Gasco Energy (GSXN) 10-Q 12 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Nov. 08, 2013
Document and Entity Information	'	'
Entity Registrant Name	'GASCO ENERGY INC	'
Entity Central Index Key	'0001086319	'
Document Type	'10-Q	'
Document Period End Date	30-Sep-13	'
Amendment Flag	'false	'
Current Fiscal Year End Date	'--12-31	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Smaller Reporting Company	'
Entity Common Stock, Shares Outstanding	'	563,532,352
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (USD $)	Sep. 30, 2013	Dec. 31, 2012
CURRENT ASSETS	'	'
Cash and cash equivalents	$2,008,434	$2,938,086
Accounts receivable	'	'
Joint interest billings	1,760,277	1,753,204
Revenue	780,952	777,567
Inventory	359,515	1,730,733
Inventory held for sale	351,575	'
Prepaid expenses	14,370	153,848
Total	5,275,123	7,353,438
Oil and gas properties (full cost method)	'	'
Proved properties	265,443,594	264,814,427
Unproved properties	31,717,970	31,486,314
Facilities and equipment	1,522,990	1,493,314
Furniture, fixtures and other	504,441	506,511
Total	299,188,995	298,300,566
Less accumulated depletion, depreciation, amortization and impairment	-254,367,017	-253,176,523
Total	44,821,978	45,124,043
NONCURRENT ASSETS	'	'
Deposits	551,370	531,443
Deferred financing costs	629,361	845,367
Total	1,180,731	1,376,810
TOTAL ASSETS	51,277,832	53,854,291
CURRENT LIABILITIES	'	'
5.5% Convertible Senior Notes due 2015, net of unamortized discount of $14,731,680	30,436,320	'
Accounts payable	1,569,713	1,548,121
Revenue payable	2,914,938	2,454,282
Advances from joint interest owners	47,667	47,667
Accrued interest	2,495,022	586,556
Accrued expenses	236,000	396,000
Total	37,699,660	5,032,626
NONCURRENT LIABILITIES	'	'
5.5% Convertible Senior Notes due 2015, net of unamortized discount of $18,530,539	'	26,637,461
Deferred income from sale of assets	2,311,338	2,463,177
Asset retirement obligation	876,201	815,660
Derivative instruments	71,000	907,500
Deferred rent	283,718	294,236
Total	3,542,257	31,118,034
STOCKHOLDERS' EQUITY	'	'
Common stock - $0.0001 par value; 600,000,000 shares authorized; 169,731,980 shares issued and 169,658,280 outstanding as of September 30, 2013 and 169,823,681 shares issued and 169,749,981 outstanding as of December 31, 2012	16,973	16,982
Additional paid-in capital	262,764,582	262,624,918
Accumulated deficit	-252,615,527	-244,808,156
Less cost of treasury stock of 73,700 common shares	-130,295	-130,295
Total	10,035,915	17,703,631
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	51,277,832	53,854,291
Series B Convertible Preferred stock	'	'
STOCKHOLDERS' EQUITY	'	'
Convertible Preferred stock	'	'
Series C Convertible Preferred stock	'	'
STOCKHOLDERS' EQUITY	'	'
Convertible Preferred stock	$182	$182

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Interest Rate, Convertible Senior Notes due 2015 (as a percent)	5.50%	5.50%
5.5% Convertible Senior Notes due 2015, unamortized discount (in dollars)	$14,731,680	$18,530,539
Common stock, par value (in dollars per share)	$0.00	$0.00
Common stock, shares authorized	600,000,000	600,000,000
Common stock, shares issued	169,731,980	169,823,681
Common stock, shares outstanding	169,658,280	169,749,981
Treasury stock, common shares	73,700	73,700
Series B Convertible Preferred stock	'	'
Convertible Preferred stock, par value (in dollars per share)	$0.00	$0.00
Convertible Preferred stock, shares authorized	20,000	20,000
Convertible Preferred stock, shares outstanding	0	0
Series C Convertible Preferred stock	'	'
Convertible Preferred stock, par value (in dollars per share)	$0.00	$0.00
Convertible Preferred stock, shares authorized	2,000,000	2,000,000
Convertible Preferred stock, shares outstanding	182,065	182,065

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
REVENUES	'	'	'	'
Gas	$1,973,446	$1,450,782	$5,793,536	$5,031,824
Oil	526,879	357,843	1,439,290	1,560,941
Total	2,500,325	1,808,625	7,232,826	6,592,765
OPERATING EXPENSES	'	'	'	'
Lease operating	815,295	975,520	2,416,559	3,815,987
Transportation and processing	820,411	326,861	2,179,655	1,502,224
Depletion, depreciation, amortization and accretion	356,480	524,995	1,125,258	2,023,261
Impairment	789,143	1,016,000	1,019,643	9,071,000
General and administrative	904,701	1,154,063	3,364,092	3,671,664
Total	3,686,030	3,997,439	10,105,207	20,084,136
OPERATING LOSS	-1,185,705	-2,188,814	-2,872,381	-13,491,371
OTHER INCOME (EXPENSE)	'	'	'	'
Interest expense	-2,077,831	-1,752,716	-5,923,329	-5,141,430
Gain on sale of assets	'	'	'	2,567,574
Derivative gains	104,000	720,000	836,500	2,508,090
Amortization of deferred income from sale of assets	50,613	50,613	151,839	151,839
Interest income	'	7	'	24,685
Total	-1,923,218	-982,096	-4,934,990	110,758
NET LOSS	($3,108,923)	($3,170,910)	($7,807,371)	($13,380,613)
NET LOSS PER COMMON SHARE - BASIC AND DILUTED (in dollars per share)	($0.02)	($0.02)	($0.05)	($0.08)
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING - BASIC AND DILUTED (in shares)	169,554,076	169,324,481	169,554,076	168,814,549

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
CASH FLOWS FROM OPERATING ACTIVITIES	'	'
Net loss	($7,807,371)	($13,380,613)
Adjustment to reconcile net loss to net cash provided by (used in) operating activities:	'	'
Depletion, depreciation, amortization, accretion and impairment expense	2,144,901	11,094,261
Stock-based compensation	139,655	215,947
Change in fair value of derivative instruments	-836,500	-1,252,142
Gain on sale of assets	'	-2,567,574
Amortization of debt discount, deferred expenses and other	3,852,508	3,013,155
Payment of deposit	-19,927	-38,138
Changes in operating assets and liabilities:	'	'
Accounts receivable	-10,458	13,338
Inventory	'	-1,463
Note receivable	'	500,000
Prepaid expenses	139,478	110,266
Accounts payable	539,592	-1,111,826
Revenue payable	460,656	538,338
Accrued interest	1,908,466	621,060
Accrued expenses	-160,000	-142
Net cash provided by (used in) operating activities	351,000	-2,245,533
CASH FLOWS FROM INVESTING ACTIVITIES	'	'
Cash paid for acquisitions, development and exploration	-1,280,652	-4,522,011
Cash paid for furniture, fixtures and other	'	-205,774
Proceeds from sale of assets	'	19,192,321
Decrease in advances from joint interest owners	'	-50,845
Net cash (used in) provided by investing activities	-1,280,652	14,413,691
CASH FLOWS FROM FINANCING ACTIVITIES	'	'
Borrowings under line of credit	'	2,000,000
Repayment of borrowings	'	-10,544,969
Net cash used in financing activities	'	-8,544,969
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS	-929,652	3,623,189
CASH AND CASH EQUIVALENTS:	'	'
BEGINNING OF PERIOD	2,938,086	1,965,967
END OF PERIOD	$2,008,434	$5,589,156

ORGANIZATION

ORGANIZATION	9 Months Ended
	Sep. 30, 2013
ORGANIZATION	'
ORGANIZATION	'
	NOTE 1 — ORGANIZATION
	Gasco Energy, Inc. (“Gasco,” the “Company,” “we,” “our” or “us”) is a natural gas and petroleum exploitation, development and production company engaged in locating and developing hydrocarbon resources, primarily in the Rocky Mountain region. The Company’s principal business strategy is to generate and develop high-potential exploitation resources in these areas. The Company’s principal business is the acquisition of leasehold interests in petroleum and natural gas rights, either directly or indirectly, and the exploitation and development of properties subject to these leases. The Company is currently focusing its operational efforts in the Riverbend Project located in the Uinta Basin of northeastern Utah, targeting the Green River, Wasatch, Mesaverde, Blackhawk, Mancos, Dakota and Morrison formations.
	The unaudited condensed consolidated financial statements included herein were prepared in accordance with generally accepted accounting principles in the United States (“US GAAP”) applicable to interim financial statements and with the instructions to Form 10-Q and the appropriate rules and regulations of the Securities and Exchange Commission (“SEC”).  Accordingly, they do not include all of the information and footnotes required by US GAAP for complete financial statements.  The accompanying unaudited condensed consolidated financial statements reflect all normal recurring adjustments which are, in the opinion of management, necessary to provide a fair statement of the results of operations and financial position of the Company for the interim periods presented.  Such financial statements conform to the presentation reflected in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012 (“2012 10-K”) filed with the SEC on March 6, 2013. The current interim period financial statements included herein should be read in conjunction with the financial statements and accompanying notes, including Note 3 — Significant Accounting Policies, contained in the 2012 10-K.

GOING_CONCERN

GOING CONCERN	9 Months Ended
	Sep. 30, 2013
GOING CONCERN	'
GOING CONCERN	'
	NOTE 2 — GOING CONCERN
	The accompanying unaudited condensed consolidated financial statements have been prepared assuming that the Company will continue as a going concern, which contemplates realization of assets and the satisfaction of liabilities in the normal course of business for the twelve-month period following the date of these consolidated financial statements.  As such, the accompanying unaudited condensed consolidated financial statements do not include any adjustments relating to the recoverability and classification of assets, carrying amounts, or the amount and classification of liabilities that may result should the Company be unable to continue as a going concern.
	Due to the extended decline in the natural gas market and low natural gas prices in recent years caused primarily by excess production, the Company has not been able to recover its exploration and development costs as anticipated.  As such, there is substantial doubt regarding the Company’s ability to generate sufficient cash flows from operations to fund its ongoing operations, and the Company currently anticipates that cash on hand and forecasted cash flows from operations will only be sufficient to fund cash requirements for working capital through February 2014. This expectation has been revised from management’s previous estimate included in the Form 10-Q for the quarter ended June 30, 2013 due to the completion of the October 2013 restructuring transactions discussed below, the implementation of cost savings measures and cash management strategies. This estimate is based on various assumptions, including those related to future natural gas and oil prices, production results and the effectiveness of the Company’s cash management strategy discussed below, some or all of which may not prove to be correct and may result in the Company’s inability to meet cash requirements prior to the end of February 2014.   As a result of these factors, there is substantial doubt about the Company’s ability to continue as a going concern.
	As of September 30, 2013, the Company had $45,168,000 aggregate principal and accrued interest of $2,495,022 outstanding under its 5.5% Convertible Senior Notes due 2015 (the “2015 Notes”). The Company elected not to make two of the $1,242,120 semi-annual interest payments due on April 5 and October 5, 2013 on its outstanding 2015 Notes.  The 2015 Notes require the Company to pay interest on overdue interest payments at a rate of 7.5% per annum.
	Because the Company did not make the April 5, 2013 interest payment prior to the expiration of the 30-day cure period, an event of default occurred under the Indenture.  As a result of the event of default, the Trustee or the holders of at least 25% in aggregate principal amount of the 2015 Notes had the right to declare the 2015 Notes immediately due and payable at their principal amount together with accrued interest. The Company did not receive any notice of acceleration of the 2015 Notes; however, as of October 17, 2013, the 2015 Notes and accrued interest were cancelled in the restructuring transactions further described in Note 4 — Restructuring Transaction, herein. As of September 30, 2013, the 2015 Notes were classified as a current obligation in the accompanying unaudited condensed consolidated financial statements.
	The Company has been seeking to restructure or refinance its debt or sell assets to improve its liquidity position since mid-year 2012. During this period, the Company has operated without a credit facility, has been delisted from the NYSE MKT LLC (the “Exchange”), and had defaulted under the 2015 Notes.
	The Company and Stephens Inc., the Company’s financial advisor, conducted a process to evaluate various strategic alternatives.  The restructuring agreements resulting from this process involve an investment in the Company by Markham LLC (“Markham”) and Orogen Energy, Inc. (“Orogen”). On October 17, 2013, these investors acquired the $45,168,000 aggregate principal amount of the Company’s 2015 Notes and accrued interest thereon, all 182,065 outstanding Series C convertible preferred shares (“Series C Stock”) and common shares owned by the holders of the 2015 Notes. Then on October 18, 2013, the investors exchanged the 2015 Notes, accrued interest and Series C Stock for 393,550,372 shares of the Company’s common stock and 50,000 shares of the newly-created Series D convertible preferred stock (“Series D Stock”) (the “Restructuring Transactions”). See Note 4 — Restructuring Transactions, herein for further discussion of the Restructuring Transactions. As a result of the Restructuring Transactions, the new investors now have fully-diluted control of approximately 97.9% of the equity of the Company.
	The new Series D Stock is convertible into 7,295,744,128 shares of common stock and is redeemable October 19, 2014 at the option of the holders for $100 per share plus accrued and unpaid dividends of 10% per annum.
	In addition to the exchange of debt and securities for the new common and preferred shares, Markham and Orogen established a 120-day, $5 million senior secured credit facility to fund working capital and capital expenditure requirements of the Company.  For extending the credit facility, the Company also issued to Markham and Orogen a total of 250,000 shares of Gasco common stock.
	In late 2012 and early 2013, the Company received notices from the Exchange  notifying the Company that it did not satisfy certain continued listing standards set forth in the NYSE MKT LLC Company Guide (the “Company Guide”). Specifically, on December 6, 2012, the Company received a notice from the Exchange indicating that it did not satisfy the continued listing standards of the Exchange set forth in Section 1003(f)(v) of the Company Guide because the Company’s common stock had traded at a low price per share for a substantial period of time.  In the notice, the Exchange predicated the Company’s continued listing on the Exchange on the Company effecting a reverse stock split of its common stock by June 6, 2013. On January 11, 2013, the Company received a notice from the Exchange indicating that it did not satisfy the continued listing standards of the Exchange set forth in Section 1003(a)(iv) of the Company Guide, which applies if a listed company has sustained losses which are so substantial in relation to its overall operations or its existing financial resources, or its financial condition has become so impaired that it appears questionable, in the opinion of the Exchange, as to whether such company will be able to continue operations and/or meet its obligations as they mature. In order to maintain its listing, the Company was required to submit a plan of compliance (a “Plan”) addressing how it intended to regain compliance with Section 1003(a)(iv) of the Company Guide by June 30, 2013.  The Company submitted a Plan to the Exchange on February 11, 2013.  The Plan indicated that the Company intended to lower costs, rationalize assets, refocus its development program toward oil and liquids, especially in the Green River Formation, and continue its California program with the potential goal of expanding activity on the California acreage.  The Plan also discussed the fact that the Company was considering certain strategic alternatives, including debt restructuring and sales of assets.
	On March 27, 2013, the Company received notice from the Exchange indicating that after a careful review of the Plan and publicly available information, the Exchange had determined that the Company had not made a reasonable demonstration of its ability to regain compliance with Section 1003(a)(iv) of the Company Guide by June 30, 2013 and that the Exchange intended to initiate delisting proceedings against the Company by filing a delisting application with the SEC pursuant to Section 1009(d) of the Company Guide.  The Company originally intended to appeal the Exchange’s determination, but subsequently determined not to proceed with such an appeal and notified the Exchange of its decision on April 23, 2013.  Accordingly, trading of the Company’s common stock on the Exchange was suspended at the opening of business on April 26, 2013 and the Exchange has delisted the Company’s common stock.  The Company’s common stock immediately became eligible to trade on the OTCQB Marketplace on April 26, 2013, and is currently trading thereon under the ticker symbol “GSXN.”
	The Company may not achieve profitability from operations in the near future or at all and it may continue to experience significant losses.  The Company had net losses for the nine months ended September 30, 2013 and has had negative cash flow from operations for the year ended December 31, 2012, and at September 30, 2013 had an accumulated deficit of $252,556,384.
	The Company also has firm commitment delivery obligations under its gas transportation and processing agreements.  If these commitments are not met, unless suspended pursuant to the terms of such agreements or waived, the Company may be required to make periodic deficiency payments for any shortfalls from the specified minimum volume commitments as discussed further in Note 9 — Gas Processing Agreements, herein.
	Failure to generate sufficient operating cash flow or to obtain additional financing for the development of the Company’s properties could result in substantial dilution of its property interests or delay or cause indefinite postponement of further exploration and development of its prospects resulting in the possible loss of its properties. This has caused the Company to alter its business plans, and the Company may be required to further reduce its exploration and development plans.  For example, the Company did not allocate any amounts to its 2013 capital budget prior to the Restructuring Transactions.  In particular, the Company faces uncertainties relating to its ability to fund the level of capital expenditures required for oil and gas exploration and production activities. The Company intends to fund its anticipated cash requirements through February 2014 primarily through cash on hand and cash inflows from operations and from borrowings under its line of credit, although the Company cannot provide assurances that these cash flows will be sufficient to fund such requirements. If they are not, the Company’s ability to execute its operations will be significantly limited, and its liquidity and results of operations will be materially adversely affected.
	To continue as a going concern, the Company must generate sufficient operating cash flows, secure additional capital or otherwise pursue a strategic restructuring, refinancing or other transaction to provide it with additional liquidity.  The Company’s ability to do so will depend on numerous factors, some of which are beyond its control.  For example, the urgency of the Company’s liquidity situation may require it to pursue such a transaction at an inopportune time when the Company has little or no negotiating leverage.  Moreover, the Company’s ability to successfully implement, and the cost of, any such transaction will depend on numerous factors, including:
	·                  demand and prices for natural gas and oil;
	·                  general economic conditions;
	·                  strength of the credit and capital markets;
	·                  the Company’s ability to successfully execute its operational strategies, and its operating and financial performance;
	·                  the Company’s ability to comply with its debt and equity instruments and to cure or obtain a waiver of any non-compliance;
	·                  the Company’s stock price, and the ability of its common stock to remain traded on the OTCQB Marketplace;
	·                  the Company’s ability to remain in compliance with its operational agreements, including its gas processing, gathering and transportation agreements;
	·                  the Company’s counterparties refraining from exercising any remedies available as a result of the determination that the Company is insolvent or unable to perform in accordance with the contract;
	·                  the Company’s ability to maintain relationships with its suppliers, customers, employees, stockholders and other third parties; and
	·                  market uncertainty in connection with the Company’s ability to continue as a going concern as well as investor confidence in the Company.
	If the Company is unable to generate sufficient operating cash flows or secure additional capital before February 2014, it will not have adequate liquidity to fund its operations and meet its obligations (including its debt payment obligations), the Company will not be able to continue as a going concern, and could potentially be forced to seek relief through a filing under Chapter 11 of the U.S. Bankruptcy Code.
	A bankruptcy filing by or against the Company would subject its business and operations to various risks, including but not limited to, the following:
	·                  a bankruptcy filing by or against the Company may adversely affect its business prospects, including its ability to continue to obtain and maintain the contracts necessary to operate its business on competitive terms;
	·                  subject to the automatic stay and other applicable provisions of the Bankruptcy Code, a bankruptcy filing by or against the Company could cause a party to attempt to declare an additional event of default under the Indenture;
	·                  subject to the automatic stay and other applicable provisions of the Bankruptcy Code, certain provisions in the Company’s operating agreements may be triggered such that  a party could attempt to assert that the Company is deemed to have resigned as operator or the agreements may be terminated by the other party;
	·                  the Company may be unable to retain and motivate key executives and employees through the process of reorganization, and it may have difficulty attracting new employees;
	·                  there can be no assurance as to the Company’s ability to maintain or obtain sufficient financing sources for operations or to fund any reorganization plan and meet future obligations;
	·                  there can be no assurance that the Company will be able to successfully develop, prosecute, confirm and consummate one or more plans of reorganization that are acceptable to the bankruptcy court and its creditors, equity holders and other parties in interest; and
	·                  the value of the Company’s common stock could be reduced to zero.
	In order to address the Company’s liquidity constraints the Company has embarked on a cash management strategy to enhance and preserve as much liquidity as possible. This plan may be further revised in light of the Restructuring Transaction; however, the plan contemplates the Company, among other things:
	·                  reducing expenditures by eliminating, delaying or curtailing discretionary and non-essential spending, and not designating any capital budget for 2013 prior to the Restructuring Transactions;
	·                  managing working capital;
	·                  delaying certain drilling projects;
	·                  pursuing farm-out and other similar types of transactions to fund working capital needs;
	·                  evaluating its options for the divestiture of certain assets;
	·                  investigating merger opportunities; and
	·                  restructuring and reengineering the Company’s organization and processes to reduce operating costs and increase efficiency.
	The Company cannot provide any assurances that it will be successful in accomplishing any of these plans or that any of these actions can be effected on a timely basis, on satisfactory terms or maintained once initiated. Furthermore, the Company’s cash management strategy, if successful, may limit certain of its initiatives, including its ability to successfully execute its strategic alternatives.

SIGNIFICANT_ACCOUNTING_POLICIE

SIGNIFICANT ACCOUNTING POLICIES	9 Months Ended
	Sep. 30, 2013
SIGNIFICANT ACCOUNTING POLICIES	'
SIGNIFICANT ACCOUNTING POLICIES	'
	NOTE 3 — SIGNIFICANT ACCOUNTING POLICIES
	Basis of Presentation
	The accompanying unaudited condensed consolidated financial statements include Gasco and its wholly-owned subsidiaries. All significant intercompany transactions have been eliminated.
	Oil and Gas Properties
	The Company follows the full cost method of accounting whereby all costs related to the acquisition and development of oil and gas properties are capitalized into a single cost center (“full cost pool”). Such costs include lease acquisition costs, geological and geophysical expenses, internal costs directly related to exploration and development activities and costs of drilling both productive and non-productive wells. The Company capitalized $0 and $8,807 of internal costs during the three and nine months ended September 30, 2013 and $0 and $11,520 during the three and nine months ended September 30, 2012, respectively.  Costs associated with production and general corporate activities are expensed in the period incurred. The Company charges a marketing fee related to the sale of its natural gas production to the wells in which it is the operator and, therefore, the net income attributable to the outside working interest owners from such marketing activities of $60,402 and $175,535 was recorded as an adjustment to proved properties during the three and nine months ended September 30, 2013 and $37,896 and $69,700 was recorded as an adjustment to proved properties during the three and nine months ended September 30, 2012, respectively. Proceeds from property sales are generally credited to the full cost pool without gain or loss recognition unless such a sale would significantly alter the relationship between capitalized costs and the proved reserves attributable to a cost center.  A significant alteration would typically involve a sale of 25% or more of the proved reserves related to a single full cost pool. Please see Note 7 — Asset Sales, herein.
	Depletion of exploration and development costs and depreciation of production equipment is computed using the units-of-production method based upon estimated proved oil and gas reserves. Costs included in the depletion base to be amortized include: (i) all proved capitalized costs including capitalized asset retirement costs net of estimated salvage values, less accumulated depletion; (ii) estimated future development costs to be incurred in developing proved reserves; and (iii) estimated dismantlement and abandonment costs, net of estimated salvage values, that have not been included as capitalized costs because they have not yet been capitalized as asset retirement costs. The costs of unproved properties of $31,717,970 as of September 30, 2013, are withheld from the depletion base until it is determined whether or not proved reserves can be assigned to the properties. The properties are reviewed quarterly for impairment. If a determination is made that acreage will be expiring or that the Company does not plan to develop some of the acreage that is no longer considered to be prospective, an impairment of the acreage is recorded by reclassifying the costs to the full cost pool. The value of these acres for the purpose of recording the impairment is estimated by calculating a per acre value from the total unproved costs incurred for the applicable acreage divided by the total net acres owned by the Company. This per acre estimate is then applied to the acres that the Company does not plan to develop in order to calculate the impairment. During the nine months ended September 30, 2013, the Company reclassified approximately $796,000 of acreage costs in California and Utah into proved property. This acreage represents the value of leases that expired during the first nine months of 2013 or that the Company does not intend to renew in the future.
	Total well costs are transferred to the depletable pool even when multiple targeted zones have not been fully evaluated. For depletion and depreciation purposes, relative volumes of oil and gas production and reserves are converted at the energy equivalent rate of six thousand cubic feet of natural gas to one barrel of crude oil. Estimated reserve quantities are affected by changes in commodity prices and actual well performance.
	Under the full cost method of accounting, the ceiling test provides that capitalized costs less related accumulated depletion and deferred income taxes for each cost center may not exceed the sum of (i) the present value of future net revenue from estimated production of proved oil and gas reserves using current prices, excluding the future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet, at a discount factor of 10%; plus (ii) the cost of properties not being amortized, if any; plus (iii) the lower of cost or estimated fair value of unproved properties included in the costs being amortized, if any; less (iv) income tax effects related to differences in the book and tax basis of oil and gas properties. Should the net capitalized costs for a cost center exceed the sum of the components noted above, a ceiling test write-down would be recognized to the extent the excess capitalized costs exceed this ceiling limitation. The present value of estimated future net revenues is computed by applying the average first-day-of-the-month oil and gas price during the 12-month period ended as of the last day of the period to estimated future production of proved oil and gas reserves as of the end of the period, less estimated future expenditures to be incurred in developing and producing the proved reserves assuming the continuation of existing economic conditions. As of March 31, 2012, June 30, 2012 and September 30, 2012, the full cost pool exceeded the ceiling limitation based on the average first-day-of-the-month oil and gas prices of $82.58 per barrel and $2.94 per Mcf during the 12-month period ended March 31, 2012, $81.16 per barrel and $2.57 per Mcf during the 12-month period ended June 30, 2012 and $80.35 per barrel and $2.23 per Mcf during the 12-month period ended September 30, 2012. Therefore, impairment expense of $1,016,000 and $9,071,000 was recorded during the three and nine months ended September 30, 2012, respectively.  No impairment expense related to the Company’s oil and gas properties was recorded during the three and nine months ended September 30, 2013.
	Facilities and Equipment
	The Company’s oil and gas equipment is depreciated using the straight-line method over an estimated useful life of five to ten years. The rental of the equipment owned by the Company is charged to the wells that are operated by the Company and, therefore, the net expense attributable to the outside working interest owners from the equipment rental was recorded as an adjustment to proved properties in the amount of $17,356 and $29,326 during the three and nine months ended September 30, 2013 and $22,359 and $14,551 during the three and nine months ended September 30, 2012, respectively.
	Inventory
	Inventory consists of pipe and tubular goods intended to be used in the Company’s oil and gas operations, and is stated at the lower of cost or market using the average cost valuation method. During the three and nine months ended September 30, 2013, the Company recorded impairment expense of $789,143 and $1,019,643, respectively, related to the decrease in the market value of its inventory.
	Inventory Held for Sale
	During the first nine months of 2013, the Company determined that it would not have a future need for some of its casing and tubing inventory. Consequently, in September 2013, the Company developed a formal plan to sell the inventory. The Company reviewed various options for selling this inventory and decided that selling this inventory at auction would be the best option based on its current financial position and the need for additional cash flow. The Company agreed to sell this inventory at auction in September and the inventory was sold in October for $323,500 less selling expenses of $16,175.
	Commodity Derivatives
	From time to time, the Company has used commodity derivative instruments to provide a measure of stability to its cash flows in an environment of volatile oil and gas prices and to manage its exposure to commodity price risk. The Company records all commodity derivative instruments at fair value within the accompanying unaudited condensed consolidated balance sheets. The Company’s management has historically decided not to use hedge accounting under the accounting guidance for commodity derivatives and therefore, the changes in fair value are recognized in earnings. See Note 8 — Derivatives, herein.
	Warrants
	On June 15, 2011, the Company issued warrants (“June Warrants”) to purchase 18,750,000 shares of common stock and on August 3, 2011, the Company issued warrants (“August Warrants” and collectively with the June Warrants, “Warrants”) to purchase 11,500,000 shares of common stock. The Warrants are exercisable immediately for a term of sixty months, beginning at issuance, at an initial exercise price of $0.35 per share; however, the exercise price and number of shares of common stock issuable on exercise of the Warrants are subject to adjustment in the event of any stock split, reverse stock split, stock dividend, recapitalization, reorganization or similar transaction.  If the Company makes a distribution of its assets to all of its stockholders, holders of the Warrants may be entitled to participate. In the event of a Fundamental Transaction (as defined in the Warrants), at the election of a holder of a Warrant, the Company may be required to purchase the holder’s Warrant for cash in an amount equal to the value of the remaining unexercised portion of the Warrant.  As a result, the Warrants are accounted for as a liability on the Company’s consolidated balance sheets with changes in their fair value reported in earnings. Subject to certain exceptions, if the average of the daily volume weighted-average price of a share of common stock for some period of time equals or exceeds 200% of the initial exercise price of the Warrants, and if at the time of such measurement the Equity Conditions (as defined in the Warrants) are satisfied, then the Company may, subject to certain conditions, require the holders of the Warrants to exercise.
	As a result of the Restructuring Transactions, the Warrants became immediately puttable. The Company has a derivative instruments liability of $71,000 to cover the potential put of the Warrants.
	Asset Retirement Obligation
	The Company accounts for its future asset retirement obligations by recording the fair value of the liability during the period in which it was incurred. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The increase in carrying value of a property associated with the capitalization of an asset retirement cost is included in proved oil and gas properties in the consolidated balance sheets. The Company depletes the amount added to proved oil and gas property costs using the units-of-production method. The Company’s asset retirement obligation consists of costs related to the plugging of wells, removal of facilities and equipment and site restoration on its oil and gas properties. The asset retirement liability is allocated to operating expense using a systematic and rational method.
	The information below reconciles the value of the asset retirement obligation for the periods presented.
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2013			2012		2013		2012
	Balance beginning of period	$	856,308		$	779,197	$	815,660	$	1,226,796
	Liabilities incurred	—			—		2,338		—
	Property dispositions	—			—		—		(493,178		)
	Accretion expense	19,893			18,019		58,203		63,598
	Balance end of period	$	876,201		$	797,216	$	876,201	$	797,216
	See Note 7 — Asset Sales, herein, for discussion of property dispositions.
	Revenue Recognition
	The Company records revenues from the sale of natural gas and crude oil when delivery to the customer has occurred, title has transferred and collectability is reasonably assured. This occurs when oil or gas has been delivered to a pipeline or a tank lifting has occurred.
	The Company may have an interest with other producers in certain properties, in which case the Company uses the sales method to account for gas imbalances. Under this method, revenue is recorded on the basis of gas actually sold by the Company. In addition, the Company records revenue for its share of gas sold by other owners that cannot be volumetrically balanced in the future due to insufficient remaining reserves. The Company also reduces revenue for other owners’ gas sold by the Company that cannot be volumetrically balanced in the future due to insufficient remaining reserves. The Company’s remaining over- and under-produced gas balancing positions are considered in the Company’s proved oil and gas reserves.
	Off-Balance Sheet Arrangements
	From time to time, the Company enters into off-balance sheet arrangements and transactions that can give rise to off-balance sheet obligations. As of September 30, 2013, the off-balance sheet arrangements and transactions that the Company had entered into included operating lease agreements, gathering, compression, processing and water disposal agreements and gas transportation commitments. See Note 9 — Gas Processing Agreements, herein, for additional discussion regarding certain gas transportation and processing agreements.
	Computation of Net Income (Loss) Per Share
	Basic net income (loss) per share is computed by dividing net income (loss) attributable to common stockholders by the weighted-average number of common shares outstanding during the reporting period. The shares of restricted common stock granted to certain officers and employees of the Company are included in the computation of basic net income (loss) per share only after the shares become fully vested. Diluted net income (loss) per share of common stock includes both vested and unvested shares of restricted stock. Diluted net income (loss) per common share of stock is computed by dividing net income as adjusted for earnings allocated to participating securities by the diluted weighted-average common shares outstanding.  Potentially dilutive securities for the diluted earnings per share calculation consist of (i) unvested shares of restricted common stock, (ii) in-the-money outstanding options and Warrants to purchase shares of common stock, (iii) outstanding shares of Series C Convertible Preferred Stock, par value $0.001 per share (“Preferred Stock”), which are convertible into shares of common stock, and (iv) the Company’s outstanding 2015 Notes, which are convertible into shares of Preferred Stock and common stock.
	The treasury stock method, which assumes that the increase in the number of shares is reduced by the number of shares that could have been repurchased by the Company with the proceeds from the exercise of the options (the repurchases of shares were assumed to have been made at the average market price of the common shares during the reporting period), is used to measure the dilutive impact of stock options, shares of restricted common stock, Warrants and shares into which the 2015 Notes and Preferred Stock are convertible.
	Net income (loss) per share information is determined using the two-class method, which includes the weighted-average number of common shares outstanding during the period and other securities that participate in dividends (“participating security”). The Company considers the Preferred Stock to be a participating security because it includes rights to participate in dividends with the common stock. In applying the two-class method, earnings are allocated to both common stock shares and the Preferred Stock common stock equivalent shares based on their respective weighted-average shares outstanding for the period. Losses are not allocated to Preferred Stock shares. Basic and diluted net loss per share was the same for the three and nine months ended September 30, 2013 and 2012.
	The following shares were excluded from the computation of diluted loss per common share as they did not have a dilutive effect.
		For the Three Months				For the Nine Months
		Ended September 30,				Ended September 30,
		2013		2012		2013	2012
	Shares related to:
	2015 Notes	75,280,000		75,280,000		75,280,000	75,280,000
	Preferred Stock	30,344,173		30,344,173		30,344,173	30,344,173
	Common stock options	6,217,647		9,815,468		6,217,647	9,815,468
	Warrants	30,250,000		30,250,000		30,250,000	30,250,000
	Unvested restricted common stock	204,000		425,500		204,000	425,500
	Use of Estimates
	The preparation of the financial statements for the Company in conformity with US 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 financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.
	The Company’s financial statements are based on a number of significant estimates, including oil and gas reserve quantities which are the basis for the calculation of depreciation, depletion and impairment of oil and gas properties, timing and costs associated with its retirement obligations, estimates of the fair value of derivative instruments, estimates used in stock-based compensation calculations and impairments to unproved property and to proved oil and gas properties
	Reclassifications
	Certain reclassifications have been made to prior years’ amounts to conform to the classifications used in the current year. Such reclassifications had no effect on the Company’s net loss for the periods presented.

RESTRUCTURING_TRANSACTIONS

RESTRUCTURING TRANSACTIONS	9 Months Ended
	Sep. 30, 2013
RESTRUCTURING TRANSACTIONS	'
RESTRUCTURING TRANSACTIONS	'
	NOTE 4 — RESTRUCTURING TRANSACTIONS
	On October 17, 2013, Markham and  Orogen (collectively, the “Purchasers”), and the holders of  the 2015 Notes (see Note 6 - Convertible Senior Notes, herein), entered into certain Purchase and Sale Agreements (the “Note Purchase Agreements”) pursuant to which, among other things, the Purchasers acquired (i) $45,168,000 in aggregate outstanding principal amount of the Company’s 2015 Notes plus accrued interest of $2,495,022, representing 100% of the issued and outstanding 2015 Notes, (ii) 182,065 shares of the Company’s Series C Stock, representing 100% of the issued and outstanding Series C Stock, and (iii) 2,743,818 shares of common stock, par value $0.0001 per share from the holders of the 2015 Notes.
	On October 18, 2013, in exchange for the issuance of 250,000 shares of common stock by the Company to the Purchasers, the Company and the Purchasers entered into a certain Credit Agreement (the “Credit Agreement”), pursuant to which, among other things, the Purchasers extended credit to the Company in the maximum principal amount of $5,000,000 in the form of a revolving credit facility to fund working capital and capital expenditure requirements of the Company (the “Credit Facility”). See Note 5 — Credit Facility, herein for further discussion.
	On October 18, 2013, following the consummation of the transactions contemplated by the Credit Agreement, the Company and Purchasers entered into a Securities Purchase Agreement, pursuant to which, in exchange for the Purchasers transferring the 2015 Notes, accrued interest and the Series C Stock to the Company, the Company issued to the Purchasers an aggregate of (i) 393,550,372 shares of common stock, and (ii) 50,000 shares of Series D Stock of the Company. The 2015 Notes, accrued interest and the Series C Stock were cancelled following their acquisition by the Company.
	Each share of Series D Stock is convertible at the option of the Purchasers into 145,914.88 shares of common stock, or an aggregate of 7,295,744,128 shares of common stock. The Series D Stock also ranks senior to all existing preferred stock and common stock of the Company with respect to dividend rights, redemption rights and rights upon liquidation. From and after the date of the issuance of any shares of Series D Stock, dividends accrue on each share at the rate of 10% per annum of the Series D Stock’s stated value of $100 per share, plus accrued but unpaid dividends, compounded quarterly. If the Company is liquidated and the assets and funds available for distribution among the holders of Series D Stock are insufficient to permit the payment in full of the liquidation value of all of the outstanding Series D Stock, then the entire assets and funds of the Company will be distributed ratably in respect of the holders of Series D Stock. Beginning one year and one day after the original date of issuance, the Purchasers can require that the Company redeem the outstanding shares of Series D Stock at a redemption price equal to the stated value of $100 per share, plus accrued and unpaid dividends. The shares of Series D Stock are entitled to vote on an as-converted basis with the holders of the common stock on any matter presented to the holders of the common stock for their action or consideration. The Series D Stock is subject to anti-dilution protection as well as certain protective provisions.
	Because the Company does not currently have a sufficient number of authorized and unreserved common shares to permit the full conversion of the Series D Stock, the Board of Directors of the Company has approved and adopted an amendment to its charter to increase the number of Gasco common shares and has recommended to the Purchasers that they approve the charter amendment by written consent.  The written consent approving the charter amendment was subsequently executed by the Purchasers on October 23, 2013, but the charter amendment is not yet effective pending the completion of required SEC filings.
	The Company will record the impact of the Restructuring Transactions in its consolidated financial statements for the year ended December 31, 2013.

CREDIT_FACILITY

CREDIT FACILITY	9 Months Ended
	Sep. 30, 2013
CREDIT FACILITY	'
CREDIT FACILITY	'
	NOTE 5 — CREDIT FACILITY
	In connection with the Restructuring Transactions and pursuant to the Credit Agreement, the Purchasers established the Credit Facility for the Company.  The Credit Facility bears interest at a fixed annual rate of 8% and becomes due on February 18, 2014.  The Credit Facility is secured by substantially all of the proved oil and gas assets and all personal property of the Company and its subsidiaries and by guarantees of each of the Company’s subsidiaries.  The Credit Facility contains certain customary restrictive covenants and also contains customary events of default, including nonpayment of principal or interest, violations of covenants, cross defaults, bankruptcy and material judgments.
	For extending the Credit Facility, the Company also issued a total of 250,000 shares of common stock to the Purchasers.
	On October 18, 2013, the Company borrowed $2,500,000 under the Credit Facility, which was used for general corporate purposes, leaving the Company with $2,500,000 of credit availability under the Credit Facility, subject to the terms and conditions thereof.

CONVERTIBLE_SENIOR_NOTES

CONVERTIBLE SENIOR NOTES	9 Months Ended
	Sep. 30, 2013
CONVERTIBLE SENIOR NOTES	'
CONVERTIBLE SENIOR NOTES	'
	NOTE 6 - CONVERTIBLE SENIOR NOTES
	As of September 30, 2013, the Company had $45,168,000 aggregate principal amount of 2015 Notes outstanding that were due October 2015.
	The 2015 Notes bore interest at a rate of 5.50% per annum, payable in cash semi-annually in arrears on April 5th and October 5th of each year.  The Company elected not to make the $1,242,120 semi-annual interest payments due on April 5, and October 5, 2013 on its outstanding 2015 Notes and therefore an event of default occurred under the Indenture requiring the Company to pay interest on overdue interest payments at a rate of 7.5% per annum. As a result of the event of default, the 2015 Notes were classified as a current liability in the accompanying unaudited condensed consolidated financial statements.
	The debt discount that was recognized in connection with the 2015 Notes was being accreted to interest expense under the effective interest method at a rate of 26.3%. The unamortized discount as of September 30, 2013 and December 31, 2012 was $14,731,680 and $18,530,539, respectively.
	As of the date of the Restructuring Transactions, total principal and accumulated interest on the 2015 Notes (including default interest) equaled $47,795,256. The 2015 Notes and accrued interest were cancelled on October 18, 2013. See Note 4 - Restructuring Transactions, herein for further discussion.

ASSET_SALES

ASSET SALES	9 Months Ended
	Sep. 30, 2013
ASSET SALES	'
ASSET SALES	'
	NOTE 7 — ASSET SALES
	Uinta Basin Joint Venture
	On March 22, 2012, the Company closed a transaction (the “Uinta Basin Transaction”) whereby, pursuant to the Purchase and Sale Agreement (the “Purchase Agreement”) dated February 23, 2012, between the Company’s wholly-owned subsidiary, Gasco Production Company, and Wapiti Oil & Gas II, L.L.C. (“Wapiti”), and a Closing Agreement (the “Closing Agreement”) dated March 22, 2012 relating to the Purchase Agreement, the Company (i) sold to Wapiti an undivided 50% of its interest in certain of its Uinta Basin producing oil and gas assets for $18.0 million in cash and $1.19 million in the form of a promissory note receivable from Wapiti, which was repaid in full during the second quarter of 2012, and (ii) transferred to Wapiti an undivided 50% of its interest in its Uinta Basin non-producing oil and gas assets in exchange for, among other agreements, Wapiti’s commitment to fund $30.0 million of the drilling and completion costs associated with the exploration and development of the subject assets.
	As a part of the Uinta Basin Transaction, Gasco Production Company entered into a Development Agreement (the “Development Agreement”) with Wapiti, which includes terms and conditions of a drilling program agreed to by the parties.
	Of Wapiti’s $30.0 million funding commitment, $15.0 million will be paid on behalf of the Company, and the Company has agreed to provide an additional $7.5 million of drilling and completion costs. Accordingly, the total program will be $37.5 million. If the Company is not able to pay its share of the above costs, it may lose certain rights granted under the Development Agreement and related operating agreements, including the right to continue as operator or contract operator of the properties, the right to make proposals or elect to participate in operations under the Development Agreement or any operating agreement, the right to call, attend and vote at meetings of the Operating Committee (as defined below), the right to transfer its interest in the properties and the joint venture, the right to acquire Wapiti’s interest in the properties under the right of first offer provisions of the Development Agreement and the right to acquire its pro rata share of additional properties acquired by Wapiti within the area of mutual interest identified in the Development Agreement. We have not incurred any costs to date and there is substantial doubt regarding our ability to fund our share of the drilling and completion costs.
	The drilling and completion program will continue until Wapiti’s funding commitment has been fully expended or for a shorter period if the Operating Committee votes to cease the drilling program after Wapiti has expended $10.0 million on drilling and completion costs related to the program wells (the “Drilling Term”).
	With respect to wells drilled pursuant to the drilling program, the net revenue interest attributable to such wells from the closing through the time when the cumulative proceeds received by Wapiti from such wells equals the amount of costs actually paid by Wapiti in respect of such wells and the drilling program (such time, “Payout”), will be allocated 32.5% to the Company and 67.5% to Wapiti. After Payout, the net revenue interest will be allocated in proportion to the actual net revenue interests of the parties in such wells.  With respect to each well drilled pursuant to the drilling program, (i) all drilling and completion costs will be borne (a) during the Drilling Term, 20% by the Company and 80% by Wapiti, (b) after the Drilling Term but before Payout, 32.5% by the Company and 67.5% by Wapiti, and (c) after Payout, in proportion to the actual working interests of the parties in such wells, and (ii) all other working interest costs will be borne (x) before Payout, 32.5% by the Company and 67.5% by Wapiti, and (y) after Payout, in proportion to the actual working interests of the parties in such wells.
	Subject to the terms of the Development Agreement, the Company will manage the operations contemplated by the drilling program.  Except for the subject assets that are already subject to joint operating agreements with third parties, the operation of (i) a portion of the subject assets will be subject to an agreed upon joint operating agreement (a “JOA”), which names Gasco Production Company as operator of record, and (ii) the remaining portion of the subject assets will be subject to an agreed upon JOA, which names Wapiti as operator of record. Gasco Production Company and Wapiti also entered into a contract operating agreement naming Gasco Production Company as contract operator with respect to the portion of the subject assets for which Wapiti is named as operator of record.  However, to the extent that Gasco Production Company, as operator under these agreements, becomes insolvent, bankrupt or is placed into receivership, it will be deemed to have resigned as operator or Wapiti may have a termination right.  The Company and Wapiti have formed an Operating Committee (the “Operating Committee”) to oversee generally the drilling program and operations in the project area and to approve certain matters specified in the Development Agreement. The Operating Committee consists of two members from each of the Company and Wapiti, with the members appointed by each party having an aggregate 50% vote.
	The Development Agreement contains transfer restrictions on each of the Company’s and Wapiti’s ability to transfer its respective interests in the subject assets. The Development Agreement also contains a customary area of mutual interest provision covering the Project Area. With certain limited exceptions, the Development Agreement will remain in effect during the Drilling Term; however, after the six-month anniversary of the end of the Drilling Term, the Development Agreement may be terminated by either the Company or Wapiti upon six months’ advance notice.
	Due primarily to permitting delays in obtaining various governmental approvals, the Company did not drill any natural gas wells in Utah from the closing of the Uinta Basin Transaction through the end of the third quarter of 2013.
	The Company used approximately $10.5 million of the proceeds from the transaction to repay the borrowings under its prior revolving credit facility.
	The sale of the proved property in the Uinta Basin Transaction was recorded by recognizing a gain of $2,567,574 rather than recording a credit to the full cost pool for the proceeds because this method would have significantly altered the relationship between capitalized costs and the proved reserves attributable to the cost center.
	No adjustments were made to the carrying value of the unproved properties upon the closing of the Uinta Basin Transaction. Rather as the wells are drilled, the cost basis of the unproved property associated with each well drilled will be reclassified from unproved property to the full cost pool to be depleted and included in the ceiling test. The cost basis will be determined based on a per acre valuation multiplied by the number of acres for each drilling location.
	The following unaudited pro forma information is presented as if the Uinta Basin Transaction had an effective date of January 1, 2012, and is not necessarily indicative of either future results of operations or results that might have been achieved had the transaction been consummated as of January 1, 2012. The pro forma results for the three and nine months ended September 30, 2013 and the three months ended September 30, 2012 were the same as the actual results and are not included in the table below.
		Nine Months Ended
		September 30, 2012
	Revenue as reported	$	6,592,765
	Less: revenue from the Uinta Basin Transaction	1,206,145
	Pro forma revenue	$	5,386,620
	Net loss as reported	$	(13,380,613	)
	Less: operating loss resulting from the Uinta Basin Transaction	(2,390,235		)
	Pro forma net loss	$	(10,990,378	)
	Net loss per share — basic and diluted as reported	$	(0.08	)
	Less net loss per share — from the Uinta Basin Transaction	(0.01		)
	Pro forma net loss income per share — basic and diluted	$	(0.07	)

DERIVATIVES

DERIVATIVES	9 Months Ended
	Sep. 30, 2013
DERIVATIVES	'
DERIVATIVES	'
	NOTE 8 — DERIVATIVES
	From time to time, the Company uses commodity derivative instruments to provide a measure of stability to its cash flows in an environment of volatile oil and gas prices and to manage its exposure to commodity price risk. During 2013, the Company did not have any commodity derivative contracts, and during the first nine months of 2012, the Company’s natural gas derivative instruments consisted of one costless collar agreement for production from January 1, 2012 through December 31, 2012. During June 2012, the Company monetized this contract for net proceeds of $677,868. Prior to the monetization, the costless collar contained a fixed floor price (purchase put) and ceiling price (written call). The Company received the difference between the published index price and the floor price if the index price was below the floor price. The Company paid the difference between the ceiling price and the index price only if the index price was above the ceiling price. If the index price was between the ceiling and the floor prices, no amounts were paid or received.
	On June 15, 2011, the Company issued the June Warrants to purchase 18,750,000 shares of common stock and on August 3, 2011, the Company issued the August Warrants to purchase 11,500,000 shares of common stock. The Warrants have an initial exercise price of $0.35 per share (subject to adjustment) and sixty-month term. The Warrants contain a contingent cash settlement provision at the option of the holder and accordingly, are classified as a derivative liability and are subject to the classification and measurement standards for derivative financial instruments.
	The following table details the fair value of the derivatives recorded in the unaudited condensed consolidated balance sheets:
		Location on		Fair Value at
		Consolidated
		Balance Sheets		September 30, 2013			December 31, 2012
	Warrant derivatives	Noncurrent liabilities		$	71,000		$	907,500
	The table below summarizes the realized and unrealized gains and losses related to the Company’s derivative instruments for the three and nine months ended September 30, 2013 and 2012.
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013		2012
	Realized gains on commodity instruments	$	—		$	—		$	—	$	1,255,948
	Change in fair value of commodity instruments	—			—			—		(865,358		)
	Change in fair value of warrant derivatives	104,000			720,000			836,500		2,117,500
	Total realized and unrealized gains recorded	$	104,000		$	720,000		$	836,500	$	2,508,090
	These realized and unrealized gains and losses are recorded in the accompanying unaudited condensed consolidated statements of operations as derivative gains (losses).

GAS_PROCESSING_AGREEMENTS

GAS PROCESSING AGREEMENTS	9 Months Ended
	Sep. 30, 2013
GAS PROCESSING AGREEMENTS	'
GAS PROCESSING AGREEMENTS	'
	NOTE 9 — GAS PROCESSING AGREEMENTS
	On September 21, 2011, the Company entered into a Gas Processing Agreement (the “Chipeta Processing Agreement”) with Chipeta Processing LLC (“Chipeta”) pursuant to which the Company dedicated certain of its natural gas production from its acreage in Utah to Chipeta for processing, and Chipeta agreed to process all natural gas production from such assets through facilities and related equipment that Chipeta constructed.
	The primary term of the Chipeta Processing Agreement is ten years, beginning after the in-service date of a 300 MMcf/d cryogenic processing facility that was built and placed in service on February 7, 2013. The primary term will be extended for one-year terms unless terminated by either party giving 180 days’ notice prior to the expiration of the then-current term.
	Pursuant to the Chipeta Processing Agreement, the Company reserved 25,000 Mcf/d of capacity in the Chipeta processing plant for cryogenic processing.  The Company agreed to pay specified processing fees per MMBtu as well as a pro rata share of all applicable electric compression costs, subject to escalation on an annual basis.  Under the agreement, the Company committed to deliver, on average, at least 90% of its contracted cryogenic capacity of 25,000 Mcf/d (the “Minimum Daily Quantity”) during each monthly accounting period. Following the first twelve monthly accounting periods, Chipeta may determine whether the Company failed to deliver equal to or greater than the Minimum Daily Quantity multiplied by the number of days in the annual accounting period.  If the Company delivered less than the quantity it committed to deliver, it would be required to pay a deficiency payment equal to the contracted cryogenic processing fee multiplied by the deficient quantity. In addition, to the extent that Chipeta has reasonable grounds for uncertainty regarding the performance of our obligations under the agreement, including a material change in the Company’s creditworthiness, Chipeta may sell the Company’s natural gas and apply amounts received against any amounts owed to Chipeta, set off any amount owed to the Company against amounts owed to Chipeta or cease processing our natural gas until the Company’s account is current, with interest.  Chipeta may also demand adequate assurance of performance from the Company, which may be in the form of a standby irrevocable letter of credit, prepayment or performance bond or guaranty. The Company has not received notification from Chipeta that it intends to pursue any of these options.
	Historically, the Company’s natural gas production had been gathered and processed by Monarch Natural Gas, LLC (“Monarch”) pursuant to the Gas Gathering and Processing Agreement, effective March 1, 2010, between Monarch and the Company. On March 22, 2012, the Company entered into an Amended and Restated Gas Gathering and Processing Agreement (the “Amended and Restated Monarch Agreement”) with Monarch in which Monarch agreed to, among other things, (a) release and waive its rights to process the first 50,000 MMBtu/day of the Company’s gas delivered to Monarch’s gathering system pursuant to the Amended and Restated Monarch Agreement (the “Excluded Production”) and (b) retain all processing rights for all gas volumes produced from certain of the Company’s reserves in excess of the Excluded Production.  The Excluded Production may be reduced if the Company fails to meet certain drilling investment targets.  The Company is committed to deliver to Monarch for gathering a minimum of 25,000 Mcf/day and, unless suspended pursuant to the terms of the Amended and Restated Monarch Agreement or waived, it is obligated to pay for any shortfall following the end of each quarterly period, measured by the shortfall quantity for the quarter multiplied by the then-current gathering and processing fees under the Amended and Restated Monarch Agreement.
	The Company has also entered into the Questar Wet Line Agreement, dated September 20, 2011, with Questar Pipeline Company (“QPC”), pursuant to which the Company agreed to enter into separate transportation services agreements for firm transportation services. The Company is currently committed to deliver to QPC for transportation services a minimum of 25,000 MMBtu/day.
	These contracts expire at various dates through 2023 and, unless suspended pursuant to the terms of the contracts or waived by the counterparty, the Company will be required to make periodic deficiency payments for any shortfalls in delivering the minimum volume commitments. These amounts are owed regardless of whether the Company delivers any natural gas quantities to the applicable parties. As described in Note 2 — Going Concern, herein, there is substantial doubt regarding the Company’s ability to generate sufficient cash flows from operations to fund its ongoing operations. If the Company is unable to fund additional drilling projects, and based on its September 30, 2013 reserve estimates, assuming no future drilling and constant gas prices, it estimates that it could have a possible future aggregate minimum production shortfall of approximately 41,000 MMcf valued at approximately $28 million on an undiscounted gross basis. The Company accrued $373,000 in shortfall commitments related to the nine months ended September 30, 2013.
	The Company is considering several alternatives to mitigate the estimated production shortfall such as the sale of its firm commitment positions, seeking relief from the firm commitments because of legal delays in the area that prevented the Company from obtaining various governmental approvals and the purchase of production quantities to meet its minimum production requirements. Also, future increases in gas prices would increase the related reserve estimates and reduce the possible shortfalls. However, there is no assurance that the Company will be successful in accomplishing these actions should there be a shortfall. Accordingly, the Company has not accrued the future possible obligation as of September 30, 2013 as it is not probable or reasonably estimable.

STOCKBASED_COMPENSATION

STOCK-BASED COMPENSATION	9 Months Ended
	Sep. 30, 2013
STOCK-BASED COMPENSATION	'
STOCK-BASED COMPENSATION	'
	NOTE 10 — STOCK-BASED COMPENSATION
	As of September 30, 2013, the Company has outstanding common stock options and restricted stock issued under its equity incentive plans. The Company measures the fair value at the grant date for stock option grants and restricted stock awards and records compensation expense over the requisite service period. The expense recognized over the service period includes an estimate of the awards that will be forfeited; however, the Company assumes no forfeitures for employee awards based on its historical forfeiture experience. During the year ended December 31, 2012 and through January 2013, the Company also had outstanding SARs which were accounted for as liability-based awards and accordingly, the Company recognized the fair value of the vested SARs each reporting period. The fair value of stock options and SARs is calculated using the Black-Scholes option-pricing model and the fair value of restricted stock is based on the fair value of the stock on the date of grant.
	During the nine months ended September 30, 2012, the Company accounted for stock compensation arrangements with non-employees using a fair value approach. Under this approach, the stock compensation related to unvested stock options issued to non-employees was recalculated at the end of each reporting period based upon the fair value on that date. There were no stock compensation arrangements with non-employees during the first nine months of 2013.
	During the three and nine months ended September 30, 2013 and 2012, the Company recognized stock-based compensation expense as follows:
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013		2012
	Employee compensation	$	39,399		$	79,182		$	139,655	$	216,053
	Consultant compensation	—			(191		)	—		(213		)
	Total stock-based compensation	39,399			78,991			139,655		215,840
	Less: consultant compensation expense capitalized as proved property	—			(95		)	—		(106		)
	Stock-based compensation expense	$	39,399		$	79,086		$	139,655	$	215,947
	Stock Options
	The following table summarizes the stock option activity in the Company’s equity incentive plans from January 1, 2013 through September 30, 2013:
		Shares Underlying		Weighted-Average
		Stock Options		Exercise Price
	Outstanding at January 1, 2013	9,506,943		$	1.04
	Granted	—		—
	Exercised	—		—
	Forfeited	(461,474	)	$	0.12
	Cancelled	(2,827,822	)	$	0.59
	Outstanding at September 30, 2013	6,217,647		$	1.09
	Exercisable at September 30, 2013	5,478,402		$	1.21
	The following table summarizes information related to the outstanding and vested options as of September 30, 2013:
		Outstanding Options		Vested Options
	Number of shares	6,217,647		5,478,402
	Weighted-Average Remaining Contractual Life	2 Years		2 years
	Weighted-Average Exercise Price	$1.09		$1.21
	Aggregate intrinsic value	—		—
	The aggregate intrinsic value in the table above represents the total pretax intrinsic value based on the fair value of the Company’s common stock of $0.02 as of September 30, 2013, which would have been received by the option holders had they exercised their options as of that date.
	The Company settles employee stock option exercises with newly issued common shares.
	As of September 30, 2013, there is $79,470 of total unrecognized compensation cost related to non-vested options granted under the Company’s equity incentive plans. That cost is expected to be recognized over a period of approximately 2 years.
	Restricted Stock
	The following table summarizes the restricted stock activity from January 1, 2013 through September 30, 2013:
		Restricted		Weighted-Average
		Stock		Grant Date
				Fair Value
	Outstanding at January 1, 2013	336,000		$	0.22
	Granted	—		—
	Vested	(48,095	)	$	0.18
	Forfeited	(92,000	)	$	0.22
	Outstanding at September 30, 2013	195,905		$	0.24
	As of September 30, 2013, there is $25,530 of total unrecognized compensation cost related to non-vested restricted stock granted under the Company’s equity incentive plans. That cost is expected to be recognized over a period of approximately 2 years.
	SARs
	Effective October 1, 2011, the Company’s non-employee directors agreed to reduce their monthly compensation and in exchange, on October 5, 2011, the Company granted SARs related to a total of 500,000 shares of the Company’s common stock to these directors. As of December 31, 2011, the SARs were recorded as a liability of $10,924. The SARs provided the right to receive a lump sum cash payment equal to the value of the product of (a) the excess of (i) the fair market value of one share of common stock on the date of exercise, over (ii) $0.25, which was an amount greater than the closing price of a share of common stock on the date of grant, multiplied by (b) the number of shares as to which an award has been exercised (“Appreciation Amount”). The SARs vested on January 31, 2012 and were automatically exercised on February 1, 2012. The fair market value of the common stock on the date of exercise was below $0.25 per share and therefore the Appreciation Amount was zero and no cash payment was made.
	Effective February 28, 2012, the Company granted another SARs award related to a total of 1,000,000 shares of its common stock to its non-employee directors.  As of December 31, 2012, the liability for the SARs was approximately zero. The SARs provided the right to receive a lump sum cash payment equal to the value of the product of (a) the excess of (i) (A) the fair market value of one share of common stock on the date of exercise or (B) $2.00, whichever was  less, over (ii) $0.30, which was an amount greater than the closing price of a share of common stock on the date of grant, multiplied by (b) the number of shares as to which an award has been exercised. The SARs vested on January 31, 2013 and were automatically exercised on February 1, 2013. The fair market value of the common stock on the date of exercise was below $0.25 per share and therefore the Appreciation Amount was zero and no cash payment was made.

FAIR_VALUE_MEASUREMENTS

FAIR VALUE MEASUREMENTS	9 Months Ended
	Sep. 30, 2013
FAIR VALUE MEASUREMENTS	'
FAIR VALUE MEASUREMENTS	'
	NOTE 11 — FAIR VALUE MEASUREMENTS
	The authoritative guidance establishes a hierarchy for inputs used in measuring fair value that maximizes the use of observable inputs and minimizes the use of unobservable inputs by requiring that the most observable inputs be used when available. Observable inputs are inputs that market participants would use in pricing the asset or liability developed based on market data obtained from sources independent of the Company. Unobservable inputs are inputs that reflect the Company’s assumptions of what market participants would use in pricing the asset or liability developed based on the best information available in the circumstances. The hierarchy is broken down into three levels based on the reliability of the inputs as follows:
	Level 1: Quoted prices are available in active markets for identical assets or liabilities;
	Level 2: Quoted prices in active markets for similar assets and liabilities that are observable for the asset or liability; or
	Level 3: Unobservable pricing inputs that are generally less observable from objective sources, such as discounted cash flows models or valuations.
	The financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The Company’s policy is to recognize transfers in and/or out of fair value hierarchy as of the end of the reporting period for which the event or change in circumstances caused the transfer. The Company has consistently applied the valuation techniques discussed below in all periods presented.
	The following table presents the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis as of September 30, 2013 and December 31, 2012 by level within the fair value hierarchy:
		Fair Value Measurements Using
		Level 1			Level 2			Level 3			Total
	September 30, 2013
	Liabilities:
	Warrant derivatives	$	—		$	—		$	71,000		$	71,000
	December 31, 2012
	Liabilities:
	Warrant derivatives	$	—		$	—		$	907,500		$	907,500
	As of September 30, 2013, the Company’s warrant derivative financial instrument is comprised of the Warrants issued by the Company to purchase 30,250,000 shares of common stock. The Warrants are valued using a binomial lattice-based valuation model and are classified as Level 3 in the fair value hierarchy. The lattice-based valuation technique is utilized because it embodies all of the requisite assumptions (including the underlying price, exercise price, term, volatility, and risk-free interest-rate) that are necessary to measure the fair value of these instruments. The valuation policies are determined by the Chief Accounting Officer and are approved by the Chief Executive Officer. Fair value measurements are discussed with the Company’s audit committee, as deemed appropriate. Each quarter, the Chief Accounting Officer and the Chief Executive Officer update the inputs used in the fair value calculations and internally review the changes from period to period for reasonableness. The Company uses data from its peers as well as from external sources in the determination of the volatility and risk free interest rates used in the fair value calculations. A sensitivity analysis is performed as well to determine the impact of the inputs on the ending fair value estimate. Estimating fair values of derivative financial instruments requires the development of significant and subjective estimates that may, and are likely to, change over the duration of the instrument due to both internal and external market factors. In addition, option-based techniques are highly sensitive to volatility assumptions, particularly since the trading price of the Company’s common stock has a high-historical volatility. With all other factors remaining constant as of September 30, 2013:
	(i)             the warrant derivative liability would decrease to zero if the trading price of Gasco’s common stock was reduced to zero, and would increase by approximately $1.4 million for a $0.10 increase in the trading price of its common stock; and
	(ii)          the warrant derivative liability would increase by $33,000 with a 10% increase and would decrease by $27,000 with a 10% decrease in the volatility rate.
	A summary of the Warrants  issued by the Company is as follows:
		Number of		Exercise			Weighted
		Warrants		Price			Average
							Remaining
							Contractual Life
	Warrants outstanding as of 12/31/12	30,250,000		$	0.35		40 months
	Warrants issued	—					—
	Warrants outstanding as of 9/30/13	30,250,000		$	0.35		33 months
	The significant assumptions used in the valuation of the warrant derivative liability as of September 30, 2013 are as follows:
	Exercise price	$0.35 per share
	Stock price	$0.02 per share
	Volatility	105%
	Remaining Term of Warrants	32 - 34 months
	Risk-free interest rate	0.5% - 1%
	The following table sets forth a reconciliation of changes in the fair value of financial liabilities classified as Level 3 in the fair value hierarchy:
		For the Three Months						For the Nine Months
		Ended						Ended
		September 30,						September 30,
		2013			2012			2013			2012
	Balance as of beginning of period	$	(175,000	)	$	(2,837,500	)	$	(907,500	)	$	(4,235,000	)
	Total gains (realized or unrealized):
	Included in earnings	104,000			720,000			836,500			2,117,500
	Included in other comprehensive income	—			—			—			—
	Issuances	—			—			—			—
	Settlements	—			—			—			—
	Transfers in and out of Level 3	—			—			—			—
	Balance as of September 30,	$	(71,000	)	$	(2,117,500	)	$	(71,000	)	$	(2,117,500	)
	Change in unrealized gains included in earnings relating to instruments still held as of September 30,	$	104,000		$	2,117,500		$	(71,000	)	$	2,117,500
	The carrying amounts of cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities approximate fair values because of the short-term maturities and/or liquid nature of these assets and liabilities. The estimated fair value of the 2015 Notes of $14,125,000 and $28,833,000 as of September 30, 2013 and December 31, 2012, respectively, was determined using trading prices as of September 30, 2013 and the income valuation technique and option pricing model as of December 31, 2012. This valuation is classified as a Level 3 in the fair value hierarchy as it relies primarily on unobservable pricing inputs.

STATEMENTS_OF_CASH_FLOWS

STATEMENTS OF CASH FLOWS	9 Months Ended
	Sep. 30, 2013
STATEMENTS OF CASH FLOWS	'
STATEMENTS OF CASH FLOWS	'
	NOTE 12 - STATEMENTS OF CASH FLOWS
	During the nine months ended September 30, 2013, the Company’s non-cash investing and financing activities consisted of the following transaction:
	·                  Additions to oil and gas properties included in accounts payable of $518,000.
	During the nine months ended September 30, 2012, the Company’s non-cash investing and financing activities consisted of the following transactions:
	·                  Settlement of a $121,000 liability with a prepaid deposit.
	·                  Conversion of 8,935 shares of Preferred Stock into 1,489,166 shares of common stock.
	·                  Additions to oil and gas properties included in accounts payable of $50,000.
	Cash paid for interest during the nine months ended September 30, 2012 was $1,353,761. There was no cash paid for interest during the nine months ended September 30, 2013 and no cash was paid for income taxes during the nine months ended September 30, 2013 and 2012.

LEGAL_PROCEEDINGS

LEGAL PROCEEDINGS	9 Months Ended
	Sep. 30, 2013
LEGAL PROCEEDINGS	'
LEGAL PROCEEDINGS	'
	NOTE 13 — LEGAL PROCEEDINGS
	The Company is party to various legal proceedings arising out of the normal course of business.  The most significant legal proceedings to which the Company is subject are summarized below.  The ultimate outcome of the Clean Water Act Compliance Order matter cannot presently be determined, nor can the liability that could potentially result from an adverse outcome be reasonably estimated at this time.  The Company does not expect the outcome of these proceedings to have a material adverse effect on its financial position, results of operations or cash flows.
	Clean Water Act Compliance Order Matter
	On October 3, 2011, the Company received a compliance order from the United States Environmental Protection Agency (the “EPA”) Region 8 under the authority of the federal Clean Water Act.  The compliance order alleges that the Company violated the Clean Water Act by discharging fill material into wetlands adjacent to the Green River in Utah without authorization on two occasions: (i) once when it constructed an access road to a future well location in either 2004 or 2005 and (ii) once when it constructed an access road and a well pad in 2007 or 2008.  The compliance order directs the Company to remove all dredged or fill material alleged to have been placed in the wetlands and to restore the wetlands to their pre-impact condition and grade, which would require that the Company plug and abandon the well alleged to have been installed in a wetlands area.  The Company disagrees with some of the factual contentions in the compliance order, and it has had a number of discussions with the EPA concerning the order.  However, it has been unable to negotiate a successful resolution of the alleged violations with the EPA, and as a result, it filed a lawsuit in federal district court in the District of Colorado on June 25, 2012.  The lawsuit seeks judicial review of the compliance order, specifically review of the EPA’s contention that the affected areas are wetlands, or if they are wetlands, whether they are wetlands that are subject to federal regulatory jurisdiction under the Clean Water Act.  On September 5, 2012, the EPA, represented by the U.S. Department of Justice (“DOJ”), answered, and the United States separately counterclaimed for an injunction seeking substantially the same relief that the EPA seeks in the compliance order but also requested civil penalties for each day of alleged discharges of fill material and each day of alleged violation of the compliance order.  The Company has answered the EPA’s counterclaim.  In late January 2013, pursuant to a Scheduling Order before the court, the Company submitted a brief in support of its claims under the original suit filed in June 2012.  At this point, it appears to us that our original claim and the DOJ’s counterclaim will be tried concurrently.
	NEPA Suit
	In June 2012, the U.S. Bureau of Land Management (“BLM”) signed and issued a Record of Decision (“ROD”) on the Environmental Impact Statement (“EIS”) that authorizes the development of the Company’s Uinta Basin field upon federal lands in Duchesne and Uintah Counties, Utah.  This field includes the Company’s core Riverbend Project.  However on January 18, 2013, certain non-governmental environmental organizations, including the Southern Utah Wilderness Alliance (“SUWA”), filed a suit against the BLM, challenging the ROD issued by that agency.  In its complaint, SUWA alleges that the BLM failed to comply with the requirements of the National Environmental Policy Act and its implementing regulations.  SUWA was seeking, among other things, that the ROD and EIS be set aside, the effect of which would void the BLM’s authorization for the Company to proceed with its planned project. Only recently, on February 13, 2013, SUWA voluntarily submitted notice of dismissal of the suit to the District Court. Because SUWA voluntarily withdrew its suit, it has the opportunity to refile the suit at a later date. Whether SUWA will refile this suit at a later date is currently unknown to the Company.
	Hat Creek Settlement
	In February 2013, the Company settled a claim with one of its working interest owners, Hat Creek Energy LLC (“Hat Creek”), in connection with a well that was operated by the Company and owned by both parties. Hat Creek filed the claim on April 2, 2012 in the Denver District Court, alleging that Hat Creek did not consent to certain reworking operations performed by the Company in violation of the joint operating agreement, and that Hat Creek’s working interest in the well was impaired as a result.  Hat Creek sought damages of not less than $200,000, and the Company sought counterclaim damages for receivables owed by Hat Creek and for the reworking costs.  The Company settled this claim for $307,000 consisting of a $160,000 cash payment to Hat Creek and the forgiveness of $147,000 in accounts receivable owed to the Company by Hat Creek. In addition, the settlement provides that the Company will receive Hat Creek’s ownership interest in the well.  The final settlement was accrued as of December 31, 2012.

GUARANTOR_SUBSIDIARIES

GUARANTOR SUBSIDIARIES	9 Months Ended
	Sep. 30, 2013
GUARANTOR SUBSIDIARIES	'
GUARANTOR SUBSIDIARIES	'
	NOTE 14 — GUARANTOR SUBSIDIARIES
	On August 31, 2011, the Company filed a Form S-3 shelf registration statement with the SEC, which was declared effective on September 20, 2011. Under this registration statement, the Company may from time to time offer and sell securities including common stock, preferred stock, depositary shares, warrants and debt securities that may be fully, irrevocably and unconditionally guaranteed by all of its subsidiaries:  Gasco Production Company, Riverbend Gas Gathering, LLC and Myton Oilfield Rentals, LLC (collectively, the “Guarantor Subsidiaries”). The stand-alone parent entity, Gasco Energy, Inc., has insignificant independent assets and no operations. Therefore, supplemental financial information on a condensed consolidating basis of the Guarantor Subsidiaries is not required. There are no restrictions on the Company’s ability to obtain cash dividends or other distributions of funds from the Guarantor Subsidiaries, except those imposed by applicable law.

SUBSEQUENT_EVENTS

SUBSEQUENT EVENTS	9 Months Ended
	Sep. 30, 2013
SUBSEQUENT EVENTS	'
SUBSEQUENT EVENTS	'
	NOTE 15 — SUBSEQUENT EVENTS
	See Note 3 – Significant Accounting Policies - Inventory Held for Sale, herein for subsequent events.
	See Note 4 – Restructuring Transactions, herein for subsequent events.

SIGNIFICANT_ACCOUNTING_POLICIE1

SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended
	Sep. 30, 2013
SIGNIFICANT ACCOUNTING POLICIES	'
Basis of Presentation	'
	Basis of Presentation
	The accompanying unaudited condensed consolidated financial statements include Gasco and its wholly-owned subsidiaries. All significant intercompany transactions have been eliminated.
Oil and Gas Properties	'
	Oil and Gas Properties
	The Company follows the full cost method of accounting whereby all costs related to the acquisition and development of oil and gas properties are capitalized into a single cost center (“full cost pool”). Such costs include lease acquisition costs, geological and geophysical expenses, internal costs directly related to exploration and development activities and costs of drilling both productive and non-productive wells. The Company capitalized $0 and $8,807 of internal costs during the three and nine months ended September 30, 2013 and $0 and $11,520 during the three and nine months ended September 30, 2012, respectively.  Costs associated with production and general corporate activities are expensed in the period incurred. The Company charges a marketing fee related to the sale of its natural gas production to the wells in which it is the operator and, therefore, the net income attributable to the outside working interest owners from such marketing activities of $60,402 and $175,535 was recorded as an adjustment to proved properties during the three and nine months ended September 30, 2013 and $37,896 and $69,700 was recorded as an adjustment to proved properties during the three and nine months ended September 30, 2012, respectively. Proceeds from property sales are generally credited to the full cost pool without gain or loss recognition unless such a sale would significantly alter the relationship between capitalized costs and the proved reserves attributable to a cost center.  A significant alteration would typically involve a sale of 25% or more of the proved reserves related to a single full cost pool. Please see Note 7 — Asset Sales, herein.
	Depletion of exploration and development costs and depreciation of production equipment is computed using the units-of-production method based upon estimated proved oil and gas reserves. Costs included in the depletion base to be amortized include: (i) all proved capitalized costs including capitalized asset retirement costs net of estimated salvage values, less accumulated depletion; (ii) estimated future development costs to be incurred in developing proved reserves; and (iii) estimated dismantlement and abandonment costs, net of estimated salvage values, that have not been included as capitalized costs because they have not yet been capitalized as asset retirement costs. The costs of unproved properties of $31,717,970 as of September 30, 2013, are withheld from the depletion base until it is determined whether or not proved reserves can be assigned to the properties. The properties are reviewed quarterly for impairment. If a determination is made that acreage will be expiring or that the Company does not plan to develop some of the acreage that is no longer considered to be prospective, an impairment of the acreage is recorded by reclassifying the costs to the full cost pool. The value of these acres for the purpose of recording the impairment is estimated by calculating a per acre value from the total unproved costs incurred for the applicable acreage divided by the total net acres owned by the Company. This per acre estimate is then applied to the acres that the Company does not plan to develop in order to calculate the impairment. During the nine months ended September 30, 2013, the Company reclassified approximately $796,000 of acreage costs in California and Utah into proved property. This acreage represents the value of leases that expired during the first nine months of 2013 or that the Company does not intend to renew in the future.
	Total well costs are transferred to the depletable pool even when multiple targeted zones have not been fully evaluated. For depletion and depreciation purposes, relative volumes of oil and gas production and reserves are converted at the energy equivalent rate of six thousand cubic feet of natural gas to one barrel of crude oil. Estimated reserve quantities are affected by changes in commodity prices and actual well performance.
	Under the full cost method of accounting, the ceiling test provides that capitalized costs less related accumulated depletion and deferred income taxes for each cost center may not exceed the sum of (i) the present value of future net revenue from estimated production of proved oil and gas reserves using current prices, excluding the future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet, at a discount factor of 10%; plus (ii) the cost of properties not being amortized, if any; plus (iii) the lower of cost or estimated fair value of unproved properties included in the costs being amortized, if any; less (iv) income tax effects related to differences in the book and tax basis of oil and gas properties. Should the net capitalized costs for a cost center exceed the sum of the components noted above, a ceiling test write-down would be recognized to the extent the excess capitalized costs exceed this ceiling limitation. The present value of estimated future net revenues is computed by applying the average first-day-of-the-month oil and gas price during the 12-month period ended as of the last day of the period to estimated future production of proved oil and gas reserves as of the end of the period, less estimated future expenditures to be incurred in developing and producing the proved reserves assuming the continuation of existing economic conditions. As of March 31, 2012, June 30, 2012 and September 30, 2012, the full cost pool exceeded the ceiling limitation based on the average first-day-of-the-month oil and gas prices of $82.58 per barrel and $2.94 per Mcf during the 12-month period ended March 31, 2012, $81.16 per barrel and $2.57 per Mcf during the 12-month period ended June 30, 2012 and $80.35 per barrel and $2.23 per Mcf during the 12-month period ended September 30, 2012. Therefore, impairment expense of $1,016,000 and $9,071,000 was recorded during the three and nine months ended September 30, 2012, respectively.  No impairment expense related to the Company’s oil and gas properties was recorded during the three and nine months ended September 30, 2013.
Facilities and Equipment	'
	Facilities and Equipment
	The Company’s oil and gas equipment is depreciated using the straight-line method over an estimated useful life of five to ten years. The rental of the equipment owned by the Company is charged to the wells that are operated by the Company and, therefore, the net expense attributable to the outside working interest owners from the equipment rental was recorded as an adjustment to proved properties in the amount of $17,356 and $29,326 during the three and nine months ended September 30, 2013 and $22,359 and $14,551 during the three and nine months ended September 30, 2012, respectively.
Inventory	'
	Inventory
	Inventory consists of pipe and tubular goods intended to be used in the Company’s oil and gas operations, and is stated at the lower of cost or market using the average cost valuation method. During the three and nine months ended September 30, 2013, the Company recorded impairment expense of $789,143 and $1,019,643, respectively, related to the decrease in the market value of its inventory.
Inventory Held for Sale	'
	Inventory Held for Sale
	During the first nine months of 2013, the Company determined that it would not have a future need for some of its casing and tubing inventory. Consequently, in September 2013, the Company developed a formal plan to sell the inventory. The Company reviewed various options for selling this inventory and decided that selling this inventory at auction would be the best option based on its current financial position and the need for additional cash flow. The Company agreed to sell this inventory at auction in September and the inventory was sold in October for $323,500 less selling expenses of $16,175.
Commodity Derivatives	'
	Commodity Derivatives
	From time to time, the Company has used commodity derivative instruments to provide a measure of stability to its cash flows in an environment of volatile oil and gas prices and to manage its exposure to commodity price risk. The Company records all commodity derivative instruments at fair value within the accompanying unaudited condensed consolidated balance sheets. The Company’s management has historically decided not to use hedge accounting under the accounting guidance for commodity derivatives and therefore, the changes in fair value are recognized in earnings. See Note 8 — Derivatives, herein.
Warrants	'
	Warrants
	On June 15, 2011, the Company issued warrants (“June Warrants”) to purchase 18,750,000 shares of common stock and on August 3, 2011, the Company issued warrants (“August Warrants” and collectively with the June Warrants, “Warrants”) to purchase 11,500,000 shares of common stock. The Warrants are exercisable immediately for a term of sixty months, beginning at issuance, at an initial exercise price of $0.35 per share; however, the exercise price and number of shares of common stock issuable on exercise of the Warrants are subject to adjustment in the event of any stock split, reverse stock split, stock dividend, recapitalization, reorganization or similar transaction.  If the Company makes a distribution of its assets to all of its stockholders, holders of the Warrants may be entitled to participate. In the event of a Fundamental Transaction (as defined in the Warrants), at the election of a holder of a Warrant, the Company may be required to purchase the holder’s Warrant for cash in an amount equal to the value of the remaining unexercised portion of the Warrant.  As a result, the Warrants are accounted for as a liability on the Company’s consolidated balance sheets with changes in their fair value reported in earnings. Subject to certain exceptions, if the average of the daily volume weighted-average price of a share of common stock for some period of time equals or exceeds 200% of the initial exercise price of the Warrants, and if at the time of such measurement the Equity Conditions (as defined in the Warrants) are satisfied, then the Company may, subject to certain conditions, require the holders of the Warrants to exercise.
	As a result of the Restructuring Transactions, the Warrants became immediately puttable. The Company has a derivative instruments liability of $71,000 to cover the potential put of the Warrants.
Asset Retirement Obligation	'
	Asset Retirement Obligation
	The Company accounts for its future asset retirement obligations by recording the fair value of the liability during the period in which it was incurred. The associated asset retirement costs are capitalized as part of the carrying amount of the long-lived asset. The increase in carrying value of a property associated with the capitalization of an asset retirement cost is included in proved oil and gas properties in the consolidated balance sheets. The Company depletes the amount added to proved oil and gas property costs using the units-of-production method. The Company’s asset retirement obligation consists of costs related to the plugging of wells, removal of facilities and equipment and site restoration on its oil and gas properties. The asset retirement liability is allocated to operating expense using a systematic and rational method.
	The information below reconciles the value of the asset retirement obligation for the periods presented.
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2013			2012		2013		2012
	Balance beginning of period	$	856,308		$	779,197	$	815,660	$	1,226,796
	Liabilities incurred	—			—		2,338		—
	Property dispositions	—			—		—		(493,178		)
	Accretion expense	19,893			18,019		58,203		63,598
	Balance end of period	$	876,201		$	797,216	$	876,201	$	797,216
	See Note 7 — Asset Sales, herein, for discussion of property dispositions.
Revenue Recognition	'
	Revenue Recognition
	The Company records revenues from the sale of natural gas and crude oil when delivery to the customer has occurred, title has transferred and collectability is reasonably assured. This occurs when oil or gas has been delivered to a pipeline or a tank lifting has occurred.
	The Company may have an interest with other producers in certain properties, in which case the Company uses the sales method to account for gas imbalances. Under this method, revenue is recorded on the basis of gas actually sold by the Company. In addition, the Company records revenue for its share of gas sold by other owners that cannot be volumetrically balanced in the future due to insufficient remaining reserves. The Company also reduces revenue for other owners’ gas sold by the Company that cannot be volumetrically balanced in the future due to insufficient remaining reserves. The Company’s remaining over- and under-produced gas balancing positions are considered in the Company’s proved oil and gas reserves.
Off-Balance Sheet Arrangements	'
	Off-Balance Sheet Arrangements
	From time to time, the Company enters into off-balance sheet arrangements and transactions that can give rise to off-balance sheet obligations. As of September 30, 2013, the off-balance sheet arrangements and transactions that the Company had entered into included operating lease agreements, gathering, compression, processing and water disposal agreements and gas transportation commitments. See Note 9 — Gas Processing Agreements, herein, for additional discussion regarding certain gas transportation and processing agreements.
Computation of Net Income (Loss) Per Share	'
	Computation of Net Income (Loss) Per Share
	Basic net income (loss) per share is computed by dividing net income (loss) attributable to common stockholders by the weighted-average number of common shares outstanding during the reporting period. The shares of restricted common stock granted to certain officers and employees of the Company are included in the computation of basic net income (loss) per share only after the shares become fully vested. Diluted net income (loss) per share of common stock includes both vested and unvested shares of restricted stock. Diluted net income (loss) per common share of stock is computed by dividing net income as adjusted for earnings allocated to participating securities by the diluted weighted-average common shares outstanding.  Potentially dilutive securities for the diluted earnings per share calculation consist of (i) unvested shares of restricted common stock, (ii) in-the-money outstanding options and Warrants to purchase shares of common stock, (iii) outstanding shares of Series C Convertible Preferred Stock, par value $0.001 per share (“Preferred Stock”), which are convertible into shares of common stock, and (iv) the Company’s outstanding 2015 Notes, which are convertible into shares of Preferred Stock and common stock.
	The treasury stock method, which assumes that the increase in the number of shares is reduced by the number of shares that could have been repurchased by the Company with the proceeds from the exercise of the options (the repurchases of shares were assumed to have been made at the average market price of the common shares during the reporting period), is used to measure the dilutive impact of stock options, shares of restricted common stock, Warrants and shares into which the 2015 Notes and Preferred Stock are convertible.
	Net income (loss) per share information is determined using the two-class method, which includes the weighted-average number of common shares outstanding during the period and other securities that participate in dividends (“participating security”). The Company considers the Preferred Stock to be a participating security because it includes rights to participate in dividends with the common stock. In applying the two-class method, earnings are allocated to both common stock shares and the Preferred Stock common stock equivalent shares based on their respective weighted-average shares outstanding for the period. Losses are not allocated to Preferred Stock shares. Basic and diluted net loss per share was the same for the three and nine months ended September 30, 2013 and 2012.
	The following shares were excluded from the computation of diluted loss per common share as they did not have a dilutive effect.
		For the Three Months				For the Nine Months
		Ended September 30,				Ended September 30,
		2013		2012		2013	2012
	Shares related to:
	2015 Notes	75,280,000		75,280,000		75,280,000	75,280,000
	Preferred Stock	30,344,173		30,344,173		30,344,173	30,344,173
	Common stock options	6,217,647		9,815,468		6,217,647	9,815,468
	Warrants	30,250,000		30,250,000		30,250,000	30,250,000
	Unvested restricted common stock	204,000		425,500		204,000	425,500
Use of Estimates	'
	Use of Estimates
	The preparation of the financial statements for the Company in conformity with US 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 financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from these estimates.
	The Company’s financial statements are based on a number of significant estimates, including oil and gas reserve quantities which are the basis for the calculation of depreciation, depletion and impairment of oil and gas properties, timing and costs associated with its retirement obligations, estimates of the fair value of derivative instruments, estimates used in stock-based compensation calculations and impairments to unproved property and to proved oil and gas properties.
Reclassifications	'
	Reclassifications
	Certain reclassifications have been made to prior years’ amounts to conform to the classifications used in the current year. Such reclassifications had no effect on the Company’s net loss for the periods presented.

SIGNIFICANT_ACCOUNTING_POLICIE2

SIGNIFICANT ACCOUNTING POLICIES (Tables)	9 Months Ended
	Sep. 30, 2013
SIGNIFICANT ACCOUNTING POLICIES	'
Schedule reconciling the value of the asset retirement obligation	'
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2013			2012		2013		2012
	Balance beginning of period	$	856,308		$	779,197	$	815,660	$	1,226,796
	Liabilities incurred	—			—		2,338		—
	Property dispositions	—			—		—		(493,178		)
	Accretion expense	19,893			18,019		58,203		63,598
	Balance end of period	$	876,201		$	797,216	$	876,201	$	797,216
Schedule of shares excluded from the computation of diluted loss per common share	'
		For the Three Months				For the Nine Months
		Ended September 30,				Ended September 30,
		2013		2012		2013	2012
	Shares related to:
	2015 Notes	75,280,000		75,280,000		75,280,000	75,280,000
	Preferred Stock	30,344,173		30,344,173		30,344,173	30,344,173
	Common stock options	6,217,647		9,815,468		6,217,647	9,815,468
	Warrants	30,250,000		30,250,000		30,250,000	30,250,000
	Unvested restricted common stock	204,000		425,500		204,000	425,500

ASSET_SALES_Tables

ASSET SALES (Tables) (Uinta Basin)	9 Months Ended
	Sep. 30, 2013
Uinta Basin	'
Asset sales	'
Schedule of unaudited pro forma information	'
		Nine Months Ended
		September 30, 2012
	Revenue as reported	$	6,592,765
	Less: revenue from the Uinta Basin Transaction	1,206,145
	Pro forma revenue	$	5,386,620
	Net loss as reported	$	(13,380,613	)
	Less: operating loss resulting from the Uinta Basin Transaction	(2,390,235		)
	Pro forma net loss	$	(10,990,378	)
	Net loss per share — basic and diluted as reported	$	(0.08	)
	Less net loss per share — from the Uinta Basin Transaction	(0.01		)
	Pro forma net loss income per share — basic and diluted	$	(0.07	)

DERIVATIVES_Tables

DERIVATIVES (Tables)	9 Months Ended
	Sep. 30, 2013
DERIVATIVES	'
Schedule of fair value of derivatives recorded in unaudited condensed consolidated balance sheets	'
		Location on		Fair Value at
		Consolidated
		Balance Sheets		September 30, 2013			December 31, 2012
	Warrant derivatives	Noncurrent liabilities		$	71,000		$	907,500
Summary of realized and unrealized gains and losses related to derivative instruments	'
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013		2012
	Realized gains on commodity instruments	$	—		$	—		$	—	$	1,255,948
	Change in fair value of commodity instruments	—			—			—		(865,358		)
	Change in fair value of warrant derivatives	104,000			720,000			836,500		2,117,500
	Total realized and unrealized gains recorded	$	104,000		$	720,000		$	836,500	$	2,508,090

STOCKBASED_COMPENSATION_Tables

STOCK-BASED COMPENSATION (Tables)	9 Months Ended
	Sep. 30, 2013
STOCK-BASED COMPENSATION	'
Summary of stock-based compensation expense	'
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013		2012
	Employee compensation	$	39,399		$	79,182		$	139,655	$	216,053
	Consultant compensation	—			(191		)	—		(213		)
	Total stock-based compensation	39,399			78,991			139,655		215,840
	Less: consultant compensation expense capitalized as proved property	—			(95		)	—		(106		)
	Stock-based compensation expense	$	39,399		$	79,086		$	139,655	$	215,947
Summary of stock option activity in the Company's equity incentive plans	'
		Shares Underlying		Weighted-Average
		Stock Options		Exercise Price
	Outstanding at January 1, 2013	9,506,943		$	1.04
	Granted	—		—
	Exercised	—		—
	Forfeited	(461,474	)	$	0.12
	Cancelled	(2,827,822	)	$	0.59
	Outstanding at September 30, 2013	6,217,647		$	1.09
	Exercisable at September 30, 2013	5,478,402		$	1.21
Summary of information related to the outstanding and vested options	'
		Outstanding Options		Vested Options
	Number of shares	6,217,647		5,478,402
	Weighted-Average Remaining Contractual Life	2 Years		2 years
	Weighted-Average Exercise Price	$1.09		$1.21
	Aggregate intrinsic value	—		—
Summary of restricted stock activity	'
		Restricted		Weighted-Average
		Stock		Grant Date
				Fair Value
	Outstanding at January 1, 2013	336,000		$	0.22
	Granted	—		—
	Vested	(48,095	)	$	0.18
	Forfeited	(92,000	)	$	0.22
	Outstanding at September 30, 2013	195,905		$	0.24

FAIR_VALUE_MEASUREMENTS_Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended
	Sep. 30, 2013
FAIR VALUE MEASUREMENTS	'
Schedule of financial assets and liabilities accounted for at fair value on a recurring basis	'
		Fair Value Measurements Using
		Level 1			Level 2			Level 3			Total
	September 30, 2013
	Liabilities:
	Warrant derivatives	$	—		$	—		$	71,000		$	71,000
	December 31, 2012
	Liabilities:
	Warrant derivatives	$	—		$	—		$	907,500		$	907,500
Summary of warrants issued	'
		Number of		Exercise			Weighted
		Warrants		Price			Average
							Remaining
							Contractual Life
	Warrants outstanding as of 12/31/12	30,250,000		$	0.35		40 months
	Warrants issued	—					—
	Warrants outstanding as of 9/30/13	30,250,000		$	0.35		33 months
Schedule of significant assumptions used in the valuation of the warrant derivative liability	'
	Exercise price	$0.35 per share
	Stock price	$0.02 per share
	Volatility	105%
	Remaining Term of Warrants	32 - 34 months
	Risk-free interest rate	0.5% - 1%
Schedule of reconciliation of changes in the fair value of financial liabilities classified as Level 3	'
		For the Three Months						For the Nine Months
		Ended						Ended
		September 30,						September 30,
		2013			2012			2013			2012
	Balance as of beginning of period	$	(175,000	)	$	(2,837,500	)	$	(907,500	)	$	(4,235,000	)
	Total gains (realized or unrealized):
	Included in earnings	104,000			720,000			836,500			2,117,500
	Included in other comprehensive income	—			—			—			—
	Issuances	—			—			—			—
	Settlements	—			—			—			—
	Transfers in and out of Level 3	—			—			—			—
	Balance as of September 30,	$	(71,000	)	$	(2,117,500	)	$	(71,000	)	$	(2,117,500	)
	Change in unrealized gains included in earnings relating to instruments still held as of September 30,	$	104,000		$	2,117,500		$	(71,000	)	$	2,117,500

GOING_CONCERN_Details

GOING CONCERN (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Oct. 18, 2013	Oct. 18, 2013	Oct. 18, 2013	Sep. 30, 2013	Dec. 31, 2012	Oct. 17, 2013	Oct. 18, 2013	Sep. 30, 2013	Oct. 17, 2013
			Markham and Orogen ('Investors")	Markham and Orogen ('Investors")	Common Stock	Series C Stock	Series C Stock	Series C Stock	Series D Stock	2015 Notes	2015 Notes
			Subsequent event	Subsequent event	Markham and Orogen ('Investors")			Markham and Orogen ('Investors")	Markham and Orogen ('Investors")	item	Markham and Orogen ('Investors")
				Senior secured credit facility	Subsequent event			Subsequent event	Subsequent event		Subsequent event
GOING CONCERN	'	'	'	'	'	'	'	'	'	'	'
Accumulated deficit	$252,615,527	$244,808,156	'	'	'	'	'	'	'	'	'
Convertible senior notes	'	'	'	'	'	'	'	'	'	'	'
Debt instrument carrying amount purchased	'	'	'	'	'	'	'	'	'	45,168,000	45,168,000
Interest rate (as a percent)	'	'	'	'	'	'	'	'	'	5.50%	'
Number of semi-annual interest payments not made	'	'	'	'	'	'	'	'	'	2	'
Semi-annual interest payment	'	'	'	'	'	'	'	'	'	1,242,120	'
Interest on overdue interest payments (as a percent)	'	'	'	'	'	'	'	'	'	7.50%	'
Accrued interest	$2,495,022	$586,556	'	'	'	'	'	'	'	$2,495,022	'
Maximum cure period for payment of interest	'	'	'	'	'	'	'	'	'	'30 days	'
Minimum percentage of debt holders required to declare debt immediately due and payable	'	'	'	'	'	'	'	'	'	25.00%	'
Number of plans of reorganization that are acceptable to the bankruptcy court	'	'	'	'	'	'	'	'	'	1	'
Preferred stock outstanding purchased (in shares)	'	'	'	'	'	182,065	182,065	182,065	'	'	'
Ownership interest in equity (as a percent)	'	'	97.90%	'	'	'	'	'	'	'	'
Redemption price of preferred stock (in dollars per share)	'	'	'	'	'	'	'	'	$100	'	'
Term of debt instrument	'	'	'	'120 days	'	'	'	'	'	'	'
Number of shares issued (in shares)	'	'	'	'	393,550,372	'	'	'	'	'	'

SIGNIFICANT_ACCOUNTING_POLICIE3

SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012
	bbl		bbl
	Mcf		Mcf
Oil and Gas Properties	'	'	'	'	'	'	'
Internal costs capitalized during the period	$0	$0	$8,807	$11,520	'	'	'
Net income from marketing activities attributable to the outside working interest owners recorded as an adjustment to proved properties	60,402	37,896	175,535	69,700	'	'	'
Minimum percentage of sale of proved reserves related to a single full cost pool for significant alteration	'	'	25.00%	'	'	'	'
Costs of unproved properties withheld from depletion base	31,717,970	'	31,717,970	'	'	'	'
Costs of acreage reclassified from unproved properties into proved properties	'	'	796,000	'	'	'	'
Relative volumes of oil and gas production and reserves converted at energy equivalent rate	6	'	6	'	'	'	'
Ceiling limitation based on average, first-day-of-the-month oil and gas prices	'	'	'	'	80.35	81.16	2.94
Impairment expense related to the entity's oil and gas properties	0	1,016,000	0	9,071,000	'	'	'
Other oil and gas equipment	'	'	'	'	'	'	'
Facilities and Equipment	'	'	'	'	'	'	'
Net expense attributable to the outside working interest owners recorded as an adjustment to proved properties	$17,356	$22,359	$29,326	$14,551	'	'	'
Other oil and gas equipment | Minimum	'	'	'	'	'	'	'
Facilities and Equipment	'	'	'	'	'	'	'
Estimated useful life	'	'	'5 years	'	'	'	'
Other oil and gas equipment | Maximum	'	'	'	'	'	'	'
Facilities and Equipment	'	'	'	'	'	'	'
Estimated useful life	'	'	'10 years	'	'	'	'

SIGNIFICANT_ACCOUNTING_POLICIE4

SIGNIFICANT ACCOUNTING POLICIES (Details 2) (USD $)	0 Months Ended		1 Months Ended	3 Months Ended		9 Months Ended
	Aug. 03, 2011	Jun. 15, 2011	Oct. 31, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
SIGNIFICANT ACCOUNTING POLICIES	'	'	'	'	'	'	'	'
Number of shares that can be purchased out of warrants issued	11,500,000	18,750,000	'	'	'	'	'	'
Term of warrants	'60 months	'60 months	'	'	'	'	'	'
Initial exercise price of warrants (in dollars per share)	$0.35	$0.35	'	'	'	'	'	'
Minimum percentage of initial exercise price of warrant to be exceeded by average daily volume weighted-average price of share to require holder to exercise the warrant	'	'	'	'	'	200.00%	'	'
Derivative instruments	'	'	'	$71,000	'	$71,000	'	$907,500
Inventory	'	'	'	'	'	'	'	'
Impairment expense related to decrease in market value of inventory	'	'	'	789,143	'	1,019,643	'	'
Inventory Held for Sale	'	'	'	'	'	'	'	'
Sale price	'	'	323,500	'	'	'	'	'
Selling expenses	'	'	16,175	'	'	'	'	'
Information reconciling the value of the asset retirement obligation	'	'	'	'	'	'	'	'
Balance beginning of period	'	'	876,201	856,308	779,197	815,660	1,226,796	'
Liabilities incurred	'	'	'	'	'	2,338	'	'
Property dispositions	'	'	'	'	'	'	-493,178	'
Accretion expense	'	'	'	19,893	18,019	58,203	63,598	'
Balance end of period	'	'	'	$876,201	$797,216	$876,201	$797,216	'
Series C Convertible Preferred stock	'	'	'	'	'	'	'	'
Computation of Net Income (Loss) Per Share	'	'	'	'	'	'	'	'
Par value of preferred stock (in dollars per share)	'	'	'	$0.00	'	$0.00	'	$0.00

SIGNIFICANT_ACCOUNTING_POLICIE5

SIGNIFICANT ACCOUNTING POLICIES (Details 3)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
2015 Notes	'	'	'	'
Shares excluded from the computation of diluted earnings (loss) per common share	'	'	'	'
Anti-dilutive shares	75,280,000	75,280,000	75,280,000	75,280,000
Preferred Stock	'	'	'	'
Shares excluded from the computation of diluted earnings (loss) per common share	'	'	'	'
Anti-dilutive shares	30,344,173	30,344,173	30,344,173	30,344,173
Common stock options	'	'	'	'
Shares excluded from the computation of diluted earnings (loss) per common share	'	'	'	'
Anti-dilutive shares	6,217,647	9,815,468	6,217,647	9,815,468
Warrants	'	'	'	'
Shares excluded from the computation of diluted earnings (loss) per common share	'	'	'	'
Anti-dilutive shares	30,250,000	30,250,000	30,250,000	30,250,000
Unvested restricted common stock	'	'	'	'
Shares excluded from the computation of diluted earnings (loss) per common share	'	'	'	'
Anti-dilutive shares	204,000	425,500	204,000	425,500

RESTRUCTURING_TRANSACTIONS_Det

RESTRUCTURING TRANSACTIONS (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Oct. 18, 2013

Oct. 18, 2013

Oct. 18, 2013

Oct. 18, 2013

Oct. 17, 2013

Oct. 17, 2013

Oct. 17, 2013

Oct. 18, 2013

Oct. 18, 2013

Oct. 18, 2013

Oct. 18, 2013

Series C Stock

Series C Stock

2015 Notes

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Note Purchase Agreements

Note Purchase Agreements

Note Purchase Agreements

Credit Agreement

Credit Agreement

Securities Purchase Agreement

Securities Purchase Agreement

item

Markham and Orogen ('Purchasers")

Markham and Orogen ('Purchasers")

Markham and Orogen ('Purchasers")

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Subsequent event

Credit Facility

Common Stock

Series D Stock

Markham and Orogen ('Purchasers")

Markham and Orogen ('Purchasers")

Markham and Orogen ('Purchasers")

Markham and Orogen ('Purchasers")

Markham and Orogen ('Purchasers")

Markham and Orogen ('Purchasers")

Markham and Orogen ('Purchasers")

Credit Facility

Series C Stock

2015 Notes

Credit Facility

Common Stock

Common Stock

Series D Stock

Credit Facility

Restructuring transaction

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument carrying amount purchased

'

'

'

'

'

$45,168,000

'

'

'

'

'

'

$45,168,000

'

'

'

'

Accrued interest purchased

'

'

'

'

'

'

'

'

'

'

'

'

2,495,022

'

'

'

'

Percentage of issued and outstanding debt purchased

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

Preferred stock outstanding purchased (in shares)

'

'

'

182,065

182,065

'

'

'

'

'

'

182,065

'

'

'

'

'

Percentage of issued and outstanding preferred stock purchased

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

Common stock purchased (in shares)

169,658,280

169,749,981

'

'

'

'

'

'

'

'

2,743,818

'

'

'

'

'

'

Par value of common stock (in dollars per share)

$0.00

$0.00

'

'

'

'

'

'

'

'

$0.00

'

'

'

'

'

'

Number of shares issued (in shares)

'

'

'

'

'

'

'

'

250,000

250,000

'

'

'

'

250,000

393,550,372

50,000

Maximum borrowing capacity

'

'

'

'

'

'

'

$5,000,000

'

'

'

'

'

$5,000,000

'

'

'

Common shares issuable upon conversion of each share

'

'

1,489,166

'

'

'

'

'

'

'

'

'

'

'

'

'

145,914.88

Common shares issuable upon conversion

'

'

'

'

'

'

'

'

'

7,295,744,128

'

'

'

'

'

'

7,295,744,128

Preferred stock dividend (as a percent)

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

10.00%

Stated value of stock (in dollars per share)

'

'

'

$0.00

$0.00

'

'

'

'

'

'

'

'

'

'

'

$100

Period after the original date of issuance of stock the Purchasers can require the company to redeem the outstanding shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year 1 day

Redemption price of preferred stock (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$100

Number of members in board of directors after closing of restructuring agreements

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

CREDIT_FACILITY_Details

CREDIT FACILITY (Details) (Credit Facility, Markham and Orogen ('Purchasers"), Subsequent event, USD $)	0 Months Ended
	Oct. 18, 2013
Credit Facility	'
Fixed annual interest rate (as a percent)	8.00%
Amount borrowed	2,500,000
Remaining borrowing capacity	2,500,000
Common Stock	'
Credit Facility	'
Number of shares of common stock issued for extending credit facility	250,000

CONVERTIBLE_SENIOR_NOTES_Detai

CONVERTIBLE SENIOR NOTES (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Jun. 25, 2010	Oct. 17, 2013
			2015 Notes	2015 Notes	2015 Notes	2015 Notes
						Subsequent event
Convertible senior notes	'	'	'	'	'	'
Interest rate (as a percent)	'	'	'	'	5.50%	'
Semi-annual interest payment	'	'	$1,242,120	'	'	'
Interest rate on overdue interest payments (as a percent)	'	'	7.50%	'	'	'
Effective interest rate for accretion of debt discount to interest expense (as a percent)	'	'	26.30%	'	'	'
Accumulated principal and interest due including default interest	'	'	'	'	'	47,795,256
Unamortized discount	$14,731,680	$18,530,539	$14,731,680	$18,530,539	'	'

ASSET_SALES_Details

ASSET SALES (Details) (USD $)	3 Months Ended		9 Months Ended				0 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2012	Sep. 30, 2012	Mar. 22, 2012	Mar. 22, 2012	Mar. 22, 2012
					Uinta Basin	Uinta Basin	Uinta Basin	Uinta Basin producing oil and gas assets	Uinta Basin non-producing oil and gas assets
						Pro forma	Wapiti	Wapiti	Wapiti
							item
Asset sales	'	'	'	'	'	'	'	'	'
Percentage of undivided interest in assets sold or transferred	'	'	'	'	'	'	'	50.00%	50.00%
Consideration in cash	'	'	'	'	'	'	'	$18,000,000	'
Consideration in the form of promissory note	'	'	'	'	'	'	'	1,190,000	'
Amount committed to fund drilling and completion costs associated with the development and exploration of the subject assets	'	'	'	'	'	'	'	'	30,000,000
Amount of funding commitment that will be paid on behalf of the entity	'	'	'	'	'	'	15,000,000	'	'
Amount of additional drilling and completion costs	'	'	'	'	'	'	7,500,000	'	'
Total program amount	'	'	'	'	'	'	37,500,000	'	'
Amount expended by counterparty on drilling and completion costs related to the program wells after which the Operating Committee can vote to cease the drilling program	'	'	'	'	'	'	10,000,000	'	'
Net revenue interest allocated to company until Wapiti cumulative proceeds equals costs paid (as a percent)	'	'	'	'	'	'	32.50%	'	'
Net revenue interest allocated to Wapiti until Wapiti cumulative proceeds equals costs paid (as a percent)	'	'	'	'	'	'	67.50%	'	'
Drilling and completion costs for each well borne by the company during the drilling term (as a percent)	'	'	'	'	'	'	20.00%	'	'
Drilling and completion costs for each well borne by Wapiti during the drilling term (as a percent)	'	'	'	'	'	'	80.00%	'	'
Drilling and completion costs borne by company after the drilling term but before Payout (as a percent)	'	'	'	'	'	'	32.50%	'	'
Drilling and completion costs borne by Wapiti after the drilling term but before Payout (as a percent)	'	'	'	'	'	'	67.50%	'	'
All other working interest costs borne by company before Payout (as a percent)	'	'	'	'	'	'	32.50%	'	'
All other working interest costs borne by Wapiti before Payout (as a percent)	'	'	'	'	'	'	67.50%	'	'
Number of members in Operating Committee	'	'	'	'	'	'	2	'	'
Voting percentage of members of each party in Operating Committee	'	'	'	'	'	'	50.00%	'	'
Period from end of drilling term after which Development Agreement may be terminated	'	'	'	'	'	'	'6 months	'	'
Period of advance notice upon which the Development Agreement may be terminated by either party	'	'	'	'	'	'	'6 months	'	'
Proceeds from transaction used to repay borrowings under prior revolving credit facility	'	'	'	'	'	'	10,500,000	'	'
Gain on sale of the proved property	'	'	'	'	'	'	2,567,574	'	'
Revenue	2,500,325	1,808,625	7,232,826	6,592,765	1,206,145	5,386,620	'	'	'
Net loss	($3,108,923)	($3,170,910)	($7,807,371)	($13,380,613)	($2,390,235)	($10,990,378)	'	'	'
Net (loss) income per share - basic and diluted (in dollars per share)	($0.02)	($0.02)	($0.05)	($0.08)	($0.01)	($0.07)	'	'	'

DERIVATIVES_Details

DERIVATIVES (Details) (USD $)	0 Months Ended				1 Months Ended		0 Months Ended
	Aug. 03, 2011	Jun. 15, 2011	Sep. 30, 2013	Dec. 31, 2012	Jun. 30, 2012	Sep. 30, 2012	Aug. 03, 2011	Jun. 15, 2011
			Warrant derivatives	Warrant derivatives	Not designated as an accounting hedge	Not designated as an accounting hedge	Not designated as an accounting hedge	Not designated as an accounting hedge
					Costless collar	Costless collar	Warrant derivatives	Warrant derivatives
						item
Derivatives	'	'	'	'	'	'	'	'
Number of derivative instruments held	'	'	'	'	'	1	'	'
Proceeds from monetization of derivative contract	'	'	'	'	$677,868	'	'	'
Warrants issued (in shares)	11,500,000	18,750,000	'	'	'	'	11,500,000	18,750,000
Initial exercise price of warrants (in dollars per share)	$0.35	$0.35	$0.35	$0.35	'	'	$0.35	$0.35
Term of warrants	'60 months	'60 months	'	'	'	'	'60 months	'60 months

DERIVATIVES_Details_2

DERIVATIVES (Details 2) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Fair value of derivatives recorded in consolidated balance sheets	'	'
Fair value of derivative liabilities, noncurrent	$71,000	$907,500
Not designated as an accounting hedge | Warrant derivatives | Noncurrent liabilities	'	'
Fair value of derivatives recorded in consolidated balance sheets	'	'
Fair value of derivative liabilities, noncurrent	$71,000	$907,500

DERIVATIVES_Details_3

DERIVATIVES (Details 3) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Realized and unrealized gains and losses related to derivative instruments	'	'	'	'
Total realized and unrealized gains recorded	$104,000	$720,000	$836,500	$2,508,090
Commodity instruments	'	'	'	'
Realized and unrealized gains and losses related to derivative instruments	'	'	'	'
Realized gains on commodity instruments	'	'	'	1,255,948
Change in fair value	'	'	'	-865,358
Warrant derivatives	'	'	'	'
Realized and unrealized gains and losses related to derivative instruments	'	'	'	'
Change in fair value	$104,000	$720,000	$836,500	$2,117,500

GAS_PROCESSING_AGREEMENTS_Deta

GAS PROCESSING AGREEMENTS (Details) (USD $)	9 Months Ended	0 Months Ended
	Sep. 30, 2013	Sep. 21, 2011	Sep. 21, 2011	Mar. 22, 2012	Sep. 21, 2011
	Mcf	Chipeta Processing Agreement	Chipeta Processing Agreement	Amended and Restated Monarch Agreement	QPC Transportation Agreement
			Minimum
Gas processing agreements	'	'	'	'	'
Primary term of agreement	'	'10 years	'	'	'
Capacity of cryogenic processing facility to be built by Chipeta (in Mcf/d)	'	300,000	'	'	'
Extended primary term of agreement unless terminated by either party	'	'1 year	'	'	'
Notice period for termination of agreement	'	'180 days	'	'	'
Committed monthly percentage of capacity in Chipeta processing plant reserved for cryogenic processing	'	'	90.00%	'	'
Minimum commitment	'	25,000	'	25,000	25,000
Initial volumes of natural gas production related to which the right to process is released and waived by the counterparty (in MMBtu/d)	'	'	'	50,000	'
Quantity of possible future aggregate minimum production shortfall due to no future drilling and constant gas prices (in Mcf)	41,000	'	'	'	'
Possible minimum production shortfall due to no future drilling and constant gas prices on an undiscounted gross basis	$28,000,000	'	'	'	'
Shortfall commitment accrual	$373,000	'	'	'	'

STOCKBASED_COMPENSATION_Detail

STOCK-BASED COMPENSATION (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
STOCK-BASED COMPENSATION	'	'	'	'
Assumption for forfeitures for employee awards based on historical forfeiture experience (in shares)	0	'	0	'
Stock-based compensation expense recognized	'	'	'	'
Employee compensation	$39,399	$79,182	$139,655	$216,053
Consultant compensation	'	-191	'	-213
Total stock-based compensation	39,399	78,991	139,655	215,840
Less: consultant compensation expense capitalized as proved property	'	-95	'	-106
Stock-based compensation expense	$39,399	$79,086	$139,655	$215,947

STOCKBASED_COMPENSATION_Detail1

STOCK-BASED COMPENSATION (Details 2) (USD $)	9 Months Ended
	Sep. 30, 2013
Additional disclosure	'
Fair value of common stock (in dollars per share)	$0.02
Stock Options	'
Stock Options	'
Outstanding at the beginning of the period (in shares)	9,506,943
Forfeited (in shares)	-461,474
Cancelled (in shares)	-2,827,822
Outstanding at the end of the period (in shares)	6,217,647
Exercisable (in shares)	5,478,402
Weighted-Average Exercise Price	'
Outstanding at the beginning of the period (in dollars per share)	$1.04
Forfeited (in dollars per share)	$0.12
Cancelled (in dollars per share)	$0.59
Outstanding at the end of the period (in dollars per share)	$1.09
Exercisable (in dollars per share)	$1.21
Additional disclosure	'
Outstanding options weighted average remaining contractual life	'2 years
Vested options weighted average remaining contractual life	'2 years
Period over which unrecognized compensation cost is expected to be recognized	'2 years
Total unrecognized compensation cost related to non-vested options (in dollars)	$79,470

STOCKBASED_COMPENSATION_Detail2

STOCK-BASED COMPENSATION (Details 3) (Restricted Stock, USD $)	9 Months Ended
	Sep. 30, 2013
Restricted Stock	'
Restricted stock activity	'
Outstanding at the beginning of the period (in shares)	336,000
Vested (in shares)	-48,095
Forfeited (in shares)	-92,000
Outstanding at the end of the period (in shares)	195,905
Weighted-Average Grant Date Fair Value	'
Outstanding at the beginning of the period (in dollars per share)	$0.22
Vested (in dollars per share)	$0.18
Forfeited (in dollars per share)	$0.22
Outstanding at the end of the period (in dollars per share)	$0.24
Total unrecognized compensation cost related to non-vested stock (in dollars)	$25,530
Period over which unrecognized compensation cost is expected to be recognized	'2 years

STOCKBASED_COMPENSATION_Detail3

STOCK-BASED COMPENSATION (Details 4) (SARs, USD $)	0 Months Ended
	Feb. 28, 2012	Oct. 05, 2011	Dec. 31, 2012	Dec. 31, 2011
SARs	'	'	'	'
Stock-based compensation	'	'	'	'
Stock appreciation rights granted to non-employee directors (in shares)	1,000,000	500,000	'	'
Amount recorded as a liability	'	'	$0	$10,924
Number of shares of common stock used to calculate fair market value for a lump sum payment	1	1	'	'
An amount greater than the closing price of a share of common stock on the date of grant used to calculate lump sum cash payment (in dollars per share)	$0.30	$0.25	'	'
Amount used to calculate lump sum cash payment	2	'	'	'
Appreciation Amount	0	0	'	'
Cash payment made upon exercise	$0	$0	'	'

FAIR_VALUE_MEASUREMENTS_Detail

FAIR VALUE MEASUREMENTS (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Liabilities:	'	'
Warrant derivatives	$71,000	$907,500
Recurring | Level 3	'	'
Liabilities:	'	'
Warrant derivatives	71,000	907,500
Recurring | Total	'	'
Liabilities:	'	'
Warrant derivatives	$71,000	$907,500

FAIR_VALUE_MEASUREMENTS_Detail1

FAIR VALUE MEASUREMENTS (Details 2) (USD $)	Sep. 30, 2013	Aug. 03, 2011	Jun. 15, 2011	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013
				Warrant derivatives	Warrant derivatives	Warrant derivatives	Warrant derivatives
						Minimum	Maximum
Derivatives	'	'	'	'	'	'	'
Increase in derivative liability due to increase in trading price of common stock	'	'	'	$1,400,000	'	'	'
Increase in trading price of common stock (in dollars per share)	'	'	'	$0.10	'	'	'
Increase or decrease in volatility rate (as a percent)	'	'	'	10.00%	'	'	'
Increase in derivative liability by increase in volatility rate	'	'	'	33,000	'	'	'
Decrease in derivative liability by decrease in volatility rate	'	'	'	$27,000	'	'	'
Summary of Warrants	'	'	'	'	'	'	'
Warrants outstanding at the beginning of the period (in shares)	'	'	'	30,250,000	'	'	'
Warrants outstanding at the end of the period (in shares)	'	'	'	30,250,000	30,250,000	'	'
Warrants outstanding at the beginning of the period (in dollars per share)	'	$0.35	$0.35	$0.35	'	'	'
Warrants outstanding at the end of the period (in dollars per share)	'	$0.35	$0.35	$0.35	$0.35	'	'
Warrants outstanding at the beginning of the period	'	'	'	'33 months	'40 months	'	'
Warrants outstanding at the end of the period	'	'	'	'33 months	'40 months	'	'
Significant assumptions used in the valuation of the warrant derivative liability	'	'	'	'	'	'	'
Stock price	$0.02	'	'	$0.02	'	'	'
Volatility (as a percent)	'	'	'	105.00%	'	'	'
Remaining Term of Warrants	'	'	'	'	'	'32 months	'34 months
Risk-free interest rate (as a percent)	'	'	'	'	'	0.50%	1.00%

FAIR_VALUE_MEASUREMENTS_Detail2

FAIR VALUE MEASUREMENTS (Details 3) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Dec. 31, 2012
					2015 Notes	2015 Notes
Reconciliation of changes in fair value of financial liabilities	'	'	'	'	'	'
Balance as of beginning of period	($175,000)	($2,837,500)	($907,500)	($4,235,000)	'	'
Total gains (realized or unrealized):	'	'	'	'	'	'
Included in earnings	104,000	720,000	836,500	2,117,500	'	'
Balance as of end of period	-71,000	-2,117,500	-71,000	-2,117,500	'	'
Change in unrealized gains included in earnings relating to instruments still held at the end of the period	104,000	2,117,500	-71,000	2,117,500	'	'
Estimated fair value of the 2015 Notes	'	'	'	'	$14,125,000	$28,833,000

STATEMENTS_OF_CASH_FLOWS_Detai

STATEMENTS OF CASH FLOWS (Details) (USD $)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
STATEMENTS OF CASH FLOWS	'	'
Additions to oil and gas properties included in accounts payable	$518,000	$50,000
Settlement of liability with prepaid deposit	'	121,000
Number of shares of preferred stock converted into common stock	'	8,935
Number of shares of common stock issued	'	1,489,166
Cash paid for interest	0	1,353,761
Cash paid for income taxes	$0	$0

LEGAL_PROCEEDINGS_Details

LEGAL PROCEEDINGS (Details) (USD $)	1 Months Ended	0 Months Ended
	Feb. 28, 2013	Apr. 02, 2012	Oct. 03, 2011
	Claim of working interest owners	Claim of working interest owners	Clean Water Act Compliance Order Matter
	Hat Creek	Hat Creek	item
	item	Minimum
Legal proceedings	'	'	'
Number of occasions when Clean Water Act was violated	'	'	2
Number of working interest owners with whom claims were settled	1	'	'
Damages sought	'	$200,000	'
Settlement of claim	307,000	'	'
Cash payment for settlement of claim	160,000	'	'
Forgiveness amount for settlement of claim	$147,000	'	'