contingencies
	Note 19— Commitments and Contingencies
	From time to time we are a party to litigation in the normal course of business. While the outcome of lawsuits or other proceedings against us are not possible to reasonably predict, management does not believe that the adverse effect on our financial condition, results of operations or cash flows, if any, will be material.
	Environmental and Regulatory
	As of December 31, 2014, there were no known environmental or other regulatory matters related to our operations that are reasonably expected to result in a material liability to us.
	Operating Lease Commitments
	We have no future minimum lease commitments as of December 31, 2014 under non-cancelable operating leases having remaining terms in excess of one year. Total rental expenses under operating leases were approximately $1.5 million and $2.3 million for the years ended December 31, 2014 and 2013, respectively.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Summary of Significant Accounting Policies
Principles of Consolidation
	Principles of Consolidation—The accompanying Consolidated Financial Statements are presented in conformity with accounting principles generally accepted in the United States of America (“GAAP”) and include our accounts and the accounts of our wholly-owned subsidiaries, GeoMet Operating Company, Inc., an Alabama corporation, and GeoMet Gathering Company LLC, an Alabama limited liability company. All inter-company accounts and transactions have been eliminated in consolidation.
Use of Estimates in the Preparation of Financial Statements
	Use of Estimates in the Preparation of Financial Statements—The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Our most significant financial estimates are related to computing taxes. Actual results could differ from these estimates.
Cash and Cash Equivalents
	Cash and Cash Equivalents—For purposes of these statements, short-term investments, which have an original maturity of three months or less, are considered cash equivalents.
Income Taxes
	Income Taxes—We record our income taxes using an asset and liability approach in accordance with GAAP. This results in the recognition of deferred tax assets and liabilities for the expected future tax consequences of temporary differences between the book carrying amounts and the tax basis of assets and liabilities using enacted tax rates at the end of the period. Under GAAP, 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. As of December 31, 2014, a full valuation allowance has been recorded against our net deferred tax asset.
	Estimating the amount of valuation allowance is dependent on estimates of future taxable income, alternative minimum tax income, and changes in stockholder ownership that could trigger limits on use of net operating losses under Section 382 of the Internal Revenue Code of 1986, as amended (the “Code”). We have a significant deferred tax asset associated with net operating loss carryforwards (“NOLs”).
	GAAP also clarifies the accounting for uncertainty in income taxes recognized in an entity’s financial statements and prescribes a consistent threshold and measurement attribute for financial statement recognition and disclosure of tax positions taken, or expected to be taken, on a tax return.
Revenue Recognition and Gas Balancing
	Revenue Recognition and Gas Balancing—Through May 12, 2014, we derived revenue primarily from the sale of produced natural gas. We used the sales method of accounting for the recognition of gas revenue whereby revenues, net of royalties, were recognized as the production was sold to a purchaser. The amount of gas sold may have differed from the amount to which the Company was entitled based on its working interest or net revenue interest in the properties. In instances where we had wellhead imbalances, we used the entitlements method. A ready market for natural gas allowed us to sell our natural gas shortly after production at various pipeline receipt points at which time title and risk of loss transferred to the buyer. Revenue was recorded when title was transferred based on our nominations and net revenue interests. Pipeline imbalances occurred when our production delivered into the pipeline varied from the gas we nominated for sale. Depending on the agreement in place, imbalances may have been made up in future production or settled with cash approximately 30 days from date of production. Imbalances were recorded as either a reduction or increase of revenue depending upon whether we are over-delivered or under-delivered.
	Settlements of gas sales occurred after the month in which the gas was produced. We estimated and accrued for the value of the sales using information available at the time financial statements were generated. Differences were reflected in the accounting period during which payments were received from the purchaser.
Industry Segment and Geographic Information
	Industry Segment and Geographic Information— On August 15, 2014, we became a “shell company” as defined by Rule 12b-2 of the Exchange Act because we no longer had operations.
Concentration of Credit Risk
	Concentration of Credit Risk—The Company maintains deposits in financial institutions which are insured by the Federal Deposit Insurance Corporation (“FDIC”). At various times, the Company has deposits in these financial institutions in excess of the amount insured by the FDIC.
Mezzanine Equity
	Mezzanine Equity—Our Series A Convertible Redeemable Preferred Stock has been classified within the mezzanine (temporary) equity section of the Consolidated Balance Sheets because the shares are redeemable at the option of the holder and therefore do not qualify for permanent equity.
Fair Value Measurement
	Fair Value Measurement—The fair value of cash and cash equivalents, current assets and payables, approximate book value because of the short maturity of these accounts.

Results_of_Discontinued_Operat1

Results of Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2014
Results of Discontinued Operations
Schedule of statement of operations
		2014			2013
	Revenues:
	Gas sales	$	13,645,825		$	38,086,539
	Other	27,505			122,844
	Total revenues	13,673,330			38,209,383
	Expenses:
	Lease operating expense	3,924,356			13,131,855
	Compression and transportation expense	2,713,296			7,716,864
	Production taxes	817,531			2,096,598
	Lease termination costs	300,000			—
	Depreciation, depletion and amortization	715,892			4,468,196
	Losses on natural gas derivatives	2,753,190			1,811,191
	Total operating expenses	11,224,265			29,224,704
	Gain on the sale of assets	62,455,861			36,948,313
	Operating income	64,904,926			45,932,992
	Interest income	4,284			1,714
	Interest expense	(1,223,348		)	(5,132,424		)
	Income tax expense	(652,543		)	—
	Income from discontinued operations	$	63,033,319		$	40,802,282

Gain_on_sale_of_assets_Tables

Gain on sale of assets (Tables)	12 Months Ended
	Dec. 31, 2014
Gain on the Sale of Assets
Schedule of total gain on the sale
	The total gain on sale of assets for the year ended December 31, 2014 as presented above includes the following:
			Sale to ARP			Other Sales			Total Gain
			Mountaineer
			Productions, LLC
	Cash proceeds		$	97,307,961		$	(246,871	)	$	97,061,090
	Buyer’s assumption of asset retirement obligations		8,027,899			1,253,198			9,281,097
	Buyer’s assumption of other liabilities		3,628,304			104,934			3,733,238
	Net book value of sold gas properties		(41,332,191		)	—			(41,332,191		)
	Net book value of sold equipment		(198,875		)	—			(198,875		)
	Transaction costs		(6,085,348		)	(3,150		)	(6,088,498		)
	Total gain on sale		$	61,347,750		$	1,108,111		$	62,455,861
	The total gain on sale of assets for the year ended December 31, 2013 as presented above includes the following:
	Cash proceeds		$	62,007,639
	Buyer’s assumption of asset retirement obligations		4,411,201
	Buyer’s assumption of other liabilities		164,108
	Net book value of sold natural gas properties		(27,998,835		)
	Net book value of sold inventory		(133,732		)
	Net book value of sold equipment		(108,642		)
	Transaction costs		(1,120,654		)
	Post-closing purchase price adjustments (1)		(272,772		)
	Total gain on sale		$	36,948,313
		-1		Post-closing purchase price adjustments results from actual operating revenues and expenses realized related to properties sold that differed from the amounts estimated at the time of closing.

Pro_Forma_Financial_Informatio1

Pro Forma Financial Information (Tables)	12 Months Ended
	Dec. 31, 2014
Pro Forma Financial Information
Schedule of pro forma adjustments related to the unaudited pro forma financial information
		2014			2013
	Revenue	$	—		$	—
	Loss from continuing operations	$	(4,427,647	)	$	(5,483,208	)
	Net (loss) income	$	(4,427,647	)	$	93,268,423
	Net (loss) income available to common stockholders	$	(9,700,835	)	$	85,712,745
	Net (loss) income per common share—basic	$	(0.24	)	$	2.12
	Net (loss) income per common share—diluted	$	(0.24	)	$	2.12

Net_Income_Per_Common_Share_Ta

Net Income Per Common Share (Tables)	12 Months Ended
	Dec. 31, 2014
Net (Loss) Income Per Common Share
Schedule of reconciliation of net income per common share
		2014			2013
	Net income	$	58,605,672		$	35,319,074
	Accretion of Series A Convertible Redeemable Preferred Stock	(2,964,762		)	(2,257,968
	PIK dividends on Series A Convertible Redeemable Preferred Stock	(2,306,466		)	(5,295,138
	Cash dividends paid on Series A Convertible Redeemable Preferred Stock	(1,960		)	(2,572
	Net income available to common stockholders —basic and diluted	$	53,332,484		$	27,763,396
	Net income per common share—basic and diluted:
	Net loss per common share from continuing operations	$	(0.24	)	$	(0.32	)
	Net income per common share from discontinued operations	1.56			1.01
	Net income per common share—basic and diluted	$	1.32		$	0.69
	Weighted average number of common shares:
	Basic and diluted	40,513,373			40,481,330

Gas_Properties_Tables

Gas Properties (Tables)	12 Months Ended
	Dec. 31, 2014
Gas Properties
Summary of the capitalized cost of gas properties
		2014		2013
	Subject to depletion	$	—	$	333,109,974
	Total not subject to depletion	—		—
	Gross natural gas properties	—		333,109,974
	Less impairment of natural gas properties	—		(241,964,803		)
	Less accumulated depletion	—		(49,161,150		)
	Net natural gas properties	$	—	$	41,984,021

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligations
Schedule of changes to ARO
		2014			2013
	Current portion of asset retirement obligation at beginning of year	$	265,470		$	73,706
	Add: Long-term portion of asset retirement obligation at beginning of year	8,915,407			13,235,318
	Asset retirement obligation at beginning of year	9,180,877			13,309,024
	Buyer’s assumption of liabilities	(9,394,507		)	(5,509,401		)
	Liabilities settled	(78,711		)	(108,123		)
	Accretion of discount	298,130			1,035,717
	Revisions in estimates	(5,789		)	453,660
	Asset retirement obligation at end of year	—			9,180,877
	Less: current portion of obligation	—			265,470
	Long-term asset retirement obligation	$	—		$	8,915,407

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities
Schedule of derivative contract positions
	Contract	Period	Volume		Fixed Price or		Derivative			Derivative			Total Fair
	Type		(MMBtu)		Sold Ceiling/		liability—			liability—			Value of
					Bought Floor		current			non-current			Contract
	Swap	January 2014 through March 2014	360,000		$3.82		$	(164,121	)	$	—		$	(164,121	)
	Collar	January 2014 through December 2015	3,650,000		$ 4.30/$3.60		(280,392		)	(296,436		)	(576,828		)
	Collar	January 2014 through December 2015	3,650,000		$ 4.20/$3.50		(389,638		)	(413,135		)	(802,773		)
			7,660,000				$	(834,151	)	$	(709,571	)	$	(1,543,722	)
Schedule of fair value of derivative instruments
		Asset Derivatives									Liability Derivatives
		December 31, 2014				December 31, 2013					December 31, 2014					December 31, 2013
		Balance Sheet	Fair			Balance Sheet		Fair			Balance Sheet		Fair			Balance Sheet	Fair
		Location	Value			Location		Value			Location		Value			Location	Value
	Derivatives not designated as hedging instruments
	Natural gas hedge positions	Derivative asset (current)	$	—		Derivative asset (current)		$	—		Derivative liability (current)		$	—		Derivative liability (current)	$	834,151
	Natural gas hedge positions	Derivative asset (non- current)	—			Derivative asset (non- current)		—			Derivative liability (non- current)		—			Derivative liability (non-current)	709,571
	Total derivatives not designated as hedging instruments		$	—				$	—				$	—			$	1,543,722
Schedule of losses (gains) on our hedging instruments have been classified as Discontinued operations included in the consolidated statements of operations
		Location of (Gain) or Loss Recognized in	Amount of (Gain) or Loss
			Recognized in Income on
			Derivative
	Derivatives not designated as hedging instruments under ASC 815-20-25	Income on Derivative	2014			2013
	Natural gas collar/swap settled positions	Discontinued operations	$	4,296,912		$	(1,106,378	)
	Natural gas collar/swap unsettled positions	Discontinued operations	(1,543,722		)	2,917,569
	Total loss		$	2,753,190		$	1,811,191

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Long-Term Debt
Summary of long-term debt
		December 31,		December 31,
		2014		2013
	Borrowings under the Credit Agreement	$	—	$	71,550,000
	Less current maturities included in current liabilities	—		(71,550,000		)
	Total long-term debt	$	—	$	—

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Taxes
Schedule of the entity's deferred tax assets and liabilities
		2014			2013
	Current deferred tax asset:
	Compensation expense and other	$	—		$	43,161
	Tax basis in excess of book basis of derivative contracts	—			318,645
	Valuation allowance	—			(361,806		)
	Total current deferred tax asset	—			—
	Net current deferred tax asset	$	—		$	—
	Long-term deferred tax asset:
	Net operating loss carryforward	$	46,316,857		$	60,233,320
	Compensation expense and other	872,852			1,084,474
	Accrued asset retirement obligations	—			2,187,078
	Tax basis in excess of book basis of derivative contracts	—			1,156,475
	Tax basis of natural gas properties in excess of book basis	—			5,502,048
	Tax basis of other fixed assets in excess of book basis	65,258			—
	Alternative minimum tax credit carryforward	652,543			—
	Capital loss on sale of Canadian properties	12,989,411			12,936,668
	Valuation allowance	(60,896,921		)	(83,100,063		)
	Net long-term deferred tax asset	$	—		$	—
Schedule of reconciliation of the effective tax rate to the statutory rate
		2014					2013
	Amount computed using statutory rates	$	20,156,293		34	%	$	12,016,985		34	%
	State income taxes—net of federal benefit	2,233,125			3.77	%	591,595			1.67	%
	Valuation Allowance	(21,928,834		)	-36.99	%	(13,179,253		)	-37.29	%
	Nondeductible items and other	216,959			0.36	%	595,673			1.69	%
	Income tax (benefit) expense	$	677,543		1.14	%	$	25,000		1.16	%
	Income tax benefit (expense)—discontinued operations	(652,543		)			—
	Income tax expense—continuing operations	$	25,000				$	25,000
Schedule of components of the income tax expense (benefit)
		2014			2013
	Current:
	State	$	25,000		$	25,000
	Federal	652,543			—
	Deferred:
	State	2,208,125			566,595
	State valuation allowance	(2,208,125		)	(566,595		)
	Federal	19,720,709			12,612,658
	Federal valuation allowance	(19,720,709		)	(12,612,658		)
	Income tax provision	$	677,543		$	25,000

Series_A_Convertible_Redeemabl1

Series A Convertible Redeemable Preferred Stock (Tables)	12 Months Ended
	Dec. 31, 2014
Series A Convertible Redeemable Preferred Stock
Schedule of activity related to the Preferred Stock
		Dividend Period	Date Issued	Number of Shares	Balance
		(Three Months Ended)
	Balance on January 1, 2013			5,305,865	$	35,851,887
	Accretion of discount on Preferred Stock				2,257,968
	PIK Dividends Issued for Preferred Stock :	3/31/13	4/1/13	165,745	1,075,685
		6/30/13	7/1/13	170,931	1,367,488
		9/30/13	9/30/13	176,266	1,277,889
		12/31/13	12/31/13	181,764	1,574,076
	Balance on December 31, 2013			6,000,571	$	43,404,993
	Accretion of discount on Preferred Stock				2,964,762
	PIK Dividends Issued for Preferred Stock :	3/31/14	3/31/14	187,461	599,875
		6/30/14	6/30/14	193,327	552,915
		9/30/14	9/30/14	199,367	649,937
		12/31/14	12/31/14	205,608	503,739
	Balance on December 31, 2014			6,786,334	$	48,676,221

Sale_of_our_Central_Appalachia1

Sale of our Central Appalachian Assets and Termination of Credit Agreement (Details) (USD $)	12 Months Ended		0 Months Ended	8 Months Ended	0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	12-May-14	Dec. 31, 2014	Jun. 14, 2013
Discontinued Operations
Repayment of borrowings under Credit Agreement	($71,550,000)	($67,750,000)
Commodity Contract [Member]
Discontinued Operations
Settlement of derivative instruments			3,100,000
Credit Agreement [Member]
Discontinued Operations
Repayment of borrowings under Credit Agreement	-71,600,000		69,100,000	-69,100,000
Coalbed Methane Properties [Member]
Discontinued Operations
Purchase price subject to purchase price adjustments			107,000,000
Purchase price adjustments			9,700,000		1,200,000
Net proceeds from sale of properties			97,300,000		62,000,000
Repayment of borrowings under Credit Agreement					$58,800,000

Results_of_Discontinued_Operat2

Results of Discontinued Operations (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Revenues:
Gas sales	$13,645,825	$38,086,539
Other	27,505	122,844
Total revenues	13,673,330	38,209,383
Expenses:
Lease operating expense	3,924,356	13,131,855
Compression and transportation expense	2,713,296	7,716,864
Production taxes	817,531	2,096,598
Lease termination costs	300,000
Depreciation, depletion and amortization	715,892	4,468,196
(Gains) losses on natural gas derivatives	2,753,190	1,811,191
Total operating expenses	11,224,265	29,224,704
Gain (loss) on the sale of assets (1)	62,455,861	36,948,313
Operating income	64,904,926	45,932,992
Interest income	4,284	1,714
Interest expense	-1,223,348	-5,132,424
Income tax benefit (expense)	-652,543	0
Income from discontinued operations	$63,033,319	$40,802,282
Canada Energy Partners Inc [Member]
Discontinued Operations
Number of shares received on sale of discontinued operations, classified as available for sale		2,000,000

Gain_on_Sale_of_Assets_Details

Gain on Sale of Assets (Details) (USD $)	12 Months Ended		0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	12-May-14	Jun. 14, 2013	Dec. 31, 2012
Gain (Loss) on Divestiture of Businesses [Abstract]
Repayment of borrowings under Credit Agreement	($71,550,000)	($67,750,000)
Payments of Financing Costs		3,801
Cash proceeds	97,061,090	60,732,775
Buyer's assumption of asset retirement obligations		265,470			73,706
Buyer's assumption of other liabilities		113,434
Net book value of sold gas properties		-333,109,974
Net book value of sold equipment		-42,329,051
Total gain on sale	62,455,861	36,948,313
Reduction in deferred tax asset	23,200,000
Reduction in valuation allowance	23,200,000
Current federal or state income taxes payable in conjunction with the sale of properties	652,543
Current federal or state income taxes estimated payment	650,000
Current federal or state income taxes remains payable	2,543
R P Mountaineer Productions L L N [Member]
Gain (Loss) on Divestiture of Businesses [Abstract]
Cash proceeds	97,307,961
Buyer's assumption of asset retirement obligations	8,027,899
Buyer's assumption of other liabilities	3,628,304
Net book value of sold gas properties	-41,332,191
Net book value of sold equipment	-198,875
Transaction costs	-6,085,348
Total gain on sale	61,347,750
New River Energy Corporation [Member]
Gain (Loss) on Divestiture of Businesses [Abstract]
Cash proceeds	-246,871
Buyer's assumption of asset retirement obligations	1,253,198
Buyer's assumption of other liabilities	104,934
Transaction costs	-3,150
Total gain on sale	1,108,111
Coalbed Methane Properties [Member]
Gain (Loss) on Divestiture of Businesses [Abstract]
Net proceeds from sale of properties			97,300,000	62,000,000
Purchase price adjustments			9,700,000	1,200,000
Repayment of borrowings under Credit Agreement				58,800,000
Payments of Financing Costs				3,200,000
Cash proceeds		62,007,639
Buyer's assumption of asset retirement obligations		4,411,201
Buyer's assumption of other liabilities		164,108
Net book value of sold gas properties		-27,998,835
Net book value of sold inventory		-133,732
Net book value of sold equipment		-108,642
Transaction costs		-1,120,654
Post-closing purchase price adjustments (1)		-272,772
Total gain on sale		36,948,313
Coalbed Methane Properties [Member] | R P Mountaineer Productions L L N [Member]
Gain (Loss) on Divestiture of Businesses [Abstract]
Cash proceeds	97,061,090
Buyer's assumption of asset retirement obligations	9,281,097
Buyer's assumption of other liabilities	3,733,238
Net book value of sold gas properties	-41,332,191
Net book value of sold equipment	-198,875
Transaction costs	-6,088,498
Total gain on sale	$62,455,861

Pro_Forma_Financials_Informati

Pro Forma Financials Information (Details) (USD $)	12 Months Ended		1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	31-May-14	Jun. 30, 2013
Discontinued Operations
Loss from continuing operations	($4,427,647)	($5,483,208)
Net income (loss)	58,605,672	35,319,074
Net income (loss) available to common stockholders	53,332,484	27,763,396
Earnings Per Share, Basic	$1.32	$0.69
Earnings Per Share, Diluted	$1.32	$0.69
Net income (loss) per common share-basic and diluted (in dollars per share)	$1.32	$0.69
Total gain on sale	62,455,861	36,948,313
Pro Forma [Member]
Discontinued Operations
Loss from continuing operations	-4,427,647	-5,483,208
Net income (loss)	-4,427,647	93,268,423
Net income (loss) available to common stockholders	-9,700,835	85,712,745
Earnings Per Share, Basic	($0.24)	$2.12
Earnings Per Share, Diluted	($0.24)	$2.12
Coalbed Methane Properties [Member]
Discontinued Operations
Total gain on sale		36,948,313
Coalbed Methane Properties [Member] | Pro Forma [Member]
Discontinued Operations
Total gain on sale			$62,455,853	$36,948,313

Net_Income_Per_Common_Share_De

Net Income Per Common Share (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Net (Loss) Income Per Common Share
Net income	$58,605,672	$35,319,074
Net (loss) income available to common stockholders-basic and diluted	53,332,484	27,763,396
Dilutive related add back:
Accretion of Series A Convertible Redeemable Preferred Stock	-2,964,762	-2,257,968
PIK dividends on Series A Convertible Redeemable Preferred Stock	-2,306,466	-5,295,138
Cash dividends paid on Series A Convertible Redeemable Preferred Stock	-1,960	-2,572
Net (loss) income available to common stockholders-basic and diluted	$53,332,484	$27,763,396
Net (loss) income per common share-basic and diluted:
Net loss per common share from continuing operations (in dollars per share)	($0.24)	($0.32)
Net income per common share from discontinued operations (in dollars per share)	$1.56	$1.01
Net income (loss) per common share-basic and diluted (in dollars per share)	$1.32	$0.69
Weighted average number of common shares:
Basic	40,513,373	40,481,330
Basic and diluted	40,513,373	40,481,330

Net_Income_Per_Common_Share_De1

Net Income Per Common Share (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Effect of anti-dilutive securities
Antidilutive securities excluded from diluted weighted average shares outstanding		193,045
Preferred stock, par value (in dollars per share)	$0.00	$0.00
Add back to Net loss available to common stockholders for Accretion of and dividends paid for Series A Convertible Redeemable Preferred Stock (in shares)	0
Accretion of Series A Convertible Redeemable Preferred Stock	($2,964,762)	($2,257,968)
Employee Stock Option [Member]
Effect of anti-dilutive securities
Antidilutive securities excluded from diluted weighted average shares outstanding		1,574,198
Restricted Stock [Member]
Effect of anti-dilutive securities
Antidilutive securities excluded from diluted weighted average shares outstanding	6,291,671	116,553
Redeemable Convertible Preferred Stock [Member]
Effect of anti-dilutive securities
Antidilutive securities excluded from diluted weighted average shares outstanding	-48,397,468	42,787,068
Dilutive shares of preferred stock		5,562,319
Accretion of Series A Convertible Redeemable Preferred Stock	2,964,762	2,257,968
Dividends paid for Series A Convertible Redeemable Preferred Stock (cash and PIK)	$2,306,466	$5,295,138

Gas_Properties_Details

Gas Properties (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Gas Properties
Discount rate per annum used to calculate present value of estimated future net revenues (as a percent)	10.00%
Unweighted arithmetic average of the Henry Hub spot market price (in dollars per Mcf)	3.69
Natural gas price when adjusted for the regional price differentials (in dollars per Mcf)	3.75
Write-down of the carrying value of U.S. full cost pool	$0
Capitalized cost of gas properties
Proved natural gas properties		333,109,974
Gross gas properties		333,109,974
Less impairment of gas properties		-241,964,803
Less accumulated depletion		-49,161,150
Net natural gas properties		$41,984,021

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Changes to asset retirement Obligations
Current portion of asset retirement obligation at the beginning of the period	$265,470	$73,706
Add: Long-term portion of asset retirement obligation at the beginning of the period	8,915,407	13,235,318
Asset retirement obligation at beginning of the period	9,180,877	13,309,024
Buyer's assumption of liabilities	-9,394,507	-5,509,401
Liabilities settled	-78,711	-108,123
Accretion of discount	298,130	1,035,717
Increase in estimated asset retirement obligations	-5,789	453,660
Asset retirement obligation at end of the period		9,180,877
Less: current portion of obligation		-265,470
Long-term asset retirement obligation		$8,915,407

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Details) (USD $)	Dec. 31, 2013	12-May-14
	item
Derivative instruments and hedging activities
Volume (in MMBtu)	7,660,000
Derivative liability - current	($834,151)
Derivative liability - non-current	-709,571
Fair Value	-1,543,722
Natural Gas Collar [Member] | January2014 Through December2015 Period One [Member]
Derivative instruments and hedging activities
Volume (in MMBtu)	3,650,000
Sold Ceiling (in dollars per unit)	4.3
Bought Floor (in dollars per unit)	3.6
Derivative liability - current	-280,392
Derivative liability - non-current	-296,436
Fair Value	-576,828
Natural Gas Collar [Member] | January2014 Through December2015 Period Two [Member]
Derivative instruments and hedging activities
Volume (in MMBtu)	3,650,000
Sold Ceiling (in dollars per unit)	4.2
Bought Floor (in dollars per unit)	3.5
Derivative liability - current	-389,638
Derivative liability - non-current	-413,135
Fair Value	-802,773
Natural Gas Swap [Member] | January2014 Through March2014 Period Two [Member]
Derivative instruments and hedging activities
Volume (in MMBtu)	360,000
Fixed Price (in dollars per unit)	3.82
Derivative liability - current	-164,121
Fair Value	-164,121
Commodity Contract [Member]
Derivative instruments and hedging activities
Settlement of derivative instruments		$3,100,000

Derivative_Instruments_and_Hed3

Derivative Instruments and Hedging Activities (Details 2) (Nondesignated [Member], USD $)	Dec. 31, 2013
Fair value of the entity's derivative instruments
Liability Derivatives, Fair Value	$1,543,722
Derivative Liabilities Current [Member]
Fair value of the entity's derivative instruments
Liability Derivatives, Fair Value	834,151
Derivative Liabilities Noncurrent [Member]
Fair value of the entity's derivative instruments
Liability Derivatives, Fair Value	$709,571

Derivative_Instruments_and_Hed4

Derivative Instruments and Hedging Activities (Details 3) (Nondesignated [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
The Effect of Derivative Instruments on the Unaudited Consolidated Statements of Operations and Other Comprehensive Income
Discontinued operations	$2,753,190	$1,811,191
Natural Gas Collar Swap Contract One [Member]
The Effect of Derivative Instruments on the Unaudited Consolidated Statements of Operations and Other Comprehensive Income
Discontinued operations	4,296,912	-1,106,378
Natural Gas Collar Swap Contract Two [Member]
The Effect of Derivative Instruments on the Unaudited Consolidated Statements of Operations and Other Comprehensive Income
Discontinued operations	($1,543,722)	$2,917,569

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	12 Months Ended		0 Months Ended	8 Months Ended	0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Jun. 14, 2013	Dec. 31, 2014	12-May-14	Aug. 12, 2012
Long-term debt
Payments made during the period	$71,550,000	$67,750,000
Average interest rate (as a percent)		4.10%
Borrowings under the Credit Agreement		71,550,000
Less current maturities included in current liabilities		-71,550,000
Fair value of long-term debt		70,100,000
Coalbed Methane Properties [Member]
Long-term debt
Payments made during the period			-58,800,000
Revolving Credit Facility [Member]
Long-term debt
Maximum borrowing capacity						148,600,000
Initial borrowing base			57,000,000
Average interest rate (as a percent)				5.00%
Credit Agreement [Member]
Long-term debt
Payments made during the period	71,600,000			69,100,000	-69,100,000
Credit Agreement [Member] | Revolving Credit Facility [Member]
Long-term debt
Borrowings outstanding			77,000,000
Payments made during the period		$67,800,000

Income_Taxes_Details

Income Taxes (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Net operating loss carryforward
Recorded valuation allowances	$60.90
Valuation allowance related to U.S. operations	48
Capital Loss Carryforward [Member]
Net operating loss carryforward
Loss carry forward	0.2
Federal
Net operating loss carryforward
Loss carry forward	119.4	156
Federal | Capital Loss Carryforward [Member] | Hudson Hope Gas Limited [Member]
Net operating loss carryforward
Loss carry forward	33.9
State
Net operating loss carryforward
Loss carry forward	133.3	162.3
Canada Energy Partners Inc [Member] | Federal | Capital Loss Carryforward [Member] | Hudson Hope Gas Limited [Member]
Net operating loss carryforward
Valuation allowance related to the capital loss carryforward	$12.90

Income_Taxes_Details_2

Income Taxes (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Current deferred tax asset:
Compensation expense and other		$43,161
Tax basis in excess of book basis of derivative contracts		318,645
Valuation allowance		-361,806
Long-term deferred tax asset:
Net operating loss carryforward	46,316,857	60,233,320
Compensation expense and other	872,852	1,084,474
Accrued asset retirement obligations		2,187,078
Tax basis in excess of book basis of derivative contracts		1,156,475
Tax basis of gas properties in excess of book basis		5,502,048
Tax basis of other fixed assets in excess of book basis	65,258
Alternative minimum tax credit carryforward	652,543
Capital loss on sale of Canadian properties	12,989,411	12,936,668
Valuation allowance	-60,896,921	-83,100,063
Income tax expense reconciliation
Amount computed using statutory rates	20,156,293	12,016,985
State income taxes - net of federal benefit	2,233,125	591,595
Reduction of valuation allowance	-21,928,834	-13,179,253
Nondeductible items and other	216,959	595,673
Income tax (benefit) expense	677,543	25,000
Income tax benefit (expense) - discontinued operations	-652,543	0
Income tax expense - continuing operations	25,000	25,000
Income tax expense reconciliation
Amount computed using statutory rates (as a percent)	34.00%	34.00%
State income taxes - net of federal benefit (as a percent)	3.77%	1.67%
Reduction of valuation allowance	-36.99%	-37.29%
Nondeductible items and other (as a percent)	0.36%	1.69%
Income tax provision (as a percent)	1.14%	1.16%
Current:
State	25,000	25,000
Federal	652,543
Deferred:
State	2,208,125	566,595
Federal	19,720,709	12,612,658
Reduction of valuation allowance	-21,928,834	-13,179,253
Income tax provision	677,543	25,000
Deferred Tax Asset Change in Amount	23,200,000
Reduction in valuation allowance	23,200,000
Taxes Payable, Current	652,543
Current federal or state income taxes estimated payment	650,000
Current federal or state income taxes remains payable	2,543
State
Income tax expense reconciliation
Reduction of valuation allowance	-2,208,125	-566,595
Deferred:
Reduction of valuation allowance	-2,208,125	-566,595
Federal
Income tax expense reconciliation
Reduction of valuation allowance	-19,720,709	-12,612,658
Deferred:
Reduction of valuation allowance	($19,720,709)	($12,612,658)

Common_Stock_Details

Common Stock (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Common Stock
Common stock, shares issued	40,523,805	40,662,749
Common stock, shares outstanding	40,513,373	40,652,317
Treasury stock (in shares)	10,432	10,432
Restricted Stock [Member]
Common Stock
Shares		158,065
Forfeited and canceled	153
Unvested and canceled	2,724
Activity related to common stock
Shares of restricted stock forfeited upon termination of employment	136,067

Series_A_Convertible_Redeemabl2

Series A Convertible Redeemable Preferred Stock (Details) (USD $)	1 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Apr. 30, 2014	Dec. 31, 2013	Sep. 30, 2013	Jul. 31, 2013	Apr. 30, 2013	Dec. 31, 2014	Dec. 31, 2013
Series A Convertible Redeemable Preferred Stock
Number of shares issued	6,786,334				6,000,571				6,786,334	6,000,571
Number of shares outstanding	6,786,334				6,000,571				6,786,334	6,000,571
Additional shares reserved for paid-in-kind dividends	821,106								821,106
Activity related to common stock (Number of Shares)
Balance at the beginning of the period (in shares)									6,000,571	5,305,865
PIK Dividend Issued for Preferred Stock	205,608	199,367	193,327	187,461	181,764	176,266	170,931	165,745
Balance at the end of the period (in shares)	6,786,334				6,000,571				6,786,334	6,000,571
Activity related to the preferred stock (Balance)
Balance at the beginning of the period									$43,404,993	$35,851,887
Accretion of discount on Preferred Stock									2,964,762	2,257,968
PIK Dividend Issued for Preferred Stock	503,739	649,937	552,915	599,875	1,574,076	1,277,889	1,367,488	1,075,685
Balance at the end of the period	$48,676,221				$43,404,993				$48,676,221	$43,404,993
Conversion of Stock, Shares Converted									52,202,569

Profit_Sharing_Plan_Details

Profit Sharing Plan (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Profit Sharing Plan
Employer match for the first 3% of employee's annual compensation (as a percent)	100.00%
Percentage of employee's annual compensation matched 100% by employer	3.00%
Employer match for the next 2% of employee's annual compensation (as a percent)	50.00%
Percentage of employee's annual compensation matched 50% by employer	2.00%
Employer's contributions to the Plan	$86,122	$174,958

Investment_in_Canada_Energy_Pa1

Investment in Canada Energy Partners (Details) (Canada Energy Partners Inc [Member], USD $)	12 Months Ended
	Dec. 31, 2013
Canada Energy Partners Inc [Member]
Investment in Canada Energy Partners
Number of shares received on sale of discontinued operations, classified as available for sale	2,000,000
Value of shares recorded in other noncurrent assets	$240,749
Accumulated other comprehensive income (loss)	53,020
Decrease in market value of investment	61,661
Gain (loss) related to currency translation	8,641
Amount offered for shares held	$140,000

ShareBased_Awards_Details

Share-Based Awards (Details) (USD $)	12 Months Ended
	Dec. 31, 2014
Share-Based Awards
Reduction in General and administrative expenses	$40,560

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Future minimum lease commitments
Total future minimum lease commitments	$0
Rental expenses under operating leases	$1,500,000	$2,300,000