GeoMet 10-K 31 Mar 14 2013 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, 2013	Mar. 01, 2014	Jun. 28, 2013
Document and Entity Information	'	'	'
Entity Registrant Name	'GeoMet, Inc.	'	'
Entity Central Index Key	'0001352302	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Amendment Flag	'false	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Smaller Reporting Company	'	'
Entity Public Float	'	'	$4.10
Entity Common Stock, Shares Outstanding	'	40,652,317	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
Current Assets:	'	'
Cash and cash equivalents	$8,108,272	$7,234,225
Accounts receivable, net of allowance of $14,744 and $17,634 at December 31, 2013 and 2012, respectively	2,900,807	6,248,819
Inventory	'	262,885
Derivative asset-natural gas contracts	'	3,929,767
Other current assets	692,740	1,437,819
Total current assets	11,701,819	19,113,515
Natural gas properties-utilizing the full cost method of accounting:	'	'
Proved natural gas properties	333,109,974	539,077,119
Other property and equipment	3,158,701	3,749,621
Total property and equipment	336,268,675	542,826,740
Less accumulated depreciation, depletion, amortization and impairment of gas properties	-293,939,624	-467,702,053
Property and equipment-net	42,329,051	75,124,687
Other noncurrent assets:	'	'
Deferred income taxes	'	1,125,804
Other	769,384	962,451
Total other noncurrent assets	769,384	2,088,255
TOTAL ASSETS	54,800,254	96,326,457
Current Liabilities:	'	'
Accounts payable	3,541,770	5,728,879
Royalties payable	3,656,272	3,830,904
Accrued liabilities	1,073,653	1,793,946
Deferred income taxes	'	1,125,804
Derivative liability-natural gas contracts	834,151	919,572
Asset retirement obligations	265,470	73,706
Current portion of long-term debt	71,550,000	10,300,000
Total current liabilities	80,921,316	23,772,811
Long-term debt	'	129,000,000
Asset retirement obligations	8,915,407	13,235,318
Derivative liability-natural gas contracts	709,571	1,636,348
Other long-term accrued liabilities	113,434	143,682
TOTAL LIABILITIES	90,659,728	167,788,159
Commitments and contingencies (Notes 10 and 19)	'	'
Mezzanine equity:	'	'
Series A Convertible Redeemable Preferred Stock-net of offering costs of $1,660,435; redemption amount $60,005,710; $.001 par value; 7,401,832 shares authorized, 6,000,571 and 5,305,865 shares were issued and outstanding at December 31, 2013 and 2012, respectively	43,404,993	35,851,887
Stockholders' (Deficit) Equity:	'	'
Preferred stock, $0.001 par value-2,598,168 shares authorized, none issued	'	'
Common stock, $0.001 par value-authorized 125,000,000 shares; 40,662,749 and 40,690,077 issued and 40,652,317 and 40,679,645 outstanding at December 31, 2013 and 2012, respectively	40,663	40,690
Treasury stock, at cost-10,432 shares at December 31, 2013 and 2012	-94,424	-94,424
Paid-in capital	187,527,716	195,033,585
Accumulated other comprehensive loss	'	-53,020
Retained deficit	-266,738,422	-302,057,496
Less notes receivable	'	-182,924
Total stockholders' deficit	-79,264,467	-107,313,589
TOTAL LIABILITIES, MEZZANINE AND STOCKHOLDERS' DEFICIT	$54,800,254	$96,326,457

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
CONSOLIDATED BALANCE SHEETS	'	'
Accounts receivable, allowance (in dollars)	$14,744	$17,634
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)	$60,005,710	$60,005,710
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	6,000,571	5,305,865
Series A Convertible Redeemable Preferred Stock, shares outstanding	6,000,571	5,305,865
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	40,662,749	40,690,077
Common stock, shares outstanding	40,652,317	40,679,645
Treasury stock, shares	10,432	10,432

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Revenues:	'	'
Gas sales	$38,086,539	$39,146,723
Other	122,844	236,364
Total revenues	38,209,383	39,383,087
Expenses:	'	'
Lease operating expense	13,131,855	17,482,709
Compression and transportation expense	7,716,864	8,349,799
Production taxes	2,096,598	1,961,804
Depreciation, depletion and amortization	4,594,093	11,531,565
Impairment of intangible asset	'	782,462
Impairment of natural gas properties	'	95,728,981
General and administrative	5,009,645	4,851,193
Restructuring costs	95,584	1,083,018
Gains (losses) on natural gas derivatives	1,811,191	-4,415,617
Total operating expenses	34,455,830	137,355,914
Gain on the sale of properties in Alabama	36,948,313	'
Operating income (Loss)	40,701,866	-97,972,827
Other income (expense):	'	'
Interest income	1,714	5,527
Interest expense	-5,132,424	-5,827,659
Write off of debt issuance costs	'	-1,377,520
Other	-227,082	-1,463
Total other income (expense):	-5,357,792	-7,201,115
Income (Loss) before income taxes from continuing operations	35,344,074	-105,173,942
Income tax expense	25,000	44,043,200
Income (Loss) from continuing operations	35,319,074	-149,217,142
Discontinued operations	'	-736,025
Net income (loss)	35,319,074	-149,953,167
Accretion of discount on Series A Convertible Redeemable Preferred Stock	-2,257,968	-1,913,134
Paid-in-kind dividends on Series A Convertible Redeemable Preferred Stock	-5,295,138	-3,934,094
Cash dividends paid on Series A Convertible Redeemable Preferred Stock	-2,572	-2,757
Net income (loss) available to Common Stockholders	$27,763,396	($155,803,152)
Net income (loss) per common share-basic:	'	'
Net income (loss) per common share from continuing operations (in dollars per share)	$0.69	($3.86)
Net loss per common share from discontinued operations (in dollars per share)	'	($0.02)
Net income (loss) per common share-basic (in dollars per share)	$0.69	($3.88)
Net income (loss) per common share-diluted:	'	'
Net income (loss) per common share from continuing operations (in dollars per share)	$0.42	($3.86)
Net loss per common share from discontinued operations (in dollars per share)	'	($0.02)
Net income (loss) per common share-diluted (in dollars per share)	$0.42	($3.88)
Weighted average number of common shares:	'	'
Basic (in shares)	40,481,330	40,123,608
Diluted (in shares)	83,384,951	40,123,608

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)	'	'
Net income (loss)	$35,319,074	($149,953,167)
Other comprehensive income (loss), net of related taxes:	'	'
Foreign currency translation adjustment	-10,182	10,661
Reclassification adjustment for loss on foreign currency translation included in net income (loss)	1,541	1,307,906
Unrealized loss on available for sale securities	-90,567	-61,661
Reclassification adjustment for impairment of available for sale securities included in net income (loss)	152,228	'
Comprehensive income (loss)	$35,372,094	($148,696,261)

CONSOLIDATED_STATEMENTS_OF_STO

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (DEFICIT) (USD $)	Total	Common Stock Par Value $0.001	Treasury Stock	Paid-in Capital	Accumulated Other Comprehensive Loss	Retained Deficit	Notes Receivable
Balance at Dec. 31, 2011	$46,631,084	$40,010	($94,424)	$200,344,209	($1,309,926)	($152,104,329)	($244,456)
Balance (in shares) at Dec. 31, 2011	'	40,010,188	'	'	'	'	'
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'	'	'
Stock-based compensation	603,612	682	'	602,930	'	'	'
Stock-based compensation (in shares)	'	682,288	'	'	'	'	'
Purchase and cancellation of Common Stock	-2,039	-2	'	-2,037	'	'	'
Purchase and cancellation of Common Stock (in shares)	'	-2,399	'	'	'	'	'
Dividends paid in-kind	-3,934,094	'	'	-3,934,094	'	'	'
Dividends paid in cash	-2,757	'	'	-2,757	'	'	'
Accretion of discount on Series A Convertible Redeemable Preferred Stock	-1,913,134	'	'	-1,913,134	'	'	'
Write-off of notes receivable	'	'	'	-62,883	'	'	62,883
Accrued interest on notes receivable	'	'	'	1,351	'	'	-1,351
Net income (loss)	-149,953,167	'	'	'	'	-149,953,167	'
Unrealized loss on available for sale securities, net of income taxes of $0 for year ended 2013 and 2012	-61,661	'	'	'	-61,661	'	'
Reclassification adjustment for loss on foreign currency translation	1,307,906	'	'	'	1,307,906	'	'
Foreign currency translation adjustment, net of income taxes of $0 for year ended 2013 and 2012	10,661	'	'	'	10,661	'	'
Balance at Dec. 31, 2012	-107,313,589	40,690	-94,424	195,033,585	-53,020	-302,057,496	-182,924
Balance (in shares) at Dec. 31, 2012	'	40,690,077	'	'	'	'	'
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'	'	'
Stock-based compensation	232,760	'	'	232,760	'	'	'
Purchase and cancellation of Common Stock	-27	'	'	-27	'	'	'
Purchase and cancellation of Common Stock (in shares)	'	-121	'	'	'	'	'
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 discount on Series A Convertible Redeemable Preferred Stock	-2,257,968	'	'	-2,257,968	'	'	'
Write-off of notes receivable	-24	-24	'	-183,208	'	'	183,208
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, net of income taxes of $0 for year ended 2013 and 2012	-90,567	'	'	'	-90,567	'	'
Reclassification adjustment for loss on foreign currency translation	1,541	'	'	'	1,541	'	'
Foreign currency translation adjustment, net of income taxes of $0 for year ended 2013 and 2012	-10,182	'	'	'	-10,182	'	'
Reclassification adjustment for impairment of available for sale securities included in net income (loss)	152,228	'	'	'	152,228	'	'
Balance at Dec. 31, 2013	($79,264,467)	$40,663	($94,424)	$187,527,716	'	($266,738,422)	'
Balance (in shares) at Dec. 31, 2013	'	40,662,749	'	'	'	'	'

CONSOLIDATED_STATEMENTS_OF_STO1

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (DEFICIT) (Parenthetical) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Available for sale securities	'	'
Income taxes	$0	$0
Foreign currency translation adjustment	'	'
Income taxes	$0	$0

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Cash flows provided by operating activities:	'	'
Net income (loss)	$35,319,074	($149,953,167)
Adjustments to reconcile net income (loss) to net cash flows provided by operating activities:	'	'
Depreciation, depletion and amortization	4,594,093	11,529,846
Impairment of available for sale securities	153,769	'
Impairment of intangible asset	'	782,462
Impairment of natural gas properties	'	95,728,981
Amortization of debt issuance costs	912,481	725,408
Write off of debt issuance costs	'	1,377,520
Deferred income tax expense	'	44,018,200
Unrealized losses from the change in market value of open derivative contracts	2,917,569	11,967,386
Stock-based compensation	232,760	580,958
Gain on the sale of properties in Alabama	-36,948,313	'
Loss on sale of Hudson's Hope Gas, Ltd.	'	683,154
Loss on sale of other assets	107,519	4,400
Accretion expense-asset retirement obligations	1,035,717	827,771
Changes in operating assets and liabilities:	'	'
Accounts receivable	3,732,313	-1,850,161
Other current assets	-276,118	93,046
Accounts payable	-2,291,340	2,518,597
Other current liabilities	-691,716	-673,449
Net cash provided by operating activities	8,797,808	18,360,952
Cash flows provided by investing activities:	'	'
Capital expenditures	-919,412	-1,077,249
Proceeds from the sale of Alabama properties	60,732,775	'
Return of original basis through the settlement of natural gas derivative contracts	'	9,109,404
Proceeds from sale of other property and equipment	19,276	4,300
Net cash provided by investing activities	59,832,639	8,036,455
Cash flows used in financing activities:	'	'
Deferred financing costs	-3,801	-832,401
Proceeds from borrowings under credit agreement	'	10,500,000
Payments on outstanding borrowings under credit agreement	-67,750,000	-29,100,000
Cash dividends paid on Series A Convertible Redeemable Preferred Stock	-2,572	-2,757
Purchase and cancellation of treasury stock	-27	-2,039
Payments on other debt	'	-188,965
Net cash used in financing activities	-67,756,400	-19,626,162
Effect of exchange rate changes on cash and cash equivalents	'	5,115
Increase in cash and cash equivalents	874,047	6,776,360
Cash and cash equivalents at beginning of year	7,234,225	457,865
Cash and cash equivalents at end of year	8,108,272	7,234,225
Cash paid during the year for:	'	'
Interest expense	5,208,800	5,022,738
Income taxes	25,000	25,000
Significant noncash investing and financing activities:	'	'
Accrued capital expenditures	26,546	450,007
Fair value of common stock received in exchange for Hudson's Hope Gas, Ltd	'	293,769
Increase in estimated asset retirement obligations	$453,660	$4,846,818

Organization_and_Our_Business

Organization and Our Business	12 Months Ended
	Dec. 31, 2013
Organization and Our Business	'
Organization and Our Business	'
	Note 1—Organization and Our Business
	GeoMet, Inc. (“GeoMet,” “Company,” “we,” or “our”) (formerly GeoMet Resources, Inc.) was incorporated under the laws of the state of Delaware on November 9, 2000. We are primarily engaged in the exploration for and development and production of natural gas from coal seams (“coalbed methane” or “CBM”). All of our production is 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 have been active as an operator, developer and producer of coalbed methane properties since 1993. Subsequent to the asset sale discussed in Note 2— Sale of Coalbed Methane Properties in Alabama, our core area of operations is the Central Appalachian Basin of Virginia and West Virginia. We also own additional coalbed methane development rights, principally in Virginia and West Virginia.

Sale_of_Coalbed_Methane_Proper

Sale of Coalbed Methane Properties in Alabama	12 Months Ended
	Dec. 31, 2013
Sale of Coalbed Methane Properties in Alabama	'
Sale of Coalbed Methane Properties in Alabama	'
	Note 2— Sale of Coalbed Methane Properties in Alabama
	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.
	Total gain on the sale included 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 current federal or state income taxes payable were recorded in conjunction with the sale of the Alabama properties which is the result of 2013 tax basis operating losses generated in the normal course of business that are estimated to be available to offset the taxable gain. Additionally, our net deferred tax asset and the offsetting valuation allowance recorded against it were both reduced by $14.1 million as a result of recording the gain on the sale of assets. At December 31, 2013, our remaining net deferred tax asset is $83.5 million for which a full valuation allowance remains recorded against it.
	The following unaudited pro forma balances reflect the sale of our coalbed methane assets in Alabama for the years ended December 31, 2013 and 2012 giving effect to events that are (i) directly attributable to the transaction, (ii) expected to have a continuing impact on the Company, and (iii) factually supportable. 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 is the total gain on sale of $36,948,313.
	Consolidated Pro Forma Information (Unaudited)
		2013			2012
	Revenue	$	31,967,227		$	27,564,502
	Income (loss) from continuing operations	$	37,908,108		$	(71,115,461	)
	Net income (loss)	$	34,861,753		$	(119,782,988	)
	Net income (loss) available to Common Stockholders	$	27,306,075		$	(125,632,973	)
	Net income (loss)per common share—basic	$	0.67		$	(3.13	)
	Net income (loss)per common share—diluted	$	0.42		$	(3.13	)

Going_Concern_and_Managements_

Going Concern and Management's Plans	12 Months Ended
	Dec. 31, 2013
Going Concern and Management's Plans	'
Going Concern and Management's Plans	'
	Note 3— Going Concern and Management’s Plans
	As of December 31, 2013, we had a working capital deficit of $69.2 million, a retained deficit of $266.7 million and stockholders’ deficit of $79.3 million.  Depressed natural gas prices in 2012 resulted in significant property impairments and full valuation of our deferred tax assets during 2012. On April 2, 2013, due to a maturity date of April 1, 2014, all the indebtedness under our credit agreement was reclassified to current liabilities.  In addition, our Preferred Stock continues to accrue a dividend of 12.5% per annum, which we have been paying through the issuance of additional shares of Preferred Stock.  Beginning in September 2015, dividends on the Preferred Stock will accrue at 9.6% per annum and be payable in cash.
	The June 2013 sale of our Alabama assets brought our borrowing base into conformity under our credit agreement; however, we remain highly leveraged. On February 13, 2014, we entered into an agreement to sell substantially all of the remaining assets (the “Asset Sale”) for $107 million, subject to various purchase price adjustments.   We expect to close this transaction in the second quarter of 2014; however, the closing is subject to numerous closing conditions such as an approval of the transaction by our stockholders.  No assurance can be given that the Asset Sale will be consummated. In order to allow a reasonable time to close the asset sale and repay all outstanding liabilities and obligations, on February 28, 2014, we amended our credit agreement to extend the maturity date from April 1, 2014 to the earliest to occur of: (i) June 30, 2014, (ii) the closing of the Asset Sale pursuant to the Asset Purchase Agreement, or the sale of the Assets pursuant to a substitute purchase agreement, or (iii) the termination of the Asset Purchase Agreement or any substitute purchase agreement, and no assurances can be made that we will be able to refinance, repay or further extend the maturity date of our credit agreement.
	We currently anticipate that the Asset Sale, if consummated, would be followed by either a merger/corporate transaction or a liquidation and distribution of our remaining assets in accordance with applicable law. Generally, in dissolution, the net proceeds of a sale would be used to repay the amount outstanding under our credit agreement, if any, and make adequate provision for satisfaction of other known or contingent payment obligations.
	Any such sale of assets, and any subsequent merger/corporate transaction or liquidation, would require approval by (i) our board of directors, (ii) at least fifty percent (50%) of the outstanding shares of our Preferred Stock entitled to vote at a special meeting of the stockholders of GeoMet and (iii) a majority of the outstanding shares of GeoMet’s Common Stock including the outstanding shares of Preferred Stock on an as-converted basis voting together with the holders of Common Stock as a single class. On an as-converted basis, the Preferred Stock currently represents approximately 53% of the outstanding shares and therefore would have the ability to control any vote requiring the approval of our shareholders, including a vote to approve a sale transaction and any subsequent merger or liquidation.
	These and other factors raise substantial doubt about the Company’s ability to continue as a going concern for the next twelve months. The accompanying audited consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“GAAP”) which contemplate continuation of the Company as a going concern.
	In the event the assumption of the continuation of the Company as a going concern was no longer appropriate, management and the board of directors would adopt a plan of liquidation. The Company would then be required to implement the liquidation basis of accounting. Under the liquidation basis of accounting, the carrying amounts of assets as of the date of the authorization of a plan for liquidation, would be adjusted to their estimated net realizable values and liabilities, including the estimated costs associated with implementing a plan for liquidation, would be stated at their estimated settlement amounts.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies	'
Summary of Significant Accounting Policies	'
	Note 4—Summary of Significant Accounting Policies
	Principles of Consolidation—The accompanying Audited Consolidated Financial Statements are presented in conformity with GAAP and include our accounts and the accounts of our wholly-owned subsidiaries, GeoMet Operating Company, Inc., GeoMet Gathering Company LLC, and Hudson’s Hope Gas, Ltd. (disposed on June 20, 2012). 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 audited consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Our most significant financial estimates are related to our proved gas reserves. Estimates of proved gas reserves are key components of our depletion rate for natural gas properties and our full cost ceiling test limitation. In addition, other significant estimates include estimates used in computing taxes, stock-based compensation, asset retirement obligations, fair value of derivative contracts and accrued receivables and payables. Actual results could differ from these estimates.
	Natural Gas Properties—The method of accounting for natural gas properties 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 proscribed by the SEC. For more information see Note 8—Natural Gas Properties.
	Asset Retirement Obligations — Accounting Standards Codification (“ASC”) 410-20-25 establishes accounting and reporting standards for retirement obligations associated with tangible long-lived assets that result from the legal obligation to plug, abandon and dismantle existing wells and facilities that we have acquired, constructed or developed. It requires that the fair value of the liability for asset retirement obligations be recognized in the period in which it is incurred. Upon initial recognition of the asset retirement obligation, the asset retirement cost is capitalized by increasing the carrying amount of the long-lived asset by the same amount as the liability. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the related asset, included in the depletable base of our natural gas properties, or impaired. Periodically, we update the cost assumptions resulting from changes in market and environmental regulation and revise the liability recorded accordingly.
	Other Property and Equipment—The cost of other property and equipment is depreciated over the estimated useful lives of the related assets. The cost of leasehold improvements is depreciated over the lesser of the length of the related leases or the estimated useful lives of the assets. Depreciation is computed on the straight-line basis over the following estimated useful lives which range from three to seven years.
	Furniture and fixtures	7 years
	Automobiles	3 years
	Machinery and equipment	5 years
	Software and computer equipment	3 years
	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 the provisions of ASC 740. 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 ASC 740, the effect of a change in tax rates of deferred tax assets and liabilities is recognized in the year of the enacted change. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. At December 31, 2013, 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 Internal Revenue Code Section 382. We have a significant deferred tax asset associated with net operating loss carryforwards (“NOLs”).
	ASC 740 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—We derive revenue primarily from the sale of produced natural gas. We use the sales method of accounting for the recognition of gas revenue whereby revenues, net of royalties, are recognized as the production is sold to a purchaser. The amount of gas sold may differ from the amount to which the Company is entitled based on its working interest or net revenue interest in the properties. In instances where we have wellhead imbalances, we use the entitlements method. A ready market for natural gas allows us to sell our natural gas shortly after production at various pipeline receipt points at which time title and risk of loss transfers to the buyer. Revenue is recorded when title is transferred based on our nominations and net revenue interests. Pipeline imbalances occur when our production delivered into the pipeline varies from the gas we nominated for sale. Depending on the agreement in place, imbalances may be made up in future production or settled with cash approximately thirty days from date of production. Imbalances are recorded as either a reduction or increase of revenue depending upon whether we are over-delivered or under-delivered.
	Settlements of gas sales occur after the month in which the gas was produced. We estimate and accrue for the value of these sales using information available at the time financial statements are generated. Differences are reflected in the accounting period during which payments are received from the purchaser.
	Industry Segment and Geographic Information—We operate in one industry, which is the exploration, development and production of natural gas.
	Concentrations of Market Risk—Our future results will be affected by the market price of natural gas. The availability of a ready market for natural gas will depend on numerous factors beyond our control, including weather, production of natural gas, imports, marketing, competitive fuels, proximity of natural gas pipelines and other transportation facilities, any oversupply or undersupply of natural gas, the regulatory environment, and other regional and political events, none of which can be predicted with certainty.
	Concentration of Credit Risk—Financial instruments, which subject us to concentrations of credit risk, consist primarily of cash and cash equivalents, accounts receivable and derivative assets. We place our cash investments with highly qualified financial institutions. Risks with respect to receivables as of December 31, 2013 and 2012 arise substantially from the sales of natural gas and joint interest billings from our working interest partners. We routinely assess the recoverability of all material trade and other receivables to determine their collectability. We accrue a reserve on a receivable when, based on management’s judgment, it is probable that a receivable will not be collected and the amount of such reserve may be reasonably estimated. Risks with respect to derivative assets as of December 31, 2013 arise from cash settlements due to us from our derivative counterparties. Five purchasers of our natural gas production purchased 99.1% of the gas we delivered to market during the year ended December 31, 2013, of which 62.0% was purchased by one entity. We do not believe the loss of the aforementioned purchaser would materially affect our ability to sell the natural gas we produce as we believe other purchasers are available in our areas of operation. As of December 31, 2013, three of our natural gas purchasers and one joint interest owner accounted for 88% of our accounts receivable related to gas sales, of which one natural gas purchaser accounted for 65% of our accounts receivable related to gas sales. At December 31, 2013 and 2012, we have recorded an allowance for doubtful accounts receivable of $14,744 and $17,634, respectively, related to other revenue and not a purchaser of our natural gas. We have not experienced any significant losses from uncollectible accounts.
	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.
	Capitalized General and Administrative Expenses—Under the full cost method of accounting, a portion of our general and administrative expenses that are directly attributable to our acquisition, exploration and development activities are capitalized as part of our natural gas properties. These capitalized costs include salaries, employee benefits, costs of consulting services and other costs directly associated with those activities. We capitalized general and administrative costs related to our acquisition, exploration and development activities, during the period ended December 31, 2012 of $134,350. No such costs were capitalized in 2013.
	Derivative Instruments and Hedging Activities. Our hedging activities consist of derivative instruments entered into to hedge against changes in natural gas prices primarily through the use of fixed price swap agreements, basis swap agreements, three-way collars, and traditional collars. Consistent with our hedging policy, we entered into a series of derivative instruments to hedge a significant portion of our expected natural gas production through 2014. Typically, these derivative instruments require payments to (receipts from) counterparties based on specific indices as required by the derivative agreements. These transactions are recorded in our audited consolidated financial statements in accordance with ASC 815. Although not risk free, we believe this policy will reduce our exposure to natural gas price fluctuations and thereby achieve a more predictable cash flow. As a result, our derivative instruments are economic or cash flow hedge transactions in which we are hedging the variability of cash flow related to a forecasted transaction. We do not enter into derivative instruments for trading or other speculative purposes. At December 31, 2013, we do not have the ability to enter into additional natural gas hedges because we do not have the credit capacity with our existing natural gas hedge counterparties.
	In accordance with ASC 815-20-25, as amended, all our derivative instruments are recorded on the balance sheet at fair value and changes in the fair value of the derivatives are recorded each period in current earnings for the natural gas derivatives. The natural gas derivatives have not been designated as hedge transactions.
	At the inception of a derivative contract, we may designate the derivative as a cash flow hedge. For all derivatives designated as cash flow hedges, we document the relationship between the derivative instrument and the hedged items as well as the risk management objective for entering into the derivative instrument. To be designated as a cash flow hedge transaction, the relationship between the derivative and hedged items must be highly effective in achieving the offset of changes in cash flows attributable to the risk both at the inception of the derivative and on an ongoing basis.
	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—Effective January 1, 2008, we adopted ASC 820-10-55, which provides a framework for measuring fair value under GAAP. ASC 820-10-55 defines fair value as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. ASC 820-10-55 also establishes a fair value hierarchy that requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The standard describes three levels of inputs that may be used to measure fair value. Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date. Level 2 inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly, such as quoted prices for similar assets or liabilities; quoted prices in markets that are not active; or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities. Level 3 inputs are derived from unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. See disclosure related to the implementation of ASC 820-10-55 in Note 10—Derivative Instruments and Hedging Activities.
	The fair value of cash and cash equivalents, current receivables and payables, approximate book value because of the short maturity of these accounts.
	Stock-Based Compensation—We use the fair value recognition provisions of ASC 718. The application of ASC 718 requires the use of an option pricing model, such as the Black Scholes model, to measure the estimated fair value of the options and as a result various assumptions must be made by management that require judgment and the assumptions could be highly uncertain.

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncements	12 Months Ended
	Dec. 31, 2013
Recent Accounting Pronouncements	'
Recent Accounting Pronouncements	'
	Note 5—Recent Accounting Pronouncements
	In July 2013, the FASB issued ASU No. 2013-10, “Derivatives and Hedging (Topic 815): Inclusion of the Fed Funds Effective Swap Rate (or Overnight Index Swap Rate) as a Benchmark Interest Rate for Hedge Accounting Purposes”. The amendments in ASU 2013-10 permit the Fed Funds Effective Swap Rate (OIS) to be used as a United States benchmark interest rate for hedge accounting purposes under Topic 815, in addition to UST and LIBOR. The amendments also remove the restriction on using different benchmark rates for similar hedges. The amendments are effective prospectively for qualifying new or redesignated hedging relationships entered into on or after July 17, 2013. We have adopted and applied the provisions of ASU 2013-10 which did not impact our operating results, financial position or cash flows.
	In March 2013, the FASB issued ASU 2013-07, “Presentation of Financial Statements (Topic 205): Liquidation Basis of Accounting.” The amendments require an entity to prepare its financial statements using the liquidation basis of accounting when liquidation is imminent. Liquidation is imminent when the likelihood is remote that the entity will return from liquidation and either (a) a plan for liquidation is approved by the person or persons with the authority to make such a plan effective and the likelihood is remote that the execution of the plan will be blocked by other parties or (b) a plan for liquidation is being imposed by other forces (for example, involuntary bankruptcy). If a plan for liquidation was specified in the entity’s governing documents from the entity’s inception (for example, limited-life entities), the entity should apply the liquidation basis of accounting only if the approved plan for liquidation differs from the plan for liquidation that was specified at the entity’s inception. The amendments require financial statements prepared using the liquidation basis of accounting to present relevant information about an entity’s expected resources in liquidation by measuring and presenting assets at the amount of the expected cash proceeds from liquidation. The entity should include in its presentation of assets any items it had not previously recognized under United States GAAP but that it expects to either sell in liquidation or use in settling liabilities (for example, trademarks). The amendments are effective for entities that determine liquidation is imminent during annual reporting periods beginning after December 15, 2013, and interim reporting periods therein. Entities should apply the requirements prospectively from the day that liquidation becomes imminent. Early adoption is permitted.
	In February 2013, the FASB issued ASU No. 2013-04, “Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date”. ASU 2013-04 provides guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date, except for obligations addressed within existing guidance. The update is effective for interim and annual periods beginning after December 15, 2013 and is required to be applied retrospectively to all prior periods presented for those obligations that existed upon adoption of ASU 2013-04. We are presently assessing the potential impact of ASU 2013-04.
	In February 2013, the FASB issued ASU No. 2013-02, “Comprehensive Income (Topic 220): Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income”, to improve the transparency of reporting reclassifications out of accumulated other comprehensive income. The update requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective line items in net income if the amount being reclassified is required under accounting principles generally accepted in the United States (“GAAP”) to be reclassified in its entirety to net income. For other amounts that are not required under GAAP to be reclassified in their entirety to net income in the same reporting period, an entity is required to cross-reference other disclosures required under GAAP that provide additional detail about those amounts. The amendments are effective prospectively for reporting periods beginning after December 15, 2012. The Company has adopted and applied the provisions of ASU 2013-02 which did not impact its operating results, financial position or cash flows.
	In January 2013, the FASB issued ASU No. 2013-01, “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities.” The amendments in this update clarify that the scope of ASU 2011-11 applies to derivatives accounted for in accordance with ASC 815, Derivatives and Hedging, including bifurcated embedded derivatives, repurchase agreements and reverse repurchase agreements, and securities borrowing and securities lending transactions that are either offset in accordance with ASC 210-20-45 or ASC 815-10-45 or subject to an enforceable master netting arrangement or similar agreement. The amendments are effective during interim and annual periods beginning on or after January 1, 2013. The Company has adopted and applied the provisions of ASU 2013-01. See disclosure provided in Note 10—Derivative Instruments and Hedging Activities.

Discontinued_Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2013
Discontinued Operations	'
Discontinued Operations	'
	Note 6—Discontinued Operations
	On June 20, 2012, we disposed of Hudson’s Hope Gas, Ltd., a subsidiary which held our Canadian natural gas properties, in exchange for two million shares of Canada Energy Partners, Inc. (“CEP Shares”) which we were restricted from selling before June 20, 2013. We recognized a loss on the disposition in the amount of $0.7 million, which was made up of a $1.3 million loss related to the currency translation adjustment, offset by $0.3 million in asset retirement obligations conveyed to the buyer and the proceeds consisting of the $0.3 million in estimated fair value of the CEP shares received. The loss on this disposition has been included in Discontinued operations, net of tax, in the Consolidated Statements of Operations. Additionally, all historical operating results related to the disposed company have been removed from Operating income (loss) and included in Discontinued operations, net of tax, in the Consolidated Statements of Operations for the periods presented.
	As a result of the disposition, we are classifying these activities as a discontinued operation for all the periods presented. Results for activities reported as discontinued operations for the years ended December 31, 2013 and 2012 were as follows:
		2013		2012
	Revenues	$	—	$	—
	Operating expenses	—		32,444
	Operating loss	—		(32,444		)
	Loss on sale of Hudson’s Hope Gas, Ltd.	—		(683,154		)
	Other expense	—		(20,427		)
	Income tax expense	—		—
	Net loss	$	—	$	(736,025	)

Net_Income_Loss_Per_Common_Sha

Net Income (Loss) Per Common Share	12 Months Ended
	Dec. 31, 2013
Net Income (Loss) Per Common Share	'
Net Income (Loss) Per Common Share	'
	Note 7—Net Income (Loss) Per Common Share
	Net Income (Loss) Per Common Share— Net income (loss) per common share —basic is calculated by dividing Net income (loss) available to Common Stockholders—basic by the basic weighted average number of shares of Common Stock outstanding during the period. Net income (loss) per common share—diluted assumes the conversion of all potentially dilutive securities and is calculated by dividing Net income (loss) available to Common Stockholders—diluted by the sum of the basic weighted average number of shares of Common Stock outstanding plus potentially dilutive securities. Net income (loss) 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 common shares would have an anti-dilutive effect. A reconciliation of the numerator and denominator is as follows:
		2013		2012
	Net income (loss) available to Common Stockholders—basic	$	27,763,396	$	(155,803,152	)
	Dilutive related add back:
	Accretion of discount on Preferred Stock	2,257,968		—
	Paid-in-kind dividends on Preferred Stock	5,295,138		—
	Cash dividends paid on Preferred Stock	2,572		—
	Net income (loss) available to Common Stockholders—diluted	$	35,319,074	$	(155,803,152	)
	Net income (loss) per common share—basic:
	Net income (loss) per common share from continuing operations	$	0.69	$	(3.86	)
	Net loss per common share from discontinued operations	—		(0.02		)
	Net income (loss) per common share—basic	$	0.69	$	(3.88	)
	Net income (loss) per common share—diluted:
	Net income (loss) per common share from continuing operations	$	0.42	$	(3.86	)
	Net loss per common share from discontinued operations	—		(0.02		)
	Net income (loss) per common share—diluted	$	0.42	$	(3.88	)
	Weighted average number of common shares:
	Basic	40,481,330		40,123,608
	Potentially dilutive securities:
	Preferred stock	42,787,068		—
	Restricted stock units	116,553		—
	Diluted	83,384,951		40,123,608
	Net income per common share—basic for the year ended December 31, 2013 included $0.91 per common share, net of $0 tax, resulting solely from the Gain on the sale of properties in Alabama. Net income per common share—diluted for the year ended December 31, 2013 included $0.44 per common share, net of $0 tax, resulting from the Gain on the sale of properties in Alabama.
	Net loss per common share—diluted for the year ended December 31, 2012 excluded the effects of the Series A Convertible Redeemable Preferred Stock, the restricted shares, the restricted stock units and the stock options as the net impact would have been anti-dilutive. The impact of the Series A Convertible Redeemable Preferred Stock would have included an addition to the numerator of the Accretion of discount on Series A Convertible Redeemable Preferred Stock of $1,913,134 and dividends on Series A Convertible Redeemable Preferred Stock of $3,936,851 and an addition to the denominator of 37,813,420 in dilutive Preferred Stock, as converted. Additionally, the denominator excluded 260,725 in dilutive restricted shares, 156,992 in dilutive restricted stock units, and 2,387,504 in dilutive stock options.

Natural_Gas_Properties

Natural Gas Properties	12 Months Ended
	Dec. 31, 2013
Natural Gas Properties	'
Natural Gas Properties	'
	Note 8—Natural Gas Properties
	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, 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.
	For the year ended December 31, 2012, the unweighted arithmetic average of the Henry Hub spot market price on the first day of each month was $2.78 per Mcf, resulting in a natural gas price of $2.91 per Mcf when adjusted for regional price differentials. For the year ended December 31, 2012, we recorded $95.7 million in write-downs of the carrying value of our full cost pool.
	The following table provides a summary of the capitalized cost of our natural gas properties as of December 31, 2013 and 2012, by the year in which the costs were incurred.
		2013			2012
	Subject to depletion	$	333,109,974		$	539,077,119
	Total not subject to depletion	—			—
	Gross natural gas properties	333,109,974			539,077,119
	Less impairment of natural gas properties	(241,964,803		)	(391,118,140		)
	Less accumulated depletion	(49,161,150		)	(73,567,602		)
	Net natural gas properties	$	41,984,021		$	74,391,377
	On February 13, 2014, the Company entered into an asset purchase agreement to sell substantially all of the natural gas assets located in the Appalachian Basin in McDowell, Harrison, Wyoming, Raleigh, Barbour and Taylor Counties, West Virginia and Buchanan County, Virginia, which comprise substantially all of the Company’s remaining assets, for a purchase price of $107 million, subject to various purchase price adjustments.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligations	'
Asset Retirement Obligations	'
	Note 9—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, 2013 and 2012.
		2013			2012
	Asset retirement obligation at beginning of year	$	13,309,024		$	8,170,579
	Buyer’s assumption of liabilities	(5,509,401		)	—
	Liabilities incurred	—			14,252
	Liabilities settled	(108,123		)	(554,991		)
	Accretion of discount	1,035,717			827,771
	Revisions in estimates	453,660			4,846,818
	Currency translation adjustment	—			4,595
	Asset retirement obligation at end of year	9,180,877			13,309,024
	Less: current portion of obligation	265,470			73,706
	Long-term asset retirement obligation	$	8,915,407		$	13,235,318
	In 2013, the buyer’s assumption of liabilities related to natural gas properties sold consisted of $4,411,201 related to the sale of our Alabama properties, as described in Note 2, and $1,098,200 related to various other natural gas properties sold. In 2012, we revised our estimates primarily related to the costs to plug and abandonment our horizontal Pinnate wells, resulting in a $4.8 million non-cash charge to our full cost pool, offset by an increase to our asset retirement obligation.

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities	'
Derivative Instruments and Hedging Activities	'
	Note 10—Derivative Instruments and Hedging Activities
	The energy markets have historically been volatile, and there can be no assurance that future natural gas prices will not be subject to wide fluctuations. At December 31, 2013, we do not have the ability to enter into natural gas hedges because we do not have the credit capacity with our existing natural gas hedge counterparties.
	In an effort to reduce the effects of the volatility of the price of natural gas on our operations, management has 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 limits the downside risk of adverse price movements, it also limits 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 prohibits 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 incur accounting losses on derivatives during periods where prices are rising and gains during periods where prices are falling which may cause significant fluctuations in our Consolidated Balance Sheets and Consolidated Statements of Operations.
	Commodity Price Risk and Related Hedging Activities
	At 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	)
	At December 31, 2012, we had the following natural gas derivative contracts:
	Contract	Period	Volume		Fixed Price or		Derivative			Derivative			Derivative			Total Fair
	Type		(MMBtu)		Sold Ceiling/		asset—			liability—			liability—			Value of
					Bought Floor		current			current			non-current			Contract
	Collar	January 2014 through December 2015	3,650,000		$4.30/$3.60		$	—		$	—		$	(556,636	)	$	(556,636	)
	Collar	January 2014 through December 2015	3,650,000		$4.20/$3.50		—			—			(796,266		)	(796,266		)
	Swap	January 2013 through March 2013	360,000		$6.42		1,100,395			—			—			1,100,395
	Swap	January 2013 through March 2013	540,000		$6.50		1,156,734			—			—			1,156,734
	Swap	January 2013 through December 2013	2,190,000		$3.60		127,253			—			—			127,253
	Swap	January 2013 through March 2014	3,640,000		$3.81		758,669			—			(144,994		)	613,675
	Swap	January 2013 through March 2014	3,640,000		$3.82		786,716			—			(138,452		)	648,264
	Swap	April 2013 through December 2013	2,750,000		$3.25		—			(919,572		)	—			(919,572		)
			20,420,000				$	3,929,767		$	(919,572	)	$	(1,636,348	)	$	1,373,847
	At December 31, 2012, we had the following forward sales at NYMEX plus a fixed basis:
	Period	Volume	Fixed
		(MMBtu)	Basis
	January 2013 through March 2013	450,000	$	0.19
	January 2013 through March 2013	918,000	$	0.22
		1,368,000
	The aforementioned forward physical sale contracts qualified for normal purchase and sale exemption and, as such, we have elected not to record it on the Consolidated Balance Sheets using mark-to-market accounting.
	We have reviewed the financial strength of our hedge counterparties and believe our credit risk to be minimal. Our hedge counterparties are participants or affiliates of the participants in our credit agreement and the collateral for the outstanding borrowings under our credit agreement is used as collateral for our hedges. We do not have rights to collateral from our counterparties, nor do we have rights of offset against borrowings under our credit agreement.
	We estimate 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 (“OTC”) 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 are used to discount future cash flows. The estimated fair value of our natural gas derivative contracts also reflects its nonperformance risk, the risk that the obligation will not be fulfilled. Because nonperformance risk includes our counterparties’ and our credit risk, we have 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 transfers of assets and liabilities between Level 1 and Level 2 of the fair value measurement hierarchy during the year ended December 31, 2013. Based on the use of observable market inputs, we have 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, 2013				December 31, 2012					December 31, 2013					December 31, 2012
		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		$	3,929,767		Derivative liability		$	834,151		Derivative liability		$	919,572
						(current)					(current)					(current)
	Natural gas hedge positions	Derivative asset (non- current)	—			Derivative asset		—			Derivative liability		709,571			Derivative liability		1,636,348
						(non- current)					(non- current)					(non-current)
	Total derivatives not designated as hedging instruments		$	—				$	3,929,767				$	1,543,722				$	2,555,920
	The following losses (gains) 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	2013			2012
	Natural gas collar/swap settled positions	Gains on natural gas derivatives	$	(1,106,378	)	$	(16,383,003	)
	Natural gas collar/swap unsettled positions	Losses on natural gas derivatives	2,917,569			11,967,386
	Total loss (gain)		$	1,811,191		$	(4,415,617	)

Investment_in_Canada_Energy_Pa

Investment in Canada Energy Partners	12 Months Ended
	Dec. 31, 2013
Investment in Canada Energy Partners	'
Investment in Canada Energy Partners	'
	Note 11—Investment in Canada Energy Partners
	At December 31, 2013, we owned two million shares of Canada Energy Partners (“CEP”), discussed in Note 6—Discontinued Operations. 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 have classified those shares as available for sale and recorded at fair value in Other current assets on the Consolidated Balance Sheets at 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 at December 31, 2013. At December 31, 2012, 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, 2012 consisted of a $61,661 decrease in market value offset by a $8,641 gain related to currency translation on the CEP shares.

Restructuring_Costs

Restructuring Costs	12 Months Ended
	Dec. 31, 2013
Restructuring Costs	'
Restructuring Costs	'
	Note 12—Restructuring Costs
	Restructuring activities consist of senior management and board of directors realignment.  The restructuring costs for the year ended December 31, 2013 of $0.1 million were cash payments to our former CEO. The restructuring costs for the year ended December 31, 2012 of $1.1 million included cash payments to our former CEO of $0.8 million under separation and consulting agreements, share-based awards conveyed to our former CEO of $0.1 million and other costs of $0.2 million

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2013
Long-Term Debt	'
Long-Term Debt	'
	Note 13—Long-Term Debt
	During 2012, the amounts borrowed under our credit agreement exceeded the borrowing base.  Borrowings under our credit agreement at August 8, 2012 totaled $148.6 million. On August 8, 2012, in connection with the excess of borrowings over the borrowing base, we amended our 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, the Company closed the sale of all of its 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 Company’s credit agreement, which eliminated the borrowing base deficiency. After this repayment, borrowings outstanding under our credit agreement totaled $77.0 million.
	Our credit agreement no longer provides for loans to be available on a revolving basis up to the amount of the borrowing base. As a result, the current outstanding loans, once repaid, may not be re-borrowed. All outstanding borrowings under our credit agreement are due and payable on the earliest to occur of: (i) June 30, 2014, (ii) the closing of the Asset Sale pursuant to the Asset Purchase Agreement, or the sale of the Assets pursuant to a substitute purchase agreement, or (iii) the termination of the Asset Purchase Agreement or any substitute purchase agreement. Our borrowing base is defined to be the equal to the amount borrowed under our credit agreement. Our credit agreement provides for interest to accrue at a rate calculated, at our option, at the Adjusted Base Rate plus a margin of 2.00% or the London Interbank Offered Rate (the “LIBOR Rate”) plus a margin of 3.00%. Adjusted Base Rate is defined to be the greater of (i) the agent’s base rate or (ii) the federal funds rate plus one half of one percent or (iii) the LIBOR Rate plus a margin of 1.00%. All financial covenants were deleted by the Amendment and were replaced with a capital expenditure covenant (a maximum of $1.5 million in 2012 and $1.0 million in 2013 and thereafter).
	As of December 31, 2013, we had $71.6 million of borrowings outstanding under our credit agreement. As of December 31, 2013, the interest rates applied to borrowings were 3.24%. For the year ended December 31, 2013, we had no borrowings and made payments of $67.8 million under our credit agreement. For the year ended December 31, 2012, we borrowed $10.5 million and made payments of $29.1 million under our credit agreement.
	For the years ended December 31, 2013 and 2012, interest on the borrowings averaged 4.10% and 3.39% per annum, respectively.
	The following is a summary of our long-term debt at December 31, 2013 and 2012:
		December 31,			December 31,
		2013			2012
	Borrowings under credit agreement	$	71,550,000		$	139,300,000
	Less current maturities included in current liabilities	(71,550,000		)	(10,300,000		)
	Total long-term debt	$	—		$	129,000,000
	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 at December 31, 2013 and 2012 was estimated to be approximately $70.1 million and $121.6 million, respectively.
	The following were maturities of long-term debt for each of the next five years at December 31, 2013:
	Year	Amount
	2014	$	71,550,000
	2015	—
	2016	—
	2017	—
	2018	—
		$	71,550,000

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Taxes	'
Income Taxes	'
	Note 14—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 net operating losses (“NOLs”) of approximately $156.0 million and $162.3 million, respectively, at December 31, 2013 that are available to reduce future taxable income. For tax reporting purposes, we had federal and state NOLs of approximately $137.8 million and $127.0 million, respectively, at December 31, 2012 that were available to reduce future taxable income. Our first material federal NOL carryforward expires in 2022 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., as described in Note 6—Discontinued Operations, of approximately $33.9 million at December 31, 2013 that is available to reduce future taxable capital gains and expiring in 2017.
	At December 31, 2013, we have a valuation allowance of $83.5 million recorded against our net deferred tax asset which includes $70.5 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., as described in Note 6—Discontinued Operations.
	Deferred Tax Assets and Liabilities
	An analysis of our deferred tax assets and liabilities as of December 31, 2013 and 2012:
		2013			2012
	Current deferred tax asset:
	Compensation expense and other	$	43,161		$	24,089
	Tax basis in excess of book basis of derivative contracts	318,645			—
	Valuation allowance	(361,806		)	—
	Total current deferred tax asset	—			24,089
	Current deferred tax liability:
	Book basis in excess of tax basis of derivative contracts	—			(1,149,893		)
	Net current deferred tax liability	$	—		$	(1,125,804	)
	Long-term deferred tax asset:
	Net operating loss carryforward	$	60,233,320		$	52,505,971
	Compensation expense and other	1,084,474			1,066,856
	Accrued asset retirement obligations	2,187,078			1,832,737
	Tax basis in excess of book basis of derivative contracts	1,156,475			1,451,763
	Tax basis of natural gas properties in excess of book basis	5,502,048			27,557,569
	Capital loss on sale of Canadian properties	12,936,668			13,352,031
	Valuation allowance	(83,100,063		)	(96,641,123		)
	Total long-term deferred tax assets	—			1,125,804
	Net long-term deferred tax asset	$	—		$	1,125,804
	Effective Tax Rate
	The income tax expense in the current year period was different than the amount computed using the statutory rate primarily due to a $13.2 million reduction of the valuation allowance on our deferred tax asset. A reconciliation of the effective tax rate to the statutory rate for the year ended December 31, 2013 is rate is as follows:
	Amount computed using statutory rates	$	12,016,985		34	%
	State income taxes—net of federal benefit	591,595			1.68	%
	Reduction of valuation allowance	(13,179,253		)	-37.29	%
	Nondeductible items and other	595,673			1.68	%
	Income tax provision	$	25,000		0.07	%
	The income tax expense for the year ended December 31, 2012 was different than the amount computed using the statutory rate primarily due to an $83.5 million valuation allowance recorded on our deferred tax asset. A reconciliation of the effective tax rate to the statutory rate is as follows:
		United States					Canada					Total
	Amount computed using statutory rates	$	(36,004,892	)	34	%	$	(3,307	)	25	%	$	(36,008,199	)	34	%
	State income taxes—net of federal benefit	(3,319,194		)	3.14	%	—			0	%	(3,319,194		)	3.13	%
	Valuation Allowance	83,537,181			–78.89	%	3,307			–25.00	%	83,540,488			–78.88	%
	Nondeductible items and other	(169,895		)	0.16	%	—			0	%	(169,895		)	0.16	%
	Income tax provision	$	44,043,200		–41.59	%	$	—		0	%	$	44,043,200		–41.59	%
	The following components of the income tax expense for the years ended December 31, 2013 and 2012 are as follows:
		2013			2012
	Current:
	State	$	25,000		$	25,000
	Federal	—			—
	Deferred:
	State	566,595			(3,344,193		)
	State valuation allowance	(566,595		)	11,663,218
	Federal	12,612,658			(36,174,788		)
	Federal valuation allowance	(12,612,658		)	71,873,963
	Income tax provision	$	25,000		$	44,043,200
	Uncertain Tax Positions
	ASC 740 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. The amount of unrecognized tax benefits of $272,600 has not changed in the three year period ended December 31, 2013. It is expected that the amount of unrecognized tax benefits may change in the next twelve months; however we do not expect the change to have a significant impact on our results of operations or the financial position.
	We file a consolidated federal income tax return in the United States and various combined and separate filings in several state and local jurisdictions. With limited exceptions, we are no longer subject to United States federal, state and local, or non-United States income tax examinations by tax authorities for years before 2002.
	Our continuing practice is to recognize estimated interest related to potential underpayment on any unrecognized tax benefits as a component of interest expense in the consolidated statement of operations. Penalties, if incurred, would be recognized as a component of penalty expense. We did not have any accrued interest or penalties associated with any unrecognized tax benefits at December 31, 2013 and 2012, nor was any interest expense recognized during the years ended December 31, 2013 and 2012. We do not anticipate that total unrecognized tax benefits will significantly change due to the settlement of audits and the expiration of statute of limitations prior to December 31, 2013.

Common_Stock

Common Stock	12 Months Ended
	Dec. 31, 2013
Common Stock	'
Common Stock	'
	Note 15—Common Stock
	At December 31, 2013 and 2012, there were 40,662,749 and 40,690,077 shares, respectively, of Common Stock, both including 10,432 shares of treasury stock held by the Company. Also included in Common Stock at December 31, 2013 and 2012 were 158,870 and 254,260 shares of restricted stock, respectively. The following table details the activity related to our Common Stock for the year ended December 31, 2013:
		Date	Shares
	Common stock at January 1, 2013		40,690,077
	Purchased by the Company and cancelled for the payment of withholding taxes due on vested shares of restricted stock	1/7/13	(121	)
	Purchased by the Company and cancelled for the payment of withholding taxes due on vested shares of restricted stock	3/15/13	(470	)
	Forfeited upon default of shareholder loans	6/6/13	(24,428	)
	Shares of restricted stock forfeited upon termination of employment	6/14/13	(1,504	)
	Shares of restricted stock forfeited upon termination of employment	7/8/13	(805	)
	Common stock at December 31, 2013		40,662,749

Series_A_Convertible_Redeemabl

Series A Convertible Redeemable Preferred Stock	12 Months Ended
	Dec. 31, 2013
Series A Convertible Redeemable Preferred Stock	'
Series A Convertible Redeemable Preferred Stock	'
	Note 16—Series A Convertible Redeemable Preferred Stock
	At December 31, 2013 and 2012, 6,000,571 and 5,305,865 shares of Preferred Stock were issued and outstanding, respectively. At December 31, 2013, an additional 1,401,261 shares of our Series A Convertible Redeemable Preferred Stock (“Preferred Stock”) are reserved exclusively for the payment of paid-in-kind dividends (“PIK dividends”). We measure the fair value of PIK dividends using a discounted cash flow analysis based on our current borrowing rates (categorized as level 3). The following table details the activity related to the Preferred Stock for the years ended December 31, 2013 and 2012:
		Dividend Period	Date Issued	Number of Shares	Balance
		(Three Months Ended)
	Balance at January 1, 2012			4,549,537	$	28,482,624
	Accretion of discount on Preferred Stock				1,913,134
	PIK Dividends Issued for Preferred Stock :	12/31/11	1/3/12	142,095	1,522,035
		3/31/12	4/2/12	146,549	1,240,719
		6/30/12	7/2/12	151,128	619,625
		9/30/12	10/1/12	155,847	864,951
		12/31/12	12/31/12	160,709	1,208,799
	Balance At December 31, 2012			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 At December 31, 2013			6,000,571	$	43,404,993

ShareBased_Awards

Share-Based Awards	12 Months Ended
	Dec. 31, 2013
Share-Based Awards	'
Share-Based Awards	'
	Note 17—Share-Based Awards
	Our 2006 Long-Term Incentive Plan (the “2006 Plan”) authorizes the granting of incentive stock options, non-qualified stock options, stock appreciation rights, stock awards, restricted stock, restricted stock units and performance awards. A maximum of 4,000,000 shares are available for grant under this plan. The 2006 Plan is available to our employees and independent directors. However, the Company does not anticipate any additional grants will be awarded under the 2006 Plan in the immediate future. The exercise price of stock options granted under this plan may not be less than the fair market value of the Common Stock on the date of grant. The options generally have a term of seven years and vest evenly over three years, except performance based awards which are granted solely to our named executive officers, and options issued to directors. Performance based awards granted under the 2006 Plan vest once the performance criteria have been met. Options granted to our directors vest immediately.
	During the year ended December 31, 2013, we recorded compensation expense of $232,760 of which $18,609 was allocated to lease operating expenses and $214,151 was allocated to general and administrative expenses. The future compensation cost of all the outstanding awards at December 31, 2013 is $67,744 which will be amortized over the vesting period of such awards. The weighted average remaining useful life of the future compensation cost is 0.51 years.
	During the year ended December 31, 2012, we recorded compensation expense of $601,571 of which $35,319 was allocated to lease operating expenses, $414,513 was allocated to general and administrative expenses, $131,127 was allocated to restructuring costs, and $20,612 was capitalized to natural gas properties.
	On May 15, 2012, 150,000 shares of restricted stock were granted to our executive officers. The compensation cost was determined using NASDAQ’s closing price of our Common Stock on the day of issuance and is expensed ratably over the three-year vesting period.
	On March 28, 2012, May 11, 2012, and August 10, 2012, 64,284, 97,824 and 300,000 shares of common stock, respectively, were issued under the 2006 Plan to our independent members of our Board of Directors, each representing 12.5% of their annual retainer. The compensation cost was determined using NASDAQ’s closing price of our common stock on the day of issuance.
	Incentive Stock Options
	The table below summarizes incentive stock option activity for the years ended December 31, 2013 and 2012:
		Number of		Weighted		Average	Aggregate
		Options		Average		Remaining	Intrinsic
				Exercise		Contractual	Value
				Price		Life
	Outstanding at January 1, 2012	1,574,886		$	1.11	3.2	$	113,071
	Forfeited	(162,147	)	$	1.05
	Outstanding at December 31, 2012	1,412,739		$	1.11	4.1	$	—
	Options exercisable at December 31, 2012	958,090		$	0.99	4.3	$	—
	Forfeited	(213,306	)	$	1.12
	Outstanding at December 31, 2013	1,199,433		$	1.11	2.7	$	—
	Options exercisable at December 31, 2013	1,046,840		$	1.04	3.5	$	—
	Non-Qualified Stock Options
	The table below summarizes non-qualified stock option activity for the years ended December 31, 2013 and 2012:
		Number of		Weighted		Average	Aggregate
		Options		Average		Remaining	Intrinsic
				Exercise		Contractual	Value
				Price		Life
	Outstanding at January 1, 2012	992,272		$	2.32
	Forfeited	(17,507	)	$	2.12
	Outstanding at December 31, 2012	974,765		$	2.33	1.3	$	—
	Options exercisable at December 31, 2012	933,242		$	2.4	1.3	$	—
	Expired	(600,000	)	$	2.5
	Outstanding at December 31, 2013	374,765		$	2.05	0.6	$	—
	Options exercisable at December 31, 2013	333,242		$	2.22	1.6	$	—
	Restricted Stock Awards
	The table below summarizes non-vested restricted stock awards activity for the years ended December 31, 2013 and 2012:
		Number of		Weighted
		Shares		Average
				Grant Date
				Fair Value
	Non-vested restricted stock at December 31, 2012	293,166		$	3.03
	Granted	150,000		$	0.43
	Vested	(159,978	)	$	3
	Forfeited	(28,928	)	$	3.77
	Non-vested restricted stock at December 31, 2012	254,260		$	1.43
	Vested	(93,416	)	$	0.74
	Forfeited	(2,779	)	$	1.32
	Non-vested restricted stock at December 31, 2013	158,065		$	1.83
	Restricted Stock Unit Awards
	On April 5, 2011, we granted 232,089 restricted stock units to our five executive officers. These restricted stock units vest upon the Company’s achievement of certain performance targets, but no earlier than ratably over the three year period following the grant date, at which time one common share will be issued and exchanged for each restricted stock unit held. If the requisite performance targets are not achieved in the seven year period ended April 5, 2018, the restricted stock units will expire. Restricted stock units are included in the calculation of diluted earnings per share utilizing the treasury stock method. On April 30, 2012, 99,108 restricted stock units vested with a vesting date fair value of $0.53 per share. On June 25, 2012, 16,428 restricted stock units were forfeited. There have been no grants of restricted stock units subsequent to the aforementioned grant. Unrecognized compensation cost related the restricted stock units is $116,553 at December 31, 2013.

Profit_Sharing_Plan

Profit Sharing Plan	12 Months Ended
	Dec. 31, 2013
Profit Sharing Plan	'
Profit Sharing Plan	'
	Note 18—Profit Sharing Plan
	Substantially all of the employees are covered by our profit sharing plan under Section 401(k) of the Internal Revenue Code. Eligible employees may make contributions to the plan by electing to defer some of their compensation. We are required to match 100 percent of the first three percent of their annual compensation contributed and 50 percent of the following two percent of their annual compensation contributed. Our matching contributions vest immediately.  Our contributions to the Plan for the years ended December 31, 2013 and 2012 were $174,958 and $227,299, respectively. We elected a Safe Harbor 401(k) plan for the years ended December 31, 2013 and 2012. 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.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
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, 2013, 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 operating leases for office space, office equipment and field compressors expiring in various years through 2019. Future minimum lease commitments as of December 31, 2013 under non-cancelable operating leases having remaining terms in excess of one year are as follows:
	Year Ended December 31,	Amount
	2014	$	841,274
	2015	420,540
	2016	378,225
	2017	186,008
	2018 and thereafter	215,333
	Total future minimum lease commitments	$	2,041,380
	Total rental expenses under operating leases were approximately $2.3 million and $2.8 million for the years ended December 31, 2013 and 2012, respectively.
	Transportation and Gathering Contracts—As of December 31, 2013, under the following firm transportation contracts, we can transport maximum daily volumes of (1) 500 MMBtu’s continuing until October 31, 2015, (2) 15,000 MMBtu’s continuing until April 1, 2022, (3) 10,000 MMBtu’s continuing until April 1, 2017, (4) 15,000 MMBtu’s continuing until October 31, 2024, and (5) 10,000 MMBtu’s continuing until June 30, 2017. We have a right to extend each of these contracts at the maximum tariff rate. Additionally, we have a firm gathering contract for daily volumes of 10,000 Dth’s through June 30, 2017. As of December 31, 2013, the maximum commitment remaining under the transportation and gathering contracts is approximately $23.9 million.
	Other Commitments
	In the event that the Asset Sale described in Note 3— Going Concern and Management’s Plans is terminated for select reasons by GeoMet, GeoMet is obligated to pay a termination fee to the buyer in the amount of $4,280,000, as well as any professional fees associated with the termination.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies	'
Principles of Consolidation	'
	Principles of Consolidation—The accompanying Audited Consolidated Financial Statements are presented in conformity with GAAP and include our accounts and the accounts of our wholly-owned subsidiaries, GeoMet Operating Company, Inc., GeoMet Gathering Company LLC, and Hudson’s Hope Gas, Ltd. (disposed on June 20, 2012). 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 audited consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Our most significant financial estimates are related to our proved gas reserves. Estimates of proved gas reserves are key components of our depletion rate for natural gas properties and our full cost ceiling test limitation. In addition, other significant estimates include estimates used in computing taxes, stock-based compensation, asset retirement obligations, fair value of derivative contracts and accrued receivables and payables. Actual results could differ from these estimates.
Natural Gas Properties	'
	Natural Gas Properties—The method of accounting for natural gas properties 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 proscribed by the SEC. For more information see Note 8—Natural Gas Properties.
Asset Retirement Obligations	'
	Asset Retirement Obligations — Accounting Standards Codification (“ASC”) 410-20-25 establishes accounting and reporting standards for retirement obligations associated with tangible long-lived assets that result from the legal obligation to plug, abandon and dismantle existing wells and facilities that we have acquired, constructed or developed. It requires that the fair value of the liability for asset retirement obligations be recognized in the period in which it is incurred. Upon initial recognition of the asset retirement obligation, the asset retirement cost is capitalized by increasing the carrying amount of the long-lived asset by the same amount as the liability. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the related asset, included in the depletable base of our natural gas properties, or impaired. Periodically, we update the cost assumptions resulting from changes in market and environmental regulation and revise the liability recorded accordingly.
Other Property and Equipment	'
	Other Property and Equipment—The cost of other property and equipment is depreciated over the estimated useful lives of the related assets. The cost of leasehold improvements is depreciated over the lesser of the length of the related leases or the estimated useful lives of the assets. Depreciation is computed on the straight-line basis over the following estimated useful lives which range from three to seven years.
	Furniture and fixtures	7 years
	Automobiles	3 years
	Machinery and equipment	5 years
	Software and computer equipment	3 years
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 the provisions of ASC 740. 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 ASC 740, the effect of a change in tax rates of deferred tax assets and liabilities is recognized in the year of the enacted change. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. At December 31, 2013, 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 Internal Revenue Code Section 382. We have a significant deferred tax asset associated with net operating loss carryforwards (“NOLs”).
	ASC 740 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—We derive revenue primarily from the sale of produced natural gas. We use the sales method of accounting for the recognition of gas revenue whereby revenues, net of royalties, are recognized as the production is sold to a purchaser. The amount of gas sold may differ from the amount to which the Company is entitled based on its working interest or net revenue interest in the properties. In instances where we have wellhead imbalances, we use the entitlements method. A ready market for natural gas allows us to sell our natural gas shortly after production at various pipeline receipt points at which time title and risk of loss transfers to the buyer. Revenue is recorded when title is transferred based on our nominations and net revenue interests. Pipeline imbalances occur when our production delivered into the pipeline varies from the gas we nominated for sale. Depending on the agreement in place, imbalances may be made up in future production or settled with cash approximately thirty days from date of production. Imbalances are recorded as either a reduction or increase of revenue depending upon whether we are over-delivered or under-delivered.
	Settlements of gas sales occur after the month in which the gas was produced. We estimate and accrue for the value of these sales using information available at the time financial statements are generated. Differences are reflected in the accounting period during which payments are received from the purchaser.
Industry Segment and Geographic Information	'
	Industry Segment and Geographic Information—We operate in one industry, which is the exploration, development and production of natural gas.
Concentrations of Market Risk	'
	Concentrations of Market Risk—Our future results will be affected by the market price of natural gas. The availability of a ready market for natural gas will depend on numerous factors beyond our control, including weather, production of natural gas, imports, marketing, competitive fuels, proximity of natural gas pipelines and other transportation facilities, any oversupply or undersupply of natural gas, the regulatory environment, and other regional and political events, none of which can be predicted with certainty.
Concentration of Credit Risk	'
	Concentration of Credit Risk—Financial instruments, which subject us to concentrations of credit risk, consist primarily of cash and cash equivalents, accounts receivable and derivative assets. We place our cash investments with highly qualified financial institutions. Risks with respect to receivables as of December 31, 2013 and 2012 arise substantially from the sales of natural gas and joint interest billings from our working interest partners. We routinely assess the recoverability of all material trade and other receivables to determine their collectability. We accrue a reserve on a receivable when, based on management’s judgment, it is probable that a receivable will not be collected and the amount of such reserve may be reasonably estimated. Risks with respect to derivative assets as of December 31, 2013 arise from cash settlements due to us from our derivative counterparties. Five purchasers of our natural gas production purchased 99.1% of the gas we delivered to market during the year ended December 31, 2013, of which 62.0% was purchased by one entity. We do not believe the loss of the aforementioned purchaser would materially affect our ability to sell the natural gas we produce as we believe other purchasers are available in our areas of operation. As of December 31, 2013, three of our natural gas purchasers and one joint interest owner accounted for 88% of our accounts receivable related to gas sales, of which one natural gas purchaser accounted for 65% of our accounts receivable related to gas sales. At December 31, 2013 and 2012, we have recorded an allowance for doubtful accounts receivable of $14,744 and $17,634, respectively, related to other revenue and not a purchaser of our natural gas. We have not experienced any significant losses from uncollectible accounts.
	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.
Capitalized General and Administrative Expenses	'
	Capitalized General and Administrative Expenses—Under the full cost method of accounting, a portion of our general and administrative expenses that are directly attributable to our acquisition, exploration and development activities are capitalized as part of our natural gas properties. These capitalized costs include salaries, employee benefits, costs of consulting services and other costs directly associated with those activities. We capitalized general and administrative costs related to our acquisition, exploration and development activities, during the period ended December 31, 2012 of $134,350. No such costs were capitalized in 2013.
Derivative Instruments and Hedging Activities	'
	Derivative Instruments and Hedging Activities. Our hedging activities consist of derivative instruments entered into to hedge against changes in natural gas prices primarily through the use of fixed price swap agreements, basis swap agreements, three-way collars, and traditional collars. Consistent with our hedging policy, we entered into a series of derivative instruments to hedge a significant portion of our expected natural gas production through 2014. Typically, these derivative instruments require payments to (receipts from) counterparties based on specific indices as required by the derivative agreements. These transactions are recorded in our audited consolidated financial statements in accordance with ASC 815. Although not risk free, we believe this policy will reduce our exposure to natural gas price fluctuations and thereby achieve a more predictable cash flow. As a result, our derivative instruments are economic or cash flow hedge transactions in which we are hedging the variability of cash flow related to a forecasted transaction. We do not enter into derivative instruments for trading or other speculative purposes. At December 31, 2013, we do not have the ability to enter into additional natural gas hedges because we do not have the credit capacity with our existing natural gas hedge counterparties.
	In accordance with ASC 815-20-25, as amended, all our derivative instruments are recorded on the balance sheet at fair value and changes in the fair value of the derivatives are recorded each period in current earnings for the natural gas derivatives. The natural gas derivatives have not been designated as hedge transactions.
	At the inception of a derivative contract, we may designate the derivative as a cash flow hedge. For all derivatives designated as cash flow hedges, we document the relationship between the derivative instrument and the hedged items as well as the risk management objective for entering into the derivative instrument. To be designated as a cash flow hedge transaction, the relationship between the derivative and hedged items must be highly effective in achieving the offset of changes in cash flows attributable to the risk both at the inception of the derivative and on an ongoing basis.
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—Effective January 1, 2008, we adopted ASC 820-10-55, which provides a framework for measuring fair value under GAAP. ASC 820-10-55 defines fair value as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. ASC 820-10-55 also establishes a fair value hierarchy that requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The standard describes three levels of inputs that may be used to measure fair value. Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date. Level 2 inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly, such as quoted prices for similar assets or liabilities; quoted prices in markets that are not active; or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities. Level 3 inputs are derived from unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. See disclosure related to the implementation of ASC 820-10-55 in Note 10—Derivative Instruments and Hedging Activities.
	The fair value of cash and cash equivalents, current receivables and payables, approximate book value because of the short maturity of these accounts.
Stock-Based Compensation	'
	Stock-Based Compensation—We use the fair value recognition provisions of ASC 718. The application of ASC 718 requires the use of an option pricing model, such as the Black Scholes model, to measure the estimated fair value of the options and as a result various assumptions must be made by management that require judgment and the assumptions could be highly uncertain.

Sale_of_Coalbed_Methane_Proper1

Sale of Coalbed Methane Properties in Alabama (Tables)	12 Months Ended
	Dec. 31, 2013
Sale of Coalbed Methane Properties in Alabama	'
Schedule of total gain on the sale	'
	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.
Schedule of unaudited pro forma balances that reflect the sale of coalbed methane assets in Alabama	'
		2013			2012
	Revenue	$	31,967,227		$	27,564,502
	Income (loss) from continuing operations	$	37,908,108		$	(71,115,461	)
	Net income (loss)	$	34,861,753		$	(119,782,988	)
	Net income (loss) available to Common Stockholders	$	27,306,075		$	(125,632,973	)
	Net income (loss)per common share—basic	$	0.67		$	(3.13	)
	Net income (loss)per common share—diluted	$	0.42		$	(3.13	)

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies	'
Schedule of estimated useful lives	'
	Furniture and fixtures	7 years
	Automobiles	3 years
	Machinery and equipment	5 years
	Software and computer equipment	3 years

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2013
Discontinued Operations	'
Schedule of statement of operations	'
		2013		2012
	Revenues	$	—	$	—
	Operating expenses	—		32,444
	Operating loss	—		(32,444		)
	Loss on sale of Hudson’s Hope Gas, Ltd.	—		(683,154		)
	Other expense	—		(20,427		)
	Income tax expense	—		—
	Net loss	$	—	$	(736,025	)

Net_Income_Loss_Per_Common_Sha1

Net Income (Loss) Per Common Share (Tables)	12 Months Ended
	Dec. 31, 2013
Net Income (Loss) Per Common Share	'
Schedule of reconciliation of the numerator and denominator	'
		2013		2012
	Net income (loss) available to Common Stockholders—basic	$	27,763,396	$	(155,803,152	)
	Dilutive related add back:
	Accretion of discount on Preferred Stock	2,257,968		—
	Paid-in-kind dividends on Preferred Stock	5,295,138		—
	Cash dividends paid on Preferred Stock	2,572		—
	Net income (loss) available to Common Stockholders—diluted	$	35,319,074	$	(155,803,152	)
	Net income (loss) per common share—basic:
	Net income (loss) per common share from continuing operations	$	0.69	$	(3.86	)
	Net loss per common share from discontinued operations	—		(0.02		)
	Net income (loss) per common share—basic	$	0.69	$	(3.88	)
	Net income (loss) per common share—diluted:
	Net income (loss) per common share from continuing operations	$	0.42	$	(3.86	)
	Net loss per common share from discontinued operations	—		(0.02		)
	Net income (loss) per common share—diluted	$	0.42	$	(3.88	)
	Weighted average number of common shares:
	Basic	40,481,330		40,123,608
	Potentially dilutive securities:
	Preferred stock	42,787,068		—
	Restricted stock units	116,553		—
	Diluted	83,384,951		40,123,608

Natural_Gas_Properties_Tables

Natural Gas Properties (Tables)	12 Months Ended
	Dec. 31, 2013
Natural Gas Properties	'
Summary of the capitalized cost of natural gas properties	'
		2013			2012
	Subject to depletion	$	333,109,974		$	539,077,119
	Total not subject to depletion	—			—
	Gross natural gas properties	333,109,974			539,077,119
	Less impairment of natural gas properties	(241,964,803		)	(391,118,140		)
	Less accumulated depletion	(49,161,150		)	(73,567,602		)
	Net natural gas properties	$	41,984,021		$	74,391,377

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligations	'
Schedule of changes to asset retirement obligations	'
		2013			2012
	Asset retirement obligation at beginning of year	$	13,309,024		$	8,170,579
	Buyer’s assumption of liabilities	(5,509,401		)	—
	Liabilities incurred	—			14,252
	Liabilities settled	(108,123		)	(554,991		)
	Accretion of discount	1,035,717			827,771
	Revisions in estimates	453,660			4,846,818
	Currency translation adjustment	—			4,595
	Asset retirement obligation at end of year	9,180,877			13,309,024
	Less: current portion of obligation	265,470			73,706
	Long-term asset retirement obligation	$	8,915,407		$	13,235,318

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative instruments and hedging activities	'
Schedule of fair value of derivative instruments	'
		Asset Derivatives									Liability Derivatives
		December 31, 2013				December 31, 2012					December 31, 2013					December 31, 2012
		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		$	3,929,767		Derivative liability		$	834,151		Derivative liability		$	919,572
						(current)					(current)					(current)
	Natural gas hedge positions	Derivative asset (non- current)	—			Derivative asset		—			Derivative liability		709,571			Derivative liability		1,636,348
						(non- current)					(non- current)					(non-current)
	Total derivatives not designated as hedging instruments		$	—				$	3,929,767				$	1,543,722				$	2,555,920
Schedule of losses (gains) on our hedging instruments 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	2013			2012
	Natural gas collar/swap settled positions	Gains on natural gas derivatives	$	(1,106,378	)	$	(16,383,003	)
	Natural gas collar/swap unsettled positions	Losses on natural gas derivatives	2,917,569			11,967,386
	Total loss (gain)		$	1,811,191		$	(4,415,617	)
Commodity derivative contract | Natural gas collar positions	'
Derivative instruments and hedging activities	'
Schedule of derivative contract positions	'
	At 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	)
	At December 31, 2012, we had the following natural gas derivative contracts:
	Contract	Period	Volume		Fixed Price or		Derivative			Derivative			Derivative			Total Fair
	Type		(MMBtu)		Sold Ceiling/		asset—			liability—			liability—			Value of
					Bought Floor		current			current			non-current			Contract
	Collar	January 2014 through December 2015	3,650,000		$4.30/$3.60		$	—		$	—		$	(556,636	)	$	(556,636	)
	Collar	January 2014 through December 2015	3,650,000		$4.20/$3.50		—			—			(796,266		)	(796,266		)
	Swap	January 2013 through March 2013	360,000		$6.42		1,100,395			—			—			1,100,395
	Swap	January 2013 through March 2013	540,000		$6.50		1,156,734			—			—			1,156,734
	Swap	January 2013 through December 2013	2,190,000		$3.60		127,253			—			—			127,253
	Swap	January 2013 through March 2014	3,640,000		$3.81		758,669			—			(144,994		)	613,675
	Swap	January 2013 through March 2014	3,640,000		$3.82		786,716			—			(138,452		)	648,264
	Swap	April 2013 through December 2013	2,750,000		$3.25		—			(919,572		)	—			(919,572		)
			20,420,000				$	3,929,767		$	(919,572	)	$	(1,636,348	)	$	1,373,847
Commodity derivative contract | Forward sales	'
Derivative instruments and hedging activities	'
Schedule of derivative contract positions	'
	At December 31, 2012, we had the following forward sales at NYMEX plus a fixed basis:
	Period	Volume	Fixed
		(MMBtu)	Basis
	January 2013 through March 2013	450,000	$	0.19
	January 2013 through March 2013	918,000	$	0.22
		1,368,000

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Long-Term Debt	'
Summary of long-term debt	'
		December 31,			December 31,
		2013			2012
	Borrowings under credit agreement	$	71,550,000		$	139,300,000
	Less current maturities included in current liabilities	(71,550,000		)	(10,300,000		)
	Total long-term debt	$	—		$	129,000,000
Summary of maturities of long-term debt	'
	Year	Amount
	2014	$	71,550,000
	2015	—
	2016	—
	2017	—
	2018	—
		$	71,550,000

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Taxes	'
Schedule of the entity's deferred tax assets and liabilities	'
		2013			2012
	Current deferred tax asset:
	Compensation expense and other	$	43,161		$	24,089
	Tax basis in excess of book basis of derivative contracts	318,645			—
	Valuation allowance	(361,806		)	—
	Total current deferred tax asset	—			24,089
	Current deferred tax liability:
	Book basis in excess of tax basis of derivative contracts	—			(1,149,893		)
	Net current deferred tax liability	$	—		$	(1,125,804	)
	Long-term deferred tax asset:
	Net operating loss carryforward	$	60,233,320		$	52,505,971
	Compensation expense and other	1,084,474			1,066,856
	Accrued asset retirement obligations	2,187,078			1,832,737
	Tax basis in excess of book basis of derivative contracts	1,156,475			1,451,763
	Tax basis of natural gas properties in excess of book basis	5,502,048			27,557,569
	Capital loss on sale of Canadian properties	12,936,668			13,352,031
	Valuation allowance	(83,100,063		)	(96,641,123		)
	Total long-term deferred tax assets	—			1,125,804
	Net long-term deferred tax asset	$	—		$	1,125,804
Schedule of reconciliation of effective tax rate to the statutory rate	'
	A reconciliation of the effective tax rate to the statutory rate for the year ended December 31, 2013 is rate is as follows:
	Amount computed using statutory rates	$	12,016,985		34	%
	State income taxes—net of federal benefit	591,595			1.68	%
	Reduction of valuation allowance	(13,179,253		)	-37.29	%
	Nondeductible items and other	595,673			1.68	%
	Income tax provision	$	25,000		0.07	%
	The income tax expense for the year ended December 31, 2012 was different than the amount computed using the statutory rate primarily due to an $83.5 million valuation allowance recorded on our deferred tax asset:
		United States					Canada					Total
	Amount computed using statutory rates	$	(36,004,892	)	34	%	$	(3,307	)	25	%	$	(36,008,199	)	34	%
	State income taxes—net of federal benefit	(3,319,194		)	3.14	%	—			0	%	(3,319,194		)	3.13	%
	Valuation Allowance	83,537,181			–78.89	%	3,307			–25.00	%	83,540,488			–78.88	%
	Nondeductible items and other	(169,895		)	0.16	%	—			0	%	(169,895		)	0.16	%
	Income tax provision	$	44,043,200		–41.59	%	$	—		0	%	$	44,043,200		–41.59	%
Schedule of components of the income tax expense	'
		2013			2012
	Current:
	State	$	25,000		$	25,000
	Federal	—			—
	Deferred:
	State	566,595			(3,344,193		)
	State valuation allowance	(566,595		)	11,663,218
	Federal	12,612,658			(36,174,788		)
	Federal valuation allowance	(12,612,658		)	71,873,963
	Income tax provision	$	25,000		$	44,043,200

Common_Stock_Tables

Common Stock (Tables)	12 Months Ended
	Dec. 31, 2013
Common Stock	'
Schedule of activity related to Common Stock	'
		Date	Shares
	Common stock at January 1, 2013		40,690,077
	Purchased by the Company and cancelled for the payment of withholding taxes due on vested shares of restricted stock	1/7/13	(121	)
	Purchased by the Company and cancelled for the payment of withholding taxes due on vested shares of restricted stock	3/15/13	(470	)
	Forfeited upon default of shareholder loans	6/6/13	(24,428	)
	Shares of restricted stock forfeited upon termination of employment	6/14/13	(1,504	)
	Shares of restricted stock forfeited upon termination of employment	7/8/13	(805	)
	Common stock at December 31, 2013		40,662,749

Series_A_Convertible_Redeemabl1

Series A Convertible Redeemable Preferred Stock (Tables)	12 Months Ended
	Dec. 31, 2013
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 at January 1, 2012			4,549,537	$	28,482,624
	Accretion of discount on Preferred Stock				1,913,134
	PIK Dividends Issued for Preferred Stock :	12/31/11	1/3/12	142,095	1,522,035
		3/31/12	4/2/12	146,549	1,240,719
		6/30/12	7/2/12	151,128	619,625
		9/30/12	10/1/12	155,847	864,951
		12/31/12	12/31/12	160,709	1,208,799
	Balance At December 31, 2012			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 At December 31, 2013			6,000,571	$	43,404,993

ShareBased_Awards_Tables

Share-Based Awards (Tables)	12 Months Ended
	Dec. 31, 2013
Incentive stock option	'
Share-Based awards	'
Schedule of stock option activity	'
		Number of		Weighted		Average	Aggregate
		Options		Average		Remaining	Intrinsic
				Exercise		Contractual	Value
				Price		Life
	Outstanding at January 1, 2012	1,574,886		$	1.11	3.2	$	113,071
	Forfeited	(162,147	)	$	1.05
	Outstanding at December 31, 2012	1,412,739		$	1.11	4.1	$	—
	Options exercisable at December 31, 2012	958,090		$	0.99	4.3	$	—
	Forfeited	(213,306	)	$	1.12
	Outstanding at December 31, 2013	1,199,433		$	1.11	2.7	$	—
	Options exercisable at December 31, 2013	1,046,840		$	1.04	3.5	$	—
Non-qualified stock option	'
Share-Based awards	'
Schedule of stock option activity	'
		Number of		Weighted		Average	Aggregate
		Options		Average		Remaining	Intrinsic
				Exercise		Contractual	Value
				Price		Life
	Outstanding at January 1, 2012	992,272		$	2.32
	Forfeited	(17,507	)	$	2.12
	Outstanding at December 31, 2012	974,765		$	2.33	1.3	$	—
	Options exercisable at December 31, 2012	933,242		$	2.4	1.3	$	—
	Expired	(600,000	)	$	2.5
	Outstanding at December 31, 2013	374,765		$	2.05	0.6	$	—
	Options exercisable at December 31, 2013	333,242		$	2.22	1.6	$	—
Restricted stock	'
Share-Based awards	'
Schedule of non-vested restricted stock awards activity	'
		Number of		Weighted
		Shares		Average
				Grant Date
				Fair Value
	Non-vested restricted stock at December 31, 2012	293,166		$	3.03
	Granted	150,000		$	0.43
	Vested	(159,978	)	$	3
	Forfeited	(28,928	)	$	3.77
	Non-vested restricted stock at December 31, 2012	254,260		$	1.43
	Vested	(93,416	)	$	0.74
	Forfeited	(2,779	)	$	1.32
	Non-vested restricted stock at December 31, 2013	158,065		$	1.83

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies	'
Schedule of future minimum lease commitments under non-cancelable operating leases	'
	Year Ended December 31,	Amount
	2014	$	841,274
	2015	420,540
	2016	378,225
	2017	186,008
	2018 and thereafter	215,333
	Total future minimum lease commitments	$	2,041,380

Sale_of_Coalbed_Methane_Proper2

Sale of Coalbed Methane Properties in Alabama (Details) (USD $)	12 Months Ended					0 Months Ended	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Jun. 14, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012
			Credit agreement	Credit agreement	Credit agreement	Coalbed methane properties	Coalbed methane properties	Coalbed methane properties	Coalbed methane properties
				Borrowings under revolving Credit Agreement	Borrowings under revolving Credit Agreement			Pro forma	Pro forma
Discontinued Operations	'	'	'	'	'	'	'	'	'
Net proceeds from sale of properties	'	'	'	'	'	$62,000,000	'	'	'
Purchase price adjustments	'	'	'	'	'	1,200,000	'	'	'
Repayment of outstanding borrowings under the Entity's Credit Agreement	67,750,000	29,100,000	58,800,000	67,800,000	29,100,000	'	'	'	'
Payment of transaction related costs and expenses	3,801	832,401	3,200,000	'	'	'	'	'	'
Total gain on the sale	'	'	'	'	'	'	'	'	'
Cash proceeds	60,732,775	'	'	'	'	62,007,639	'	'	'
Buyer's assumption of asset retirement obligations	265,470	73,706	'	'	'	4,411,201	-4,411,201	'	'
Buyer's assumption of other liabilities	113,434	143,682	'	'	'	164,108	'	'	'
Net book value of sold natural gas properties	-333,109,974	-539,077,119	'	'	'	-27,998,835	'	'	'
Net book value of sold inventory	'	-262,885	'	'	'	-133,732	'	'	'
Net book value of sold equipment	-42,329,051	-75,124,687	'	'	'	-108,642	'	'	'
Transaction costs	'	'	'	'	'	-1,120,654	'	'	'
Post-closing purchase price adjustments	'	'	'	'	'	-272,772	'	'	'
Total gain on sale	36,948,313	'	'	'	'	36,948,313	'	'	'
Current federal or state income taxes payable in conjunction with the sale of properties	'	'	'	'	'	'	0	'	'
Reduction in deferred tax asset	'	'	'	'	'	'	14,100,000	'	'
Reduction in valuation allowance	'	'	'	'	'	'	14,100,000	'	'
Net deferred tax asset	'	'	'	'	'	'	83,500,000	'	'
Unaudited pro forma balances that reflect the sale of coalbed methane assets in Alabama	'	'	'	'	'	'	'	'	'
Revenues	38,209,383	39,383,087	'	'	'	'	'	31,967,227	27,564,502
Income (loss) from continuing operations	35,344,074	-105,173,942	'	'	'	'	'	37,908,108	-71,115,461
Net income (loss)	35,319,074	-149,953,167	'	'	'	'	'	34,861,753	-119,782,988
Net income (loss) available to Common Stockholders	$27,763,396	($155,803,152)	'	'	'	'	'	$27,306,075	($125,632,973)
Net income (loss) per common share-basic (in dollars per share)	$0.69	($3.88)	'	'	'	'	'	$0.67	($3.13)
Net income (loss) per common share-diluted (in dollars per share)	$0.42	($3.88)	'	'	'	'	'	$0.42	($3.13)

Going_Concern_and_Managements_1

Going Concern and Management's Plans (Details) (USD $)	1 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Feb. 13, 2014
					Minimum	Subsequent event
Going Concern and Management's Plans	'	'	'	'	'	'
Working capital deficit	'	$69,200,000	'	'	'	'
Retained deficit	'	266,738,422	302,057,496	'	'	'
Stockholders' deficit	'	79,264,467	107,313,589	-46,631,084	'	'
Preferred stock dividend rate (as a percent)	9.60%	12.50%	'	'	'	'
Preferred stock as a percentage of outstanding shares (as a percent)	'	53.00%	'	'	50.00%	'
Discontinued Operations	'	'	'	'	'	'
Purchase price subject to purchase price adjustments	'	'	'	'	'	$107,000,000
Preferred stock as a percentage of outstanding shares (as a percent)	'	53.00%	'	'	50.00%	'

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details)	12 Months Ended
	Dec. 31, 2013
	item
Revenue Recognition and Gas Balancing	'
Pipeline imbalances settlement period from the date of production	'30 days
Industry Segment and Geographic Information	'
Number of industries in which the entity operates	1
Minimum	'
Other property and equipment	'
Estimated useful life	'3 years
Maximum	'
Other property and equipment	'
Estimated useful life	'7 years
Furniture and fixtures	'
Other property and equipment	'
Estimated useful life	'7 years
Automobiles	'
Other property and equipment	'
Estimated useful life	'3 years
Machinery and equipment	'
Other property and equipment	'
Estimated useful life	'5 years
Software and computer equipment	'
Other property and equipment	'
Estimated useful life	'3 years

Summary_of_Significant_Account4

Summary of Significant Accounting Policies (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
	item
Summary of Significant Accounting Policies	'	'
Number of factors beyond control that affects availability of ready market for natural gas which can be predicted with certainty	0	'
Concentration of credit risk	'	'
Allowance for doubtful accounts receivable	$14,744	$17,634
Capitalized General and Administrative Expenses	'	'
General and administrative costs capitalized	$0	$134,350
Customer	'	'
Concentration of credit risk	'	'
Number of natural gas production purchasers	5	'
Sale of gas	'	'
Concentration of credit risk	'	'
Natural gas production sale to five purchasers (as a percent)	99.10%	'
Sale of gas | Customer | Major customers	'	'
Concentration of credit risk	'	'
Number of major customers	1	'
Sale of gas | Customer | Three natural gas purchasers	'	'
Concentration of credit risk	'	'
Concentration risk (as a percent)	62.00%	'
Accounts receivable | Credit | Major customers	'	'
Concentration of credit risk	'	'
Concentration risk (as a percent)	88.00%	'
Accounts receivable | Credit | Three natural gas purchasers	'	'
Concentration of credit risk	'	'
Number of major customers	3	'
Accounts receivable | Credit | One joint interest owner	'	'
Concentration of credit risk	'	'
Number of major customers	1	'
Accounts receivable | Credit | One natural gas purchaser	'	'
Concentration of credit risk	'	'
Concentration risk (as a percent)	65.00%	'
Number of major customers	1	'

Discontinued_Operations_Detail

Discontinued Operations (Details) (USD $)	12 Months Ended					0 Months Ended	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Jun. 20, 2012	Dec. 31, 2013
			Canada Energy Partners, Inc.	Hudson's Hope Gas, Ltd.	Hudson's Hope Gas, Ltd.	Hudson's Hope Gas, Ltd.	Hudson's Hope Gas, Ltd.
						Canada Energy Partners, Inc.	Canada Energy Partners, Inc.
Discontinued Operations	'	'	'	'	'	'	'
Number of shares received on sale of discontinued operations, classified as available for sale	'	'	2,000,000	'	'	2,000,000	'
Loss recognized on disposition	'	$736,025	'	$700,000	'	'	'
Loss related to currency translation adjustment	'	'	'	1,300,000	'	'	'
Assets retirement obligations conveyed	'	'	'	300,000	'	'	'
Fair value of proceeds from CEP shares received	'	'	'	'	'	'	300,000
Statements of operations (unaudited):	'	'	'	'	'	'	'
Operating expenses	34,455,830	137,355,914	'	'	32,444	'	'
Operating loss	40,701,866	-97,972,827	'	'	-32,444	'	'
Loss on sale of Hudson's Hope, Ltd	'	'	'	'	-683,154	'	'
Other expense	-5,357,792	-7,201,115	'	'	-20,427	'	'
Net loss	'	'	'	'	($736,025)	'	'

Net_Income_Loss_Per_Common_Sha2

Net Income (Loss) Per Common Share (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Net Income (Loss) Per Common Share	'	'
Net income (loss) available to Common Stockholders-basic	$27,763,396	($155,803,152)
Dilutive related add back:	'	'
Accretion of discount on Preferred Stock	2,257,968	1,913,134
Paid-in-kind dividends on Preferred Stock	5,295,138	3,934,094
Cash dividends paid on Preferred Stock	2,572	2,757
Net income (loss) available to Common Stockholders-diluted	35,319,074	-155,803,152
Net income (loss) per common share-basic:	'	'
Net income (loss) per common share from continuing operations (in dollars per share)	$0.69	($3.86)
Net loss per common share from discontinued operations (in dollars per share)	'	($0.02)
Net income (loss) per common share-basic (in dollars per share)	$0.69	($3.88)
Net income (loss) per common share-diluted:	'	'
Net income (loss) per common share from continuing operations (in dollars per share)	$0.42	($3.86)
Net loss per common share from discontinued operations (in dollars per share)	'	($0.02)
Net income (loss) per common share-diluted (in dollars per share)	$0.42	($3.88)
Weighted average number of common shares:	'	'
Basic (in shares)	40,481,330	40,123,608
Diluted (in shares)	83,384,951	40,123,608
Net (loss) income per common share	'	'
Gain on the sale of properties included in basic net income per common share (in dollars per share)	'	($0.02)
Gain on sale of properties included in diluted net income per common share (in dollars per share)	'	($0.02)
Sale of Properties in Alabama	'	'
Net income (loss) per common share-basic:	'	'
Net loss per common share from discontinued operations (in dollars per share)	$0.91	'
Net income (loss) per common share-diluted:	'	'
Net loss per common share from discontinued operations (in dollars per share)	$0.44	'
Net (loss) income per common share	'	'
Gain on the sale of properties included in basic net income per common share (in dollars per share)	$0.91	'
Tax on gain on the sale of properties included in basic net income per common share	0	'
Gain on sale of properties included in diluted net income per common share (in dollars per share)	$0.44	'
Tax on gain on the sale of Properties included in diluted net income per common share	$0	'
Preferred stock	'	'
Net (loss) income per common share	'	'
Potentially dilutive securities:	42,787,068	37,813,420
Restricted stock units	'	'
Net (loss) income per common share	'	'
Potentially dilutive securities:	116,553	156,992

Net_Income_Loss_Per_Common_Sha3

Net Income (Loss) Per Common Share (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Effect of anti-dilutive securities	'	'
Accretion of discount on Series A Convertible Redeemable Preferred Stock	$2,257,968	$1,913,134
Dividends paid for Series A Convertible Redeemable Preferred Stock (cash and PIK)	'	$3,936,851
Stock options	'	'
Effect of anti-dilutive securities	'	'
Antidilutive securities excluded from diluted weighted average shares outstanding	'	2,387,504
Restricted Stock	'	'
Effect of anti-dilutive securities	'	'
Antidilutive securities excluded from diluted weighted average shares outstanding	'	260,725
Restricted stock units	'	'
Effect of anti-dilutive securities	'	'
Antidilutive securities excluded from diluted weighted average shares outstanding	116,553	156,992
Series A Convertible Redeemable Preferred Stock	'	'
Effect of anti-dilutive securities	'	'
Antidilutive securities excluded from diluted weighted average shares outstanding	42,787,068	37,813,420

Natural_Gas_Properties_Details

Natural Gas Properties (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Feb. 13, 2014
			Subsequent event
Natural Gas Properties	'	'	'
Discount rate per annum used to calculate present value of estimated future net revenues (as a percent)	10.00%	'	'
Period of natural gas prices prior to the end of the reporting period whose unweighted arithmetic average used to calculate ceiling test	'12 months	'	'
Unweighted arithmetic average of the Henry Hub spot market price (in dollars per Mcf)	3.69	2.78	'
Natural gas price when adjusted for the regional price differentials (in dollars per Mcf)	3.75	2.91	'
Write-down of the carrying value of U.S. full cost pool	'	$95,728,981	'
Capitalized cost of natural gas properties	'	'	'
Subject to depletion	333,109,974	539,077,119	'
Gross natural gas properties	333,109,974	539,077,119	'
Less impairment of natural gas properties	-241,964,803	-391,118,140	'
Less accumulated depletion	-49,161,150	-73,567,602	'
Net natural gas properties	41,984,021	74,391,377	'
Natural Gas Properties	'	'	'
Purchase price subject to purchase price adjustments	'	'	$107,000,000

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Jun. 14, 2013	Dec. 31, 2013
			Coalbed methane properties	Coalbed methane properties	Other natural gas properties
Changes to asset retirement Obligations	'	'	'	'	'
Asset retirement obligation at beginning of year	$13,309,024	$8,170,579	'	'	'
Buyer's assumption of liabilities	-5,509,401	'	'	'	'
Liabilities incurred	'	14,252	'	'	'
Liabilities settled	-108,123	-554,991	'	'	'
Accretion of discount	1,035,717	827,771	'	'	'
Revisions in estimates	453,660	4,846,818	'	'	'
Currency translation adjustment	'	4,595	'	'	'
Asset retirement obligation at end of year	9,180,877	13,309,024	'	'	'
Less: current portion of obligation	-265,470	-73,706	4,411,201	-4,411,201	1,098,200
Long-term asset retirement obligation	$8,915,407	$13,235,318	'	'	'

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

Commodity derivative contract

MMBTU

MMBTU

Natural gas collar positions

Natural gas collar positions

Natural gas collar positions

Natural gas collar positions

Natural gas swap

Natural gas swap

Natural gas swap

Natural gas swap

Natural gas swap

Natural gas swap

Natural gas swap

Forward sales

Forward sales

Forward sales

January 2014 through December 2015, one

January 2014 through December 2015, one

January 2014 through December 2015, two

January 2014 through December 2015, two

January 2014 through March 2014, two

January 2013 through March 2013, one

January 2013 through March 2013, two

January 2013 through December 2013

January 2013 through March 2014, one

January 2013 through March 2014, two

April 2013 through December 2013

MMBTU

January 2013 through March 2013, one

January 2013 through March 2013, two

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

Derivative instruments and hedging activities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period of derivative contracts

'

'

'2 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Volume (in MMBtu)

'

'

7,660,000

20,420,000

3,650,000

3,650,000

3,650,000

3,650,000

360,000

360,000

540,000

2,190,000

3,640,000

3,640,000

2,750,000

1,368,000

450,000

918,000

Sold Ceiling (in dollars per unit)

'

'

'

'

4.3

4.3

4.2

4.2

'

'

'

'

'

'

'

'

'

'

Bought Floor (in dollars per unit)

'

'

'

'

3.6

3.6

3.5

3.5

'

'

'

'

'

'

'

'

'

'

Fixed Price (in dollars per unit)

'

'

'

'

'

'

'

'

3.82

6.42

6.5

3.6

3.81

3.82

3.25

'

'

'

Derivative asset - current

'

$3,929,767

'

$3,929,767

'

'

'

'

'

$1,100,395

$1,156,734

$127,253

$758,669

$786,716

'

'

'

'

Derivative liability - current

-834,151

-919,572

-834,151

-919,572

-280,392

'

-389,638

'

-164,121

'

'

'

'

'

-919,572

'

'

'

Derivative liability - non-current

-709,571

-1,636,348

-709,571

-1,636,348

-296,436

-556,636

-413,135

-796,266

'

'

'

'

-144,994

-138,452

'

'

'

'

Fair Value

'

'

($1,543,722)

$1,373,847

($576,828)

($556,636)

($802,773)

($796,266)

($164,121)

$1,100,395

$1,156,734

$127,253

$613,675

$648,264

($919,572)

'

'

'

Fixed Basis (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.19

0.22

Derivative_Instruments_and_Hed3

Derivative Instruments and Hedging Activities (Details 2) (Derivatives not designated as hedging instruments, USD $)	Dec. 31, 2013	Dec. 31, 2012
Fair value of the entity's derivative instruments	'	'
Asset Derivatives, Fair Value	'	$3,929,767
Liability Derivatives, Fair Value	1,543,722	2,555,920
Natural gas hedge positions | Derivative asset (current)	'	'
Fair value of the entity's derivative instruments	'	'
Asset Derivatives, Fair Value	'	3,929,767
Natural gas hedge positions | Derivative liability (current)	'	'
Fair value of the entity's derivative instruments	'	'
Liability Derivatives, Fair Value	834,151	919,572
Natural gas hedge positions | Derivative liability (non-current)	'	'
Fair value of the entity's derivative instruments	'	'
Liability Derivatives, Fair Value	$709,571	$1,636,348

Derivative_Instruments_and_Hed4

Derivative Instruments and Hedging Activities (Details 3) (Derivatives not designated as hedging instruments, USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
The Effect of Derivative Instruments on the Unaudited Consolidated Statements of Operations and Other Comprehensive Income	'	'
Amount of (Gain) or Loss Recognized in Income on Derivative	$1,811,191	($4,415,617)
Natural gas collar/swap settled positions	'	'
The Effect of Derivative Instruments on the Unaudited Consolidated Statements of Operations and Other Comprehensive Income	'	'
Amount of (Gain) or Loss Recognized in Income on Derivative	-1,106,378	-16,383,003
Natural gas collar/swap unsettled positions	'	'
The Effect of Derivative Instruments on the Unaudited Consolidated Statements of Operations and Other Comprehensive Income	'	'
Amount of (Gain) or Loss Recognized in Income on Derivative	$2,917,569	$11,967,386

Investment_in_Canada_Energy_Pa1

Investment in Canada Energy Partners (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Investment in Canada Energy Partners	'	'
Value of shares recorded in other noncurrent assets	'	$240,749
Accumulated other comprehensive income (loss)	'	53,020
Canada Energy Partners, Inc.	'	'
Investment in Canada Energy Partners	'	'
Amount offered for shares held	140,000	'
Number of shares received on sale of discontinued operations, classified as available for sale	2,000,000	'
Decrease in market value of investment	'	61,661
Gain (loss) related to currency translation	'	$8,641

Restructuring_Costs_Details

Restructuring Costs (Details) (Employee severance, Former CEO, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Employee severance | Former CEO	'	'
Restructuring Costs	'	'
Restructuring costs	$0.10	$1.10
Restructuring costs, cash payments	'	0.8
Restructuring costs, share-based awards conveyed	'	0.1
Other costs	'	$0.20

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Jun. 14, 2013	Aug. 08, 2012
Long-term debt	'	'	'	'
Amount borrowed during the period	'	10,500,000	'	'
Payments made during the period	67,750,000	29,100,000	'	'
Total debt	71,550,000	139,300,000	'	'
Less current maturities included in current liabilities	-71,550,000	-10,300,000	'	'
Total long-term debt	'	129,000,000	'	'
Fair value of long-term debt	70,100,000	121,600,000	'	'
Maturities of long-term debt	'	'	'	'
2014	71,550,000	'	'	'
Total debt	71,550,000	139,300,000	'	'
Borrowings under revolving Credit Agreement	'	'	'	'
Long-term debt	'	'	'	'
Maximum borrowing capacity	'	'	'	148,600,000
Initial borrowing base	'	'	57,000,000	'
Average interest rate (as a percent)	4.10%	3.39%	'	'
Credit agreement	'	'	'	'
Long-term debt	'	'	'	'
Payments made during the period	58,800,000	'	'	'
Credit agreement | LIBOR	'	'	'	'
Long-term debt	'	'	'	'
Basis spread on variable rate (as a percent)	3.00%	'	'	'
Credit agreement | Adjusted Base Rate	'	'	'	'
Long-term debt	'	'	'	'
Basis spread on variable rate (as a percent)	2.00%	'	'	'
Credit agreement | Borrowings under revolving Credit Agreement	'	'	'	'
Long-term debt	'	'	'	'
Borrowings outstanding	71,600,000	'	77,000,000	'
Interest rate at period end (as a percent)	3.24%	'	'	'
Amount borrowed during the period	0	10,500,000	'	'
Payments made during the period	67,800,000	29,100,000	'	'
Credit agreement | Borrowings under revolving Credit Agreement | 2012	'	'	'	'
Long-term debt	'	'	'	'
Capital expenditure covenant maximum	1,500,000	'	'	'
Credit agreement | Borrowings under revolving Credit Agreement | 2013 and thereafter	'	'	'	'
Long-term debt	'	'	'	'
Capital expenditure covenant maximum	1,000,000	'	'	'
Credit agreement | Borrowings under revolving Credit Agreement | LIBOR	'	'	'	'
Long-term debt	'	'	'	'
Description of variable rate basis	'LIBOR Rate	'	'	'
Credit agreement | Borrowings under revolving Credit Agreement | Adjusted Base Rate	'	'	'	'
Long-term debt	'	'	'	'
Description of variable rate basis	'Adjusted Base Rate	'	'	'
Credit agreement | Borrowings under revolving Credit Agreement | Agent's base rate	'	'	'	'
Long-term debt	'	'	'	'
Description of variable rate basis	'Agent's base rate	'	'	'
Credit agreement | Borrowings under revolving Credit Agreement | Federal funds rate	'	'	'	'
Long-term debt	'	'	'	'
Description of variable rate basis	'federal funds rate	'	'	'
Basis spread on variable rate (as a percent)	0.50%	'	'	'
Credit agreement | Borrowings under revolving Credit Agreement | LIBOR	'	'	'	'
Long-term debt	'	'	'	'
Description of variable rate basis	'LIBOR Rate	'	'	'
Basis spread on variable rate (as a percent)	1.00%	'	'	'

Income_Taxes_Details

Income Taxes (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Net operating loss carryforward	'	'
Recorded valuation allowances	$83.50	'
Valuation allowance related to U.S. operations	70.5	'
Federal	'	'
Net operating loss carryforward	'	'
Loss carry forward	156	137.8
Federal | Capital Loss Carryforward | Hudson's Hope Gas, Ltd.	'	'
Net operating loss carryforward	'	'
Loss carry forward	33.9	'
Valuation allowance related to the capital loss carryforward	12.9	'
State	'	'
Net operating loss carryforward	'	'
Loss carry forward	$162.30	$127

Income_Taxes_Details_2

Income Taxes (Details 2) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Current deferred tax asset:	'	'
Compensation expense and other	$43,161	$24,089
Tax basis in excess of book basis of derivative contracts	318,645	'
Valuation allowance	-361,806	'
Total current deferred tax asset	'	24,089
Current deferred tax liability:	'	'
Book basis in excess of tax basis of derivative contracts	'	-1,149,893
Net current deferred tax liability	'	-1,125,804
Long-term deferred tax asset:	'	'
Net operating loss carryforward	60,233,320	52,505,971
Compensation expense and other	1,084,474	1,066,856
Accrued asset retirement obligations	2,187,078	1,832,737
Tax basis in excess of book basis of derivative contracts	1,156,475	1,451,763
Tax basis of natural gas properties in excess of book basis	5,502,048	27,557,569
Capital loss on sale of Canadian properties	12,936,668	13,352,031
Valuation allowance	-83,100,063	-96,641,123
Total long-term deferred tax assets	'	1,125,804
Long-term deferred tax liability:	'	'
Net long-term deferred tax asset	'	$1,125,804

Income_Taxes_Details_3

Income Taxes (Details 3) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Income tax expense reconciliation	'	'
Amount computed using statutory rates	$12,016,985	($36,008,199)
State income taxes - net of federal benefit	591,595	-3,319,194
Reduction of valuation allowance	-13,179,253	83,540,488
Nondeductible items and other	595,673	-169,895
Income tax provision	25,000	44,043,200
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)	1.68%	3.13%
Reduction of valuation allowance (as a percent)	-37.29%	-78.88%
Nondeductible items and other (as a percent)	1.68%	0.16%
Income tax provision (as a percent)	0.07%	-41.59%
Current:	'	'
State	25,000	25,000
Deferred:	'	'
State	566,595	-3,344,193
Federal	12,612,658	-36,174,788
Valuation Allowance	-13,179,253	83,540,488
Income tax provision	25,000	44,043,200
Uncertain Tax Positions	'	'
Unrecognized tax benefit	272,600	'
Federal	'	'
Income tax expense reconciliation	'	'
Reduction of valuation allowance	-12,612,658	71,873,963
Deferred:	'	'
Valuation Allowance	-12,612,658	71,873,963
State	'	'
Income tax expense reconciliation	'	'
Reduction of valuation allowance	-566,595	11,663,218
Deferred:	'	'
Valuation Allowance	-566,595	11,663,218
United States	'	'
Income tax expense reconciliation	'	'
Amount computed using statutory rates	'	-36,004,892
State income taxes - net of federal benefit	'	-3,319,194
Reduction of valuation allowance	'	83,537,181
Nondeductible items and other	'	-169,895
Income tax provision	'	44,043,200
Income tax expense reconciliation	'	'
Amount computed using statutory rates (as a percent)	'	34.00%
State income taxes - net of federal benefit (as a percent)	'	3.14%
Reduction of valuation allowance (as a percent)	'	-78.89%
Nondeductible items and other (as a percent)	'	0.16%
Income tax provision (as a percent)	'	-41.59%
Deferred:	'	'
Valuation Allowance	'	83,537,181
Canada	'	'
Income tax expense reconciliation	'	'
Amount computed using statutory rates	'	-3,307
Reduction of valuation allowance	'	3,307
Income tax expense reconciliation	'	'
Amount computed using statutory rates (as a percent)	'	25.00%
State income taxes - net of federal benefit (as a percent)	'	0.00%
Reduction of valuation allowance (as a percent)	'	-25.00%
Nondeductible items and other (as a percent)	'	0.00%
Income tax provision (as a percent)	'	0.00%
Deferred:	'	'
Valuation Allowance	'	$3,307

Common_Stock_Details

Common Stock (Details)	0 Months Ended			0 Months Ended				12 Months Ended
	Jun. 06, 2013	Dec. 31, 2013	Dec. 31, 2012	Jul. 08, 2013	Jun. 14, 2013	Mar. 15, 2013	Jan. 07, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
				Restricted stock	Restricted stock	Restricted stock	Restricted stock	Restricted stock	Restricted stock	Restricted stock
Common Stock	'	'	'	'	'	'	'	'	'	'
Treasury stock (in shares)	'	10,432	10,432	'	'	'	'	'	'	'
Common Stock	'	'	'	'	'	'	'	'	'	'
Shares	'	'	'	'	'	'	'	158,065	254,260	293,166
Activity related to common stock	'	'	'	'	'	'	'	'	'	'
Common stock at the beginning of the period (in shares)	'	40,662,749	40,690,077	'	'	'	'	'	'	'
Purchase and cancellation of Common Stock (in shares)	'	'	'	'	'	-470	-121	'	'	'
Forfeited upon default of shareholder loans	-24,428	'	'	'	'	'	'	'	'	'
Shares of restricted stock forfeited upon termination of employment	'	'	'	-805	-1,504	'	'	-2,779	-28,928	'
Common stock at the end of the period (in shares)	'	40,662,749	40,690,077	'	'	'	'	'	'	'

Series_A_Convertible_Redeemabl2

Series A Convertible Redeemable Preferred Stock (Details) (USD $)	1 Months Ended									12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jul. 31, 2013	Apr. 30, 2013	Dec. 31, 2012	Oct. 31, 2012	Jul. 31, 2012	Apr. 30, 2012	Jan. 31, 2012	Dec. 31, 2013	Dec. 31, 2012
Series A Convertible Redeemable Preferred Stock	'	'	'	'	'	'	'	'	'	'	'
Number of shares issued	6,000,571	'	'	'	5,305,865	'	'	'	'	6,000,571	5,305,865
Number of shares outstanding	6,000,571	'	'	'	5,305,865	'	'	'	'	6,000,571	5,305,865
Activity related to the preferred stock (Balance)	'	'	'	'	'	'	'	'	'	'	'
Balance at the end of the period	$43,404,993	'	'	'	$35,851,887	'	'	'	'	$43,404,993	$35,851,887
Series A Convertible Redeemable Preferred Stock	'	'	'	'	'	'	'	'	'	'	'
Series A Convertible Redeemable Preferred Stock	'	'	'	'	'	'	'	'	'	'	'
Number of shares issued	6,000,571	'	'	'	5,305,865	'	'	'	'	6,000,571	5,305,865
Number of shares outstanding	6,000,571	'	'	'	5,305,865	'	'	'	'	6,000,571	5,305,865
Additional shares reserved for paid-in-kind dividends	1,401,261	'	'	'	'	'	'	'	'	1,401,261	'
Activity related to common stock (Number of Shares)	'	'	'	'	'	'	'	'	'	'	'
Balance at the beginning of the period (in shares)	'	'	'	'	'	'	'	'	4,549,537	5,305,865	4,549,537
PIK Dividends Issued for Preferred Stock :	181,764	176,266	170,931	165,745	160,709	155,847	151,128	146,549	142,095	'	'
Balance at the end of the period (in shares)	6,000,571	'	'	'	5,305,865	'	'	'	'	6,000,571	5,305,865
Activity related to the preferred stock (Balance)	'	'	'	'	'	'	'	'	'	'	'
Balance at the beginning of the period	'	'	'	'	'	'	'	'	28,482,624	35,851,887	28,482,624
Accretion of discount on Preferred Stock	'	'	'	'	'	'	'	'	'	2,257,968	1,913,134
PIK Dividends Issued for Preferred Stock :	1,574,076	1,277,889	1,367,488	1,075,685	1,208,799	864,951	619,625	1,240,719	1,522,035	'	'
Balance at the end of the period	$43,404,993	'	'	'	$35,851,887	'	'	'	'	$43,404,993	$35,851,887

ShareBased_Awards_Details

Share-Based Awards (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Share-Based Awards	'	'
Number of shares available for grant under the plan	4,000,000	'
Term of options	'7 years	'
Vesting period	'3 years	'
Compensation expense	'	'
Compensation expense accrual	$232,760	$601,571
Future compensation cost of outstanding awards	67,744	'
Weighted average remaining useful life of the future compensation cost	'6 months 4 days	'
Compensation expense capitalized to natural gas properties	'	20,612
Lease operating expenses	'	'
Compensation expense	'	'
Allocated compensation expense	18,609	35,319
General and administrative expense	'	'
Compensation expense	'	'
Allocated compensation expense	214,151	414,513
Restructuring costs	'	'
Compensation expense	'	'
Allocated compensation expense	'	$131,127

ShareBased_Awards_Details_2

Share-Based Awards (Details 2) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Jul. 08, 2013

Jun. 14, 2013

Dec. 31, 2013

Dec. 31, 2012

15-May-12

Dec. 31, 2013

Aug. 10, 2012

11-May-12

Mar. 28, 2012

Incentive stock option

Incentive stock option

Incentive stock option

Non-qualified stock option

Non-qualified stock option

Restricted Stock

Restricted Stock

Restricted Stock

Restricted Stock

Executive officers

2006 Plan

2006 Plan

2006 Plan

2006 Plan

Restricted Stock

Independent Members

Independent Members

Independent Members

Independent Members

Share-Based awards

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock, shares issued

40,662,749

40,690,077

'

'

'

'

'

'

'

'

'

'

'

300,000

97,824

64,284

Percentage of annual retainer

'

'

'

'

'

'

'

'

'

'

'

'

12.50%

'

'

'

Number of Options

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at the beginning of the period (in shares)

'

'

1,412,739

1,574,886

'

974,765

992,272

'

'

'

'

'

'

'

'

'

Forfeited (in shares)

'

'

-213,306

-162,147

'

'

-17,507

'

'

'

'

'

'

'

'

'

Expired (in shares)

'

'

'

'

'

-600,000

'

'

'

'

'

'

'

'

'

'

Outstanding at the end of the period (in shares)

'

'

1,199,433

1,412,739

1,574,886

374,765

974,765

'

'

'

'

'

'

'

'

'

Options exercisable at the end of the period (in shares)

'

'

1,046,840

958,090

'

333,242

933,242

'

'

'

'

'

'

'

'

'

Weighted Average Exercise Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at the beginning of the period (in dollars per share)

'

'

$1.11

$1.11

'

$2.33

$2.32

'

'

'

'

'

'

'

'

'

Forfeited (in dollars per share)

'

'

$1.12

$1.05

'

'

$2.12

'

'

'

'

'

'

'

'

'

Expired (in dollars per share)

'

'

'

'

'

$2.50

'

'

'

'

'

'

'

'

'

'

Outstanding at the end of the period (in dollars per share)

'

'

$1.11

$1.11

$1.11

$2.05

$2.33

'

'

'

'

'

'

'

'

'

Options exercisable at the end of the period (in dollars per share)

'

'

$1.04

$0.99

'

$2.22

$2.40

'

'

'

'

'

'

'

'

'

Average Remaining Contractual Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at the end of the period

'

'

'2 years 8 months 12 days

'4 years 1 month 6 days

'3 years 2 months 12 days

'7 months 6 days

'1 year 3 months 18 days

'

'

'

'

'

'

'

'

'

Options exercisable at the end of the period

'

'

'3 years 6 months

'4 years 3 months 18 days

'

'1 year 7 months 6 days

'1 year 3 months 18 days

'

'

'

'

'

'

'

'

'

Aggregate Intrinsic Value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at the end of the period

'

'

'

'

$113,071

'

'

'

'

'

'

'

'

'

'

'

Number of Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-vested at the beginning of the period (in shares)

'

'

'

'

'

'

'

'

'

254,260

293,166

'

'

'

'

'

Granted (in shares)

'

'

'

'

'

'

'

'

'

'

150,000

150,000

'

'

'

'

Vested (in shares)

'

'

'

'

'

'

'

'

'

-93,416

-159,978

'

'

'

'

'

Forfeited (in shares)

'

'

'

'

'

'

'

-805

-1,504

-2,779

-28,928

'

'

'

'

'

Non-vested at the end of the period (in shares)

'

'

'

'

'

'

'

'

'

158,065

254,260

'

'

'

'

'

Weighted Average Value at Grant Date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-vested at the beginning of the period (in dollars per share)

'

'

'

'

'

'

'

'

'

$1.43

$3.03

'

'

'

'

'

Granted (in dollars per share)

'

'

'

'

'

'

'

'

'

'

$0.43

'

'

'

'

'

Vested (in dollars per share)

'

'

'

'

'

'

'

'

'

$0.74

$3

'

'

'

'

'

Forfeited (in dollars per share)

'

'

'

'

'

'

'

'

'

$1.32

$3.77

'

'

'

'

'

Non-vested at the end of the period (in dollars per share)

'

'

'

'

'

'

'

'

'

$1.83

$1.43

'

'

'

'

'

ShareBased_Awards_Details_3

Share-Based Awards (Details 3) (USD $)

12 Months Ended

0 Months Ended

1 Months Ended

1 Months Ended

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

15-May-12

Jun. 25, 2012

Apr. 30, 2012

Apr. 30, 2012

Apr. 30, 2011

Dec. 31, 2013

Apr. 05, 2011

Apr. 30, 2011

Restricted Stock

Restricted Stock

Restricted Stock

Restricted Stock

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Restricted stock units

Executive officers

Executive officers

officer

Share-Based awards

'

'

'

'

'

'

'

'

'

'

'

'

Granted (in shares)

'

'

150,000

'

150,000

'

'

'

232,089

'

'

'

Number of executive officers

'

'

'

'

'

'

'

'

'

'

'

5

Vesting period

'3 years

'

'

'

'3 years

'

'

'

'

'

'

'3 years

Number of common shares for each unit held

'

'

'

'

'

'

'

'

'

'

1

'

Period for achieving requisite performance targets failing which the restricted stock units will expire

'

'

'

'

'

'

'

'

'7 years

'

'

'

Vested (in shares)

'

-93,416

-159,978

'

'

'

'

-99,108

'

'

'

'

Vesting date fair value (in dollars per share)

'

'

'

'

'

'

$0.53

'

'

'

'

'

Forfeited (in shares)

'

'

'

'

'

-16,428

'

'

'

'

'

'

Number of options granted

'

158,065

254,260

293,166

'

0

'

'

'

'

'

'

Unrecognized compensation cost related to the restricted stock units

'

'

'

'

'

'

'

'

'

$116,553

'

'

Profit_Sharing_Plan_Details

Profit Sharing Plan (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
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	$174,958	$227,299

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Commitments and Contingencies	'	'
Environmental or other regulatory liability	$0	'
Future minimum lease commitments	'	'
2014	841,274	'
2015	420,540	'
2016	378,225	'
2017	186,008	'
2018 and thereafter	215,333	'
Total future minimum lease commitments	2,041,380	'
Rental expenses under operating leases	$2,300,000	$2,800,000

Commitments_and_Contingencies_2

Commitments and Contingencies (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2013
Transportation and Gathering Contracts	'
Maximum commitment remaining under transportation and gathering contracts	$23,900,000
Other Commitments	'
Termination fee	$4,280,000
Firm transportation contract continuing until October 31, 2015	'
Transportation and Gathering Contracts	'
Maximum daily transport volume	500
Firm transportation contract continuing until April 1, 2022	'
Transportation and Gathering Contracts	'
Maximum daily transport volume	15,000
Firm transportation contract continuing until April 1, 2017	'
Transportation and Gathering Contracts	'
Maximum daily transport volume	10,000
Firm transportation contract continuing until October 31, 2024	'
Transportation and Gathering Contracts	'
Maximum daily transport volume	15,000
Firm transportation contract continuing until June 30, 2017	'
Transportation and Gathering Contracts	'
Maximum daily transport volume	10,000
Firm gathering contract through June 30, 2017	'
Transportation and Gathering Contracts	'
Daily gathering volume	10,000