Contango Oil & Gas (MCF) 10-K/A 28 Mar 14 2013 FY Annual report (amended) Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Mar. 27, 2014	Jun. 30, 2013
Document And Entity Information [Abstract]	'	'	'
Document Type	'10-K	'	'
Amendment Flag	'true	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Entity Registrant Name	'CONTANGO OIL & GAS CO	'	'
Entity Central Index Key	'0001071993	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Accelerated Filer	'	'
Entity Common Stock, Shares Outstanding	'	19,367,411	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Public Float	'	'	$455
Amendment Description	'On October 1, 2013, Contango Oil & Gas Company (“Contango”, "we" or the “Company”) completed a merger with Crimson Exploration Inc. (“Crimson”) under an all-stock transaction pursuant to which Crimson became a wholly-owned subsidiary of the Company (the “Merger”). The Merger is described in greater detail within this Annual Report on Form 10-K/A.In connection with the closing of the Merger, our Board of Directors approved a change of our fiscal year end from June 30 to December 31, commencing with the twelve-month period beginning on January 1, 2014. As a result of this change, on March 3, 2014 we filed a Transition Report on Form 10-K for the six-month period ended December 31, 2013 (the “Original Filing”). This Annual Report on Form 10-K/A is filed to present a recast of historical financial information for the three-year period ended December 31, 2013. Financial statements as of December 31, 2013 and 2012 and for the three years ended December 31, 2013 include consolidated results of operations of both Contango and Crimson for the period from the closing of the Merger on October 1, 2013 to December 31, 2013 and consolidated financial statements of Contango only for all other periods.This Annual Report on Form 10-K/A should be read in conjunction with the Original Filing. This Annual Report on Form 10-K/A does not generally reflect events that occurred after the filing date of the Original Filing although certain provisions have been updated or otherwise modified where we believe appropriate to give proper context to the results for the periods included herein. In addition, the following provisions of the Original Filing have also been amended:•Cover page. We have updated the shares of common stock outstanding as of March 27, 2014.•Part II. Item 5. General. We have updated the shares of common stock outstanding and issued as of March 27, 2014.•Part II. Item 7. Capital Resources and Liquidity. We have updated the amount of debt outstanding as of March 27, 2014.•Part IV. Item 15(b). Exhibits. We have amended the exhibits to reference the current version of the Company’s Bylaws. •We have updated the Annual Report to reference the resignation of Mr. Brad Juneau from the board of directors.Other than as described in this explanatory note, this Annual Report on Form 10-K/A does not modify or update the disclosures in the Original Filing.	'	'

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
CURRENT ASSETS:	'	'
Cash and cash equivalents	$0	$79,487
Accounts receivable, net	60,613	48,850
Prepaid expenses	2,031	2,479
Inventory	2,147	2,757
Current deferred tax asset	1,326	0
Total current assets	66,117	133,573
Natural gas and oil properties, successful efforts method of accounting:	'	'
Proved properties	1,001,361	554,967
Unproved properties	49,443	22,661
Other property and equipment	900	227
Accumulated depreciation, depletion and amortization	-260,681	-197,874
Total property, plant and equipment, net	791,023	379,981
NON-CURRENT ASSETS:	'	'
Investment in affiliates	50,901	47,327
Other	2,263	225
Total non-current assets	53,164	47,552
TOTAL ASSETS	910,304	561,106
CURRENT LIABILITIES:	'	'
Accounts payable and accrued liabilities	96,833	32,672
Current derivative liability	1,131	0
Current asset retirement obligation	1,315	0
Total current liabilities	99,279	32,672
NON-CURRENT LIABILITIES:	'	'
Long-term debt	90,000	0
Deferred tax liability	105,956	115,858
Asset retirement obligation	22,019	8,647
Total non-current liabilities	217,975	124,505
Total liabilities	317,254	157,177
COMMITMENTS AND CONTINGENCIES (NOTE 14)	'	'
SHAREHOLDERS’ EQUITY:	'	'
Common stock, $0.04 par value, 50 million shares authorized, 24,356,236 shares issued and 19,363,711 shares outstanding at December 31, 2013, 20,135,107 shares issued and 15,194,952 shares outstanding at December 31, 2012	962	805
Additional paid-in capital	228,644	79,025
Treasury stock at cost (4,992,525 shares at December 31, 2013 and 4,940,155 shares at December 31, 2012)	-119,180	-117,163
Retained earnings	482,624	441,262
Total shareholders’ equity	593,050	403,929
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$910,304	$561,106

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Statement of Financial Position [Abstract]	'	'
Common stock, par value (in dollars per share)	$0.04	$0.04
Common stock, shares authorized	50,000,000	50,000,000
Common stock, shares issued	24,356,236	20,135,107
Common stock, shares outstanding	19,363,711	15,194,952
Treasury stock, shares	4,992,525	4,940,155

Consolidated_Statements_Of_Ope

Consolidated Statements Of Operations (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
REVENUES:	'	'	'
Crude oil and condensate sales	$59,608	$56,237	$67,594
Natural gas sales	79,289	60,691	94,666
Natural gas liquids sales	25,224	28,940	36,238
Total revenues	164,121	145,868	198,498
EXPENSES:	'	'	'
Lease operating expenses	32,091	20,118	23,745
Production and ad valorem taxes	4,693	3,602	4,540
Exploration expenses	1,811	51,903	0
Depreciation, depletion and amortization	65,529	44,896	48,988
Impairment of oil and gas properties	776	14,079	1,680
General and administrative expense	26,512	11,265	10,614
Total expenses	131,412	145,863	89,567
OTHER INCOME (EXPENSE):	'	'	'
Gain from investment in affiliates (net of income taxes)	2,310	60	0
Gain (loss) from sale of assets and return on investments	31,785	-463	4
Interest income/(expense)	-1,171	96	-205
Net loss on derivatives	-1,132	0	0
Total other income/(expense)	31,792	-307	-201
NET INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	64,501	-302	108,730
Provision for income taxes	-23,139	-605	-38,821
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	41,362	-907	69,909
DISCONTINUED OPERATIONS, NET OF INCOME TAX (NOTE 18)	0	-29	-1,204
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	$41,362	($936)	$68,705
Basic	'	'	'
Continuing operations (in dollars per share)	$2.56	($0.06)	$4.49
Discontinued operations (in dollars per share)	$0	$0	($0.08)
Total (in dollars per share)	$2.56	($0.06)	$4.41
Diluted	'	'	'
Continuing operations (in dollars per share)	$2.56	($0.06)	$4.49
Discontinued operations (in dollars per share)	$0	$0	($0.08)
Total (in dollars per share)	$2.56	($0.06)	$4.41
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:	'	'	'
Basic (in shares)	16,156	15,295	15,582
Diluted (in shares)	16,158	15,295	15,585

Consolidated_Statement_Of_Shar

Consolidated Statement Of Shareholders' Equity (USD $)	Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Treasury Stock [Member]	Retained Earnings [Member]
In Thousands, except Share data, unless otherwise specified
Balance at Dec. 31, 2010	$392,298	$805	$79,279	($91,789)	$404,003
Balance, shares at Dec. 31, 2010	'	15,665,000	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'
Treasury shares at cost	-17,000	'	'	-17,000	'
Treasury shares at cost, shares	'	-308,000	'	'	'
Net income	68,705	'	'	'	68,705
Balance at Dec. 31, 2011	444,003	805	79,279	-108,789	472,708
Balance, shares at Dec. 31, 2011	'	15,357,000	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'
Tax benefit from exercise of stock options	-254	'	-254	'	'
Treasury shares at cost	-8,374	'	'	-8,374	'
Treasury shares at cost, shares	'	-162,000	'	'	'
Dividends	-30,510	'	'	'	-30,510
Net income	-936	'	'	'	-936
Balance at Dec. 31, 2012	403,929	805	79,025	-117,163	441,262
Balance, shares at Dec. 31, 2012	15,194,952	15,195,000	'	'	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'
Acquisition of Crimson	146,568	154	146,414	'	'
Acquisition of Crimson, shares	'	3,864,000	'	'	'
Exercise of stock options	29	3	26	'	'
Exercise of stock options, shares	'	1,000	'	'	'
Treasury shares at cost	-2,017	'	'	-2,017	'
Treasury shares at cost, shares	-2,400,000	-52,000	'	'	'
Stock-based compensation	3,179	'	3,179	'	'
Stock-based compensation, shares	'	356,000	'	'	'
Net income	41,362	'	'	'	41,362
Balance at Dec. 31, 2013	$593,050	$962	$228,644	($119,180)	$482,624
Balance, shares at Dec. 31, 2013	19,363,711	19,364,000	'	'	'

Consolidated_Statements_Of_Cas

Consolidated Statements Of Cash Flows (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES:	'	'	'
Income (loss) from continuing operations	$41,362,000	($907,000)	$69,909,000
Income (loss) from discontinued operations, net of taxes	0	-29,000	-1,204,000
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	41,362,000	-936,000	68,705,000
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'	'
Depreciation, depletion and amortization	65,529,000	44,896,000	52,398,000
Impairment of natural gas and oil properties	767,000	14,078,000	3,240,000
Exploration expenses	-9,000	51,379,000	-477,000
Deferred income taxes	13,159,000	-8,569,000	-6,382,000
Loss (gain) on sale of assets	-21,961,000	0	1,094,000
Loss (gain) from investment in affiliates	-3,554,000	-92,000	0
Stock-based compensation	3,180,000	-154,000	179,000
Tax benefit from exercise of stock options	0	-254,000	0
Unrealized loss on derivative instruments	1,410,000	0	0
Changes in operating assets and liabilities:	'	'	'
Decrease (increase) in accounts receivable and other	-6,285,000	19,894,000	-2,789,000
Decrease (increase) in inventory	610,000	-2,497,000	470,000
Decrease (increase) in prepaids and other receivables	30,000	-347,000	2,828,000
Increase (decrease) in accounts payable and advances from joint owners	-4,720,000	-10,918,000	583,000
Increase (decrease) in other accrued liabilities	3,569,000	-877,000	-958,000
Increase (decrease) in income taxes payable, net	11,778,000	-15,117,000	9,204,000
Other	172,000	-364,000	5,000
Net cash provided by operating activities	105,037,000	90,122,000	128,100,000
CASH FLOWS FROM INVESTING ACTIVITIES:	'	'	'
Natural gas and oil exploration and development	-62,208,000	-78,536,000	-40,229,000
Sale of oil and gas properties	20,000,000	0	38,671,000
Advance under note receivable	0	-500,000	-400,000
Repayment of note receivable	0	900,000	0
Investments in affiliates	-15,397,000	-54,765,000	-499,000
Distributions from affiliates	23,154,000	8,969,000	0
Additions to furniture and equipment	-344,000	-13,000	-101,000
Net cash used in investing activities	-34,795,000	-123,945,000	-2,558,000
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'	'
Borrowings under credit facility	180,394,000	0	0
Repayments under credit facility	-90,394,000	0	0
Payment of long-term debt	-235,373,000	0	0
Dividends	0	-30,510,000	0
Purchase of common stock	-2,017,000	-8,374,000	-17,000,000
Proceeds from exercise of stock options	31,000	0	0
Tax benefit from exercise/cancellation of stock options	0	254,000	0
Debt issuance costs	-2,370,000	0	-37,000
Net cash used in financing activities	-149,729,000	-38,630,000	-17,037,000
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	-79,487,000	-72,453,000	108,505,000
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	79,487,000	151,940,000	43,435,000
CASH AND CASH EQUIVALENTS, END OF PERIOD	$0	$79,487,000	$151,940,000

Organization_and_Business

Organization and Business	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization and Business	'
	Organization and Business
	Contango Oil & Gas Company (collectively with its subsidiaries, “Contango” or the “Company”) is a Houston, Texas based, independent natural gas and oil company. The Company’s business is to explore, develop, produce and acquire natural gas and oil properties in the shallow waters of the Gulf of Mexico ("GOM") and in the Gulf Coast region of the United States and Colorado.
	On October 1, 2013, the Company completed a merger with Crimson Exploration Inc. ("Crimson"), in an all-stock transaction pursuant to which Crimson became a wholly-owned subsidiary of Contango (the "Merger"). As a result of the Merger, each share of Crimson common stock was converted into the right to receive 0.08288 shares of common stock of Contango. As a result, we issued approximately 3.9 million shares of common stock in exchange for all of Crimson's outstanding capital stock, resulting in Crimson stockholders owning 20.3% of the post-Merger Contango. See Note 4 - "Merger with Crimson Exploration, Inc." for additional information.
	Contango has historically focused its operations offshore in the Gulf of Mexico ("GOM") in water-depths of less than 300 feet, but the Merger has given the Company access to lower risk, long life resource plays in Southeast Texas (the Woodbine oil and liquids rich play), South Texas (the Eagle Ford Shale and Buda oil and liquids rich plays), and East Texas (the James Lime liquids rich play and, under an improved natural gas price environment, the Haynesville/Mid-Bossier gas play). The Company believes these plays provide significant long-term growth potential from multiple formations.
	The Company intends to grow reserves and production by developing its existing producing property base, by exploiting its oil/liquids resource potential, by drilling in the GOM, and by pursuing opportunistic acquisitions in areas where the Company has current operations and specific operating expertise, as well as additional areas the Company identifies that they have significant exploration and/or operational upside. The Company has developed a significant inventory of high quality drilling opportunities on its existing property base that should provide multi-year reserve growth, and until improvement is seen in natural gas prices, we will concentrate drilling activity on further developing the oil and liquids-rich onshore assets in Southeast Texas and South Texas, complemented by some potentially high-impact offshore exploratory drilling. In 2014 specifically, the Company will focus on its inventory of crude oil and liquids-rich projects with a continuous rig targeting each of the Woodbine in Madison and Grimes counties, Texas, the Buda in Dimmit County, Texas, and the James Lime in San Augustine County, Texas. The Company also plans to drill a number of other wells testing new formations in existing areas and one to two exploratory wells in the shallow waters of the Gulf of Mexico. Contango has additional onshore investments in i) Alta Resources Investments, LLC, whose primary area of focus is the liquids-rich Kaybob Duvernay in Alberta, Canada, which was sold in August 2013; ii) Exaro Energy III LLC ("Exaro"), which is primarily focused on the development of proved natural gas reserves in the Jonah Field in Wyoming; and iii) the Tuscaloosa Marine Shale ("TMS"), where the Company owns approximately 29,000 net acres.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	Summary of Significant Accounting Policies
	Basis of Presentation
	The Company’s consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America and include the accounts of Contango Oil & Gas Company and its subsidiaries, after elimination of all material intercompany balances and transactions. All wholly-owned subsidiaries are consolidated. Oil and gas exploration and development affiliates which are not controlled by the Company, such as REX, are proportionately consolidated. Financial statements as of December 31, 2013 and 2012 and for the three years ended December 31, 2013 contained herein, include consolidated results of operations of both Contango Oil and Gas Company ("Contango") and Crimson for the period from the closing date of the Merger to December 31, 2013 and only consolidated financial statements of Contango for all other the periods presented herein.
	Financial statements as of December 31, 2013 and 2012 and for the three years ended December 31, 2013 include consolidated results of operations of both Contango and Crimson for the period from the closing of the Merger on October 1, 2013 to December 31, 2013 and consolidated financial statements of Contango only for all other periods.
	Change of Year-End
	On October 1, 2013 the Company's board of directors approved a change in fiscal year end from June 30 to December 31, commencing with the twelve-month period beginning on January 1, 2014. Unless otherwise noted, all references to "years" in this report refer to the twelve-month period which ends on December 31 of each year. As a result of this change, on March 3, 2014 we filed a Transition Report on Form 10-K for the six-month period ended December 31, 2013. This Annual Report on Form 10-K/A is filed to present a recast of historical financial information for the three-year period ending on December 31, 2013.
	Other Investments
	Contango’s 19.5% ownership of Moblize Inc. (“Moblize”) and 2.0% indirect ownership of Alta Energy Canada Partnership, LLC ("Alta") are accounted for using the cost method. Under the cost method, Contango records an investment at cost, and recognizes dividends or distributions received as income. Dividends received in excess of earnings subsequent to the date of investment are considered a return of investment and are recorded as reductions of cost of the investment. During the year ended December 31, 2013, the Company had a significant distribution from Alta in excess of its original investment. The gain in excess of the original investment is included in the Gain (loss) from sale of assets and return on investments line item in the Company's income statement and in the investing cash flows in the Company's Cash Flow Statement for the year ended December 31, 2013.
	The Company has two seats on the board of directors of Exaro and has significant influence, but not control, over the company. As a result, the Company's 37% ownership in Exaro is accounted for using the equity method. Under the equity method, the Company's proportionate share of Exaro's net income increases the balance of our investment in Exaro, while a net loss or payment of dividends decreases our investment. In our consolidated statement of operations, our proportionate share of Exaro's net income or loss is reported as a single line-item in Gain (loss) from investment in affiliates (net of income taxes).
	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America 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 periods. The most significant estimates include oil and gas revenues, income taxes, stock-based compensation, reserve estimates, impairment of natural gas and oil properties, valuation of derivatives, and accrued liabilities. Actual results could differ from those estimates.
	Revenue Recognition
	Revenues from the sale of natural gas and oil produced are recognized upon the passage of title, net of royalties. Revenues from natural gas production are recorded using the sales method. When sales volumes exceed the Company’s entitled share, production imbalance occurs. If production imbalance exceeds the Company’s share of the remaining estimated proved natural gas reserves for a given property, the Company records a liability. As of December 31, 2013, and 2012, the Company had no significant imbalances.
	Cash Equivalents
	Cash equivalents are considered to be highly liquid investment grade debt investments having an original maturity of 90 days or less. As of December 31, 2013, the Company had no cash and cash equivalents. Under the Company’s cash management system, checks issued but not presented to banks frequently result in book overdraft balances for accounting purposes and are classified in accounts payable in the consolidated balance sheets. At December 31, 2013, accounts payable included $5.9 million representing outstanding checks that had not been presented for payment net of cash balance in the bank as of December 31, 2013. There were no outstanding checks that had not been presented for payment included in accounts payable at December 31, 2012.
	Accounts Receivable
	The Company sells natural gas and crude oil to a limited number of customers. In addition, the Company participates with other parties in the operation of natural gas and crude oil wells. Substantially all of the Company’s accounts receivables are due from either purchasers of natural gas and crude oil or participants in natural gas and crude oil wells for which the Company serves as the operator. Generally, operators of natural gas and crude oil properties have the right to offset future revenues against unpaid charges related to operated wells.
	The allowance for doubtful accounts is an estimate of the losses in the Company’s accounts receivable. The Company periodically reviews the accounts receivable from customers for any collectability issues. An allowance for doubtful accounts is established based on reviews of individual customer accounts, recent loss experience, current economic conditions, and other pertinent factors. Amounts deemed uncollectible are charged to the allowance.
	Accounts receivable allowance for bad debt was $0.6 million and zero, as of December 31, 2013 and 2012, respectively. At December 31, 2013 and 2012 the carrying value of the Company’s accounts receivable approximated fair value.
	Oil and Gas Properties - Successful Efforts
	The Company follows the successful efforts method of accounting for its natural gas and oil activities. Under the successful efforts method, lease acquisition costs and all development costs are capitalized. Exploratory drilling costs are capitalized until the results are determined. If proved reserves are not discovered, the exploratory drilling costs are expensed. Other exploratory costs, such as seismic costs and other geological and geophysical expenses, are expensed as incurred. Depreciation, depletion and amortization is calculated on a field by field basis using the unit of production method, with lease acquisition costs amortized over total proved reserves and other capitalized costs amortized over proved developed reserves.
	Depreciation, depletion and amortization ("DD&A") of capitalized drilling and development costs of producing natural gas and crude oil properties, including related support equipment and facilities and net of salvage value, are computed using the unit-of-production method on a field basis based on total estimated proved developed natural gas and crude oil reserves. Amortization of producing leaseholds is based on the unit-of-production method using total estimated proved reserves. Upon sale or retirement of properties, the cost and related accumulated depreciation, depletion, and amortization are eliminated from the accounts and the resulting gain or loss, if any, is recognized. Unit-of-production rates are revised whenever there is an indication of a need, but at least annually. Revisions are accounted for prospectively as changes in accounting estimates.
	Other property and equipment are depreciated using the straight-line method over their estimated useful lives which range between three and 13 years.
	Impairment of Oil and Gas Properties
	When circumstances indicate that proved properties may be impaired, the Company compares expected undiscounted future cash flows on a field by field basis to the unamortized capitalized cost of the asset. If the estimated future undiscounted cash flows, based on the Company’s estimate of future reserves, natural gas and oil prices and operating costs and anticipated production levels from oil and natural gas reserves, are lower than the unamortized capitalized cost, then the capitalized cost is reduced to its fair value. No impairment of proved properties was recognized during the years ended December 31, 2013 or 2011. For the year ended December 31, 2012, the Company recorded an impairment expense of approximately $14.1 million related to proved properties. Of this amount, approximately $12.0 million related to our Ship Shoal 263 well and $2.1 million related to the Eugene Island 24 platform and other properties. Despite the write-down of Ship Shoal 263, this well reached payout during the year ended December 31, 2012.
	Unproved properties are reviewed quarterly to determine if there has been impairment of the carrying value, and any such impairment is charged to expense in the period. The Company did not recognize any impairment of unproved properties for the year ended December 31, 2012. For the year ended December 31, 2013, we recorded an impairment expense on unproved properties of $0.6 million related to leasehold costs on our Ship Shoal 83 prospect which we relinquished in August 2013, and $0.2 million related to leasehold costs on our Brazos Area 543 prospect. For the year ended December 31, 2011, we recorded impairment expense on unproved properties of approximately $1.7 million, related to the relinquishment of 14 unproved lease blocks owned by Republic Exploration, LLC ("REX") and Contango.
	Asset Retirement Obligations
	ASC 410, Asset Retirement and Environmental Obligations (ASC 410) requires that the fair value of an asset retirement cost, and corresponding liability, should be recorded as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method. The Company records asset retirement obligations to reflect the Company's legal obligations related to future plugging and abandonment of its oil and natural gas wells, platforms and associated pipelines and equipment. The Company estimates the expected cash flows associated with the obligation and discounts the amounts using a credit-adjusted, risk-free interest rate. At least annually, the Company reassesses the obligation to determine whether a change in the estimated obligation is necessary. The Company evaluates whether there are indicators that suggest the estimated cash flows underlying the obligation have materially changed. Should these indicators suggest the estimated obligation may have materially changed on an interim basis (quarterly), the Company will accordingly update its assessment. Additional retirement obligations increase the liability associated with new oil and natural gas wells, platforms, and associated pipelines and equipment as these obligations are incurred. The liability is accreted to its present value each period and the capitalized cost is depleted over the useful life of the related asset. The accretion expense is included in depreciation, depletion and amortization expense.
	The estimated liability is based on historical experience in plugging and abandoning wells. The estimated remaining lives of the wells is based on reserve life estimates and federal and state regulatory requirements. The liability is discounted using an assumed credit-adjusted risk-free rate.
	Revisions to the liability could occur due to changes in estimates of plugging and abandonment costs, changes in the risk-free rate or changes in the remaining lives of the wells, or if federal or state regulators enact new plugging and abandonment requirements. At the time of abandonment, the Company recognizes a gain or loss on abandonment to the extent that actual costs do not equal the estimated costs. This gain or loss on abandonment is included in impairment and abandonment of oil and gas properties expense. See Note 12 - "Asset Retirement Obligations" for additional information.
	Income Taxes
	The Company follows the liability method of accounting for income taxes under which deferred tax assets and liabilities are recognized for the future tax consequences of (i) temporary differences between the tax basis of assets and liabilities and their reported amounts in the financial statements and (ii) operating loss and tax credit carryforwards for tax purposes. Deferred tax assets are reduced by a valuation allowance when, based upon management’s estimates, it is more likely than not that a portion of the deferred tax assets will not be realized in a future period. The Company reviews its tax positions quarterly for tax uncertainties. The Company did not have significant uncertain tax positions as of December 31, 2013. The amount of unrecognized tax benefits did not materially change from December 31, 2012. The amount of unrecognized tax benefits may change in the next twelve months; however, we do not expect the change to have a significant impact on our financial position or results of operations. The Company includes interest and penalties in interest income and general and administrative expenses, respectively, in its statement of operations.
	The Company files income tax returns in the United States and various state jurisdictions. The Company’s federal tax returns for 2009 – 2013, and state tax returns for 2008 - 2013, remain open for examination by the taxing authorities in the respective jurisdictions where those returns were filed.
	Concentration of Credit Risk
	Substantially all of the Company’s accounts receivable result from natural gas and oil sales or joint interest billings to a limited number of third parties in the natural gas and oil industry. This concentration of customers and joint interest owners may impact the Company’s overall credit risk in that these entities may be similarly affected by changes in economic and other conditions. See Note 3 - "Concentration of Credit Risk" for additional information.
	Debt Issuance Costs
	Debt issuance costs incurred are capitalized and subsequently amortized over the term of the related debt. During the year ended December 31, 2013 the Company incurred $2.2 million of debt issuance costs in relation to the new RBC credit facility entered into in conjunction with the Merger with Crimson. The debt issuance costs will be amortized over the original four year term of the credit line with amortization expense included in Depreciation, Depletion and Amortization line item in the Company's income statement for the year ended December 31, 2013.
	Stock-Based Compensation
	The Company applies the fair value based method to account for stock based compensation. Under this method, compensation cost is measured at the grant date based on the fair value of the award and is recognized over the award vesting period. The Company classifies the benefits of tax deductions in excess of the compensation cost recognized for the options (excess tax benefit) as financing cash flows. The fair value of each award is estimated as of the date of grant using the Black-Scholes option-pricing model.
	Inventory
	Inventory primarily consists of casing and tubing which will be used for drilling or completion of wells.  Also, included in inventory are items for the repair and maintenance of equipment used on wells and facilities that the Company operates.  Inventory is recorded at the lower of cost or market using specific identification method.
	Derivative Instruments and Hedging Activities
	The Company accounts for its derivative activities under the provisions of ASC 815, Derivatives and Hedging (ASC 815). ASC 815 establishes accounting and reporting that every derivative instrument be recorded on the balance sheet as either an asset or liability measured at fair value. From time to time, the Company may hedge a portion of its forecasted oil and natural gas production. Derivative contracts entered into by the Company have consisted of transactions in which the Company hedges the variability of cash flow related to a forecasted transactions using variable to fixed swaps and collars . The Company elected to not designate any of its derivative positions for hedge accounting. Accordingly, the net change in the mark-to-market valuation of these positions as well as all payments and receipts on settled derivative contracts are recognized in "Net loss on derivatives" on the consolidated statements of operations for the year ended December 31, 2013. The Company did not have any derivative instruments or hedging activities for the year ending December 31, 2012 or 2011. Derivative instruments with settlement date within one year are included in current assets or liabilities, whereas derivative instruments with settlement dates exceeding one year are included in non-current assets or liabilities. The Company calculates a net asset or liability for current and non-current derivative instruments for each counterparty based on the settlement dates within the respective contracts.
	Reclassifications
	Certain reclassifications have been made to the presentation of certain balance sheet, income statement and cash flow items in the respective statements for the year ended December 31, 2012 and 2011 in order to conform to the presentation for the year ended December 31, 2013. These reclassifications were not material.
	Subsidiary Guarantees
	Contango Oil & Gas Company, as the parent company (the “Parent Company”), filed a registration statement on Form S-3 with the SEC to register, among other securities, debt securities that the Parent Company may issue from time to time. Crimson Exploration Inc., Crimson Exploration Operating, Inc., Contango Energy Company, Contango Operators, Inc., Contango Mining Company, Conterra Company, Contaro Company, Contango Alta Investments, Inc., Contango Venture Capital Corporation and any other of our future subsidiaries specified in the prospectus supplement (each a “Subsidiary Guarantor”) are Co-Registrants with the Parent Company under the registration statement, and the registration statement also registered guarantees of debt securities by the Subsidiary Guarantors. The Subsidiary Guarantors are wholly-owned by the Parent Company, either directly or indirectly, and any guarantee by the Subsidiary Guarantors will be full and unconditional. The Parent Company has no assets or operations independent of the Subsidiary Guarantors, and there are no significant restrictions upon the ability of the Subsidiary Guarantors to distribute funds to the Parent Company. The Parent Company has one other wholly-owned subsidiary that is inactive. Finally, the Parent Company’s wholly-owned subsidiaries do not have restricted assets that exceed 25% of net assets as of the most recent fiscal year end that may not be transferred to the Parent Company in the form of loans, advances or cash dividends by such subsidiary without the consent of a third party.
	Recent Accounting Pronouncements
	In May 2013, the Committee of Sponsoring Organizations of the Treadway Commission ("COSO"), revised its criteria related to internal controls over financial reporting from the originally established 1992 Internal Control - Integrated Framework with 2013 Internal Control - Integrated Framework. The modified framework provides enhanced guidance that ties control objectives to the related risk, enhancement of governance concepts, increased emphasis on globalization of markets and operations, increased recognition of use and reliance on information technology, increased discussion of fraud as it relates to internal control, changes of control deficiency descriptions, and that internal reporting is included in both financial and nonfinancial objectives. The revised framework is effective for interim and annual periods beginning after December 15, 2013, with early adoption being permitted. We will implement any changes required by the new COSO framework during the year ended December 31, 2014. Currently we are evaluating the provisions of the revised framework and continue to assess the impact, if any, it may have on our internal control structure.
	In February 2013, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2013-04 Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date (ASU 2013-04). ASU 2013-04 provides guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, except for obligations addressed within existing guidance in U.S. GAAP. Examples of obligations within the scope of this update include debt arrangements, other contractual obligations, and settled litigation and judicial rulings. U.S. GAAP does not include specific guidance on accounting for such obligations with joint and several liability, which has resulted in diversity in practice. The accounting update is effective for interim and annual periods beginning after December 15, 2013. We are currently evaluating the provisions of this accounting update and assessing the impact, if any, it may have on our financial position and results of operations.
	Further, management is closely monitoring the joint standard-setting efforts of the FASB and the International Accounting Standards Board. There are a large number of pending accounting standards that are being targeted for completion in 2014 and beyond, including, but not limited to, standards relating to revenue recognition, accounting for leases, fair value measurements, accounting for financial instruments, disclosure of loss contingencies and financial statement presentation. Because these pending standards have not yet been finalized, at this time management is not able to determine the potential future impact that these standards will have, if any, on the Company's financial position, results of operations, or cash flows.

Concentration_of_Credit_Risk

Concentration of Credit Risk	12 Months Ended
	Dec. 31, 2013
Concentration Risks, Types, With Concentration Percentage [Abstract]	'
Concentration Risk Disclosure	'
	Concentration of Credit Risk
	The customer base for the Company is concentrated in the natural gas and oil industry. Major purchasers of our natural gas, oil and natural gas liquids for the year ended December 31, 2013 were ConocoPhillips Company (48%), Shell Trading US Company (16%), Sunoco Inc (9%), Enterprise Products Operating LLC (7%), and ExxonMobil Oil Corp. (7%). Our sales to these companies are not secured with letters of credit and in the event of non-payment, we could lose up to two months of revenues. The loss of two months of revenues would have a material adverse effect on our financial position. There are numerous other potential purchasers of our production.

Merger_with_Crimson_Exploratio

Merger with Crimson Exploration Inc.	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Merger with Crimson Exploration Inc.	'
	Merger with Crimson Exploration Inc.
	On October 1, 2013, the Company completed the Merger with Crimson. The Merger was effected pursuant to an Agreement and Plan of Merger, dated as of April 29, 2013, by and among Contango, Crimson and certain subsidiaries (the “Merger Agreement”).
	As a result of the Merger, each share of Crimson common stock was converted into the right to receive 0.08288 shares of common stock of Contango, and the Company issued approximately 3.9 million shares of common stock in exchange for all of Crimson's outstanding capital stock, resulting in Crimson stockholders owning 20.3% of the post-merger Contango.
	The Merger qualified as a tax-free reorganization for U.S. federal income tax purposes, so that none of the Company, Crimson, or any of its stockholders recognized any gain or loss in the Merger, except that Crimson's stockholders may have recognized gain or loss with respect to cash received in lieu of fractional shares of Company common stock.
	Upon consummation of the Merger, the newly constituted board of directors of the Company consisted of Joseph J. Romano, Allan D. Keel, B.A. Berilgen, B. James Ford, Brad Juneau, Ellis L. McCain, Charles M. Reimer, and Steven L. Schoonover. The board of directors has appointed Allan D. Keel as President and Chief Executive Officer and E. Joseph Grady as Senior Vice President and Chief Financial Officer of the Company. Joseph J. Romano remains as Chairman of the Board. Messrs. Keel, Grady and certain other employees of Crimson entered into employment agreements with the Company that became effective upon the consummation of the Merger. The combined company has its headquarters and principal corporate office in Houston, Texas.
	The Merger was accounted for as a business combination in accordance with ASC 805 which, among other things, requires assets acquired and liabilities assumed to be measured at their acquisition date fair values.     Crimson's results of operations are reflected in the Company's consolidated statement of operations, beginning October 1, 2013.
	The following table summarizes the consideration transferred and preliminary estimates of the fair value of assets acquired, and liabilities assumed as of the date of the Merger (in thousands, except for number of shares and share price):
	Consideration transferred:
	Crimson common stock to be acquired by the Company	46,624,721
	Exchange ratio of the Company common shares for each Crimson common share	0.08288
	The Company common stock to be issued to Crimson stockholders	3,864,101
	Closing price of the Company common stock on October 1, 2013	$	37.75
	Fair value of common stock issued	$	145,870
	Cash paid for partial shares	6
	Fair value of stock options issued	698
	Total estimated consideration transferred	$	146,574
	Fair value of other liabilities assumed:
	Current liabilities	$	60,124
	Long-term debt	235,373
	Asset retirement obligations and other non-current liabilities	10,450
	Amount attributable to liabilities assumed	305,947
	Total consideration including liabilities assumed	$	452,521
	Fair value of assets acquired:
	Current assets	$	13,492
	Current and non-current deferred tax asset, net	24,905
	Natural gas and oil properties, net	413,916
	Other non-current assets	208
	Amount attributable to net assets acquired	$	452,521
	Goodwill	$	—
	Estimates of the fair value of assets acquired and liabilities assumed are preliminary and based on information currently available. The fair value estimate of certain of Crimson's assets and liabilities, including asset retirement obligations and current and deferred tax balances, cannot be currently finalized due to information not being available to the Company. The Company expects to be able to obtain the necessary information to finalize the valuation of assets acquired and liabilities assumed by the end of the second quarter of 2014.
	In accordance with the Merger Agreement, Contango issued 0.08288 shares for each of the common shares of Crimson. Additionally, as a result of the merger, all restricted shares of Crimson previously issued to its directors and employees were exchanged for shares of Contango’s common stock using the same conversion factor.
	Consideration paid by the Company consisted of approximately 3.9 million shares of Contango’s common stock issued in exchange for 46.6 million of Crimson’s shares outstanding as of September 30, 2013, including restricted stock vesting at the Transaction date and approximately 136,000 of vested Contango stock options issued to Crimson’s employees in exchange for all Crimson stock options issued and outstanding as of September 30, 2013. The number of options granted and the strike price of the options was adjusted using the same conversion ratio as for the exchange of common stock. All of Crimson’s restricted shares and stock options vested immediately prior to the merger.
	The purchase price is calculated assuming fair value of the Company’s stock of $37.75 per share based upon the closing price of the Company’s common stock as of October 1, 2013.
	Fair value of the Company’s options issued in exchange for Crimson’s stock options was calculated using the Black-Scholes Model by applying the following weighted-average assumptions: (a) risk-free interest rate of 0.62% to 1.35%; (b) expected life of 2.70 to 4.79 years; (c) expected volatility of 29.3% to 38.6%; and (d) expected dividend yield of 0%.  The weighted average fair value per share for the options was estimated to be $5.14.
	Immediately subsequent to the closing of the Merger, the Company assumed and immediately repaid Crimson’s $175.0 million term loan with Barclays Bank PLC ("Barclays") and other lenders, its $58.6 million in loans outstanding under its senior revolving credit facility with Wells Fargo and other lenders, and $1.8 million in accrued interest and prepayment premiums.
	In order to finance the assumed debt, the Company entered into a $500 million four-year revolving credit facility with Royal Bank of Canada and other lenders (the “RBC Credit Facility”) with an initial hydrocarbon supported borrowing base of $275 million. The RBC Credit Facility replaced the Company's $40 million revolving credit facility with Amegy Bank. The Company incurred $2.2 million of arrangement and upfront fees in connection with the RBC Credit Facility. Borrowings under the RBC Credit Facility bear interest at a rate that is dependent upon LIBOR or the U.S. prime rate of interest, plus a margin dependent upon the amount outstanding. On October 1, 2013, the $235.4 million of assumed debt, accrued interest, and prepayment premium and $2.2 million of arrangement and upfront fees under the RBC Credit Facility were paid with the Company's existing cash of $127.6 million and drawings under our RBC Credit Facility of $110.0 million. For the period from October 1, 2013 through December 31, 2013, the effective interest rate on the facility was 2.2%.
	Fair value of the deferred tax liabilities was calculated giving the tax effect of step-up adjustment for oil and gas properties. Contango received carryover tax basis in Crimson’s assets and liabilities because the merger is not a taxable transaction under the United States Internal Revenue Code. Based upon the purchase price allocation, a step-up in financial reporting carrying value related to the property to be acquired from Crimson resulted in an additional deferred tax liability of approximately $42.8 million assuming a 37% expected effective tax rate of the combined company.
	Additionally, fair value of the deferred tax assets was increased by approximately $10.2 million due to elimination of a valuation allowance included in the historical financial statements of Crimson. This adjustment is based on the expectation that it is more likely than not that the majority of $110 million of Crimson’s accumulated Net Operating Losses ("NOLs") will be realized by the combined company in the foreseeable future.    The fair value of Crimson’s oil and gas properties acquired was determined by using commodity prices based on future expected prices for oil, natural gas and NGLs, after adjustment for transportation fees and regional price differentials.
	There is no goodwill attributable to the Merger as the consideration transferred did not exceed the fair value of Crimson's net assets acquired on October 1, 2013.
	Crimson contributed revenues of $33.4 million and a loss of $0.7 million to the Company for the period from October 1, 2013 to December 31, 2013. The following unaudited pro forma summary presents consolidated information of the Company as if the Merger had occurred on January 1, 2012 (in thousands):
			Year Ended December 31,
			2013		2012
			(Unaudited)
	Revenue		$	256,594	$	261,772
	Net income (loss)		$	40,166	$	(83,912	)
	The unaudited pro forma amounts have been calculated after applying the Company's accounting policies and adjusting the results of Crimson to reflect the additional depletion that would have been charged assuming the fair value adjustment to oil and gas properties had been applied from January 1, 2012, together with the consequential tax effects. The pro forma depletion for each period presented was calculated based on the value of the oil and gas properties acquired giving effect to the fair value adjustments as a result of acquisition accounting and estimated DD&A rate for each period. This depletion rate was calculated by dividing production for the period by the beginning of the period proved reserves (calculated by adding back production to the ending proved reserves as of December 31, 2013). The combined historical depreciation, depletion and amortization expenses for the year ended December 31, 2013 and 2012 were increased by $1.9 million and $7.5 million, respectively, including $0.6 million and $0.4 million related to amortization of debt issuance costs for a new credit facility.
	The pro forma interest expense for each period presented was adjusted to reflect the results of the repayment of the $175 million principal balance of the Second Lien Loan using cash available at the Merger date and total borrowings of $110.0 million under the new RBC Credit Facility, as if such repayment had occurred on January 1, 2012, which reduced total combined interest expenses for the years ended December 31, 2013 and 2012 by $16.0 million and $21.3 million, respectively. The expense related to the amortization of the original issue discount on the Second Lien Loan was also eliminated for each period. The reduction in interest expense is offset by amortization of the debt issuance costs related to the debt refinancing which took take place at the Merger date, net of amortization related to the debt issuance costs for the historical Crimson First and Second Lien agreement that was refinanced upon closing of the Merger.
	The pro forma net income was not adjusted for combined historical impairment charges of $2.9 million, $132.0 million, for the years ended December 31, 2013 and 2012, respectively.
	Historical financial statements of Contango for the year ended December 31, 2013 include approximately $6.8 million of Merger related costs, including bankers success fees of $2.8 million and an accrued expense of $1.3 million related to bonus payable to Mr. Joseph J. Romano as a result of successfully completing the Merger. These expenses are included in general and administrative expense in the Company's consolidated statements of income for the respective periods.
	Pro forma net income for the year ended December 31, 2013 does not include $5.7 million of stock based compensation expenses related to vesting of Crimson stock options on October 1, 2013 as a result of the Merger, amortization of debt issuance cost of $0.8 million, amortization of the remaining balance of debt discount of $3.7 million for Crimson debt as of the date of the Merger, and other Merger related costs, including $2.8 million bankers success fees, which were recognized in Crimson's results of operations for the period October 1, 2013, which is not included in consolidated financial statements of the Company. Pro forma net income also does not include benefit related to release of valuation allowance of $10.2 million in relation with the Merger. Although such expenses relate to the Merger, they do not represent recurring expenses and, therefore, are not included in the pro forma results of operations.

Acquisitions_Dispositions_and_

Acquisitions, Dispositions and Gains from Affiliates	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Acquisitions, Dispositions and Gains from Affiliates	'
	Acquisitions, Dispositions and Gains from Affiliates
	Acquisition of Additional Interest in Dutch
	In December 2013, we exercised a preferential right and purchased an additional 7.84% working interest and 6.53% net revenue interest in the five Contango-operated Dutch wells from an independent oil and gas company for $18.8 million, subject to a purchase price adjustment, based on production and operating expenses between the effective date of July 1, 2013 and the closing date of December 12, 2013. Preliminary estimated adjustments of approximately $3.8 million reduced the purchase price to a total of $15.0 million, net to the Company. The purchase price adjustment is expected to be finalized in the first quarter of 2014.
	Southeast Texas Disposition
	On December 31, 2013, the Company sold to an independent third party approximately 7.1% of its interest in all developed and undeveloped properties in Madison and Grimes Counties. The total sales price of $20 million is subject to a purchase price adjustment, based on production and operating expenses between the effective date of July 1, 2013 and the closing date of December 31, 2013. Preliminary estimated adjustment to the sales price of approximately $0.4 million increased the total proceeds from sales of these properties and is expected to be finalized in the first quarter of 2014. A gain of approximately $6.6 million related to this sale was recognized in the year ended December 31, 2013.
	Proceeds from Alta
	In August 2013, Alta sold its interest in the liquids-rich Kaybob Duvernay, which closed in October 2013. Proceeds from the sale are expected to be approximately $30.5 million, net to Contango. Contango has a 2% interest in Alta and a 5% interest in the Kaybob Duvernay project. The total distribution received from Alta during the year ended December 31, 2013 was approximately $23.1 million. An additional $5.4 million was received in February 2014. The total distributions from Alta are expected to exceed our original investment by $15.3 million.

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	Fair Value Measurements
	Pursuant to ASC 820, Fair Value Measurements and Disclosures (ASC 820), the Company's determination of fair value incorporates not only the credit standing of the counterparties involved in transactions with the Company resulting in receivables on the Company's consolidated balance sheets, but also the impact of the Company's nonperformance risk on its own liabilities. ASC 820 defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy assigns the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). Level 2 measurements are inputs that are observable for assets or liabilities, either directly or indirectly, other than quoted prices included within Level 1. The Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. The Company classifies fair value balances based on the observability of those inputs.
	The following table sets forth by level within the fair value hierarchy the Company's financial assets and liabilities that were accounted for at fair value as of December 31, 2013. As required by ASC 820, a financial instrument's level within the fair value hierarchy is 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 fair value assets and liabilities and their placement within the fair value hierarchy levels. There have been no transfers between Level 1, Level 2 or Level 3.
	Fair value information for financial assets and (liabilities) was as follows at December 31, 2013 (in thousands):
		Total			Fair Value Measurements Using
		Carrying Value			Level 1		Level 2			Level 3
	Derivatives
	Commodity price contracts - assets	$	76		$	—	$	76		$	—
	Commodity price contracts - liabilities	$	(1,207	)	$	—	$	(1,207	)	$	—
	Derivatives listed above include swaps and collars that are carried at fair value. The Company records the net change in the fair value of these positions in "Net loss on derivatives" in the Company's consolidated statements of operations. The Company is able to value the assets and liabilities based on observable market data for similar instruments, which resulted in the Company reporting its derivatives as Level 2. This observable data includes the forward curves for commodity prices based on quoted markets prices and implied volatility factors related to changes in the forward curves. See Note 7, "Derivative Instruments" for additional discussion of derivatives.
	As of December 31, 2013, the Company's derivative contracts were with major financial institutions with investment grade credit ratings which are believed to have a minimal credit risk. As such, the Company is exposed to credit risk to the extent of nonperformance by the counterparties in the derivative contracts discussed above; however, the Company does not anticipate such nonperformance. Some of the counterparties to the Company's current derivative contracts are lenders in the Company's RBC Credit Facility. The Company did not post collateral under any of these contracts as they are secured under the RBC Credit Facility.
	Estimates of the fair value of financial instruments are made in accordance with the requirements of ASC 825, Financial Instruments. The estimated fair value amounts have been determined at discrete points in time based on relevant market information. These estimates involve uncertainties and cannot be determined with precision. The estimated fair value of cash, accounts receivable and accounts payable approximates their carrying value due to their short-term nature. The estimated fair value of the Company's RBC Credit Facility approximates carrying value because the facilities interest rate approximates current market rates and are re-set at least every three months. See Note 13 - "Long-Term Debt" for further information.
	Fair value estimates used for non-financial assets are evaluated at fair value on a non-recurring basis include oil and gas properties evaluated for impairment, when facts and circumstances indicate that there may be an impairment. If the unamortized cost of properties exceeds the undiscounted cash flows related to the properties, the value of the properties is compared to the fair value estimated as discounted cash flows related to the risk-adjusted proved, probable and possible reserves related to the properties. Fair value measurements based on inputs are classified as Level 3.
	Impairments
	Contango tests proved oil and gas properties for impairment when events and circumstances indicate a decline in the recoverability of the carrying value of such properties, such as a downward revision of the reserve estimates or lower commodity prices. The Company estimates the undiscounted future cash flows expected in connection with the oil and gas properties on a field by field basis and compare such future cash flows to the unamortized capitalized costs of the properties. If the estimated future undiscounted cash flows are lower than the unamortized capitalized cost, the the capitalized cost is reduced to its fair value. The factors used to determine fair value include, but are not limited to, estimates of proved and probable reserves, future commodity prices, the timing of future production and capital expenditures and a discount rate commensurate with the risk reflective of the lives remaining for the respective oil and gas properties.  Additionally, the Company may use appropriate market data to determine fair value.  Because these significant fair value inputs are typically not observable, impairments of long-lived assets are classified as a level 3 fair value measure.
	Asset Retirement Obligations
	The initial measurement of ARO at fair value is calculated using discounted cash flow techniques and based on internal estimates of future retirement costs associated with oil and gas properties. The factors used to determine fair value include, but are not limited to, estimated future plugging and abandonment costs, expected lives of the related reserves.

Derivative_Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Instruments	'
	Derivative Instruments
	The Company is exposed to certain risks relating to its ongoing business operations, such as commodity price risk. Derivative contracts are utilized to hedge the Company's exposure to price fluctuations and reduce the variability in the Company's cash flows associated with anticipated sales of future oil and natural gas production. The Company generally hedges a substantial, but varying, portion of anticipated oil and natural gas production for future periods. We believe that these derivative arrangements, although not free of risk, allow us to achieve a more predictable cash flow and to reduce exposure to commodity price fluctuations. However, derivative arrangements limit the benefit of increases in the prices of crude oil, natural gas and natural gas liquids sales. Moreover, because our derivative arrangements apply only to a portion of our production and provide only partial protection against declines in commodity prices. Such arrangements may expose us to risk of financial loss in certain circumstances. We continuously reevaluate our hedging programs in light of changes in production, market conditions, and commodity price forecasts.
	As of December 31, 2013, the Company's crude oil and natural gas derivative positions consisted of swaps and costless put/call "collars". Swaps are designed so that the Company receives or makes payments based on a differential between fixed and variable prices for crude oil and natural gas. A costless collar consists of a sold call, which establishes a maximum price the Company will receive for the volumes under contract and a purchased put that establishes a minimum price. A sold put option limits the exposure of the counterparty's risk should the price fall below the strike price. Sold put options limit the effectiveness of purchased put options at the low end of the put/call collars to market prices in excess of the strike price of the put option sold.
	It is the Company's policy to enter into derivative contracts only with counterparties that are creditworthy financial institutions deemed by management as competent and competitive market makers. The counterparties to the Company's current derivative contracts are lenders or affiliates of lenders in the RBC Credit Facility. The Company did not post collateral under any of these contracts as they are secured under the RBC Credit Facility.
	The Company has elected not to designate any of its derivative contracts for hedge accounting. Accordingly, derivatives are carried at fair value on the consolidated balance sheets as assets or liabilities, with the changes in the fair value included in the consolidated statements of operations for the period in which the change occurs. The Company records the net change in the mark-to-market valuation of these derivative contracts, as well as all payments and receipts on settled derivative contracts, in "Net gain (loss) on derivatives" on the consolidated statements of operations. See Note 6 - Fair Value Measurements for additional information.
	The following derivative contracts were in place at December 31, 2013, (fair value in thousands):
	Commodity	Period	Derivative	Volume/Month (1)	Price/Unit (2)	Fair Value
	Crude Oil	Jan 2014-Dec 2014	Swap	7,500 Bbls	$102.10 (4)	$	(558	)
	Crude Oil	Jan 2014-Jun 2014	Swap	2,000 Bbls	$108.07 (4)	(21		)
	Crude Oil	Jan 2014-Dec 2014	Swap	6,000 Bbls	$106.40 (4)	(139		)
	Crude Oil	Jan 2014-Mar 2014	Swap	40,000 Bbls	$97.00 (3)	(171		)
	Crude Oil	Apr 2014-May 2014	Swap	32,000 Bbls	$95.17 (3)	(142		)
	Crude Oil	Jun 2014-Sep 2014	Swap	13,000 Bbls	$93.22 (3)	(91		)
	Crude Oil	Oct 2014-Dec 2014	Swap	11,000 Bbls	$90.61 (3)	(60		)
	Natural Gas	Jan 2014-May 2014	Collar	1,000,000 MMBtu	$4.00 - $4.425 (5)	68
	Natural Gas	Jun 2014-Dec 2014	Collar	120,000 MMBtu	$4.00 - $4.415 (5)	7
	Natural Gas	Jan 2014-Dec 2014	Collar	42,500 MMBtu	$3.75 - $4.60 (5)	(14		)
	Natural Gas	Jan 2014-Dec 2014	Collar	42,500 MMBtu	$3.50 - $5.00 (5)	(10		)
		Total net fair value of derivative instruments				$	(1,131	)
	-1	Average volume per month for the remaining contract term
	-2	Average price per unit for the remaining contract term
	-3	Commodity derivative based on NYMEX West Texas Intermediate crude oil prices
	-4	Commodity derivative based on Brent crude oil prices
	-5	Commodity derivative based on Henry Hub NYMEX natural gas prices
	There was no activity or outstanding derivative contracts during the year ended December 31, 2012 or 2011.
	The following summarizes the fair value of commodity derivatives outstanding on a gross and net basis as of December 31, 2013 (in thousands):
			31-Dec-13
			Gross				Netting (1)			Total
	Assets		$	76			$	(76	)	$	—
	Liabilities		$	(1,207	)		$	76		$	(1,131	)
	-1	Represents counterparty netting under agreements governing such derivatives
	The following table summarizes the effect of derivative contracts on the Consolidated Statements of Operations for the year ended December 31, 2013 (in thousands):
	Contract Type		Year ended December 31, 2013
	Crude oil contracts		$	180
	Natural gas contracts		98
	Realized gain		$	278
	Crude oil contracts		$	(1,179	)
	Natural gas contracts		(231		)
	Unrealized loss		$	(1,410	)
	Net loss on derivatives		$	(1,132	)
	There were no gains or losses related to derivative instruments for the years ended December 31, 2012 or 2011.

Stock_Based_Compensation

Stock Based Compensation	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Stock Based Compensation	'
	Stock Based Compensation
	As of December 31, 2013, the Company had in place a share-based compensation program which allows for stock options and/or restricted stock to be awarded to officers, directors and employees as a performance-based award or granted upon initial employment as part of their overall compensation package. This program includes (i) the Company's original 2009 Equity Compensation Plan (the “2009 Plan”); and (ii) the Crimson 2005 Stock Incentive Plan (the “2005 Plan” or "Crimson Plan") adopted in conjunction with the Merger.
	2009 Equity Compensation Plan
	The 2009 Plan was adopted by the Company’s Board of Directors (the “Board”) on September 15, 2009. Under the 2009 Plan, the Board may grant restricted stock and option awards to officers, directors, employees or consultants of the Company. Awards made under the 2009 Plan are subject to such restrictions, terms and conditions, including forfeitures, if any, as may be determined by the Board.
	Under the original terms of the 2009 Plan, the Company may issue up to 1,500,000 shares of common stock or stock options with an exercise price of each option equal to or greater than the market price of the Company’s common stock on the date of grant. The Company may grant officers and employees both incentive stock options intended to qualify under Section 422 of the Internal Revenue Code of 1986, as amended, and stock options that are not qualified as incentive stock options. Stock option grants to non-employees, such as directors and consultants, can only be stock options that are not qualified as incentive stock options. Options granted generally expire after five or ten years. The vesting schedule varies, and can vest over a two, three or four-year period.
	During the year ended December 31, 2013, 312,838 restricted stock awards were granted under the 2009 Plan to officers, employees and directors of the Company. Of this amount, 63,667 shares were fully vested, of which 17,459 shares were withheld by the Company to satisfy certain officer's tax liability resulting from the vesting of these shares, as provided for in the restricted stock agreement, with the vested balance released to the officers.
	As of December 31, 2013, the Company had approximately 1.2 million shares of common stock and stock options available for future grant under the 2009 Plan.
	2005 Stock Incentive Plan
	The 2005 Plan was adopted by the Company's Board in conjunction with the Merger with Crimson. Under the 2005 Plan, the Board may grant incentive stock options, nonstatutory stock options, restricted awards, unrestricted awards, performance awards, stock appreciation rights and dividend equivalent rights to officers, directors, employees or consultants of the Company and its affiliates. Awards made under the 2005 Plan are subject to such terms and conditions, without limitation, as may be determined by the Board. Options granted generally expire after ten years. The vesting schedule varies but generally vests over a one or four-year period. Upon adoption of the 2005 Plan at the Merger closing date, a total of 135,898 stock option awards and 136,428 shares of restricted stock (as converted, which all fully vested upon the Merger) were already issued and outstanding, leaving a balance of 43,472 shares of common stock or stock options available to be granted to Company employees and directors.
	During the quarter ended December 31, 2013, the Company issued 43,461 shares of restricted common stock to Company employees under the 2005 Plan. These shares vest 25% each year over the next four years. Additionally, 791 stock options were exercised and sold in the open market, leaving 135,107 stock options vested and exercisable at December 31, 2013. The converted exercise price for such options range from $25.70 to $60.33 per share, with an average remaining contractual life of seven years. As of December 31, 2013, there were 11 shares of common stock or stock options available to be granted under the 2005 Plan.
	Shortly after completion of the Merger, certain officers and employees sold 34,911 Contango shares with the total value of $1.3 million back to the Company to satisfy the employees’ tax liability resulting from the vesting of their restricted shares on October 1, 2013. These shares were recognized in the Company balance sheet in Treasury Shares.
	1999 Stock Incentive Plan
	The Company’s 1999 Stock Incentive Plan (the “1999 Plan”) expired in August 2009. There were no outstanding options issued under the 1999 Plan as of December 31, 2013.
	Stock Options
	A summary of the stock options granted under the 1999 Plan, 2009 Plan, and 2005 Plan as of and for the years ended December 31, 2013, 2012, and 2011 is presented in the table below (dollars in thousands, except per share data):
		Year Ended December 31,
		2013							2012					2011
		Shares				Weighted			Shares			Weighted		Shares		Weighted
		Under				Average			Under			Average		Under		Average
		Options				Exercise			Options			Exercise		Options		Exercise
						Price						Price				Price
	Outstanding, beginning of the period	—				—			45,000			$	54.21	45,000		$	54.21
	Options assumed due to Merger	135,898				$	52.9		—			$	—	—		$	—
	Exercised	(791		)		$	36.16		—			$	—	—		$	—
	Canceled / Forfeited (1)	—							(45,000		)	$	54.21	—		$	—
	Outstanding, end of year	135,107				$	53		—			$	—	45,000		$	54.21
	Aggregate intrinsic value	$	459						$	—				$	179
	Exercisable, end of year	135,107				$	53		—			$	—	45,000		$	54.21
	Aggregate intrinsic value	$	459						$	—				$	179
	Available for grant, end of the period	1,162,173							1,475,000					1,475,000
	Weighted average fair value of options granted during the period	$	—						$	—				$	—
	-1	For the year ended December 31, 2012, forfeited options consist of options that were net-settled for cash with the Company.
	Under the fair value method of accounting for stock options, cash flows from the exercise of stock options resulting from tax benefits in excess of recognized cumulative compensation cost (excess tax benefits) are classified as financing cash flows. For the years ended December 31, 2013 and 2011, there were no excess tax benefits recognized. For the year ended December 31, 2012, approximately $0.3 million of such excess tax benefits were classified as financing cash flows. See Note 2 – "Summary of Significant Accounting Policies".
	Compensation expense related to employee stock option grants are recognized over the stock option’s vesting period based on the fair value at the date the options are granted. The fair value of each option is estimated as of the date of grant using the Black-Scholes options-pricing model. In November 2010, the Company’s Board of Directors approved the immediate vesting of all outstanding stock options under both the 1999 Plan and the 2009 Plan. Additionally, the Board authorized management to net-settle any outstanding stock options in cash. The option holder had a choice of receiving cash upon net settlement of options or to settle options for shares of the Company. Such modification of the stock options resulted in recognizing a liability equal to the portion of each award attributable to past service multiplied by the modified awards fair value, and was adjusted quarterly. The accelerated vesting and modification affected no other terms or conditions of the options, including the number of outstanding options or exercise price.
	During the years ended December 31, 2013 and 2011, the Company recognized stock option expense of approximately zero and $179,000, respectively. During the year ended December 31, 2012, the Company recognized a stock option gain of approximately $154,000 due to evaluating the market price of options on a quarterly basis. The aggregate intrinsic value of stock options exercised/forfeited during the years ended December 31, 2013 and 2012 was approximately $7,721 and $0.5 million, respectively.
	Restricted Stock
	The Company did not grant any shares of restricted stock for the years ended December 31, 2012 or 2011 and did not have any restricted shares outstanding as of December 31, 2012.
	In November 2013, the Company issued 254,677 shares of restricted common stock to senior officers and certain other vice presidents, of which 25 percent vested immediately and the remaining balance vests over a three-year period. Also in November 2013, the Company issued 1,802 shares of restricted common stock to newly hired employees as part of their compensation package, which vest over a four-year period. In December 2013, the Company issued 88,466 shares of restricted common stock to Company employees which vest over a four-year period, plus an additional 11,354  shares of restricted common stock to the board of directors as compensation pursuant to our new director compensation plan which vest on the one-year anniversary of the date of grant. The weighted average fair value of the of the restricted shares granted during the quarter, was $44.10 with a total fair value of approximately $8.1 million after adjustment for estimated weighted average forfeiture rate of 5.7%.
	Restricted stock activity as of December 31, 2013 and for the year then ended is presented in the table below (dollars in thousands, except per share data):
		Restricted Shares			Weighted			Aggregate Intrinsic Value
					Average
					Fair Value
	Outstanding, beginning of the period	—						$0
	Granted	356,299			$	44.1		$	15,723
	Vested	(63,667	)		42.8			2,725
	Canceled / Forfeited	—			—			—
	Not vested, end of the period	292,632			44.38			13,830
	Vested, end of the period	—			—			—
	Expected to vest, end of the period	260,359			44.36			12,305
	During the quarter ended December 31, 2013, the Company recognized approximately $3.2 million in stock compensation expense for restricted shares granted to its officers, employees and directors. An additional $11.1 million of compensation expense will be recognized over the remaining vesting period.
	During the first quarter of 2014, the Company issued 3,700 restricted shares to employees under the 2009 Plan, with 1,158,473 shares remaining available for grant under the 2009 Plan as of February 28, 2013.
	Incentive Compensation Plans effective January 1, 2014
	Beginning in 2014 the Company will provide performance-based long-term bonus plans for the benefit of all employees - the Cash Incentive Bonus Plan (“CIBP”) and the Long-Term Incentive Plan (“LTIP”). Both plans, and specific targeted performance measures under those plans, will be approved by the Compensation Committee and the Board. Upon achieving the performance levels established each year, bonus awards will be calculated as a percentage of base salary of each employee for the plan year. The plan awards for each year are disbursed in the first quarter of the following year. Employees must be employed by the Company at the time that final plan awards are disbursed to be eligible.
	The CIBP awards will be paid in cash. The LTIP bonus awards can be paid in restricted common stock and/or stock options. The stock awards and options are expected to vest 25% per year, over the first through fourth anniversaries from the date of grant. The number of shares of restricted common stock and the number of shares underlying the stock options granted as Stock Awards will be determined based upon the fair market value of the common stock on the date of the grant. The stock awards to be granted pursuant to the LTIP will be granted under the 2009 Plan.

Share_Repurchase_Programs

Share Repurchase Programs	12 Months Ended
	Dec. 31, 2013
Share Repurchase Programs [Abstract]	'
Share Repurchase Programs	'
	Share Repurchase Programs
	$100 Million Share Repurchase Program
	In September 2008, the Company’s board of directors approved a $100 million share repurchase program which concluded in October 2011. Under this share repurchase program, the Company purchased a total of 2,157,278 shares of common stock at an average price of $46.35 per share. All shares were purchased in the open market or through privately negotiated transactions. The purchases were made subject to market conditions and certain volume, pricing and timing restrictions to minimize the impact of the purchases upon the market, and when we believed the Company's stock price to be undervalued. Repurchased shares of common stock became authorized but unissued shares, and may be issued in the future for general corporate and other purposes.
	$50 Million Share Repurchase Program
	In September 2011, the Company’s board of directors approved a $50 million share repurchase program, effective upon completion of purchases under the Company’s $100 million share repurchase program. The purchases made under the $50 million share repurchase program are subject to the same terms and conditions as purchases made under the $100 million share repurchase program. No shares were purchased during the year ended December 31, 2013. During the year ended December 31, 2012, the Company purchased 162,214 shares at an average price of $51.62 per share, for a total of approximately $8.4 million, plus it net-settled 45,000 stock options from two employees for a total of $465,000, under the $50 million share repurchase program.
	As of December 31, 2013, the Company had invested $10.8 million in this share repurchase program to purchase 197,877 shares and net-settle 45,000 stock options from two officers, leaving $39.2 million available for future purchases.
	As of December 31, 2013, under both share repurchase programs combined, the Company has purchased approximately 2.4 million shares of its common stock at an average cost per share of $46.84 and 45,000 stock options from two employees for $465,000, for a total of approximately $110.8 million.
	Under the terms of our revolving credit facility with Royal Bank of Canada entered into on October 1, 2013, share repurchases are limited to $1 million per calendar year, and may only be purchased from officers, directors, employees and consultants upon their death, disability, retirement or termination, in accordance with any termination agreement or employment agreement.

Other_Financial_Information

Other Financial Information	12 Months Ended
	Dec. 31, 2013
Other Financial Information [Abstract]	'
Other Financial Information	'
	Other Financial Information
	The following table provides additional detail for accounts receivable, prepaids, and accounts payable and accrued liabilities which are presented on the consolidated balance sheets (in thousands):
		December 31,
		2013			2012
	Accounts Receivable:
	Trade receivable	$	42,196		$	28,091
	Receivable for Alta Resources distribution	7,358			—
	Joint interest billing	5,172			3,848
	Income taxes receivable	4,293			16,177
	Other receivables	2,172			734
	Allowance for doubtful accounts	(578		)	—
	Total Accounts Receivable	$	60,613		$	48,850
	Prepaid Expenses:
	Prepaid insurance	$	1,113		$	396
	Prepaid capital costs	108			1,727
	Prepaid vendors	486			—
	Other prepaid expenses	324			356
	Total Prepaid Expenses	$	2,031		$	2,479
	Accounts Payable and Accrued Liabilities:
	Royalties and revenue payable	$	44,933		$	22,281
	Accrued exploration and development	17,803			1,208
	Trade payable	11,589			4,335
	Advances from partners	6,538			—
	Accrued bonus and severance	7,273			949
	Accrued general and administrative expenses	3,599			1,279
	Accrued lease operating and workover expense	3,529			2,608
	Taxes payable	236			—
	Other accounts payable and accrued liabilities	1,333			12
	Total Accounts Payable and Accrued Liabilities	$	96,833		$	32,672
	Included in the table below is supplemental information about non-cash transactions related to the Merger during the year ended December 31, 2013, in thousands:
		Years Ended December 31,
		2013			2012		2011
	Cash payments:
	Interest payments	$	1,056		$	71	$	49
	Income tax payments	341			24,307		29,961
	Non-cash items excluded from investing activities in the consolidated statements of cash flows:
	Increase (decrease) in accrued capital expenditures	7,004			1,192		(2,315		)
	Assets acquired & liabilities assumed in the Merger:
	Accounts receivable	12,955			—		—
	Prepaids	639			—		—
	Proved natural gas and oil properties	413,916			—		—
	Deferred tax asset and other	24,940			—		—
	Accounts payable and accrued liabilities	(60,110		)	—		—
	Other non-current liabilities	(256		)	—		—
	Long-term debt	(235,373		)	—		—
	Asset retirement obligations	(11,183		)	—		—
	Non-cash items excluded from financing activities in the consolidated statements of cash flows:
	Issuance of common stock in connection with the merger	145,870			—		—

Investment_in_Exaro_Energy_III

Investment in Exaro Energy III LLC	12 Months Ended
	Dec. 31, 2013
Investments, All Other Investments [Abstract]	'
Investment in Exaro Energy III LLC	'
	Investment in Exaro Energy III LLC
	In April 2012, the Company entered into a Limited Liability Company Agreement (the “LLC Agreement”) in connection with the formation of Exaro. Pursuant to the LLC Agreement, as amended, the Company has committed to invest up to $67.5 million in Exaro for an ownership interest of approximately 37%. The aggregate commitment of all the Exaro partners was approximately $183 million. As of December 31, 2013, the Company had invested approximately $46.9 million, including $13.1 million during the year ended December 31, 2013.
	The following table presents condensed balance sheet data for Exaro as of December 31, 2013 and December 31, 2012. The balance sheet data was derived from the Exaro balance sheet as of December 31, 2013 and December 31, 2012 and was not adjusted to represent our percentage of ownership interest in Exaro. Our share in the equity of Exaro at December 31, 2013 was approximately $50.5 million.
		December 31,
		2013			2012
	Current assets	$	30,284		$	14,377
	Non-current assets:
	Net property and equipment	182,226			55,709
	Restricted cash escrow account	8,732			40,014
	Other non-current assets	1,103			4,886
	Total non-current assets	$	192,061		$	100,609
	Total assets	$	222,345		$	114,986
	Current liabilities	$	13,717		$	17,674
	Non-current liabilities:
	Long-term debt	70,000			8,000
	Other non-current liabilities	923			297
	Total non-current liabilities	$	70,923		$	8,297
	Member's equity	137,705			89,015
	Total liabilities & member's equity	$	222,345		$	114,986
	The following table presents the condensed results of operations for Exaro for the year ended December 31, 2013 and for the period from the inception of Exaro, March 19, 2012, to December 31, 2012. The results of operations for the year ended December 31, 2013 and the period from inception of Exaro, March 19, 2012, to December 31, 2012 were derived from Exaro's financial statements for the respective periods. The income statement data below was not adjusted to represent our ownership interest but rather reflects the results of Exaro as a Company. The Company's share in Exaro's results of operations recognized for the years ended December 31, 2013 and 2012 was a gain of $2.3 million, net of tax expense of $1.2 million, and a gain of $60 thousand, net of tax expense of $32 thousand, respectively.
		Year ended December 31, 2013			Period from inception to December 31, 2012
	Oil and natural gas sales	$	52,698		$	7,514
	Other loss	(544		)	(3,269		)
	Less:
	Lease operating expenses	16,136			2,035
	Depreciation, depletion, amortization & accretion	16,058			2,350
	General & administrative expense	3,294			2,872
	Income/(loss) from continuing operations	$	16,666		$	(3,012	)
	Net interest income/(expense)	(3,536		)	25
	Net income (loss)	$	13,130		$	(2,987	)
	Included in Other losses are realized and unrealized losses attributable to derivatives, whose value is likely to change based on future oil and gas prices. Exaro's results of operations do not include income taxes, because Exaro is treated as a partnership for tax purposes.

Asset_Retirement_Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligation	'
	Asset Retirement Obligation
	The Company accounts for its retirement obligation of long lived assets by recording the net present value of a liability for an asset retirement obligation (“ARO”) in the period in which it is incurred. When the liability is initially recorded, a company increases the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement. Activities related to the Company’s ARO during the year ended December 31, 2013 and 2012 were as follows (in thousands):
		Year ended December 31,
		2013			2012
	Balance as of the beginning of the period	$	8,678		$	8,704
	Liabilities incurred during period	14,145			2,005
	Liabilities settled during period	(207		)	(2,037		)
	Accretion	660			478
	Change in estimate	58			(472		)
	Balance as of the end of the period	$	23,334		$	8,678
	Of the total liabilities incurred during the year ended December 31, 2013, $11.2 million were assumed in conjunction with the merger with Crimson and $2.9 million related to new wells drilled during the period. Of the total liabilities settled during the year ended December 31, 2013, approximately $137,000 related to wells plugged and abandoned during the period and approximately $70,000 related to the sale of assets in Madison and Grimes County to a third party See Note 5 - "Acquisitions, Dispositions, and Return on Investments."

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2013
Line of Credit Facility [Abstract]	'
Long-Term Debt	'
	Long-Term Debt
	RBC Credit Facility
	In connection with the Merger, the Company assumed and immediately repaid $235.4 million of Crimson debt, including Crimson’s $175.0 million second lien term loan with Barclays Bank PLC ("Barclays") and other lenders, Crimson’s $58.6 million senior secured revolving credit facility with Wells Fargo Bank and other lenders, and a $1.8 million prepayment premium for the second lien term loan and accrued interest. Of the amount repaid, $127.6 million was made from existing cash with the remainder financed through new borrowing arrangements.
	In order to finance the assumed debt, the Company entered into a $500 million four-year secured revolving credit facility with Royal Bank of Canada and other lenders (the “RBC Credit Facility”) on October 1, 2013, with an initial hydrocarbon-supported borrowing base of $275 million. The Company incurred $2.2 million of arrangement and upfront fees in connection with the RBC Credit Facility which will be amortized over the original four-year term of the RBC Credit Facility. Proceeds of the RBC Credit Facility were, or may be used (i) to finance working capital and for general corporate purposes, (ii) for permitted acquisitions, and (iii) to finance transaction expenses in connection with the RBC Credit Facility and the Merger. The total amount borrowed on October 1, 2013 was $110.0 million.
	As of December 31, 2013, the Company had $90.0 million outstanding under the RBC Credit Facility and $1.9 million in outstanding letters of credit. As of December 31, 2013 borrowing availability under the RBC Credit Facility was $183.1 million.
	The RBC Credit Facility is collateralized by a lien on substantially all the assets of the Company and its subsidiaries, including a security interest in the stock of Contango’s subsidiaries and a security interest in the Company’s oil and gas properties
	Borrowings under the RBC Credit Facility bear interest at a rate that is dependent upon LIBOR, the U.S. prime rate, or the federal funds rate, plus a margin dependent upon the amount outstanding. Additionally, the Company must pay a commitment fee on the amount of the facility that remains unused, which varies from .375% to .5%, depending on the amount of the credit facility that is unused. Total interest expense under the RBC Credit Facility, including commitment fees, for the year ended December 31, 2013 was approximately $1.2 million.
	The RBC Credit Facility contains restrictive covenants which, among other things, restrict the declaration or payment of dividends by Contango and require the maintenance of a minimum current ratio and a maximum leverage ratio. As of December 31, 2013, we were in compliance with all covenants under the RBC Credit Facility. The RBC Credit Facility also contains events of default that may accelerate repayment of any borrowings and/or termination of the facility. Events of default include, but are not limited to, payment defaults, breach of certain covenants, bankruptcy, insolvency or change of control events.
	Amegy Bank Credit Facility
	The RBC Credit Facility replaced the Company's $40 million credit facility with Amegy Bank. On October 22, 2010, the Company completed the arrangement of a secured revolving credit agreement with Amegy Bank (the “Amegy Credit Agreement”) to replace its expiring credit agreement with BBVA Compass Bank. The Amegy Credit Agreement had a $40 million hydrocarbon borrowing base and was available to fund the Company’s exploration and development activities, as well as repurchase shares of common stock, pay dividends, and fund working capital as needed. The Amegy Credit Agreement was secured by substantially all of the assets of the Company. Borrowings under the Amegy Credit Agreement would bear interest at LIBOR plus 2.5%, subject to a LIBOR floor of 0.75%. The principal was due October 1, 2014, and could be prepaid at any time with no prepayment penalty. An arrangement fee of $300,000 was paid in connection with the facility and a commitment fee of 0.125% was owed on unused borrowing capacity. The Amegy Credit Agreement contained customary covenants including limitations on our current ratio and additional indebtedness. Upon termination of the Amegy Credit Agreement, the Company was in compliance with all covenants and had no amounts outstanding. No early termination penalty was incurred as a result of the termination of the Amegy Credit Agreement. Interest expense under the Amegy Credit Agreement for the years ended December 31, 2013, 2012 and 2011 was approximately $37,000, $50,000, and $133,000, respectively.
	As of December 31, 2013 and 2012, the Company had the following debt balances (in thousands):
		December 31,
		2013		2012
	RBC Credit Facility (weighted average interest rate in effect at December 31, 2013 was 2.1875%)	90,000		—
	Total long-term debt	$	90,000	$	—
	This $90 million balance is due by October 1, 2017.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	Contango pays delay rentals on its offshore leases and leases its office space and certain other equipment. Effective October 1, 2013, we moved our corporate offices to 717 Texas Avenue in downtown Houston, Texas, under a lease that expires March 31, 2019. We remain responsible for the rent at our previous corporate office at 3700 Buffalo Speedway in Houston, Texas, through February 29, 2016, however, effective January 1, 2014, we subleased our previous corporate offices through February 29, 2016 and expect to recover the substantial majority of the rent we pay at that location.
	As of December 31, 2013, minimum future lease payments for delay rentals and operating leases for our fiscal years are as follows (in thousands):
	Fiscal years ending December 31,
	2014	$	4,503
	2015	2,103
	2016	1,595
	2017	1,378
	2018	1,109
	2019 and thereafter	269
	Total	$	10,957
	The amount incurred under operating leases and delay rentals during the years ended December 31, 2013, 2012, and 2011 were approximately $1.0 million, $0.5 million, $0.2 million, respectively. As of December 31, 2013, our commitment for potential future equity contributions with Exaro Energy III, LLC to develop onshore natural gas assets, was $20.6 million.
	In July 2012, the Company granted year-end bonuses to employees and certain consultants. A portion of these bonuses have already been paid, with the remainder to vest and be paid on June 30, 2014, to incentivize the individuals to remain with the Company. As of December 31, 2013, approximately $230,000 of compensation remained to be vested, which will vest and be paid on June 30, 2014, as long as the employees are employed by the Company on the vesting date.
	In conjunction with the merger with Crimson (See Note 4 - "Merger with Crimson Exploration Inc."), certain employees did not remain with the Company. The Company entered into agreements with these individuals and paid approximately $0.4 million in severance payments.
	Legal Proceedings
	From time to time, we are involved in legal proceedings relating to claims associated with our properties, operations or business or arising from disputes with vendors in the normal course of business, including the material matters discussed below.
	Mineral interest owners in South Louisiana filed suit against a subsidiary of the Company and several co-defendants in June 2009 in the 31st Judicial District Court situated in Jefferson Davis Parish, Louisiana alleging failure to act as a reasonably prudent operator, failure to explore, waste, breach of contract, etc. in connection with two wells located in Jefferson Davis Parish. Many of the alleged improprieties occurred prior to our ownership of an interest in the wells at issue, although we may have assumed liability otherwise attributable to our predecessors-in-interest through the acquisition documents relating to the acquisition of our interest in these wells. The damages most recently alleged by the plaintiffs are approximately $13.4 million. We and our co-defendants are vigorously defending this lawsuit and believe that we have meritorious defenses. We and our co-defendants obtained a favorable judgment from the trial court following a trial, but the judgment is being appealed by the plaintiffs. A companion case involving the same claims, wells, etc. was filed in the same court on April 19, 2013 on behalf of additional mineral interest owners.
	In November 2010, a subsidiary of the Company, several predecessor operators and several product purchasers were named in a lawsuit filed in the District Court for Lavaca County in Texas by an entity alleging that it owns a working interest in two wells that has not been recognized by us or by predecessor operators to which we have granted indemnification rights. In dispute is whether ownership rights were transferred through a number of decade-old poorly documented transactions. The trial court has granted the plaintiffs motion for partial summary judgment as to liability (but not damages). The Plaintiff recently asserted damages of approximately $6.0 million, inclusive of interest but exclusive of legal fees which may be recoverable by the plaintiff if it ultimately prevails in this case. We are vigorously defending this lawsuit, believe that we have meritorious defenses and intend to appeal the aforementioned decision.
	In September 2012, a subsidiary of the Company was named as defendant in a lawsuit filed in district court for Harris County in Texas involving a title dispute over a 1/16th mineral interest in the producing intervals of certain wells operated by us in the Catherine Henderson “A” Unit in Liberty County in Texas. This case was subsequently transferred to district court for Liberty County, Texas and combined with a suit filed by other parties against the plaintiff claiming ownership of the disputed interest. The plaintiff has alleged that, based on its interpretation of a series of 1972 deeds, it owns an additional 1/16th unleased mineral interest in the producing intervals of these wells on which it has not been paid (this claimed interest is in addition to a 1/16th unleased mineral interest on which it has been paid). We have made royalty payments with respect to the disputed interest in reliance, in part, upon leases obtained from successors to the grantors under the aforementioned deeds, who claim to have retained the disputed mineral interests thereunder. In their initial pleading the plaintiff alleges damages in excess of $6.0 million, which is generally in line with amounts received on its undisputed 1/16th mineral interest as of the date the suit was filed. As of January 2014, the Plaintiff had received approximately $8.5 million in royalties in respect of its undisputed interest. We are vigorously defending this lawsuit and believe that we have meritorious defenses. We believe if this matter were to be determined adversely, amounts owed to the plaintiff could be partially offset by recoupment rights we may have against other working interest and/or royalty interest owners in the unit.
	In connection with our Merger, several class action lawsuits have been brought by Crimson stockholders in Delaware Chancery Court seeking damages and injunctive relief including, among other things, compensatory damages and costs and disbursements relating to the lawsuits. Various combinations of the Company, certain subsidiaries of the Company, members of Crimson’s pre-merger board of directors, members of Crimson’s pre-merger management team and Oaktree Capital Management L.P. have been named as defendants in these lawsuits. The Delaware lawsuits have been consolidated into a single action referred to as In Re: Crimson Exploration Inc. Stockholder Litigation; C.A. 8541-VCP. Additionally, on July 13, 2013, a separate and similar complaint was filed in the District Court of Harris County Texas, in the matter of Fisichella Family Trust v. Crimson Exploration Inc. It is possible that additional similar lawsuits may be filed.
	The merger-related lawsuits allege, among other things, that Crimson’s board of directors failed to take steps to obtain a fair price, failed to properly value Crimson, failed to protect against alleged conflicts of interest, failed to conduct a reasonably informed evaluation of whether the transaction was in the best interests of stockholders, failed to fully disclose all material information to stockholders, acted in bad faith and for improper motives, engaged in self-dealing, discouraged other strategic alternatives, took steps to avoid competitive bidding, and agreed to allegedly unreasonable deal protection mechanisms, including the no-shop, fiduciary-out provisions and termination fee. The lawsuits also allege that Contango and certain other defendants aided and abetted the other defendants in violating duties to the Crimson stockholders. The known plaintiffs in these lawsuits collectively owned a very small percentage of the total outstanding shares of Crimson common stock at the time of the Merger, which was approved by Contango's pre-merger shareholders (89% of outstanding shares and 99% of voted shares were voted in favor of the Merger) and Crimson's pre-merger shareholders (69% of outstanding shares and 88% of voted shares were voted in favor of the Merger). The Company believes that these merger-related lawsuits are without merit and intends to contest them vigorously.
	While many of these matters involve inherent uncertainty and we are unable at the date of this filing to estimate an amount of possible loss with respect to certain of these matters, we believe that the amount of the liability, if any, ultimately incurred with respect to these proceedings or claims will not have a material adverse effect on our consolidated financial position as a whole or on our liquidity, capital resources or future annual results of operations. The Company has maintained an officers and directors liability insurance policy for Crimson former directors and officers and has made a claim under the policy for coverage of these merger related lawsuits.
	Employment Agreements
	As a result of successfully completing the Merger, Mr. Joseph J. Romano, the Company's Chairman and former Chief Executive Officer is entitled to receive a $4.0 million bonus payment. This payment is expected to paid in July 2014.
	In connection with the Merger, Contango entered into employment agreements with each of Allan D. Keel, E. Joseph Grady, A. Carl Isaac, Jay S. Mengle and Thomas H. Atkins, which all became effective on October 1, 2013. The employment agreements provide for a term of three years with automatic two-year extensions of the initial term, unless Contango or the executive provides prior notice of intention not to extend the agreement. The employment agreements replace the June 29, 2011 employment agreements between Crimson and Messrs. Keel, Grady, Mengle and Atkins, and the April 18, 2012 employment agreement between Crimson and Mr. Isaac, except as described below.
	Under the new employment agreements, Mr. Keel is entitled to a base salary of $600,000, Mr. Grady is entitled to a base salary of $400,000, Mr. Isaac is entitled to a base salary of $320,000, Mr. Mengle is entitled to a base salary of $300,000 and Mr. Atkins is entitled to a base salary of $310,000. Each executive shall participate in the CIBP and the LTIP. With respect to the CIBP, the executives are eligible to receive a cash bonus based upon minimum, target and maximum award levels of not less than 50%, 100% and 150% for Mr. Keel; 50%, 90% and 130% for Mr. Grady; and 50%, 80% and 120% for Messrs. Isaac, Mengle and Atkins, respectively, of such executive’s base salary. With respect to the LTIP, the executives are eligible to receive stock option awards, restricted stock awards or a combination of both upon minimum, target and maximum award levels of not less than 75%, 350% and 450% for Mr. Keel; 75%, 250% and 450% for Mr. Grady; and 75%, 250% and 350% for Messrs. Isaac, Mengle and Atkins, respectively, of such executive’s base salary.
	In addition, as of December 31, 2013, the Company had entered into employment agreements with two other employees, which provide for a term of two years with automatic one-year extensions of the initial term, unless Contango or the employee provides prior notice of intention not to extend the agreement. One employee is entitled to a base salary of $270,000 per year while the other is entitled to a base salary of $250,000 per year, with minimum, target and maximum CIBP targets of 30%, 50% and 75% for both, based on each employees' base salary. Minimum, target and maximum LTIP incentive equity plan targets for both are 40%, 100%, and 200% of each employee's base salary.
	Effective January 1, 2014, the Company entered into an employment agreement with another employee, which provides for a term of two years with an automatic one-year extensions of the initial term, unless Contango or the employee provides prior notice of intention not to extend the agreement. The employee's base salary is $250,000 per year, with minimum, target and maximum CIBP targets of 30%, 50% and 75%; and minimum, target and maximum LTIP incentive equity plan targets of 40%, 100%, and 200% of the employee's base salary.

Net_Income_Loss_Per_Common_Sha

Net Income (Loss) Per Common Share	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Net Income (Loss) Per Common Share	'
	Net Income (Loss) Per Common Share
	A reconciliation of the components of basic and diluted net income per common share for the years ended December 31, 2013, 2012 and 2011 is presented below (in thousands, except per share amounts):
		Year Ended December 31, 2013
		Net Income			Shares	Per Share
	Basic Earnings per Share:
	Net income attributable to common stock	$	41,362		16,156	$	2.56
	Diluted Earnings per Share:
	Effect of potential dilutive securities:
	Stock options, weighted average of incremental shares	$	—		2	—
	Net income attributable to common stock	$	41,362		16,158	$	2.56
		Year Ended December 31, 2012
		Net Loss			Shares	Per Share
	Basic Earnings per Share:
	Loss from continuing operations	$	(907	)	15,295	$	(0.06	)
	Discontinued operations, net of income taxes	(29		)	15,295	0
	Net loss attributable to common stock	$	(936	)	15,295	$	(0.06	)
	Diluted Earnings per Share:
	Loss from continuing operations	$	(907	)	15,295	$	(0.06	)
	Discontinued operations, net of income taxes	(29		)	15,295	0
	Net loss attributable to common stock	$	(936	)	15,295	$	(0.06	)
		Year Ended December 31, 2011
		Net Income (loss)			Shares	Per Share
	Basic Earnings per Share:
	Income from continuing operations	$	69,909		15,582	$	4.49
	Discontinued operations, net of income taxes	(1,204		)	15,582	(0.08		)
	Net income attributable to common stock	$	68,705		15,582	$	4.41
	Diluted Earnings per Share
	Effect of potential dilutive securities:
	Stock options, weighted average of incremental shares				3
	Income from continuing operations	$	69,909		15,585	$	4.49
	Discontinued operations, net of income taxes	(1,204		)	15,585	(0.08		)
	Net income attributable to common stock	$	68,705		15,585	$	4.41
	The numerator for basic earnings per share is net income (loss) attributable to common stockholders. The numerator for diluted earnings per share is net income unless there is a loss and then is (loss) available to common stockholders, due to antidilution.
	Potential dilutive securities (stock options, stock warrants and convertible preferred stock) have not been considered when their effect would be antidilutive. The potentially dilutive shares would have been 187,302 shares for the year ended December 31, 2013. Prior to this period, the Company had no potentially dilutive securities.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	Actual income tax expense from continuing operations differs from income tax expense from continuing operations computed by applying the U.S. federal statutory corporate rate of 35 percent to pretax income as follows (dollars in thousands):
		Year Ended December 31,
		2013						2012						2011
	Provision/(benefit) at statutory tax rate	$	23,011		35	%		$	(94	)		35	%	$	38,056		35	%
	State income tax provision, net of federal benefit	2,928			4.45	%		654				(241.84	)%	2,960			2.72	%
	Permanent differences	(1,559		)	(2.37	)%		450				(166.34	)%	(2,223		)	(2.04	)%
	Other	4			0.01	%		(373		)		137.65	%	28			0.03	%
	Income tax provision /(benefit)	$	24,384		37.09	%		$	637			(235.53	)%	$	38,821		35.71	%
	Included in permanent differences for the fiscal year ended December 31, 2013, is $10 million in proceeds from life insurance, offset by $3 million in non-deductible expenses related to the Merger. Included in permanent differences for the fiscal year ended December 31, 2011, is the IRC Section 199 benefit.
	The provision (benefit) for income taxes from continuing operations for the periods indicated are comprised of the following (in thousands):
		Year Ended December 31,
		2013			2012				2011
	Current:
	Federal	$	8,739		$	7,038			$	31,743
	State	3,857			2,168				3,461
	Total	$	12,596		$	9,206			$	35,204
	Deferred:
	Federal	$	11,361		$	(8,343	)		$	4,599
	State	427			(226		)		(982		)
	Total	$	11,788		$	(8,569	)		$	3,617
	Total:
	Federal	$	20,100		$	(1,305	)		$	36,342
	State	4,284			1,942				2,479
	Total	$	24,384		$	637			$	38,821
	Included in gain/loss from affiliates	1,245			32				—
	Total income tax provision (benefit)	$	23,139		$	605			$	38,821
	The net deferred tax liability is comprised of the following (in thousands):
		December 31,
		2013			2012
	Deferred tax assets:
	Net operating loss carryforward	$	49,204		$	—
	Income tax credits	2,676			—
	Derivative instruments	564			—
	Deferred compensation	406			—
	Other	1,165			—
	Total deferred tax assets before valuation allowance	$	54,015		$	—
	Valuation allowance	(2,552		)	—
	Net deferred tax assets	$	51,463		$	—
	Deferred tax liability:
	Oil and gas properties	$	(133,894	)	$	(109,538	)
	Investment in affiliates	(21,681		)	(6,320		)
	Other	(518		)	—
	Deferred tax liability	$	(156,093	)	$	(115,858	)
	Total net deferred tax liability	$	(104,630	)	$	(115,858	)
	As of December 31, 2013, the Company had federal and state net operating loss (“NOL") carryforwards of approximately $132.3 million. All NOL were acquired in a Merger with Crimson. These NOL are available to reduce future taxable income and the related income tax liability of combined company.  At the date of the Merger Crimson had valuation allowance of approximately $36.4 million, or $12.8 million tax-adjusted. As part of acquisition accounting for the Merger, the Company released valuation allowance of approximately $29.2 million, or $10.2 million tax-adjusted. Remaining valuation allowance of $7.3 million, or $2.6 million tax-adjusted was due to Internal Revenue Code Section 382 (“Section 382”) limitations on utilization of NOL acquired by Crimson in previous acquisitions.  Utilization of NOL acquired in a Merger with Crimson is limited by Section 382 as discussed below.
	In assessing the realizability of deferred tax assets, we consider whether it is more likely than not that some portion or all of the deferred tax assets will not be realized.  The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible.  We consider the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning strategies in making this assessment.  Based upon the amount of deferred tax liabilities, level of historical taxable income and projections for future taxable income over the periods in which the deferred tax assets are deductible, we believe it is more likely than not that we will realize the benefits of these deductible differences net of a tax-adjusted $2.6 million valuation allowance.
	Federal NOL carryforwards of $132.3 million expire at various dates beginning in 2014 and ending in 2033. NOL carryforwards of $7.3 million impacted by Crimson's Section 382 limitations, which are not expected to be realized, will expire between 2014 and 2016.  Federal NOL carryforwards of $131.0 million, associated with Crimson's losses incurred in recent years, which are also impacted by Section 382 limitations and expected to be realized, will expire at various dates beginning in 2026 and ending in 2033.  We believe that we will be able to utilize most of the NOL carryforwards, as discussed above, before they expire.
	ASC 740, Income Taxes ("ASC 740") prescribes a recognition threshold and a measurement attribute for the financial statement recognition and measurement of income tax positions taken or expected to be taken in an income tax return.  For those benefits to be recognized, an income tax position must be more-likely-than-not to be sustained upon examination by taxing authorities.  As a results of the Merger, we acquired certain tax positions taken by Crimson in prior years. These positions are not expected to have a material impact on results of operations, financial position or cash flows.  A reconciliation of the beginning and ending amount of unrecognized income tax benefits is as follows (in thousands):
			Unrecognized Tax Benefits
	Balance at December 31, 2012		$	—
	Additions based on tax positions related to the current year		—
	Additions based on tax positions related to prior years		—
	Additions due to acquisitions		518
	Reductions due to a lapse of the applicable statute of limitations		—
	Balance at December 31, 2013		$	518
	Company's policy is to recognize interest and penalties related to uncertain tax positions as income tax benefit (expense) in our Consolidated Statements of Operations.  The Company had no interest or penalties related to unrecognized tax benefits for the year ended December 31, 2013 or any prior years. The total amount of unrecognized tax benefit if recognized that would affect the effective tax rate was zero.
	The Company's tax returns are subject to periodic audits by the various jurisdictions in which the Company operates.  These audits can result in adjustments of taxes due or adjustments of the NOL carryforwards that are available to offset future taxable income. We do not anticipate that total unrecognized tax benefits will significantly change due to the settlement of audits and the expiration of statute of limitations prior to December 31, 2013.
	Generally, the Company's income tax years of 2009 through the current year remain open and subject to examination by Federal tax authorities or the tax authorities in Texas and Louisiana which are the jurisdictions where the Company carries its principal operations. These audits can result in adjustments of taxes due or adjustments of the net operating loss carryforwards that are available to offset future taxable income.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	Juneau Exploration L.P.
	In April 2012, the Company announced that Mr. Brad Juneau, the sole manager of the general partner of JEX, had joined the Company’s board of directors and that the Company had entered into an advisory agreement with JEX (the "Advisory Agreement"), whereby in addition to generating and evaluating offshore and onshore exploration prospects for the Company, JEX would direct Contango’s staff on operational matters including drilling, completions and production. Pursuant to the Advisory Agreement, JEX was to be paid an annual fee of $2.0 million.
	In August 2012, the Company's founder, Chairman and Chief Executive Officer, Mr. Kenneth R. Peak, took a medical leave of absence and the board of directors of the Company appointed Mr. Juneau as President and Acting Chief Executive Officer of the Company, which he held until December 2012.
	Effective January 1, 2013, the Advisory Agreement was terminated, and the Company and JEX entered into a First Right of Refusal Agreement (the "First Right Agreement"). Under the First Right Agreement, JEX granted a first right of refusal to Contango to purchase any exploration prospects generated and recommended by JEX. Prospects were presented along with terms and conditions for purchasing each prospect and Contango had the first right of refusal to purchase the prospect from JEX, subject to mutually acceptable terms. Pursuant to the First Right Agreement, JEX was to be paid an annual fee of $0.5 million, which approximates the costs incurred by JEX for its support to the Company in the areas of operations, engineering, and land functions. JEX and its employees continued to be eligible to receive overriding royalty interests, carried interests and certain back-in rights. The First Right Agreement was terminated effective as of March 31, 2013.
	Effective January 1, 2013, Contaro Company, a wholly-owned subsidiary of the Company, entered into an advisory agreement with JEX (the "Contaro Advisory Agreement"). Under the Contaro Advisory Agreement, JEX will provide advisory services to Contaro in connection with Contaro's investment in Exaro, and Mr. Juneau will serve on the Board of Managers of Exaro and perform such duties as described in the limited liability company operating agreement of Exaro. Pursuant to the Contaro Advisory Agreement, JEX will be paid a monthly fee of $10,000 and shall be entitled to receive a one percent (1%) fee of the cash profit earned by Contaro. Cash profit is defined as the amount of cash received by Contango as a result of its investment in Contaro, less the cash invested by the Company as a result of its investment in Contaro.
	On March 19, 2014, Mr. Juneau resigned from the board of directors.
	Olympic Energy Partners
	In December 2012, Mr. Joseph J. Romano was elected President and Chief Executive Officer of the Company. Mr. Peak passed away on April 19, 2013 and Mr. Romano was named Chairman of the Company. Upon the Merger with Crimson on October 1, 2013, Mr. Romano resigned as President and Chief Executive Officer, but remains Chairman. Mr. Romano is also the President and Chief Executive Officer of Olympic Energy Partners LLC ("Olympic").
	JEX, affiliates of JEX, and Olympic have historically participated with the Company in the drilling and development of certain prospects through participation agreements and joint operating agreements, which specify each participant’s working interest ("WI"), net revenue interest ("NRI"), and describe when such interests are earned, as well as allocate an overriding royalty interest ("ORRI") of up to 3.33% to benefit the employees of JEX, excluding Mr. Juneau, except where otherwise noted. Olympic last participated with the Company in the drilling of wells in March 2010, and its ownership in Company-operated wells is limited to our Dutch and Mary Rose wells.
	Republic Exploration LLC
	In his capacity as sole manager of the general partner of JEX, Mr. Juneau also controls the activities of Republic Exploration LLC ("REX"), an entity owned 34.4% by JEX, 32.3% by Contango, and 33.3% by a third party which contributed other assets to REX. REX generates and evaluates offshore exploration prospects and has historically participated with the Company in the drilling and development of certain prospects through participation agreements and joint operating agreements, which specify each participant’s working interest, net revenue interest, and describe when such interests are earned, as well as allocate an overriding royalty interest of up to 3.33% to benefit the employees of JEX. The Company proportionately consolidates the results of REX in its consolidated financial statements.
	As of December 31, 2013, Contango, Olympic, JEX, REX and JEX employees owned the following interests in the Company's offshore wells.
		Contango					Olympic					JEX					REX				JEX Employees
		WI		NRI			WI		NRI			WI		NRI			WI		NRI		ORRI
	Dutch #1 - #5	54.89	%	44.65	%		3.53	%	2.84	%		1.88	%	1.51	%		—	%	—	%	2.02%
	Mary Rose #1	53.21	%	40.44	%		3.61	%	2.7	%		2.01	%	1.51	%		—	%	—	%	2.79%
	Mary Rose #2 - #3	53.21	%	38.67	%		3.61	%	2.58	%		2.01	%	1.44	%		—	%	—	%	2.79%
	Mary Rose #4	34.58	%	25.49	%		2.34	%	1.7	%		1.31	%	0.95	%		—	%	—	%	1.82%
	Mary Rose #5	37.8	%	27.88	%		2.56	%	1.87	%		1.43	%	1.04	%		—	%	—	%	1.54%
	Ship Shoal 263	100	%	80	%		—	%	—	%		—	%	—	%		—	%	—	%	3.33%
	Vermilion 170	83.2	%	64.83	%		—	%	—	%		4.3	%	3.35	%		12.5	%	9.74	%	3.33%
	Prior to December 2013, Contango, Olympic, and JEX had the following lower WI and NRI in Dutch #1-#5, as a result of exercising a preferential right in December 2013:
		Contango				Olympic					JEX
		WI	NRI			WI		NRI			WI	NRI
	Dutch #1 - #5	47.05%	38.12	%		3.02	%	2.42	%		1.61%	1.29%
	During the year ended December 31, 2013, Mr. Romano earned $26,000 and Mr. Juneau earned $97,500 in cash, and each received 1,622 shares of restricted stock, which vest 100% on the one-year anniversary of the date of grant, as part of their board of director compensation. Below is a summary of transactions between the Company, Olympic, JEX, and REX during the years ended December 31, 2013, 2012 and 2011.
	•	In March 2010 the Company spud the Eloise South well. All owners paid for their proportionate share of drilling and completion costs based on their ownership percentage. The Company had a 23.8% working interest in this well, Olympic had a 3.33% working interest, and REX had a 9.6% working interest. Once production began, JEX employees received an ORRI of 1.33%.
	•	In June 2010 the Company spud its Rexer #1 well. Under the terms of the applicable participation agreement, the Company had a 100% working interest through payout of all costs. In May 2011, the Company sold Rexer #1 (See Note 18 - "Discontinued Operations") prior to reaching payout. Once payout is reached with the new operator, JEX will have an option to back-in for a 10% working interest (7.25% net revenue interest). Other third-parties own the remaining working interests. JEX employees maintained a 2.5% ORRI in this well. The Company paid JEX a prospect fee of $250,000 for generating this prospect.
	•	Prior to its dissolution, Contango Offshore Exploration LLC owed the Company $5.9 million in principal and interest under a promissory note (the “COE Note”) payable on demand. In connection with the dissolution, the Company assumed its 65.63% share of the obligation under the COE Note, while JEX assumed the remaining 34.37%, or approximately $2 million. This $2 million was paid to the Company in October 2010.
	•	In February 2011 the Company spud Vermilion 170 which was owned 100% by the Company. Under the terms of the applicable participation agreement, Contango had a 100% working interest through casing point. Once casing point was reached, JEX and REX each exercised their option to back-in for a 2.6% and 7.5% working interest, respectively. Once production began, JEX and REX each received their carried working interest of 1.7% and 5.0%, respectively, resulting in JEX having a final working interest of 4.3% and REX having a final working interest of 12.5%. The Company owns the remaining working interests in this well. The Company paid JEX a prospect fee of $250,000 for generating this prospect.
	•	In May 2011 the Company spud its Rexer-Tusa #2 well. Under the terms of the applicable participation agreement, the Company had a 25% working interest through payout of all costs. In October 2011, the Company completed selling Rexer-Tusa #2 (See Note 18 - "Discontinued Operations") prior to reaching payout. Once payout is reached with the new operator, JEX will have an option to back-in for a 10% working interest (7.36% net revenue interest). Other third-parties own the remaining working interests. JEX employees maintained a 2.92% ORRI in this well.
	•	In July 2011, the Company recompleted its Eloise South well uphole in the Cib-Op sands as our Dutch #5 well. Under the terms of the applicable joint operating agreement, all Dutch #5 well owners were required to purchase the Eloise South well bore from the Eloise South owners (the "Dutch Well Cost Adjustment"). All Eloise South and Dutch #5 well owners paid and/or received their proportionate share of the Dutch Well Cost Adjustment based on their ownership percentage in each well. At the time of the Dutch Well Cost Adjustment, JEX had a 1.6% working interest in Dutch #5; Olympic had a 3.02% working interest in Dutch #5 and a 3.33% working interest in Eloise South; REX had a 9.6% working interest in Eloise South; and Contango had a 47.05% working interest in Dutch #5 and a 23.8% working interest in Eloise South.
	•	In December 2011, the Company purchased an additional working interest in Mary Rose #5 (see below) from an existing partner. The Company then sold to Olympic and JEX its proportionate share of the existing partner's interest, based on Olympic and JEX's ownership percentage in the well.
	•	In January 2012, the Company recompleted its Eloise North well uphole in the Cib-Op sands as our Mary Rose #5 well. Under the terms of the applicable joint operating agreement, all Mary Rose #5 well owners were required to purchase the Eloise North well bore from the Eloise North owners. (the "Mary Rose Well Cost Adjustment"). All Eloise North and Mary Rose #5 well owners paid and/or received their proportionate share of the Mary Rose Well Cost Adjustment based on their ownership percentage in each well. JEX had a 1.4% working interest in Mary Rose #5 and a 0.1% working interest in Eloise North; Olympic had a 2.56% working interest in Mary Rose #5 and a 4.79% working interest in Eloise North; REX had a 13.2% working interest in Eloise North; and the Company had a 37.8% working interest in Mary Rose #5 and a 35.8% working interest in Eloise North.
	•	In July 2012 the Company spud the Ship Shoal 134 prospect which was owned 100% by the Company. The Company paid 100% of the costs to drill, plug and abandon this well. The Company paid JEX a prospect fee of $250,000 for generating this prospect.
	•	In July 2012 the Company spud the South Timbalier 75 prospect which was farmed-in 100% by the Company and REX. Under the terms of the applicable participation agreement, the Company paid 100% of the costs to drill, plug and abandon this well. The Company paid JEX a prospect fee of $250,000 for generating this prospect.
	•	For the five REX-generated lease blocks that the Company purchased at the June 20, 2012 lease sale, the Company will have a 100% working interest through first production. At first production (if successful), REX will receive a carried working interest of 10%. Once payout of post casing point costs has been reached, REX will have an option to back-in for up to 12.5% working interest, resulting in REX having a final working interest of up to 22.5% (17.5% net revenue interest) and the Company owning the remaining working interests. JEX employees will receive an ORRI of 3.33% in these prospects. The Company will pay JEX a prospect fee of $250,000 for each prospect the Company drills. Should the Company not drill these prospects within 48 months of the effective date of each lease, the Company shall assign such lease to REX.
	•	For the one JEX-generated lease block that the Company purchased at the June 20, 2012 lease sale, the Company will carry JEX for 10% through first production and JEX employees will receive an ORRI of 3.33%. The Company paid JEX a prospect fee of $250,000 in December 2013 upon spudding this prospect.
	•	For the three REX-generated lease blocks that the Company purchased at the March 20, 2013 lease sale, the Company will have a 100% working interest through first production. At first production (if successful), REX will receive a carried working interest of 10%. Once payout of post casing point costs has been reached, REX will have an option to back-in for up to 12.5% working interest, resulting in REX having a final working interest of up to 22.5% (17.5% net revenue interest) and the Company owning the remaining working interests. JEX employees will receive an ORRI of 3.33% in these prospects. The Company paid JEX two prospect fees of $250,000 each, for evaluating these two prospects located on three leases. Should the Company not drill these prospects within 48 months of the effective date of each lease, the Company shall assign such lease to REX.
	•	In June 2013, the Company purchased South Timbalier 17 from an independent oil and gas company. Under the terms of the applicable participation agreement, the Company will have a 75% working interest in this well, with several other owners owning the remainder, until payout of all costs is reached. Once payout of all costs has been reached, REX will have an option to back-in for up to a 9.4% working interest, (6.7% net revenue interest), resulting in the Company owning a 56.3% working interests (39.9% net revenue interest). The Company paid JEX a prospect fee of $250,000 for evaluating this prospect. There are no JEX employee ORRIs on this prospect.
	•	In the Tuscaloosa Marine Shale ("TMS"), a shale play in central Louisiana and Mississippi, the Company has a 100% working interest through first production. Beginning with production from the fourth well on the existing acreage (if successful), JEX will receive a carried working interest of 10% and JEX employees will receive an ORRI of 2%, of which Mr. Juneau receives 0.75%, to reimburse Mr. Juneau for out-of-pocket costs incurred in order for Contango to participate in the prospect. An additional 2% was granted to the geologist who generated the TMS prospect for us. The geologist has subsequently been employed by Contango. Should the Company not drill on its TMS acreage within six months of the leases expiring, the Company shall assign such leases to JEX.
	•	Effective January 1, 2014, the Company subleased to JEX a portion of its previous office space at 3700 Buffalo Speedway, Houston, Texas for approximately $0.1 million per year, which approximates our rental liability for that space.
	Below is a summary of payments received from (paid to) Olympic, JEX, and REX in the ordinary course of business in our capacity as operator of the wells and platforms for the periods indicated. The Company made and received similar types of payments with other well owners (in thousands):
		Year ended December 31,
		2013										2012									2011
		Olympic			JEX			REX				Olympic			JEX			REX			Olympic			JEX			REX
	Revenue payments as well owners	$	(6,859	)	$	(4,628	)	$	(1,932	)		$	(6,888	)	$	(5,230	)	$	(4,308	)	$	(9,669	)	$	(5,393	)	$	(816	)
	Joint interest billing receipts	945			1,201			2,090				1,081			724			885			1,867			1,069			3,229
	Dutch well cost adjustment	—			—			—				—			—			—			(389		)	161			(957		)
	Mary Rose well cost adjustment	—			—			—				(201		)	118			(1,185		)	—			—			—
	Below is a summary of payments received from (paid to) Olympic, JEX and REX as a result of specific transactions between the Company, Olympic, JEX and REX. While these payments are in the ordinary course of business, the Company did not have similar transactions with other well owners (in thousands):
		Year ended December 31,
		2013										2012									2011
		Olympic			JEX			REX				Olympic			JEX			REX			Olympic			JEX			REX
	Sale of interest in Mary Rose #5	$	—		$	—		$	—			$	—		$	—		$	—		$	—		$	8		$	—
	Reimbursement of certain costs	—			(115		)	(4		)		—			(496		)	(9		)	—			(185		)	(149		)
	Prospect fees	—			(1,000		)	—				—			—			—			—			(250		)	—
	Advisory Agreements	—			(361		)	—				—			(1,530		)	—			—			—			—
	REX distribution to members	—			—			(197		)		—			—			1,469			—			—			—
	As of December 31, 2013 and 2012, the Company's consolidated balance sheets reflected the following balances (in thousands):
		31-Dec-13										31-Dec-12
		Olympic			JEX			REX				Olympic			JEX			REX
Accounts receivable:
Trade receivable	$	—		$	—		$	—			$	2		$	1		$	1
Joint interest billing	34			87			116				79			85			78
Accounts payable:
Royalties and revenue payable	(1,293		)	(877		)	(466		)		(1,133		)	(842		)	(642		)
Joint interest billings	—			—			—				—			(101		)	—
Oaktree Capital Management L.P.
Oaktree Capital Management L.P. ("Oaktree"), through various funds, owns approximately 6.7% of the Company's stock. On October 1, 2013 following the closing of the Merger, Mr. James Ford, a Manging Director and Portfolio Manager within Oaktree, was elected to the Company's board of directors. Mr. Ford was previously a member of Crimson's board of directors from February 2005 until the closing of the Merger.
As part of Mr. Ford's director compensation, all cash and equity awards payable to Mr. Ford, are instead granted to an affiliate of Oaktree. During the year ended December 31, 2013, an affiliate of Oaktree earned $17,000 in cash and 1,622 shares of restricted common stock as a result of Mr. Ford's board participation. These shares vest one year from the date of grant.
Prior to the Merger, Crimson maintained a second lien credit agreement with Barclays Bank Plc, as agent, and other parties, including an affiliate of Oaktree, which was Crimson's largest stockholder at the time (the “Second Lien Credit Agreement”). The Second Lien Credit Agreement provided for a term loan, made to Crimson in a single draw, in an aggregate principal amount of $175.0 million. In connection with the Merger, the Company assumed and immediately repaid Crimson’s $175.0 million loan under the Second Lien Credit Agreement, plus $1.8 million in interest and prepayment premiums.
Contango ORE, Inc.
Contango Mining Company (“Contango Mining”), a wholly owned subsidiary of the Company, was formed in October 2009 for the purpose of engaging in exploration on properties in the state of Alaska for (i) gold ore and associated minerals and (ii) rare earth elements. Contango Mining initially acquired a 50% interest in these properties in Alaska from JEX in exchange for $1 million and a 1% ORRI in the properties under a Joint Exploration Agreement (the “Joint Exploration Agreement”). We believe JEX expended approximately $1 million on exploratory activities and related work on the properties prior to selling the initial 50% interest to Contango Mining.
In September 2010, Contango Mining acquired the remaining 50% interest in the properties by increasing the ORRI in the properties granted to JEX to 3% pursuant to an Amended and Restated Conveyance of Overriding Royalty Interest (the “Amended ORRI Agreement”). Contango Mining assumed control of the exploration activities and JEX and Contango Mining terminated the Joint Exploration Agreement.
Contango ORE, Inc. ("CORE") was formed on September 1, 2010 as a wholly-owned subsidiary of the Company and in November 2010, Contango Mining assigned the properties and certain other assets and liabilities to Contango. Contango contributed the properties and $3.5 million of cash to CORE, pursuant to the terms of a Contribution Agreement (the “Contribution Agreement”), in exchange for approximately 1.6 million shares of CORE's common stock. The transactions took place between companies under common control. Contango distributed all of CORE's common stock to Contango’s stockholders of record as of October 15, 2010, promptly after the effective date of CORE's Registration Statement Form 10 on the basis of one share of common stock for each ten (10) shares of Contango’s common stock then outstanding.
In November 2011, the Company executed a $1.0 million Revolving Line of Credit Promissory Note to lend money to CORE (the “CORE Note”). The Company and CORE shared executive officers at that time. The CORE Note contained covenants limiting CORE’s ability to enter into additional indebtedness and prohibiting liens on any of its assets or properties. Borrowings under the CORE Note bore interest at 10% per annum. On March 30, 2012 the Company received repayment of the $500,000 it had advanced under the CORE Note, plus accrued interest of approximately $15,000. The CORE Note was terminated on December 31, 2012.
Equity Compensation
In February 2012, the Company net-settled 45,000 stock options from two employees for a total of approximately $465,000. All settlements were approved by the Company’s board of directors and were completed at the closing price of the Company’s common stock on the date of settlement.

Discontinued_Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Discontinued Operations	'
	Discontinued Operations
	Joint Venture Assets
	In October 2009, the Company entered into a joint venture with Patara Oil & Gas LLC (“Patara”) to develop proved undeveloped reserves. B.A. Berilgen, a member of the Company’s board of directors, was the Chief Executive Officer of Patara at the time. In May 2011, the Company sold to Patara its 90% working interest and 5% overriding royalty interest in the 21 wells drilled under this joint venture for approximately $36.2 million and recognized a pre-tax loss of approximately $0.7 million. These 21 wells had proved reserves of approximately 16,700 Mmcfe, net to Contango. The Company accounted for this sale as discontinued operations as of December 31, 2011 and has included the results of the joint venture operations in discontinued operations for all periods presented. The summarized financial results for the joint venture assets for the periods ended December 31, 2012 and 2011 are as follows (in thousands):
		December 31,
		2012			2011
	Revenues	$	—		$	3,939
	Operating expenses	(40		)	(827		)
	Depletion expenses	—			(1,755		)
	Loss on sale	—			(651		)
	Income (loss) before income taxes	$	(40	)	$	706
	Benefit (provision) for income taxes	14			(459		)
	Income (loss) from discontinued operations, net of income taxes	$	(26	)	247
	Rexer Assets
	In May 2011, the Company sold to Patara its (i) 100% working interest (72.5% net revenue interest) in Rexer #1 drilled in south Texas; and (ii) 75% working interest (54.4% net revenue interest) in Rexer-Tusa #2 for approximately $2.5 million and recognized a pre-tax loss of approximately $0.3 million. The Rexer #1 well had proved reserves of approximately 0.5 Bcfe, net to Contango, while the Rexer-Tusa #2 had not been spud at the time of sale.
	In October 2011, the Company sold its remaining 25% working interest (18.4% net revenue interest) in Rexer-Tusa #2 for $10,000 to Patara. The Company has accounted for the sale of the Rexer #1 and Rexer-Tusa #2 as discontinued operations as of December 31, 2012 and has included the results of these operations as discontinued operations for all periods presented. The summarized financial results for these Rexer assets for the periods ended December 31, 2012 and 2011 are as follows (in thousands):
		December 31,
		2012			2011
	Revenues	$	—		$	1,175
	Operating expenses	(5		)	(169		)
	Depletion expenses	—			(1,821		)
	Impairment of natural gas and oil properties	—			(1,031		)
	Exploration expenses	—			(8		)
	Loss on sale	—			$	(273	)
	Loss before income taxes	$	(5	)	$	(2,127	)
	Benefit for income taxes	2			744
	Loss from discontinued operations, net of income taxes	$	(3	)	$	(1,383	)
	Contango Mining Company
	On September 29, 2010, Contango ORE, Inc. (“CORE”), then a wholly-owned subsidiary of the Company, filed with the Securities and Exchange Commission a Registration Statement on Form 10 which became effective November 29, 2010. Following the effective date, CORE acquired the assets and assumed the liabilities of Contango Mining Company (“Contango Mining”), another wholly-owned subsidiary of the Company. Additionally, subsequent to the effective date, the Company contributed $3.5 million of cash to CORE. In exchange, CORE issued 1,566,367 shares of its common stock to the Company in addition to the 100 shares which the Company held prior to that date. The Company distributed all its shares of CORE, valued at approximately $7.3 million, to its stockholders of record as of October 15, 2010 on the basis of one share of common stock of CORE for each ten shares of the Company’s common stock then outstanding. In addition to the distribution of shares of CORE, in 2010 the Company paid $6,213 in cash to its stockholders of record in exchange for partial shares. As of December 31, 2013 and 2011, the assets and liabilities of Contango Mining were excluded from the Company’s financial statements. No income or expenses related to CORE were recognized for the year ended December 31, 2013, 2012 or 2011.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	We have evaluated subsequent events through the date the financial statements were available to be issued. Nothing that would require recognition or disclosure in the financial statements were identified in addition to the items disclosed in the financial statements.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Principles of Consolidation	'
	Basis of Presentation
	The Company’s consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America and include the accounts of Contango Oil & Gas Company and its subsidiaries, after elimination of all material intercompany balances and transactions. All wholly-owned subsidiaries are consolidated. Oil and gas exploration and development affiliates which are not controlled by the Company, such as REX, are proportionately consolidated. Financial statements as of December 31, 2013 and 2012 and for the three years ended December 31, 2013 contained herein, include consolidated results of operations of both Contango Oil and Gas Company ("Contango") and Crimson for the period from the closing date of the Merger to December 31, 2013 and only consolidated financial statements of Contango for all other the periods presented herein.
	Financial statements as of December 31, 2013 and 2012 and for the three years ended December 31, 2013 include consolidated results of operations of both Contango and Crimson for the period from the closing of the Merger on October 1, 2013 to December 31, 2013 and consolidated financial statements of Contango only for all other periods.
Change of Year-End	'
	Change of Year-End
	On October 1, 2013 the Company's board of directors approved a change in fiscal year end from June 30 to December 31, commencing with the twelve-month period beginning on January 1, 2014. Unless otherwise noted, all references to "years" in this report refer to the twelve-month period which ends on December 31 of each year. As a result of this change, on March 3, 2014 we filed a Transition Report on Form 10-K for the six-month period ended December 31, 2013. This Annual Report on Form 10-K/A is filed to present a recast of historical financial information for the three-year period ending on December 31, 2013.
Other Investments, cost method	'
	Contango’s 19.5% ownership of Moblize Inc. (“Moblize”) and 2.0% indirect ownership of Alta Energy Canada Partnership, LLC ("Alta") are accounted for using the cost method. Under the cost method, Contango records an investment at cost, and recognizes dividends or distributions received as income. Dividends received in excess of earnings subsequent to the date of investment are considered a return of investment and are recorded as reductions of cost of the investment. During the year ended December 31, 2013, the Company had a significant distribution from Alta in excess of its original investment. The gain in excess of the original investment is included in the Gain (loss) from sale of assets and return on investments line item in the Company's income statement and in the investing cash flows in the Company's Cash Flow Statement for the year ended December 31, 2013.
Other Investments, equity method	'
	The Company has two seats on the board of directors of Exaro and has significant influence, but not control, over the company. As a result, the Company's 37% ownership in Exaro is accounted for using the equity method. Under the equity method, the Company's proportionate share of Exaro's net income increases the balance of our investment in Exaro, while a net loss or payment of dividends decreases our investment. In our consolidated statement of operations, our proportionate share of Exaro's net income or loss is reported as a single line-item in Gain (loss) from investment in affiliates (net of income taxes).
Use of Estimates	'
	Use of Estimates
	The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America 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 periods. The most significant estimates include oil and gas revenues, income taxes, stock-based compensation, reserve estimates, impairment of natural gas and oil properties, valuation of derivatives, and accrued liabilities. Actual results could differ from those estimates.
Revenue Recognition	'
	Revenue Recognition
	Revenues from the sale of natural gas and oil produced are recognized upon the passage of title, net of royalties. Revenues from natural gas production are recorded using the sales method. When sales volumes exceed the Company’s entitled share, production imbalance occurs. If production imbalance exceeds the Company’s share of the remaining estimated proved natural gas reserves for a given property, the Company records a liability.
Cash Equivalents	'
	Cash Equivalents
	Cash equivalents are considered to be highly liquid investment grade debt investments having an original maturity of 90 days or less.
Accounts Receivable	'
	Accounts Receivable
	The Company sells natural gas and crude oil to a limited number of customers. In addition, the Company participates with other parties in the operation of natural gas and crude oil wells. Substantially all of the Company’s accounts receivables are due from either purchasers of natural gas and crude oil or participants in natural gas and crude oil wells for which the Company serves as the operator. Generally, operators of natural gas and crude oil properties have the right to offset future revenues against unpaid charges related to operated wells.
	The allowance for doubtful accounts is an estimate of the losses in the Company’s accounts receivable. The Company periodically reviews the accounts receivable from customers for any collectability issues. An allowance for doubtful accounts is established based on reviews of individual customer accounts, recent loss experience, current economic conditions, and other pertinent factors. Amounts deemed uncollectible are charged to the allowance.
Oil and Gas Properties - Successful Efforts	'
	Oil and Gas Properties - Successful Efforts
	The Company follows the successful efforts method of accounting for its natural gas and oil activities. Under the successful efforts method, lease acquisition costs and all development costs are capitalized. Exploratory drilling costs are capitalized until the results are determined. If proved reserves are not discovered, the exploratory drilling costs are expensed. Other exploratory costs, such as seismic costs and other geological and geophysical expenses, are expensed as incurred. Depreciation, depletion and amortization is calculated on a field by field basis using the unit of production method, with lease acquisition costs amortized over total proved reserves and other capitalized costs amortized over proved developed reserves.
	Depreciation, depletion and amortization ("DD&A") of capitalized drilling and development costs of producing natural gas and crude oil properties, including related support equipment and facilities and net of salvage value, are computed using the unit-of-production method on a field basis based on total estimated proved developed natural gas and crude oil reserves. Amortization of producing leaseholds is based on the unit-of-production method using total estimated proved reserves. Upon sale or retirement of properties, the cost and related accumulated depreciation, depletion, and amortization are eliminated from the accounts and the resulting gain or loss, if any, is recognized. Unit-of-production rates are revised whenever there is an indication of a need, but at least annually. Revisions are accounted for prospectively as changes in accounting estimates.
	Other property and equipment are depreciated using the straight-line method over their estimated useful lives which range between three and 13 years.
Impairment of Oil and Gas Properties	'
	Impairment of Oil and Gas Properties
	When circumstances indicate that proved properties may be impaired, the Company compares expected undiscounted future cash flows on a field by field basis to the unamortized capitalized cost of the asset. If the estimated future undiscounted cash flows, based on the Company’s estimate of future reserves, natural gas and oil prices and operating costs and anticipated production levels from oil and natural gas reserves, are lower than the unamortized capitalized cost, then the capitalized cost is reduced to its fair value. No impairment of proved properties was recognized during the years ended December 31, 2013 or 2011. For the year ended December 31, 2012, the Company recorded an impairment expense of approximately $14.1 million related to proved properties. Of this amount, approximately $12.0 million related to our Ship Shoal 263 well and $2.1 million related to the Eugene Island 24 platform and other properties. Despite the write-down of Ship Shoal 263, this well reached payout during the year ended December 31, 2012.
	Unproved properties are reviewed quarterly to determine if there has been impairment of the carrying value, and any such impairment is charged to expense in the period.
Income Taxes	'
	Income Taxes
	The Company follows the liability method of accounting for income taxes under which deferred tax assets and liabilities are recognized for the future tax consequences of (i) temporary differences between the tax basis of assets and liabilities and their reported amounts in the financial statements and (ii) operating loss and tax credit carryforwards for tax purposes. Deferred tax assets are reduced by a valuation allowance when, based upon management’s estimates, it is more likely than not that a portion of the deferred tax assets will not be realized in a future period. The Company reviews its tax positions quarterly for tax uncertainties. The Company did not have significant uncertain tax positions as of December 31, 2013. The amount of unrecognized tax benefits did not materially change from December 31, 2012. The amount of unrecognized tax benefits may change in the next twelve months; however, we do not expect the change to have a significant impact on our financial position or results of operations. The Company includes interest and penalties in interest income and general and administrative expenses, respectively, in its statement of operations.
	The Company files income tax returns in the United States and various state jurisdictions. The Company’s federal tax returns for 2009 – 2013, and state tax returns for 2008 - 2013, remain open for examination by the taxing authorities in the respective jurisdictions where those returns were filed.
Concentration of Credit Risk	'
	Concentration of Credit Risk
	Substantially all of the Company’s accounts receivable result from natural gas and oil sales or joint interest billings to a limited number of third parties in the natural gas and oil industry. This concentration of customers and joint interest owners may impact the Company’s overall credit risk in that these entities may be similarly affected by changes in economic and other conditions.
Debt Issuance Costs	'
	Debt Issuance Costs
	Debt issuance costs incurred are capitalized and subsequently amortized over the term of the related debt. During the year ended December 31, 2013 the Company incurred $2.2 million of debt issuance costs in relation to the new RBC credit facility entered into in conjunction with the Merger with Crimson. The debt issuance costs will be amortized over the original four year term of the credit line with amortization expense included in Depreciation, Depletion and Amortization line item in the Company's income statement for the year ended December 31, 2013.
Stock-Based Compensation	'
	Stock-Based Compensation
	The Company applies the fair value based method to account for stock based compensation. Under this method, compensation cost is measured at the grant date based on the fair value of the award and is recognized over the award vesting period. The Company classifies the benefits of tax deductions in excess of the compensation cost recognized for the options (excess tax benefit) as financing cash flows. The fair value of each award is estimated as of the date of grant using the Black-Scholes option-pricing model.
Inventory	'
	Inventory
	Inventory primarily consists of casing and tubing which will be used for drilling or completion of wells.  Also, included in inventory are items for the repair and maintenance of equipment used on wells and facilities that the Company operates.  Inventory is recorded at the lower of cost or market using specific identification method.
Derivatives Instruments and Hedging Activities	'
	Derivative Instruments and Hedging Activities
	The Company accounts for its derivative activities under the provisions of ASC 815, Derivatives and Hedging (ASC 815). ASC 815 establishes accounting and reporting that every derivative instrument be recorded on the balance sheet as either an asset or liability measured at fair value. From time to time, the Company may hedge a portion of its forecasted oil and natural gas production. Derivative contracts entered into by the Company have consisted of transactions in which the Company hedges the variability of cash flow related to a forecasted transactions using variable to fixed swaps and collars . The Company elected to not designate any of its derivative positions for hedge accounting. Accordingly, the net change in the mark-to-market valuation of these positions as well as all payments and receipts on settled derivative contracts are recognized in "Net loss on derivatives" on the consolidated statements of operations for the year ended December 31, 2013. The Company did not have any derivative instruments or hedging activities for the year ending December 31, 2012 or 2011. Derivative instruments with settlement date within one year are included in current assets or liabilities, whereas derivative instruments with settlement dates exceeding one year are included in non-current assets or liabilities. The Company calculates a net asset or liability for current and non-current derivative instruments for each counterparty based on the settlement dates within the respective contracts.
Reclassifications	'
	Reclassifications
	Certain reclassifications have been made to the presentation of certain balance sheet, income statement and cash flow items in the respective statements for the year ended December 31, 2012 and 2011 in order to conform to the presentation for the year ended December 31, 2013. These reclassifications were not material.
Subsidiary Guarantees	'
	Subsidiary Guarantees
	Contango Oil & Gas Company, as the parent company (the “Parent Company”), filed a registration statement on Form S-3 with the SEC to register, among other securities, debt securities that the Parent Company may issue from time to time. Crimson Exploration Inc., Crimson Exploration Operating, Inc., Contango Energy Company, Contango Operators, Inc., Contango Mining Company, Conterra Company, Contaro Company, Contango Alta Investments, Inc., Contango Venture Capital Corporation and any other of our future subsidiaries specified in the prospectus supplement (each a “Subsidiary Guarantor”) are Co-Registrants with the Parent Company under the registration statement, and the registration statement also registered guarantees of debt securities by the Subsidiary Guarantors. The Subsidiary Guarantors are wholly-owned by the Parent Company, either directly or indirectly, and any guarantee by the Subsidiary Guarantors will be full and unconditional. The Parent Company has no assets or operations independent of the Subsidiary Guarantors, and there are no significant restrictions upon the ability of the Subsidiary Guarantors to distribute funds to the Parent Company. The Parent Company has one other wholly-owned subsidiary that is inactive. Finally, the Parent Company’s wholly-owned subsidiaries do not have restricted assets that exceed 25% of net assets as of the most recent fiscal year end that may not be transferred to the Parent Company in the form of loans, advances or cash dividends by such subsidiary without the consent of a third party.
Recent Accounting Pronouncements	'
	Recent Accounting Pronouncements
	In May 2013, the Committee of Sponsoring Organizations of the Treadway Commission ("COSO"), revised its criteria related to internal controls over financial reporting from the originally established 1992 Internal Control - Integrated Framework with 2013 Internal Control - Integrated Framework. The modified framework provides enhanced guidance that ties control objectives to the related risk, enhancement of governance concepts, increased emphasis on globalization of markets and operations, increased recognition of use and reliance on information technology, increased discussion of fraud as it relates to internal control, changes of control deficiency descriptions, and that internal reporting is included in both financial and nonfinancial objectives. The revised framework is effective for interim and annual periods beginning after December 15, 2013, with early adoption being permitted. We will implement any changes required by the new COSO framework during the year ended December 31, 2014. Currently we are evaluating the provisions of the revised framework and continue to assess the impact, if any, it may have on our internal control structure.
	In February 2013, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2013-04 Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date (ASU 2013-04). ASU 2013-04 provides guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, except for obligations addressed within existing guidance in U.S. GAAP. Examples of obligations within the scope of this update include debt arrangements, other contractual obligations, and settled litigation and judicial rulings. U.S. GAAP does not include specific guidance on accounting for such obligations with joint and several liability, which has resulted in diversity in practice. The accounting update is effective for interim and annual periods beginning after December 15, 2013. We are currently evaluating the provisions of this accounting update and assessing the impact, if any, it may have on our financial position and results of operations.
	Further, management is closely monitoring the joint standard-setting efforts of the FASB and the International Accounting Standards Board. There are a large number of pending accounting standards that are being targeted for completion in 2014 and beyond, including, but not limited to, standards relating to revenue recognition, accounting for leases, fair value measurements, accounting for financial instruments, disclosure of loss contingencies and financial statement presentation. Because these pending standards have not yet been finalized, at this time management is not able to determine the potential future impact that these standards will have, if any, on the Company's financial position, results of operations, or cash flows.
Fair Value Measurements	'
	Estimates of the fair value of financial instruments are made in accordance with the requirements of ASC 825, Financial Instruments. The estimated fair value amounts have been determined at discrete points in time based on relevant market information. These estimates involve uncertainties and cannot be determined with precision. The estimated fair value of cash, accounts receivable and accounts payable approximates their carrying value due to their short-term nature. The estimated fair value of the Company's RBC Credit Facility approximates carrying value because the facilities interest rate approximates current market rates and are re-set at least every three months. See Note 13 - "Long-Term Debt" for further information.
	Fair value estimates used for non-financial assets are evaluated at fair value on a non-recurring basis include oil and gas properties evaluated for impairment, when facts and circumstances indicate that there may be an impairment. If the unamortized cost of properties exceeds the undiscounted cash flows related to the properties, the value of the properties is compared to the fair value estimated as discounted cash flows related to the risk-adjusted proved, probable and possible reserves related to the properties. Fair value measurements based on inputs are classified as Level 3.
Asset Retirement Obligations	'
	Asset Retirement Obligations
	ASC 410, Asset Retirement and Environmental Obligations (ASC 410) requires that the fair value of an asset retirement cost, and corresponding liability, should be recorded as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method. The Company records asset retirement obligations to reflect the Company's legal obligations related to future plugging and abandonment of its oil and natural gas wells, platforms and associated pipelines and equipment. The Company estimates the expected cash flows associated with the obligation and discounts the amounts using a credit-adjusted, risk-free interest rate. At least annually, the Company reassesses the obligation to determine whether a change in the estimated obligation is necessary. The Company evaluates whether there are indicators that suggest the estimated cash flows underlying the obligation have materially changed. Should these indicators suggest the estimated obligation may have materially changed on an interim basis (quarterly), the Company will accordingly update its assessment. Additional retirement obligations increase the liability associated with new oil and natural gas wells, platforms, and associated pipelines and equipment as these obligations are incurred. The liability is accreted to its present value each period and the capitalized cost is depleted over the useful life of the related asset. The accretion expense is included in depreciation, depletion and amortization expense.
	The estimated liability is based on historical experience in plugging and abandoning wells. The estimated remaining lives of the wells is based on reserve life estimates and federal and state regulatory requirements. The liability is discounted using an assumed credit-adjusted risk-free rate.
	Revisions to the liability could occur due to changes in estimates of plugging and abandonment costs, changes in the risk-free rate or changes in the remaining lives of the wells, or if federal or state regulators enact new plugging and abandonment requirements. At the time of abandonment, the Company recognizes a gain or loss on abandonment to the extent that actual costs do not equal the estimated costs. This gain or loss on abandonment is included in impairment and abandonment of oil and gas properties expense.
	The Company accounts for its retirement obligation of long lived assets by recording the net present value of a liability for an asset retirement obligation (“ARO”) in the period in which it is incurred. When the liability is initially recorded, a company increases the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement.

Merger_with_Crimson_Exploratio1

Merger with Crimson Exploration Inc. (Tables)	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Business combination, consideration transferred, assets acquired and liabilities assumed at fair value	'
	The following table summarizes the consideration transferred and preliminary estimates of the fair value of assets acquired, and liabilities assumed as of the date of the Merger (in thousands, except for number of shares and share price):
	Consideration transferred:
	Crimson common stock to be acquired by the Company	46,624,721
	Exchange ratio of the Company common shares for each Crimson common share	0.08288
	The Company common stock to be issued to Crimson stockholders	3,864,101
	Closing price of the Company common stock on October 1, 2013	$	37.75
	Fair value of common stock issued	$	145,870
	Cash paid for partial shares	6
	Fair value of stock options issued	698
	Total estimated consideration transferred	$	146,574
	Fair value of other liabilities assumed:
	Current liabilities	$	60,124
	Long-term debt	235,373
	Asset retirement obligations and other non-current liabilities	10,450
	Amount attributable to liabilities assumed	305,947
	Total consideration including liabilities assumed	$	452,521
	Fair value of assets acquired:
	Current assets	$	13,492
	Current and non-current deferred tax asset, net	24,905
	Natural gas and oil properties, net	413,916
	Other non-current assets	208
	Amount attributable to net assets acquired	$	452,521
	Goodwill	$	—
Schedule of pro forma information from the merger	'
	The following unaudited pro forma summary presents consolidated information of the Company as if the Merger had occurred on January 1, 2012 (in thousands):
			Year Ended December 31,
			2013		2012
			(Unaudited)
	Revenue		$	256,594	$	261,772
	Net income (loss)		$	40,166	$	(83,912	)

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Schedule of fair value information related to derivative instruments	'
	Fair value information for financial assets and (liabilities) was as follows at December 31, 2013 (in thousands):
		Total			Fair Value Measurements Using
		Carrying Value			Level 1		Level 2			Level 3
	Derivatives
	Commodity price contracts - assets	$	76		$	—	$	76		$	—
	Commodity price contracts - liabilities	$	(1,207	)	$	—	$	(1,207	)	$	—

Derivative_Instruments_Tables

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of derivative contracts	'
	The following derivative contracts were in place at December 31, 2013, (fair value in thousands):
	Commodity	Period	Derivative	Volume/Month (1)	Price/Unit (2)	Fair Value
	Crude Oil	Jan 2014-Dec 2014	Swap	7,500 Bbls	$102.10 (4)	$	(558	)
	Crude Oil	Jan 2014-Jun 2014	Swap	2,000 Bbls	$108.07 (4)	(21		)
	Crude Oil	Jan 2014-Dec 2014	Swap	6,000 Bbls	$106.40 (4)	(139		)
	Crude Oil	Jan 2014-Mar 2014	Swap	40,000 Bbls	$97.00 (3)	(171		)
	Crude Oil	Apr 2014-May 2014	Swap	32,000 Bbls	$95.17 (3)	(142		)
	Crude Oil	Jun 2014-Sep 2014	Swap	13,000 Bbls	$93.22 (3)	(91		)
	Crude Oil	Oct 2014-Dec 2014	Swap	11,000 Bbls	$90.61 (3)	(60		)
	Natural Gas	Jan 2014-May 2014	Collar	1,000,000 MMBtu	$4.00 - $4.425 (5)	68
	Natural Gas	Jun 2014-Dec 2014	Collar	120,000 MMBtu	$4.00 - $4.415 (5)	7
	Natural Gas	Jan 2014-Dec 2014	Collar	42,500 MMBtu	$3.75 - $4.60 (5)	(14		)
	Natural Gas	Jan 2014-Dec 2014	Collar	42,500 MMBtu	$3.50 - $5.00 (5)	(10		)
		Total net fair value of derivative instruments				$	(1,131	)
	-1	Average volume per month for the remaining contract term
	-2	Average price per unit for the remaining contract term
	-3	Commodity derivative based on NYMEX West Texas Intermediate crude oil prices
	-4	Commodity derivative based on Brent crude oil prices
	-5	Commodity derivative based on Henry Hub NYMEX natural gas prices
Summary of the fair value of derivatives outstanding on a gross and net basis	'
	The following summarizes the fair value of commodity derivatives outstanding on a gross and net basis as of December 31, 2013 (in thousands):
			31-Dec-13
			Gross				Netting (1)			Total
	Assets		$	76			$	(76	)	$	—
	Liabilities		$	(1,207	)		$	76		$	(1,131	)
	-1	Represents counterparty netting under agreements governing such derivatives
Schedule of effect of derivative contracts on the Consolidated Statements of Operations	'
	The following table summarizes the effect of derivative contracts on the Consolidated Statements of Operations for the year ended December 31, 2013 (in thousands):
	Contract Type		Year ended December 31, 2013
	Crude oil contracts		$	180
	Natural gas contracts		98
	Realized gain		$	278
	Crude oil contracts		$	(1,179	)
	Natural gas contracts		(231		)
	Unrealized loss		$	(1,410	)
	Net loss on derivatives		$	(1,132	)

Stock_Based_Compensation_Table

Stock Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Stock options granted under the 1999 Plan and 2009 Plan	'
	A summary of the stock options granted under the 1999 Plan, 2009 Plan, and 2005 Plan as of and for the years ended December 31, 2013, 2012, and 2011 is presented in the table below (dollars in thousands, except per share data):
		Year Ended December 31,
		2013							2012					2011
		Shares				Weighted			Shares			Weighted		Shares		Weighted
		Under				Average			Under			Average		Under		Average
		Options				Exercise			Options			Exercise		Options		Exercise
						Price						Price				Price
	Outstanding, beginning of the period	—				—			45,000			$	54.21	45,000		$	54.21
	Options assumed due to Merger	135,898				$	52.9		—			$	—	—		$	—
	Exercised	(791		)		$	36.16		—			$	—	—		$	—
	Canceled / Forfeited (1)	—							(45,000		)	$	54.21	—		$	—
	Outstanding, end of year	135,107				$	53		—			$	—	45,000		$	54.21
	Aggregate intrinsic value	$	459						$	—				$	179
	Exercisable, end of year	135,107				$	53		—			$	—	45,000		$	54.21
	Aggregate intrinsic value	$	459						$	—				$	179
	Available for grant, end of the period	1,162,173							1,475,000					1,475,000
	Weighted average fair value of options granted during the period	$	—						$	—				$	—
	-1	For the year ended December 31, 2012, forfeited options consist of options that were net-settled for cash with the Company.
Summary of restricted stock activity	'
	Restricted stock activity as of December 31, 2013 and for the year then ended is presented in the table below (dollars in thousands, except per share data):
		Restricted Shares			Weighted			Aggregate Intrinsic Value
					Average
					Fair Value
	Outstanding, beginning of the period	—						$0
	Granted	356,299			$	44.1		$	15,723
	Vested	(63,667	)		42.8			2,725
	Canceled / Forfeited	—			—			—
	Not vested, end of the period	292,632			44.38			13,830
	Vested, end of the period	—			—			—
	Expected to vest, end of the period	260,359			44.36			12,305

Other_Financial_Information_Ta

Other Financial Information (Tables)	12 Months Ended
	Dec. 31, 2013
Other Financial Information [Abstract]	'
Additional detail for accounts receivable, prepaids, accounts payable and accrued liabilities	'
	The following table provides additional detail for accounts receivable, prepaids, and accounts payable and accrued liabilities which are presented on the consolidated balance sheets (in thousands):
		December 31,
		2013			2012
	Accounts Receivable:
	Trade receivable	$	42,196		$	28,091
	Receivable for Alta Resources distribution	7,358			—
	Joint interest billing	5,172			3,848
	Income taxes receivable	4,293			16,177
	Other receivables	2,172			734
	Allowance for doubtful accounts	(578		)	—
	Total Accounts Receivable	$	60,613		$	48,850
	Prepaid Expenses:
	Prepaid insurance	$	1,113		$	396
	Prepaid capital costs	108			1,727
	Prepaid vendors	486			—
	Other prepaid expenses	324			356
	Total Prepaid Expenses	$	2,031		$	2,479
	Accounts Payable and Accrued Liabilities:
	Royalties and revenue payable	$	44,933		$	22,281
	Accrued exploration and development	17,803			1,208
	Trade payable	11,589			4,335
	Advances from partners	6,538			—
	Accrued bonus and severance	7,273			949
	Accrued general and administrative expenses	3,599			1,279
	Accrued lease operating and workover expense	3,529			2,608
	Taxes payable	236			—
	Other accounts payable and accrued liabilities	1,333			12
	Total Accounts Payable and Accrued Liabilities	$	96,833		$	32,672
Supplemental information about non-cash transactions	'
	Included in the table below is supplemental information about non-cash transactions related to the Merger during the year ended December 31, 2013, in thousands:
		Years Ended December 31,
		2013			2012		2011
	Cash payments:
	Interest payments	$	1,056		$	71	$	49
	Income tax payments	341			24,307		29,961
	Non-cash items excluded from investing activities in the consolidated statements of cash flows:
	Increase (decrease) in accrued capital expenditures	7,004			1,192		(2,315		)
	Assets acquired & liabilities assumed in the Merger:
	Accounts receivable	12,955			—		—
	Prepaids	639			—		—
	Proved natural gas and oil properties	413,916			—		—
	Deferred tax asset and other	24,940			—		—
	Accounts payable and accrued liabilities	(60,110		)	—		—
	Other non-current liabilities	(256		)	—		—
	Long-term debt	(235,373		)	—		—
	Asset retirement obligations	(11,183		)	—		—
	Non-cash items excluded from financing activities in the consolidated statements of cash flows:
	Issuance of common stock in connection with the merger	145,870			—		—

Investment_in_Exaro_Energy_III1

Investment in Exaro Energy III LLC (Tables)	12 Months Ended
	Dec. 31, 2013
Investments, All Other Investments [Abstract]	'
Schedule of Condensed Balance Sheet Data	'
	The following table presents condensed balance sheet data for Exaro as of December 31, 2013 and December 31, 2012. The balance sheet data was derived from the Exaro balance sheet as of December 31, 2013 and December 31, 2012 and was not adjusted to represent our percentage of ownership interest in Exaro. Our share in the equity of Exaro at December 31, 2013 was approximately $50.5 million.
		December 31,
		2013			2012
	Current assets	$	30,284		$	14,377
	Non-current assets:
	Net property and equipment	182,226			55,709
	Restricted cash escrow account	8,732			40,014
	Other non-current assets	1,103			4,886
	Total non-current assets	$	192,061		$	100,609
	Total assets	$	222,345		$	114,986
	Current liabilities	$	13,717		$	17,674
	Non-current liabilities:
	Long-term debt	70,000			8,000
	Other non-current liabilities	923			297
	Total non-current liabilities	$	70,923		$	8,297
	Member's equity	137,705			89,015
	Total liabilities & member's equity	$	222,345		$	114,986
Schedule of Condensed Income Statement Data	'
	The following table presents the condensed results of operations for Exaro for the year ended December 31, 2013 and for the period from the inception of Exaro, March 19, 2012, to December 31, 2012. The results of operations for the year ended December 31, 2013 and the period from inception of Exaro, March 19, 2012, to December 31, 2012 were derived from Exaro's financial statements for the respective periods. The income statement data below was not adjusted to represent our ownership interest but rather reflects the results of Exaro as a Company. The Company's share in Exaro's results of operations recognized for the years ended December 31, 2013 and 2012 was a gain of $2.3 million, net of tax expense of $1.2 million, and a gain of $60 thousand, net of tax expense of $32 thousand, respectively.
		Year ended December 31, 2013			Period from inception to December 31, 2012
	Oil and natural gas sales	$	52,698		$	7,514
	Other loss	(544		)	(3,269		)
	Less:
	Lease operating expenses	16,136			2,035
	Depreciation, depletion, amortization & accretion	16,058			2,350
	General & administrative expense	3,294			2,872
	Income/(loss) from continuing operations	$	16,666		$	(3,012	)
	Net interest income/(expense)	(3,536		)	25
	Net income (loss)	$	13,130		$	(2,987	)
	Included in Other losses are realized and unrealized losses attributable to derivatives, whose value is likely to change based on future oil and gas prices. Exaro's results of operations do not include income taxes, because Exaro is treated as a partnership for tax purposes.

Asset_Retirement_Obligation_Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Schedule of Change in Asset Retirement Obligation	'
	Activities related to the Company’s ARO during the year ended December 31, 2013 and 2012 were as follows (in thousands):
		Year ended December 31,
		2013			2012
	Balance as of the beginning of the period	$	8,678		$	8,704
	Liabilities incurred during period	14,145			2,005
	Liabilities settled during period	(207		)	(2,037		)
	Accretion	660			478
	Change in estimate	58			(472		)
	Balance as of the end of the period	$	23,334		$	8,678

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Long-Term Debt	'
	As of December 31, 2013 and 2012, the Company had the following debt balances (in thousands):
		December 31,
		2013		2012
	RBC Credit Facility (weighted average interest rate in effect at December 31, 2013 was 2.1875%)	90,000		—
	Total long-term debt	$	90,000	$	—

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Minimum Future Lease Operating Leases	'
	As of December 31, 2013, minimum future lease payments for delay rentals and operating leases for our fiscal years are as follows (in thousands):
	Fiscal years ending December 31,
	2014	$	4,503
	2015	2,103
	2016	1,595
	2017	1,378
	2018	1,109
	2019 and thereafter	269
	Total	$	10,957

Net_Income_Loss_Per_Common_Sha1

Net Income (Loss) Per Common Share (Tables)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Components Of Basic And Diluted Net Income Per Share Of Common Stock	'
	A reconciliation of the components of basic and diluted net income per common share for the years ended December 31, 2013, 2012 and 2011 is presented below (in thousands, except per share amounts):
		Year Ended December 31, 2013
		Net Income			Shares	Per Share
	Basic Earnings per Share:
	Net income attributable to common stock	$	41,362		16,156	$	2.56
	Diluted Earnings per Share:
	Effect of potential dilutive securities:
	Stock options, weighted average of incremental shares	$	—		2	—
	Net income attributable to common stock	$	41,362		16,158	$	2.56
		Year Ended December 31, 2012
		Net Loss			Shares	Per Share
	Basic Earnings per Share:
	Loss from continuing operations	$	(907	)	15,295	$	(0.06	)
	Discontinued operations, net of income taxes	(29		)	15,295	0
	Net loss attributable to common stock	$	(936	)	15,295	$	(0.06	)
	Diluted Earnings per Share:
	Loss from continuing operations	$	(907	)	15,295	$	(0.06	)
	Discontinued operations, net of income taxes	(29		)	15,295	0
	Net loss attributable to common stock	$	(936	)	15,295	$	(0.06	)
		Year Ended December 31, 2011
		Net Income (loss)			Shares	Per Share
	Basic Earnings per Share:
	Income from continuing operations	$	69,909		15,582	$	4.49
	Discontinued operations, net of income taxes	(1,204		)	15,582	(0.08		)
	Net income attributable to common stock	$	68,705		15,582	$	4.41
	Diluted Earnings per Share
	Effect of potential dilutive securities:
	Stock options, weighted average of incremental shares				3
	Income from continuing operations	$	69,909		15,585	$	4.49
	Discontinued operations, net of income taxes	(1,204		)	15,585	(0.08		)
	Net income attributable to common stock	$	68,705		15,585	$	4.41

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Schedule of Effective Income Tax Rate Reconciliation	'
	Actual income tax expense from continuing operations differs from income tax expense from continuing operations computed by applying the U.S. federal statutory corporate rate of 35 percent to pretax income as follows (dollars in thousands):
		Year Ended December 31,
		2013						2012						2011
	Provision/(benefit) at statutory tax rate	$	23,011		35	%		$	(94	)		35	%	$	38,056		35	%
	State income tax provision, net of federal benefit	2,928			4.45	%		654				(241.84	)%	2,960			2.72	%
	Permanent differences	(1,559		)	(2.37	)%		450				(166.34	)%	(2,223		)	(2.04	)%
	Other	4			0.01	%		(373		)		137.65	%	28			0.03	%
	Income tax provision /(benefit)	$	24,384		37.09	%		$	637			(235.53	)%	$	38,821		35.71	%
Components Of Income Tax Expense (Benefit)	'
	The provision (benefit) for income taxes from continuing operations for the periods indicated are comprised of the following (in thousands):
		Year Ended December 31,
		2013			2012				2011
	Current:
	Federal	$	8,739		$	7,038			$	31,743
	State	3,857			2,168				3,461
	Total	$	12,596		$	9,206			$	35,204
	Deferred:
	Federal	$	11,361		$	(8,343	)		$	4,599
	State	427			(226		)		(982		)
	Total	$	11,788		$	(8,569	)		$	3,617
	Total:
	Federal	$	20,100		$	(1,305	)		$	36,342
	State	4,284			1,942				2,479
	Total	$	24,384		$	637			$	38,821
	Included in gain/loss from affiliates	1,245			32				—
	Total income tax provision (benefit)	$	23,139		$	605			$	38,821
Schedule of Net Deferred Tax Liability	'
	The net deferred tax liability is comprised of the following (in thousands):
		December 31,
		2013			2012
	Deferred tax assets:
	Net operating loss carryforward	$	49,204		$	—
	Income tax credits	2,676			—
	Derivative instruments	564			—
	Deferred compensation	406			—
	Other	1,165			—
	Total deferred tax assets before valuation allowance	$	54,015		$	—
	Valuation allowance	(2,552		)	—
	Net deferred tax assets	$	51,463		$	—
	Deferred tax liability:
	Oil and gas properties	$	(133,894	)	$	(109,538	)
	Investment in affiliates	(21,681		)	(6,320		)
	Other	(518		)	—
	Deferred tax liability	$	(156,093	)	$	(115,858	)
	Total net deferred tax liability	$	(104,630	)	$	(115,858	)
Schedule of Unrecognized Tax Benefits	'
	A reconciliation of the beginning and ending amount of unrecognized income tax benefits is as follows (in thousands):
			Unrecognized Tax Benefits
	Balance at December 31, 2012		$	—
	Additions based on tax positions related to the current year		—
	Additions based on tax positions related to prior years		—
	Additions due to acquisitions		518
	Reductions due to a lapse of the applicable statute of limitations		—
	Balance at December 31, 2013		$	518

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Schedule of Oil and Gas Ownership Interests	'
	As of December 31, 2013, Contango, Olympic, JEX, REX and JEX employees owned the following interests in the Company's offshore wells.
		Contango					Olympic					JEX					REX				JEX Employees
		WI		NRI			WI		NRI			WI		NRI			WI		NRI		ORRI
	Dutch #1 - #5	54.89	%	44.65	%		3.53	%	2.84	%		1.88	%	1.51	%		—	%	—	%	2.02%
	Mary Rose #1	53.21	%	40.44	%		3.61	%	2.7	%		2.01	%	1.51	%		—	%	—	%	2.79%
	Mary Rose #2 - #3	53.21	%	38.67	%		3.61	%	2.58	%		2.01	%	1.44	%		—	%	—	%	2.79%
	Mary Rose #4	34.58	%	25.49	%		2.34	%	1.7	%		1.31	%	0.95	%		—	%	—	%	1.82%
	Mary Rose #5	37.8	%	27.88	%		2.56	%	1.87	%		1.43	%	1.04	%		—	%	—	%	1.54%
	Ship Shoal 263	100	%	80	%		—	%	—	%		—	%	—	%		—	%	—	%	3.33%
	Vermilion 170	83.2	%	64.83	%		—	%	—	%		4.3	%	3.35	%		12.5	%	9.74	%	3.33%
	Prior to December 2013, Contango, Olympic, and JEX had the following lower WI and NRI in Dutch #1-#5, as a result of exercising a preferential right in December 2013:
		Contango				Olympic					JEX
		WI	NRI			WI		NRI			WI	NRI
	Dutch #1 - #5	47.05%	38.12	%		3.02	%	2.42	%		1.61%	1.29%
Schedule of Payments Received from (made to) JEX and REX	'
	Below is a summary of payments received from (paid to) Olympic, JEX, and REX in the ordinary course of business in our capacity as operator of the wells and platforms for the periods indicated. The Company made and received similar types of payments with other well owners (in thousands):
		Year ended December 31,
		2013										2012									2011
		Olympic			JEX			REX				Olympic			JEX			REX			Olympic			JEX			REX
	Revenue payments as well owners	$	(6,859	)	$	(4,628	)	$	(1,932	)		$	(6,888	)	$	(5,230	)	$	(4,308	)	$	(9,669	)	$	(5,393	)	$	(816	)
	Joint interest billing receipts	945			1,201			2,090				1,081			724			885			1,867			1,069			3,229
	Dutch well cost adjustment	—			—			—				—			—			—			(389		)	161			(957		)
	Mary Rose well cost adjustment	—			—			—				(201		)	118			(1,185		)	—			—			—
	Below is a summary of payments received from (paid to) Olympic, JEX and REX as a result of specific transactions between the Company, Olympic, JEX and REX. While these payments are in the ordinary course of business, the Company did not have similar transactions with other well owners (in thousands):
		Year ended December 31,
		2013										2012									2011
		Olympic			JEX			REX				Olympic			JEX			REX			Olympic			JEX			REX
	Sale of interest in Mary Rose #5	$	—		$	—		$	—			$	—		$	—		$	—		$	—		$	8		$	—
	Reimbursement of certain costs	—			(115		)	(4		)		—			(496		)	(9		)	—			(185		)	(149		)
	Prospect fees	—			(1,000		)	—				—			—			—			—			(250		)	—
	Advisory Agreements	—			(361		)	—				—			(1,530		)	—			—			—			—
	REX distribution to members	—			—			(197		)		—			—			1,469			—			—			—
	As of December 31, 2013 and 2012, the Company's consolidated balance sheets reflected the following balances (in thousands):
		31-Dec-13										31-Dec-12
		Olympic			JEX			REX				Olympic			JEX			REX
	Accounts receivable:
	Trade receivable	$	—		$	—		$	—			$	2		$	1		$	1
	Joint interest billing	34			87			116				79			85			78
	Accounts payable:
	Royalties and revenue payable	(1,293		)	(877		)	(466		)		(1,133		)	(842		)	(642		)
	Joint interest billings	—			—			—				—			(101		)	—

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2013
Joint Venture Assets [Member]	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Summarized Financial Results for Discontinued Operations	'
	The summarized financial results for the joint venture assets for the periods ended December 31, 2012 and 2011 are as follows (in thousands):
		December 31,
		2012			2011
	Revenues	$	—		$	3,939
	Operating expenses	(40		)	(827		)
	Depletion expenses	—			(1,755		)
	Loss on sale	—			(651		)
	Income (loss) before income taxes	$	(40	)	$	706
	Benefit (provision) for income taxes	14			(459		)
	Income (loss) from discontinued operations, net of income taxes	$	(26	)	247
Rexer Assets [Member]	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Summarized Financial Results for Discontinued Operations	'
	The Company has accounted for the sale of the Rexer #1 and Rexer-Tusa #2 as discontinued operations as of December 31, 2012 and has included the results of these operations as discontinued operations for all periods presented. The summarized financial results for these Rexer assets for the periods ended December 31, 2012 and 2011 are as follows (in thousands):
		December 31,
		2012			2011
	Revenues	$	—		$	1,175
	Operating expenses	(5		)	(169		)
	Depletion expenses	—			(1,821		)
	Impairment of natural gas and oil properties	—			(1,031		)
	Exploration expenses	—			(8		)
	Loss on sale	—			$	(273	)
	Loss before income taxes	$	(5	)	$	(2,127	)
	Benefit for income taxes	2			744
	Loss from discontinued operations, net of income taxes	$	(3	)	$	(1,383	)

Organization_and_Business_Deta

Organization and Business (Details)	12 Months Ended
	Dec. 31, 2013	Oct. 01, 2013	Dec. 31, 2012
	ft
Gas and Oil Acreage [Line Items]	'	'	'
Common stock issued in exchange for all of Crimson's outstanding capital stock	24,356,236	3,900,000	20,135,107
Oil and Gas Operations, Water Depth (less than 300 feet)	300	'	'
Tuscaloosa Marine Shale [Member]	'	'	'
Gas and Oil Acreage [Line Items]	'	'	'
Gas and Oil Area, Undeveloped, Net (in acres)	29,000	'	'
Crimson [Member]	'	'	'
Gas and Oil Acreage [Line Items]	'	'	'
Conversion rate for crimson stock	'	0.08288	'
Business Acquisition, Percentage of Voting Interests Acquired	'	20.30%	'

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Details) (USD $)

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Apr. 30, 2012

Dec. 31, 2013

Dec. 31, 2013

lease_block

RBC Credit Facility [Member]

Ship Shoal 263 [Member]

Eugene Island 24 [Member]

Ship Shoal 83 [Member]

Brazos 543 [Member]

Minimum [Member]

Maximum [Member]

Exaro Energy III LLC [Member]

Exaro Energy III LLC [Member]

Moblize, Inc. [Member]

Alta Energy [Member]

Other Capitalized Property Plant and Equipment [Member]

Other Capitalized Property Plant and Equipment [Member]

board_of_director_seat

Significant Accounting Policies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost method investment ownership percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

19.50%

2.00%

Number of seats on Board of Directors

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

Equity method investment, ownership percentage

'

'

'

'

'

'

'

'

'

'

'

37.00%

37.00%

'

'

Gas balancing asset (liability)

$0

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash and cash equivalents

0

79,487,000

151,940,000

43,435,000

'

'

'

'

'

'

'

'

'

'

'

Allowance for doubtful accounts

578,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

Property and equipment depreciation, estimated useful life

'

'

'

'

'

'

'

'

'

'3 years

'13 years

'

'

'

'

Impairment of proved properties

0

14,100,000

0

'

'

12,000,000

2,100,000

'

'

'

'

'

'

'

'

Impairment charges, unproved properties

'

0

1,700,000

'

'

'

'

600,000

200,000

'

'

'

'

'

'

Unproven lease blocks

'

'

14

'

'

'

'

'

'

'

'

'

'

'

'

Debt issuance costs incurred

'

'

'

'

2,200,000

'

'

'

'

'

'

'

'

'

'

Original term of credit line

'

'

'

'

'4 years

'

'

'

'

'

'

'

'

'

'

Restricted assets, percent of net assets

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding checks in accounts payable that have not yet been presented for payment

$5,900,000

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

Concentration_of_Credit_Risk_D

Concentration of Credit Risk (Details)	12 Months Ended
	Dec. 31, 2013
Concentration Risk [Line Items]	'
Number of Months of Potential Revenue Loss	'2 months
Sales Revenue, Goods, Net [Member] | ConocoPhillips Company [Member] | Customer Concentration Risk [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	48.00%
Sales Revenue, Goods, Net [Member] | Shell Trading US Company [Member] | Customer Concentration Risk [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	16.00%
Sales Revenue, Goods, Net [Member] | Sunoco Inc [Member] | Customer Concentration Risk [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	9.00%
Sales Revenue, Goods, Net [Member] | Enterprise Products Operating LLC [Member] | Customer Concentration Risk [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	7.00%
Sales Revenue, Goods, Net [Member] | Exxon Mobil Oil Corp. [Member] | Customer Concentration Risk [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	7.00%

Merger_with_Crimson_Exploratio2

Merger with Crimson Exploration Inc. - Narrative (Details) (USD $)

0 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Oct. 01, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Oct. 01, 2013

Dec. 31, 2013

Oct. 22, 2010

Oct. 01, 2013

Oct. 01, 2013

Dec. 31, 2013

Dec. 31, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Dec. 31, 2013

RBC Credit Facility [Member]

RBC Credit Facility [Member]

Amegy Bank Credit Agreement [Member]

Debt Assumed from Crimson Acquisition [Member]

Crimson [Member]

Crimson [Member]

Crimson [Member]

Crimson [Member]

Crimson [Member]

Crimson [Member]

Crimson [Member]

General and Administrative Expense [Member]

Rate

Barclays [Member]

Wells Fargo [Member]

Minimum [Member]

Maximum [Member]

Crimson [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Conversion rate for crimson stock

'

'

'

'

'

'

'

'

0.08288

'

'

'

'

'

'

'

The Company common stock to be issued to Crimson stockholders

'

'

'

'

'

'

'

'

3,864,101

'

'

'

'

'

'

'

Business Acquisition, Percentage of Voting Interests Acquired

'

'

'

'

'

'

'

'

20.30%

'

'

'

'

'

'

'

Common stock shares acquired

'

'

'

'

'

'

'

'

46,624,721

'

'

'

'

'

'

'

Stock options issued pursuant to acquisition

'

'

'

'

'

'

'

'

136,000

'

'

'

'

'

'

'

Closing price of the Company common stock on October 1, 2013

'

'

'

'

'

'

'

'

$37.75

'

'

'

'

'

'

'

Minimum risk free interest rate

'

'

'

'

'

'

'

'

0.62%

'

'

'

'

'

'

'

Maximum risk free interest rate

'

'

'

'

'

'

'

'

1.35%

'

'

'

'

'

'

'

Average expected term (in years)

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years 8 months 12 days

'4 years 9 months 15 days

'

Minimum expected volatility rate

'

'

'

'

'

'

'

'

29.30%

'

'

'

'

'

'

'

Maximum expected volatility rate

'

'

'

'

'

'

'

'

38.60%

'

'

'

'

'

'

'

Expected dividend yields

'

'

'

'

'

'

'

'

0.00%

'

'

'

'

'

'

'

Weighted average fair value per share for the options (in USD per share)

'

'

'

'

'

'

'

'

$5.14

'

'

'

'

'

'

'

Long-term debt

'

'

'

'

'

'

'

'

'

'

'

$175,000,000

$58,600,000

'

'

'

Accrued interest and pre-payment penalty

'

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

Revolving credit facility, maximum borrowing capacity

'

'

'

'

500,000,000

'

40,000,000

'

'

'

'

'

'

'

'

'

Revolving credit facility, expiration period

'

'

'

'

'4 years

'

'

'

'

'

'

'

'

'

'

'

Revolving credit facility, borrowing base

'

'

'

'

275,000,000

'

'

'

'

'

'

'

'

'

'

'

Credit facility fees

'

'

'

'

2,200,000

'

'

'

'

'

'

'

'

'

'

'

Assumed debt, accrued interest, and prepayment premium

'

'

'

'

'

'

'

'

235,373,000

'

'

'

'

'

'

'

Repayment of long-term debt

127,600,000

235,373,000

0

0

'

'

'

127,600,000

'

'

'

'

'

'

'

'

Drawings on credit facility

'

'

'

'

110,000,000

'

'

'

'

'

'

'

'

'

'

'

Effective interest rate on credit facility

'

'

'

'

'

2.20%

'

'

'

'

'

'

'

'

'

'

Additional deferred tax liability due to basis differences

'

'

'

'

'

'

'

'

42,800,000

'

'

'

'

'

'

'

Provision/(benefit) at statutory tax rate

'

'

'

'

'

'

'

'

'

'

37.00%

'

'

'

'

'

Increase (decrease) in valuation allowance of deferred tax asset

'

'

'

'

'

'

'

'

10,200,000

'

'

'

'

'

'

'

Operating losses

'

'

'

'

'

'

'

'

110,000,000

'

'

'

'

'

'

'

Crimson contributed revenue since acquisition

'

'

'

'

'

'

'

'

'

33,400,000

'

'

'

'

'

'

Crimson contributed income (loss) since acquisition

'

'

'

'

'

'

'

'

'

700,000

'

'

'

'

'

'

Pro forma, depletion adjustment

'

1,900,000

7,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization of debt issuance costs

'

600,000

400,000

'

'

'

'

'

800,000

'

'

'

'

'

'

'

Decrease in interest expense

'

16,000,000

21,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Pro forma, impairment charge adjustment

'

2,900,000

132,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Merger related expenditures

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,800,000

Bankers success fees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,800,000

Accrued bonus expense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,300,000

Stock-based compensation expense

'

'

'

'

'

'

'

'

'

'

5,700,000

'

'

'

'

'

Amortization of debt discount

'

'

'

'

'

'

'

'

$3,700,000

'

'

'

'

'

'

'

Merger_with_Crimson_Exploratio3

Merger with Crimson Exploration Inc. - Consideration Transferred, Liabilities Assumed, Assets Acquired (Details) (Crimson [Member], USD $)	0 Months Ended
In Thousands, except Share data, unless otherwise specified	Oct. 01, 2013
	Rate
Crimson [Member]	'
Consideration transferred:	'
Crimson common stock to be acquired by the Company	46,624,721
Exchange ratio of the Company common shares for each Crimson common share	0.08288
The Company common stock to be issued to Crimson stockholders	3,864,101
Closing price of the Company common stock on October 1, 2013	$37.75
Fair value of common stock issued	$145,870
Cash paid for partial shares	6
Fair value of stock options issued	698
Total estimated consideration transferred	146,574
Fair value of other liabilities assumed:	'
Current liabilities	60,124
Long-term debt	235,373
Asset retirement obligations and other non-current liabilities	10,450
Amount attributable to liabilities assumed	305,947
Total consideration including liabilities assumed	452,521
Fair value of assets acquired:	'
Current assets	13,492
Current and non-current deferred tax asset, net	24,905
Natural gas and oil properties, net	413,916
Other non-current assets	208
Amount attributable to net assets acquired	452,521
Goodwill	$0

Merger_with_Crimson_Exploratio4

Merger with Crimson Exploration Inc. - Pro Forma Information (Details) (Crimson [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Crimson [Member]	'	'
Pro forma merger summary	'	'
Revenue	$256,594	$261,772
Net income (loss)	$40,166	($83,912)

Acquisitions_Dispositions_and_1

Acquisitions, Dispositions and Gains from Affiliates (Details) (USD $)	12 Months Ended		1 Months Ended		1 Months Ended	3 Months Ended	12 Months Ended	3 Months Ended
	Dec. 31, 2013	Aug. 31, 2013	Feb. 28, 2014	Aug. 31, 2013	Dec. 31, 2013	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014
	Alta Energy [Member]	Alta Energy [Member]	Alta Energy [Member]	Kaybob Duvernay [Member]	Dutch Well [Member]	Scenario, Forecast [Member]	Developed and Undeveloped Properties in Madison and Grimes Counties, Southeast Texas [Member]	Developed and Undeveloped Properties in Madison and Grimes Counties, Southeast Texas [Member]
			Subsequent Event [Member]			Dutch Well [Member]		Scenario, Forecast [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'
Percentage of working interest acquired	'	'	'	'	7.84%	'	'	'
Percentage of revenue interest acquired	'	'	'	'	6.53%	'	'	'
Acquisition purchase price	'	'	'	'	$18,800,000	'	'	'
Purchase price adjustment (reduction in purchase price)	'	'	'	'	'	3,800,000	'	400,000
Acquisition purchase price, net	'	'	'	'	'	15,000,000	'	'
Percentage of interest sold	'	'	'	'	'	'	7.10%	'
Aggregate sales price of assets sold	'	'	'	'	'	'	20,000,000	'
Gain on sale of oil and gas property	'	'	'	'	'	'	6,600,000	'
Expected proceeds from sale of investment	'	30,500,000	'	'	'	'	'	'
Cost method investment ownership percentage	'	2.00%	'	5.00%	'	'	'	'
Gain on sale of investments	23,100,000	'	5,400,000	'	'	'	'	'
Accumulated distributions in excess of original investment	'	'	$15,300,000	'	'	'	'	'

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	12 Months Ended
	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Maximum period of interest rate on floating-rate debt	'3 months
Commodity Contract [Member]	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Commodity price contracts - assets	76,000
Commodity price contracts - liabilities	-1,207,000
Level 1 [Member] | Commodity Contract [Member]	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Commodity price contracts - assets	0
Commodity price contracts - liabilities	0
Level 2 [Member] | Commodity Contract [Member]	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Commodity price contracts - assets	76,000
Commodity price contracts - liabilities	-1,207,000
Level 3 [Member] | Commodity Contract [Member]	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Commodity price contracts - assets	0
Commodity price contracts - liabilities	0

Derivative_Instruments_Details

Derivative Instruments (Details) (Commodity Contract [Member], Not Designated as Hedging Instrument [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
	MBbls
Derivative [Line Items]	'
Fair Value, Asset (Liability)	($1,131)
January 2014 to December 2014 Term [Member] | Brent Crude Oil [Member] | Swap [Member]	'
Derivative [Line Items]	'
Volume/Month (in Bbls)	7.5
Price/Unit (in USD per Bbls)	102.1
Fair Value, Asset (Liability)	-558
January 2014 to December 2014 Term [Member] | Henry Hub NYMEX Natural Gas [Member] | Costless Collar [Member]	'
Derivative [Line Items]	'
Volume/Month (in MMBtu)	42,500
Floor Price (in USD per MMBtu)	3.75
Cap Price (in USD per MMBtu)	4.6
Fair Value, Asset (Liability)	-14
January 2014 to June 2014 Term [Member] | Brent Crude Oil [Member] | Swap [Member]	'
Derivative [Line Items]	'
Volume/Month (in Bbls)	2
Price/Unit (in USD per Bbls)	108.07
Fair Value, Asset (Liability)	-21
January 2014 to December 2014 Term Two [Member] | Brent Crude Oil [Member] | Swap [Member]	'
Derivative [Line Items]	'
Volume/Month (in Bbls)	6
Price/Unit (in USD per Bbls)	106.4
Fair Value, Asset (Liability)	-139
January 2014 to December 2014 Term Two [Member] | Henry Hub NYMEX Natural Gas [Member] | Costless Collar [Member]	'
Derivative [Line Items]	'
Volume/Month (in MMBtu)	42,500
Floor Price (in USD per MMBtu)	3.5
Cap Price (in USD per MMBtu)	5
Fair Value, Asset (Liability)	-10
January 2014 to March 2014 [Member] | West Texas Intermediate Crude Oil [Member] | Swap [Member]	'
Derivative [Line Items]	'
Volume/Month (in Bbls)	40
Price/Unit (in USD per Bbls)	97
Fair Value, Asset (Liability)	-171
April 2014 to May 2014 Term [Member] | West Texas Intermediate Crude Oil [Member] | Swap [Member]	'
Derivative [Line Items]	'
Volume/Month (in Bbls)	32
Price/Unit (in USD per Bbls)	95.17
Fair Value, Asset (Liability)	-142
June 2014 to September 2014 Term [Member] | West Texas Intermediate Crude Oil [Member] | Swap [Member]	'
Derivative [Line Items]	'
Volume/Month (in Bbls)	13
Price/Unit (in USD per Bbls)	93.22
Fair Value, Asset (Liability)	-91
October 2014 to December 2014 Term [Member] | West Texas Intermediate Crude Oil [Member] | Swap [Member]	'
Derivative [Line Items]	'
Volume/Month (in Bbls)	11
Price/Unit (in USD per Bbls)	90.61
Fair Value, Asset (Liability)	-60
January 2014 to May 2014 Term [Member] | Henry Hub NYMEX Natural Gas [Member] | Costless Collar [Member]	'
Derivative [Line Items]	'
Volume/Month (in MMBtu)	1,000,000
Floor Price (in USD per MMBtu)	4
Cap Price (in USD per MMBtu)	4.425
Fair Value, Asset (Liability)	68
June 2014 to December 2014 Term [Member] | Henry Hub NYMEX Natural Gas [Member] | Costless Collar [Member]	'
Derivative [Line Items]	'
Volume/Month (in MMBtu)	120,000
Floor Price (in USD per MMBtu)	4
Cap Price (in USD per MMBtu)	4.415
Fair Value, Asset (Liability)	$7

Derivative_Instruments_Details1

Derivative Instruments (Details 2) (Commodity derivatives [Member], USD $)	Dec. 31, 2013
Commodity derivatives [Member]	'
Commodity derivatives	'
Gross	$76,000
Netting	-76,000
Total	0
Liabilities:	'
Gross	-1,207,000
Netting	76,000
Total	($1,131,000)

Derivative_Instruments_Details2

Derivative Instruments (Details 3) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Realized gain	$278,000	'	'
Unrealized loss	-1,410,000	'	'
Net loss on derivatives	-1,132,000	0	0
Crude Oil Contracts [Member] | Net Loss on Derivatives [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Realized gain	180,000	'	'
Unrealized loss	-1,179,000	'	'
Natural Gas Contracts [Member] | Net Loss on Derivatives [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Realized gain	98,000	'	'
Unrealized loss	($231,000)	'	'

Stock_Based_Compensation_Detai

Stock Based Compensation (Details) (USD $)	1 Months Ended	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Feb. 29, 2012	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
			1999 Plan, 2009 and 2005 Plan [Member]	1999 Plan, 2009 and 2005 Plan [Member]	1999 Plan, 2009 and 2005 Plan [Member]
			Stock Options [Member]	Stock Options [Member]	Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]	'	'	'	'	'
Outstanding, beginning of year (in shares)	'	'	0	45,000	45,000
Awards granted (in shares)	'	'	135,898	0	0
Exercised (in shares)	'	'	-791	0	0
Forfeited (in shares)	-45,000	-45,000	0	-45,000	0
Outstanding, end of year (in shares)	'	'	135,107	0	45,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price [Roll Forward]	'	'	'	'	'
Outstanding, beginning of year (in dollars per share)	'	'	$0	$54.21	$54.21
Granted (in dollars per share)	'	'	$52.90	$0	$0
Exercised (in dollars per share)	'	'	$36.16	$0	$0
Forfeited (in dollars per share)	'	'	'	$54.21	$0
Outstanding, end of year (in dollars per share)	'	'	$53	$0	$54.21
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]	'	'	'	'	'
Expected to vest, end of the period	'	'	$459	$0	$179
Exercisable, end of year (in shares)	'	'	135,107,000	0	45,000
Exercisable, end of year (in dollars per share)	'	'	$53	$0	$54.21
Aggregate intrinsic value ($000), exercisable	'	'	$459	$0	$179
Available for grant, end of year (in shares)	'	'	1,162,173	1,475,000	1,475,000
Weighted average fair value of options granted during the year (in dollars per share)	'	'	$0	$0	$0

Stock_Based_Compensation_Detai1

Stock Based Compensation (Details 2) (Restricted Stock [Member], USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013
Restricted Stock [Member]	'
Restricted stock activity, shares	'
Outstanding, beginning of the period (in shares)	0
Granted (in shares)	356,299
Vested (in shares)	-63,667
Canceled/Forfeited (in shares)	0
Outstanding, end of the period (in shares)	292,632
Vested, end of the year (in shares)	0
Expected to vest, end of the period (in shares)	260,359
Restricted stock activity, weighted average fair value	'
Outstanding, beginning of the period (in dollars per share)	'
Granted (in dollars per share)	$44.10
Vested (in dollars per share)	$42.80
Non vested, end of the period (in dollars per share)	$44.38
Expected to vest (in dollars per share)	$44.36
Restricted stock activity, intrinsic value	'
Outstanding, beginning of the period	$0
Granted	$15,723,000
Vested	$2,725,000
Canceled / Forfeited	$0
Not vested, end of the period	$13,830,000
Vested, end of the period	$0
Expected to vest, end of the period	$12,305

Stock_Based_Compensation_Narra

Stock Based Compensation Narrative (Details) (USD $)

3 Months Ended

12 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

2 Months Ended

0 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Oct. 01, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Oct. 01, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Feb. 28, 2014

Dec. 02, 2013

Nov. 12, 2013

Nov. 30, 2013

Dec. 20, 2013

Dec. 02, 2013

Nov. 12, 2013

Nov. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 02, 2013

Dec. 31, 2013

Stock Options [Member]

Stock Options [Member]

Stock Options [Member]

Restricted Stock [Member]

2009 Equity Compensation Plan [Member]

2009 Equity Compensation Plan [Member]

2009 Equity Compensation Plan [Member]

Stock Incentive Plan 2005 [Member]

Stock Incentive Plan 2005 [Member]

Stock Incentive Plan 2005 [Member]

Stock Incentive Plan 2005 [Member]

Stock Incentive Plan 2005 [Member]

Stock Incentive Plan 2005 [Member]

Stock Incentive Plan 2005 [Member]

Stock Incentive Plan 2005 [Member]

Stock Incentive Plan 2005 [Member]

Stock Incentive Plan 2005 [Member]

Stock Incentive Plan 2005 [Member]

1999 Plan, 2009 and 2005 Plan [Member]

1999 Plan, 2009 and 2005 Plan [Member]

1999 Plan, 2009 and 2005 Plan [Member]

1999 Plan, 2009 and 2005 Plan [Member]

1999 Plan [Member]

2009 Plan [Member]

2009 and 2005 Plan [Member]

2009 and 2005 Plan [Member]

2009 and 2005 Plan [Member]

2009 and 2005 Plan [Member]

2009 and 2005 Plan [Member]

2009 and 2005 Plan [Member]

2009 and 2005 Plan [Member]

2009 and 2005 Plan [Member]

Cash Incentive Bonus Plan [Member]

Vesting Period 1 [Member]

Vesting Period 1 [Member]

Vesting Period 2 [Member]

Stock Options [Member]

Stock Options [Member]

Restricted Stock [Member]

Common Stock and Stock Options [Member]

Stock Options [Member]

Stock Options [Member]

Stock Options [Member]

Stock Options [Member]

Stock Options [Member]

Stock Options [Member]

Stock Options [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Stock Options [Member]

Stock Options [Member]

Stock Options [Member]

Stock Options [Member]

Stock Options [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Stock Options [Member]

2009 Equity Compensation Plan [Member]

2009 and 2005 Plan [Member]

2009 Equity Compensation Plan [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Maximum [Member]

Maximum [Member]

Subsequent Event [Member]

Stock Options [Member]

Restricted Stock [Member]

Stock Options [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Options available for grant (in shares)

'

'

'

'

'

'

'

'

1,500,000

'

'

'

'

'

43,461

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Option contractual term (in years)

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Vesting period (in years)

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'4 years

'

'4 years

'

'

'

'

'

'

'

'

'

'

'

'4 years

'3 years

'4 years

'

'

'2 years

'1 year

'3 years

Options outstanding (in shares)

'

'

'

'

'

'

'

260,359

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

Granted vested options, contractual term

'

'

'

'

'

'

'

'

'

'

'

'

'7 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Vested, end of the year (in shares)

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

135,107

0

45,000

45,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Options granted, exercise price (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

$135,898

'

$25.70

'

$60.33

'

'

'

$136,428

$52.90

$0

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value of options granted (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

$0

$0

'

'

'

'

'

'

'

'

'

'

$44.10

'

'

'

'

Options exercised in period (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

791

'

'

'

'

'

'

'

'

'

791

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Options vested and exercisable (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

135,107

135,107

'

'

'

'

'

'

'

'

135,107,000

0

45,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock vested in period (in shares)

'

'

'

'

'

'

'

63,667

'

'

63,667

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares withheld from vesting

'

'

'

'

'

'

'

'

'

'

17,459

'

'

'

'

'

'

'

'

34,911

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exercise of stock options, value

'

$29,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock granted in period (in shares)

'

'

'

'

'

'

'

356,299

'

'

312,838

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Vesting percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

25.00%

'

'

'

Shares available for grant

'

'

'

'

'

'

'

'

'

'

1,200,000

43,472

11

11

'

'

'

'

'

'

'

'

1,162,173

1,475,000

1,475,000

'

'

1,158,473

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate intrinsic value of exercies during period

'

'

'

'

7,721

500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Tax benefit from exercise/cancellation of stock options

'

0

254,000

0

0

300,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock option expense

'

'

'

'

0

154,000

179,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock issued (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,700

'

'

'

11,354

'

'

'

'

'

'

'

'

Restricted stock awards issued (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

88,466

254,677

1,802

'

'

'

'

'

'

'

'

'

Weighted average forfeiture rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.70%

'

'

'

'

Value of issued stock after adjustment for estimated forfeiture rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,100,000

'

'

'

'

Restricted stock expense

3,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Compensation expense not yet recognized

'

'

'

'

'

'

'

$11,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share_Repurchase_Programs_Deta

Share Repurchase Programs (Details) (USD $)	1 Months Ended	12 Months Ended		1 Months Ended			12 Months Ended
	Feb. 29, 2012	Dec. 31, 2013	Oct. 01, 2013	Sep. 30, 2011	Sep. 30, 2008	Sep. 30, 2011	Dec. 31, 2013	Dec. 31, 2012
	employee	officer	Revolving Credit Facility [Member]	$100 Million Share Repurchase Program [Member]	$100 Million Share Repurchase Program [Member]	$50 Million Share Repurchase Program [Member]	$50 Million Share Repurchase Program [Member]	$50 Million Share Repurchase Program [Member]
Equity, Class of Treasury Stock [Line Items]	'	'	'	'	'	'	'	'
Approved share repurchase program value	'	'	'	$100,000,000	$100,000,000	$50,000,000	'	'
Treasury shares at cost	'	2,400,000	'	'	2,157,278	'	'	162,214
Average price of shares repurchased (in dollars per share)	'	$46.84	'	'	$46.35	'	'	$51.62
Stock repurchased value	'	110,800,000	'	'	'	'	10,800,000	8,400,000
Stock options, net-settled (in shares)	45,000	45,000	'	'	'	'	'	'
Number of employees net-settled stock options	2	2	'	'	'	'	'	'
Cash used to net-settle awards	465,000	'	'	'	'	'	'	'
Number of shares repurchased during period	'	'	'	'	'	'	197,877	'
Value of repurchase program available for future purchases	'	39,200,000	'	'	'	'	'	'
Share repurchase limit per calendar year	'	'	$1,000,000	'	'	'	'	'

Other_Financial_Information_De

Other Financial Information (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Accounts Receivable:	'	'
Trade receivable	$42,196	$28,091
Receivable for Alta Resources distribution	7,358	0
Joint interest billing	5,172	3,848
Income taxes receivable	4,293	16,177
Other receivables	2,172	734
Allowance for doubtful accounts	-578	0
Total Accounts Receivable	60,613	48,850
Prepaid Expenses:	'	'
Prepaid insurance	1,113	396
Prepaid capital costs	108	1,727
Prepaid vendors	486	0
Other prepaid expenses	324	356
Total Prepaid Expenses	2,031	2,479
Accounts Payable and Accrued Liabilities:	'	'
Royalties and revenue payable	44,933	22,281
Accrued exploration and development	17,803	1,208
Trade payable	11,589	4,335
Advances from partners	6,538	0
Accrued bonus and severance	7,273	949
Accrued general and administrative expenses	3,599	1,279
Accrued lease operating and workover expense	3,529	2,608
Taxes payable	236	0
Other accounts payable and accrued liabilities	1,333	12
Total Accounts Payable and Accrued Liabilities	$96,833	$32,672

Other_Financial_Information_De1

Other Financial Information (Details 2) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash payments:	'	'	'
Interest payments	$1,056	$71	$49
Income tax payments	341	24,307	29,961
Non-cash items excluded from investing activities in the consolidated statements of cash flows:	'	'	'
Increase (decrease) in accrued capital expenditures	7,004	1,192	-2,315
Assets acquired & liabilities assumed in the Merger:	'	'	'
Accounts receivable	12,955	'	'
Prepaids	639	'	'
Proved natural gas and oil properties	413,916	'	'
Deferred tax asset and other	24,940	'	'
Accounts payable and accrued liabilities	-60,110	'	'
Other non-current liabilities	-256	'	'
Long-term debt	-235,373	'	'
Asset retirement obligations	-11,183	'	'
Non-cash items excluded from financing activities in the consolidated statements of cash flows:	'	'	'
Issuance of common stock in connection with the merger	$145,870	'	'

Investment_in_Exaro_Energy_III2

Investment in Exaro Energy III LLC (Details) (USD $)	12 Months Ended			1 Months Ended	12 Months Ended		21 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Apr. 30, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
				Exaro Energy III LLC [Member]	Exaro Energy III LLC [Member]	Exaro Energy III LLC [Member]	Exaro Energy III LLC [Member]
Schedule of Equity Method Investments [Line Items]	'	'	'	'	'	'	'
Future Investment In Affiliates	'	'	'	$67,500,000	'	'	'
Equity method investment, ownership percentage	'	'	'	37.00%	37.00%	'	37.00%
Total Investment Commitment In Affiliates With Other Parties	'	'	'	183,000,000	'	'	'
Payments to Acquire Equity Method Investments	'	'	'	'	13,100,000	'	46,900,000
Equity Method Investments	'	'	'	'	50,500,000	'	50,500,000
Equity Method Investment, Summarized Financial Information [Abstract]	'	'	'	'	'	'	'
Current assets	'	'	'	'	30,284,000	14,377,000	30,284,000
Non-current assets:	'	'	'	'	'	'	'
Net property and equipment	791,023,000	379,981,000	'	'	182,226,000	55,709,000	182,226,000
Restricted cash escrow account	'	'	'	'	8,732,000	40,014,000	8,732,000
Other non-current assets	'	'	'	'	1,103,000	4,886,000	1,103,000
Total non-current assets	'	'	'	'	192,061,000	100,609,000	192,061,000
Total assets	'	'	'	'	222,345,000	114,986,000	222,345,000
Current liabilities	'	'	'	'	13,717,000	17,674,000	13,717,000
Non-current liabilities:	'	'	'	'	'	'	'
Long-term debt	'	'	'	'	70,000,000	8,000,000	70,000,000
Other non-current liabilities	'	'	'	'	923,000	297,000	923,000
Total non-current liabilities	'	'	'	'	70,923,000	8,297,000	70,923,000
Member's equity	'	'	'	'	137,705,000	89,015,000	137,705,000
Total liabilities & member's equity	'	'	'	'	222,345,000	114,986,000	222,345,000
Gain from investment in affiliates (net of income taxes)	2,310,000	60,000	0	'	'	'	'
Included in gain/loss from affiliates	1,245,000	32,000	0	'	'	'	'
Equity Method Investment, Summarized Financial Information, Income Statement [Abstract]	'	'	'	'	'	'	'
Oil and natural gas sales	'	'	'	'	52,698,000	7,514,000	'
Other loss	'	'	'	'	-544,000	-3,269,000	'
Less:	'	'	'	'	'	'	'
Lease operating expenses	'	'	'	'	16,136,000	2,035,000	'
Depreciation, depletion, amortization & accretion	'	'	'	'	16,058,000	2,350,000	'
General & administrative expense	26,512,000	11,265,000	10,614,000	'	3,294,000	2,872,000	'
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	41,362,000	-907,000	69,909,000	'	16,666,000	-3,012,000	'
Net interest income/(expense)	-1,171,000	96,000	-205,000	'	-3,536,000	25,000	'
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	$41,362,000	($936,000)	$68,705,000	'	$13,130,000	($2,987,000)	'

Asset_Retirement_Obligation_De

Asset Retirement Obligation (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Balance as of the beginning of the period	$8,678	$8,704
Liabilities incurred during period	14,145	2,005
Liabilities settled during period	-207	-2,037
Accretion	660	478
Change in estimate	58	-472
Balance as of the end of the period	23,334	8,678
Business Acquisition [Line Items]	'	'
Liabilities incurred during period	14,145	2,005
Liabilities settled	207	2,037
Crimson [Member]	'	'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Liabilities incurred during period	11,200	'
Business Acquisition [Line Items]	'	'
Liabilities incurred during period	11,200	'
New Wells Drilled [Member]	'	'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Liabilities incurred during period	2,900	'
Business Acquisition [Line Items]	'	'
Liabilities incurred during period	2,900	'
Wells Plugged and Abandoned [Member]	'	'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Liabilities settled during period	-137	'
Business Acquisition [Line Items]	'	'
Liabilities settled	137	'
Developed and Undeveloped Properties in Madison and Grimes Counties, Southeast Texas [Member]	'	'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Liabilities settled during period	-70	'
Business Acquisition [Line Items]	'	'
Liabilities settled	$70	'

LongTerm_Debt_Narrative_Detail

Long-Term Debt - Narrative (Details) (USD $)

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

Oct. 01, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Oct. 01, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 22, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Oct. 22, 2010

RBC Credit Facility [Member]

RBC Credit Facility [Member]

RBC Credit Facility [Member]

RBC Credit Facility [Member]

Crimson [Member]

Barclays [Member]

Wells Fargo [Member]

Amegy Bank Credit Agreement [Member]

Amegy Bank Credit Agreement [Member]

Amegy Bank Credit Agreement [Member]

Amegy Bank Credit Agreement [Member]

Amegy Bank Credit Agreement [Member]

Minimum [Member]

Maximum [Member]

Crimson [Member]

Crimson [Member]

LIBOR [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt assumed with merger

'

'

'

'

'

'

'

'

$235,373,000

'

'

'

'

'

'

'

Long-term debt

'

'

'

'

'

'

'

'

'

175,000,000

58,600,000

'

'

'

'

'

Accrued interest and pre-payment penalty

'

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

Repayment of long-term debt

127,600,000

235,373,000

0

0

'

'

'

'

'

'

'

'

'

'

'

'

Revolving credit facility, maximum borrowing capacity

'

'

'

'

500,000,000

'

'

'

'

'

'

40,000,000

'

'

'

'

Revolving credit facility, expiration period

'

'

'

'

'4 years

'

'

'

'

'

'

'

'

'

'

'

Revolving credit facility, borrowing base

'

'

'

'

275,000,000

'

'

'

'

'

'

'

'

'

'

'

Credit facility fees

'

'

'

'

2,200,000

'

'

'

'

'

'

'

'

'

'

'

Proceeds from (Repayments of) Lines of Credit

'

'

'

'

110,000,000

'

'

'

'

'

'

'

'

'

'

'

Credit facility amount outstanding

'

'

'

'

'

90,000,000

'

'

'

'

'

'

'

0

'

'

Letters of Credit Outstanding, Amount

'

1,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Remaining Borrowing Capacity

'

'

'

'

'

183,100,000

'

'

'

'

'

'

'

'

'

'

Commitment fee percentage

'

'

'

'

'

'

0.38%

0.50%

'

'

'

0.13%

'

'

'

'

Interest Expense

'

1,200,000

'

'

'

'

'

'

'

'

'

'

37,000

50,000

133,000

'

Interest rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.50%

Interest rate (floor)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.75%

Arrangement fee

'

'

'

'

'

$2,200,000

'

'

'

'

'

$300,000

'

'

'

'

LongTerm_Debt_Debt_Balances_De

Long-Term Debt - Debt Balances (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
Total long-term debt	$90,000	$0
RBC Credit Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Credit facility amount outstanding	90,000	'
Weighted average interest rate (as a percent)	2.19%	2.19%
Credit Facility with Amegy Bank [Member]	'	'
Debt Instrument [Line Items]	'	'
Credit facility amount outstanding	'	$0

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Delay Rentals and Operating and Capital Leases [Abstract]	'
2014	$4,503
2015	2,103
2016	1,595
2017	1,378
2018	1,109
2019 and thereafter	269
Total	$10,957

Commitment_and_Contingencies_N

Commitment and Contingencies Narrative (Details) (USD $)

12 Months Ended

1 Months Ended

0 Months Ended

0 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 30, 2009

Nov. 30, 2010

Sep. 30, 2012

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Oct. 01, 2013

Oct. 01, 2013

Oct. 01, 2013

Dec. 31, 2013

Jan. 31, 2014

Jefferson Davis Parish Case [Member]

Lavaca County Case [Member]

Litigation Case Filed by Mineral Interest Owner Harris County [Member]

Directors and Officers [Member]

Chief Executive Officer [Member]

Chief Executive Officer [Member]

Chief Executive Officer [Member]

Chief Executive Officer [Member]

Chief Executive Officer [Member]

Chief Executive Officer [Member]

Chief Executive Officer [Member]

Chief Financial Officer [Member]

Chief Financial Officer [Member]

Chief Financial Officer [Member]

Chief Financial Officer [Member]

Chief Financial Officer [Member]

Chief Financial Officer [Member]

Chief Financial Officer [Member]

Directors [Member]

Directors [Member]

Directors [Member]

Directors [Member]

Directors [Member]

Directors [Member]

Director, Isaac [Member]

Director, Mengle [Member]

Director, Atkins [Member]

Other Employees [Member]

Other Employees [Member]

Other Employees [Member]

Other Employees [Member]

Other Employees [Member]

Other Employees [Member]

Other Employees [Member]

Other Employees [Member]

Employee One [Member]

Employees Two and Three [Member]

Exaro Energy III LLC [Member]

Contango [Member]

Crimson [Member]

Crimson [Member]

Crimson [Member]

Subsequent Event [Member]

well

well

Cash Incentive Bonus Plan [Member]

Cash Incentive Bonus Plan [Member]

Cash Incentive Bonus Plan [Member]

Incentive Equity Plan [Member]

Incentive Equity Plan [Member]

Incentive Equity Plan [Member]

Cash Incentive Bonus Plan [Member]

Cash Incentive Bonus Plan [Member]

Cash Incentive Bonus Plan [Member]

Incentive Equity Plan [Member]

Incentive Equity Plan [Member]

Incentive Equity Plan [Member]

Cash Incentive Bonus Plan [Member]

Cash Incentive Bonus Plan [Member]

Cash Incentive Bonus Plan [Member]

Incentive Equity Plan [Member]

Incentive Equity Plan [Member]

Incentive Equity Plan [Member]

employee

Cash Incentive Bonus Plan [Member]

Cash Incentive Bonus Plan [Member]

Cash Incentive Bonus Plan [Member]

Incentive Equity Plan [Member]

Incentive Equity Plan [Member]

Incentive Equity Plan [Member]

Deferred Bonus [Member]

Merger-Related Lawsuits [Member]

Merger-Related Lawsuits [Member]

Board of Directors Chairman [Member]

Litigation Case Filed by Mineral Interest Owner Harris County [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Deferred Compensation Arrangement, Excluding Share-based Payments and Postretirement Benefits [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayments of operating leases and delay rentals during fiscal year

$1,000,000

$500,000

$200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Future planned investments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20,600,000

'

'

'

'

'

Deferred compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

230,000

'

'

'

'

'

'

'

'

Severance payments

400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Legal Proceedings

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of wells involved in litigation

'

'

'

2

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Damages sought by plaintiffs (in Harris County case, in excess of $6.0 million)

'

'

'

13,400,000

6,000,000

6,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Additional portion of mineral interest claimed by plaintiff

'

'

'

'

'

6.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Royalties for undisputed claims, payments made to date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,500,000

Percentage of pre-merger acquiring shareholders approving merger, by outstanding shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

89.00%

'

'

'

'

Percentage of pre-merger acquiring shareholders approving merger, voting interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

99.00%

'

'

Percentage of pre-merger acquiree shareholders approving merger, by outstanding shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

69.00%

'

'

'

Percentage of pre-merger acquiree shareholders approving merger, voting interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

88.00%

'

'

Employment Agreements

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued bonus

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,000,000

'

Employment agreement, initial term

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Employment agreement, extension term

'

'

'

'

'

'

'2 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Base salary under employment agreement

'

'

'

'

'

'

'

$600,000

'

'

'

'

'

'

$400,000

'

'

'

'

'

'

'

'

'

'

'

'

$320,000

$300,000

$310,000

'

'

'

'

'

'

'

'

$270,000

$250,000

'

'

'

'

'

'

Cash bonus awards based on % of salary

'

'

'

'

'

'

'

'

100.00%

50.00%

150.00%

350.00%

75.00%

450.00%

'

90.00%

50.00%

130.00%

250.00%

75.00%

450.00%

80.00%

50.00%

120.00%

250.00%

75.00%

350.00%

'

'

'

'

50.00%

30.00%

75.00%

100.00%

40.00%

200.00%

'

'

'

'

'

'

'

'

'

Number of other employees covered by employment agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net_Income_Loss_Per_Common_Sha2

Net Income (Loss) Per Common Share (Components of Basic and Diluted Net Income Per Share of Common Stock) (Details) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings Per Share [Abstract]	'	'	'
Income (loss) from continuing operations	$41,362	($907)	$69,909
Income (loss) from discontinued operations, net of taxes	0	-29	-1,204
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	$41,362	($936)	$68,705
Weighted average shares, basic (in shares)	16,156,000	15,295,000	15,582,000
Stock options, net of shares assumed purchased (in shares)	2,000	'	3,000
Weighted average shares, diluted (in shares)	16,158,000	15,295,000	15,585,000
Income from continuing operations, basic (in dollars per share)	$2.56	($0.06)	$4.49
Discontinued operations, net of income taxes, basic (in dollars per share)	$0	$0	($0.08)
Total (in dollars per share)	$2.56	($0.06)	$4.41
Income from continuing operations, diluted (in dollars per share)	$2.56	($0.06)	$4.49
Discontinued operations, net of income taxes, diluted (in dollars per share)	$0	$0	($0.08)
Total (in dollars per share)	$2.56	($0.06)	$4.41
Stock Options [Member]	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'	'
Potentially dilutive shares	187,302	'	'

Income_Taxes_Effective_Income_

Income Taxes (Effective Income Tax Rate Reconciliation) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Effective Income Tax Rate Reconciliation, Amount [Abstract]	'	'	'
Provision/(benefit) at statutory tax rate	$23,011	($94)	$38,056
State income tax provision, net of federal benefit	2,928	654	2,960
Permanent differences	-1,559	450	-2,223
Other	4	-373	28
Income tax provision /(benefit)	$24,384	$637	$38,821
Effective Income Tax Rate Reconciliation, Percent [Abstract]	'	'	'
Provision/(benefit) at statutory tax rate	35.00%	35.00%	35.00%
State income tax provision, net of federal benefit	4.45%	-241.84%	2.72%
Permanent differences	-2.37%	-166.34%	-2.04%
Other	0.01%	137.65%	0.03%
Income tax provision /(benefit)	37.09%	-235.53%	35.71%

Income_Taxes_Components_of_Inc

Income Taxes (Components of Income Tax Expense Benefit) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Current:	'	'	'
Federal	$8,739	$7,038	$31,743
State	3,857	2,168	3,461
Total	12,596	9,206	35,204
Deferred:	'	'	'
Federal	11,361	-8,343	4,599
State	427	-226	-982
Total	11,788	-8,569	3,617
Total:	'	'	'
Federal	20,100	-1,305	36,342
State	4,284	1,942	2,479
Income tax provision /(benefit)	-24,384	-637	-38,821
Included in gain/loss from affiliates	1,245	32	0
Total income tax provision (benefit)	$23,139	$605	$38,821

Income_Taxes_Net_Deferred_Tax_

Income Taxes (Net Deferred Tax Liability) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Deferred tax assets:	'	'
Net operating loss carryforward	$49,204	$0
Income tax credits	2,676	0
Derivative instruments	564	0
Deferred compensation	406	0
Other	1,165	0
Total deferred tax assets before valuation allowance	54,015	0
Valuation allowance	-2,552	0
Net deferred tax assets	51,463	0
Deferred tax liability:	'	'
Oil and gas properties	-133,894	-109,538
Investment in affiliates	-21,681	-6,320
Other	-518	0
Deferred tax liability	-156,093	-115,858
Total net deferred tax liability	($104,630)	($115,858)

Income_Taxes_Narrative_Details

Income Taxes (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Oct. 01, 2013
Operating Loss Carryforwards [Line Items]	'	'	'	'
U.S. federal statutory corporate rate	35.00%	35.00%	35.00%	'
Proceeds from Life Insurance Policies	$10,000,000	'	'	'
Permanent differences	3,000,000	'	'	'
Operating Loss Carryforwards, Valuation Allowance	'	'	'	36,400,000
Tax Adjusted Operating Loss Carryforwards Valuation Allowance	'	'	'	12,800,000
Interest and penalties related to unrecognized tax benefits	0	0	0	'
Unrecognized tax benefits that would impact effective tax rate	0	'	'	'
Crimson [Member]	'	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'	'
Operating Loss Carryforwards	'	'	'	110,000,000
Operating Loss Carryforwards, Valuation Allowance	'	'	'	29,200,000
Tax Adjusted Operating Loss Carryforwards Valuation Allowance	'	'	'	10,200,000
Federal and State [Member]	'	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'	'
Operating Loss Carryforwards	132,300,000	'	'	'
Federal [Member]	'	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'	'
Operating Loss Carryforwards	132,300,000	'	'	'
Internal Revenue Service (IRS) [Member]	'	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'	'
Operating Loss Carryforwards, Valuation Allowance	'	'	'	7,300,000
Tax Adjusted Operating Loss Carryforwards Valuation Allowance	2,600,000	'	'	2,600,000
Operating Loss Carryforwards Amount Expiring in Next Four Years	7,300,000	'	'	'
Operating Loss Carryforwards Remaining Amount Subject to Expiration Between 2026 and 2033	$131,000,000	'	'	'

Income_Taxes_Unrecognized_Tax_

Income Taxes (Unrecognized Tax Benefits) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Reconciliation of Unrecognized Tax Benefits [Roll Forward]	'
Beginning Balance	$0
Additions based on tax positions related to the current year	0
Additions based on tax positions related to prior years	0
Additions due to acquisitions	518
Reductions due to a lapse of the applicable statute of limitations	0
Ending Balance	$518

Related_Party_Transactions_Sch

Related Party Transactions - Schedule of Oil and Gas Ownership Interests (Details)

12 Months Ended

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jan. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Jan. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Oct. 31, 2011

Dutch Number 1 - 5 [Member]

Dutch Number 1 - 5 [Member]

Dutch Number 1 - 5 [Member]

Dutch Number 1 - 5 [Member]

Dutch Number 1 - 5 [Member]

Mary Rose Number 1 [Member]

Mary Rose Number 1 [Member]

Mary Rose Number 1 [Member]

Mary Rose Number 1 [Member]

Mary Rose Number 1 [Member]

Mary Rose Number 2-3 [Member]

Mary Rose Number 2-3 [Member]

Mary Rose Number 2-3 [Member]

Mary Rose Number 2-3 [Member]

Mary Rose Number 2-3 [Member]

Mary Rose Number 4 [Member]

Mary Rose Number 4 [Member]

Mary Rose Number 4 [Member]

Mary Rose Number 4 [Member]

Mary Rose Number 4 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Ship Shoal 263 [Member]

Ship Shoal 263 [Member]

Ship Shoal 263 [Member]

Ship Shoal 263 [Member]

Ship Shoal 263 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Olympic [Member]

JEX [Member]

REX [Member]

JEX Employees [Member]

Olympic [Member]

JEX [Member]

REX [Member]

JEX Employees [Member]

Olympic [Member]

JEX [Member]

REX [Member]

JEX Employees [Member]

Olympic [Member]

JEX [Member]

REX [Member]

JEX Employees [Member]

Olympic [Member]

JEX [Member]

JEX [Member]

REX [Member]

JEX Employees [Member]

Olympic [Member]

JEX [Member]

REX [Member]

JEX Employees [Member]

Olympic [Member]

JEX [Member]

REX [Member]

JEX Employees [Member]

JEX Employees [Member]

Related Party Transaction [Line Items]

'

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'

'

Working interests

54.89%

3.53%

1.88%

0.00%

'

53.21%

3.61%

2.01%

0.00%

'

53.21%

3.61%

2.01%

0.00%

'

34.58%

2.34%

1.31%

0.00%

'

37.80%

37.80%

2.56%

1.43%

1.40%

0.00%

'

100.00%

0.00%

0.00%

0.00%

'

83.20%

0.00%

4.30%

12.50%

'

'

Net revenue interest

44.65%

2840.00%

1.51%

0.00%

'

40.44%

2700.00%

1.51%

0.00%

'

38.67%

2580.00%

1.44%

0.00%

'

25.49%

1700.00%

0.95%

0.00%

'

27.88%

'

1870.00%

1.04%

'

0.00%

'

80.00%

0.00%

0.00%

0.00%

'

64.83%

0.00%

3.35%

9.74%

'

'

Overriding royalty interest, employee benefit

'

'

'

'

2.02%

'

'

'

'

2.79%

'

'

'

'

2.79%

'

'

'

'

1.82%

'

'

'

'

'

'

1.54%

'

'

'

'

3.33%

'

'

'

'

3.33%

2.92%

Working interests, during the period

47.05%

3.02%

1.61%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net revenue interests, during the period

38.12%

2420.00%

1.29%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

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'

'

'

'

'

'

'

'

'

'

'

'

'

Related_Party_Transactions_Pay

Related Party Transactions - Payments Received from (paid to) JEX and REX during Ordinary Course of Business (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Olympic [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Revenue payments as well owners	($6,859)	($6,888)	($9,669)
Joint interest billing receipts	945	1,081	1,867
JEX [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Revenue payments as well owners	-4,628	-5,230	-5,393
Joint interest billing receipts	1,201	724	1,069
REX [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Revenue payments as well owners	-1,932	-4,308	-816
Joint interest billing receipts	2,090	885	3,229
Dutch Well [Member] | Olympic [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Well cost adjustment	0	0	-389
Dutch Well [Member] | JEX [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Well cost adjustment	0	0	161
Dutch Well [Member] | REX [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Well cost adjustment	0	0	-957
Mary Rose Well [Member] | Olympic [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Well cost adjustment	0	-201	0
Mary Rose Well [Member] | JEX [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Well cost adjustment	0	118	0
Mary Rose Well [Member] | REX [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Well cost adjustment	$0	($1,185)	$0

Related_Party_Transactions_Pay1

Related Party Transactions - Payments Received from (paid to) JEX and REX during Specific Transactions (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Olympic [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Sale of interest in Mary Rose 5	$0	$0	$0
Reimbursement of certain costs	0	0	0
Prospect fees	0	0	0
Advisory Agreements	0	0	0
REX distribution to members	0	0	0
JEX [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Sale of interest in Mary Rose 5	0	0	8
Reimbursement of certain costs	-115	-496	-185
Prospect fees	-1,000	0	-250
Advisory Agreements	-361	-1,530	0
REX distribution to members	0	0	0
REX [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Sale of interest in Mary Rose 5	0	0	0
Reimbursement of certain costs	-4	-9	-149
Prospect fees	0	0	0
Advisory Agreements	0	0	0
REX distribution to members	($197)	$1,469	$0

Related_Party_Transactions_Due

Related Party Transactions - Due to/Due from Affiliates (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Accounts receivable:	'	'
Accounts receivable, net	$60,613	$48,850
Joint interest billing	5,172	3,848
Olympic [Member]	'	'
Accounts receivable:	'	'
Accounts receivable, net	0	2
Joint interest billing	34	79
Accounts payable:	'	'
Royalties and revenue payable	-1,293	-1,133
Oil And Gas, Joint Interest Billing, Payables, Current	0	0
JEX [Member]	'	'
Accounts receivable:	'	'
Accounts receivable, net	0	1
Joint interest billing	87	85
Accounts payable:	'	'
Royalties and revenue payable	-877	-842
Oil And Gas, Joint Interest Billing, Payables, Current	0	-101
REX [Member]	'	'
Accounts receivable:	'	'
Accounts receivable, net	0	1
Joint interest billing	116	78
Accounts payable:	'	'
Royalties and revenue payable	-466	-642
Oil And Gas, Joint Interest Billing, Payables, Current	$0	$0

Related_Party_Transactions_Nar

Related Party Transactions Narrative (Details) (USD $)

1 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

Feb. 29, 2012

Dec. 31, 2013

Dec. 31, 2013

Oct. 01, 2013

Oct. 31, 2010

Jun. 20, 2012

Dec. 31, 2013

Mar. 20, 2013

Dec. 31, 2013

Dec. 31, 2012

Oct. 31, 2010

Dec. 31, 2013

Dec. 31, 2013

Nov. 30, 2011

Nov. 29, 2010

Oct. 15, 2010

Mar. 30, 2012

Nov. 30, 2011

Dec. 31, 2013

Oct. 15, 2010

Oct. 01, 2013

Oct. 01, 2013

Dec. 31, 2013

Dec. 31, 2013

Jul. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jul. 31, 2011

Mar. 31, 2010

Mar. 31, 2010

Jun. 30, 2010

Jun. 30, 2010

Jun. 30, 2010

Jun. 30, 2010

Feb. 28, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Oct. 31, 2011

Dec. 31, 2013

Feb. 28, 2011

Dec. 31, 2013

Feb. 28, 2011

Feb. 28, 2011

Feb. 28, 2011

Feb. 28, 2011

31-May-11

Oct. 31, 2011

Jul. 31, 2011

Jul. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jan. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jan. 31, 2012

Jan. 31, 2012

Jan. 31, 2012

Jul. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Jul. 31, 2012

Jul. 31, 2012

Dec. 31, 2013

Jun. 20, 2012

Dec. 31, 2013

Jun. 30, 2013

Jun. 30, 2013

Jun. 30, 2013

Jun. 30, 2013

Jun. 20, 2012

Jun. 20, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Oct. 31, 2009

Sep. 30, 2010

Oct. 31, 2009

Sep. 30, 2010

Dec. 31, 2012

Oct. 31, 2010

Oct. 31, 2010

Dec. 31, 2013

Dec. 31, 2013

Jul. 31, 2011

Mar. 31, 2010

Feb. 28, 2011

Feb. 28, 2011

Feb. 28, 2011

Jan. 31, 2012

Mar. 20, 2013

Dec. 31, 2013

Mar. 20, 2013

Jul. 31, 2011

Jan. 31, 2012

employee

officer

Oaktree Capital Partners [Member]

Oaktree Capital Partners [Member]

Contango Offshore Exploration LLC [Member]

JEX Employees [Member]

REX [Member]

REX [Member]

JEX [Member]

JEX [Member]

JEX [Member]

Mr Romano [Member]

Mr Juneau [Member]

Contango ORE, Inc. [Member]

Contango ORE, Inc. [Member]

Contango ORE, Inc. [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Maximum [Member]

Maximum [Member]

Crimson [Member]

Crimson [Member]

Ship Shoal 263 [Member]

Ship Shoal 263 [Member]

Ship Shoal 263 [Member]

Ship Shoal 263 [Member]

Ship Shoal 263 [Member]

Ship Shoal 263 [Member]

Eloise South [Member]

Eloise South [Member]

Eloise South [Member]

Rexer Number 1 [Member]

Rexer Number 1 [Member]

Rexer Number 1 [Member]

Rexer Number 1 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Rexer-Tusa Number 2 [Member]

Rexer-Tusa Number 2 [Member]

Dutch Number 5 [Member]

Dutch Number 5 [Member]

Dutch Number 1 - 5 [Member]

Dutch Number 1 - 5 [Member]

Dutch Number 1 - 5 [Member]

Dutch Number 1 - 5 [Member]

Dutch Number 1 - 5 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Mary Rose Number 5 [Member]

Eloise North [Member]

Eloise North [Member]

Ship Soal 134 [Member]

Ship Soal 134 [Member]

Ship Soal 134 [Member]

South Timbalier 75 [Member]

South Timbalier 75 [Member]

All Future Projects Generated by REX [Member]

All Future Projects Generated by REX [Member]

All Future Projects Generated by REX [Member]

South Timbalier 17 [Member]

South Timbalier 17 [Member]

South Timbalier 17 [Member]

South Timbalier 17 [Member]

All Future Projects Generated Outside of REX [Member]

All Future Projects Generated Outside of REX [Member]

Tuscaloosa Marine Shale [Member]

Tuscaloosa Marine Shale [Member]

Tuscaloosa Marine Shale [Member]

Tuscaloosa Marine Shale [Member]

Tuscaloosa Marine Shale [Member]

Tuscaloosa Marine Shale [Member]

State of Alaska [Member]

State of Alaska [Member]

State of Alaska [Member]

State of Alaska [Member]

Contaro [Member]

Contango Offshore Exploration LLC [Member]

Contango Offshore Exploration LLC [Member]

REX [Member]

REX [Member]

REX [Member]

REX [Member]

REX [Member]

REX [Member]

REX [Member]

REX [Member]

REX [Member]

REX [Member]

REX [Member]

Olympic [Member]

Olympic [Member]

lease_block

lease_block

Contango ORE, Inc. [Member]

Contango ORE, Inc. [Member]

Contango Offshore Exploration LLC [Member]

Contango ORE, Inc. [Member]

Barclays [Member]

Olympic [Member]

JEX Employees [Member]

JEX Employees [Member]

REX [Member]

JEX [Member]

JEX Employees [Member]

JEX Employees [Member]

JEX [Member]

Payout of All Costs [Member]

After Payout [Member]

Olympic [Member]

JEX Employees [Member]

JEX Employees [Member]

REX [Member]

JEX [Member]

JEX [Member]

Until Casing Point [Member]

After Casing Point [Member]

Beginning of Production [Member]

Total [Member]

Payout of All Costs [Member]

After Payout [Member]

JEX [Member]

Olympic [Member]

JEX Employees [Member]

REX [Member]

JEX [Member]

Olympic [Member]

JEX Employees [Member]

REX [Member]

JEX [Member]

JEX [Member]

JEX [Member]

JEX [Member]

JEX [Member]

Through Production [Member]

lease_block

JEX Employees [Member]

REX [Member]

Total [Member]

Final [Member]

JEX Employees [Member]

Beginning of Production [Member]

JEX Employees [Member]

JEX Employees [Member]

Chief Executive Officer [Member]

Geologist, Tuscaloosa Marine Shale [Member]

Beginning of Production [Member]

JEX [Member]

Contango ORE, Inc. [Member]

Contango ORE, Inc. [Member]

JEX [Member]

JEX [Member]

JEX [Member]

Eloise South [Member]

Eloise South [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Vermilion 170 [Member]

Eloise North [Member]

All Future Projects Generated by REX [Member]

All Future Projects Generated by REX [Member]

All Future Projects Generated by REX [Member]

Eloise South [Member]

Eloise North [Member]

JEX [Member]

JEX [Member]

JEX [Member]

JEX [Member]

JEX [Member]

JEX [Member]

JEX [Member]

After Casing Point [Member]

Beginning of Production [Member]

Total [Member]

Beginning of Production [Member]

Total [Member]

Payout of Post Casing Point Costs [Member]

Related Party Transaction, Oil and Gas Properties [Abstract]

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Annual advisory payment

'

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$2,000,000

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First Rights Agreement Payment

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500,000

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Contaro Advisory Agreement payment

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'

'

'

'

10,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Agreement Fee, Percent of Cash Profits Earned

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Overriding royalty interest, employee benefit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.33%

'

'

'

'

'

'

3.33%

'

'

'

'

1.33%

2.50%

'

'

'

'

'

'

3.33%

2.92%

'

'

'

'

'

'

'

'

'

'

'

'

'

2.02%

'

'

'

'

'

1.54%

'

'

'

'

'

'

'

'

'

'

'

'

3.33%

'

'

'

'

3.33%

'

'

'

2.00%

0.75%

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest in REX by related parties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

32.30%

34.40%

'

'

'

'

'

'

'

'

'

'

'

Ownership interest in REX by a third party

'

33.30%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Director Compensation for Related Party

'

'

17,000

'

'

'

'

'

'

'

'

26,000

97,500

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Director Compensation for Related Party, Shares

'

1,622

'

'

'

'

1,622

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Vesting percentage

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Vesting period (in years)

'

'1 year

'

'

'

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Working interests

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

0.00%

'

'

0.00%

0.00%

23.80%

23.80%

'

'

'

'

'

'

83.20%

0.00%

'

'

12.50%

'

4.30%

100.00%

2.60%

1.70%

4.30%

25.00%

10.00%

47.05%

1.60%

54.89%

3.53%

'

0.00%

1.88%

37.80%

37.80%

2.56%

'

0.00%

1.43%

1.40%

35.80%

0.10%

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

9.60%

9.60%

7.50%

5.00%

12.50%

13.20%

10.00%

22.50%

12.50%

3.33%

4.79%

Working interests, during the period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

47.05%

3.02%

'

'

1.61%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest in oil and gas well

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

10.00%

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

100.00%

'

100.00%

'

'

'

9.40%

75.00%

56.30%

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net revenue interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

80.00%

0.00%

'

'

0.00%

0.00%

'

'

'

'

'

'

7.25%

'

64.83%

0.00%

'

'

9.74%

'

3.35%

'

'

'

'

'

7.36%

'

'

44.65%

2840.00%

'

0.00%

1.51%

27.88%

'

1870.00%

'

0.00%

1.04%

'

'

'

'

'

'

'

'

'

'

'

39.90%

6.70%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17.50%

'

'

'

Prospect fees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

250,000

'

'

'

'

'

'

'

250,000

'

'

'

'

'

'

'

'

250,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

250,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Due from COE

'

'

'

'

5,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Portion assumed of COE upon dissolution

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

65.63%

34.37%

'

'

'

'

'

'

'

'

'

'

'

'

'

Portion of promissory note assumed

'

'

'

'

'

'

'

'

'

'

2,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of lease blocks, oil and gas

'

'

'

'

'

1

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period required to drill oil prospects

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'48 months

'

'

'

'

'

'

'

'

'

'

'

'

'6 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Sublease rental value

'

'

'

'

'

'

'

'

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership Percentage in Company's Stock

'

'

'

6.70%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

175,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued interest and pre-payment penalty

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Related Party Transaction, Mining Properties [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest in mining properties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments to acquire mining assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Overriding royalty interest, mining property

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Mining exploration expense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Remaining ownership interest in mining properties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Overriding royalty interest, employee benefit, mining property

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Related Party Transaction, Stock Transactions [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash contributed

'

'

'

'

'

'

'

'

'

'

'

'

'

3,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock shares issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares distributed of CORE per each 10 shares of Company owned

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revolving line of credit promissory note, maximum borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revolving line of credit promissory note, interest rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Advance under the CORE note

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest received on CORE note

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of employees net-settled stock options

2

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock options, net-settled (in shares)

45,000

45,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash used to net-settle awards

$465,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Discontinued_Operations_Narrat

Discontinued Operations (Narrative) (Details) (USD $)	12 Months Ended			1 Months Ended		1 Months Ended		0 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	31-May-11	31-May-11	31-May-11	Oct. 31, 2011	Nov. 29, 2010	Oct. 15, 2010
				Joint Venture Assets [Member]	Rexer [Member]	Rexer Tusa [Member]	Rexer Tusa [Member]	Contango ORE, Inc. [Member]	Contango ORE, Inc. [Member]
				Mcfe	Mcfe
				well
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'
Working interest sold	'	'	'	90.00%	100.00%	75.00%	25.00%	'	'
Royalty interest sold	'	'	'	5.00%	'	'	'	'	'
Number of wells sold	'	'	'	21	'	'	'	'	'
Aggregate purchase price of onshore asset sold in Texas	'	'	'	$36,200,000	'	$0	$10,000	'	'
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax	'	'	'	-700,000	'	-2,500,000	'	'	'
Proved reserves, joint ventures assets (Mmcfe and Bcfe)	'	'	'	16,700,000	500,000	'	'	'	'
Revenue interest percentage sold	'	'	'	'	72.50%	54.40%	18.40%	'	'
Cash contributed	'	'	'	'	'	'	'	3,500,000	'
Common stock shares issued	'	'	'	'	'	'	'	1,566,367	'
Shares held in CORE prior to acquisition	'	'	'	'	'	'	'	100	'
Value of common stock	'	'	'	'	'	'	'	'	7,300,000
Shares distributed of CORE per each 10 shares of Company owned	'	'	'	'	'	'	'	'	1
Cash paid to stockholders	$0	$30,510,000	$0	'	'	'	'	$6,213	'

Discontinued_Operations_Summar

Discontinued Operations (Summarized Financial Results for Discontinued Operations) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'
Impairment of natural gas and oil properties	($776)	($14,079)	($1,680)
Joint Venture Assets [Member]	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'
Revenues	'	0	3,939
Operating expenses	'	-40	-827
Depletion expenses	'	0	-1,755
Gain (Loss) on sale	'	0	-651
Income (loss) before income taxes	'	-40	706
Benefit (provision) for income taxes	'	14	-459
Income (loss) from discontinued operations, net of income taxes	'	-26	247
Rexer Assets [Member]	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'
Revenues	'	0	1,175
Operating expenses	'	-5	-169
Depletion expenses	'	0	-1,821
Impairment of natural gas and oil properties	'	0	-1,031
Exploration expenses	'	0	-8
Gain (Loss) on sale	'	0	-273
Income (loss) before income taxes	'	-5	-2,127
Benefit (provision) for income taxes	'	2	744
Income (loss) from discontinued operations, net of income taxes	'	($3)	($1,383)