Contango Oil & Gas (MCF) 10-K 3 Mar 15 2014 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Feb. 27, 2015	Jun. 30, 2014
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Entity Registrant Name	CONTANGO OIL & GAS CO
Entity Central Index Key	1071993
Current Fiscal Year End Date	-19
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		19,155,847
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$618

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
CURRENT ASSETS:
Cash and cash equivalents	$0
Accounts receivable, net	25,309	60,613
Prepaid expenses and other	1,941	2,031
Inventory	2,166	2,147
Current deferred tax asset	1,624	1,326
Total current assets	31,040	66,117
Natural gas and oil properties, successful efforts method of accounting:
Proved properties	1,138,054	1,001,361
Unproved properties	35,783	49,443
Other property and equipment	1,084	900
Accumulated depreciation, depletion and amortization	-426,298	-260,681
Total property, plant and equipment, net	748,623	791,023
OTHER NON-CURRENT ASSETS:
Investments in affiliates	62,085	50,901
Other	1,667	2,263
Total other non-current assets	63,752	53,164
TOTAL ASSETS	843,415	910,304
CURRENT LIABILITIES:
Accounts payable and accrued liabilities	92,892	96,833
Current derivative liability		1,131
Current asset retirement obligations	4,123	1,315
Total current liabilities	97,015	99,279
NON-CURRENT LIABILITIES:
Long-term debt	63,359	90,000
Deferred tax liability	93,952	105,956
Asset retirement obligations	21,623	22,019
Total non-current liabilities	178,934	217,975
Total liabilities	275,949	317,254
COMMITMENTS AND CONTINGENCIES
SHAREHOLDERS’ EQUITY:
Common stock, $0.04 par value, 50 million shares authorized, 24,357,099 shares issued and 19,364,574 shares outstanding at June 30, 2014, 24,356,236 shares issued and 19,363,711 shares outstanding at December 31, 2013	963	962
Additional paid-in capital	233,278	228,644
Treasury shares at cost (4,992,525 shares at June 30, 2014 and December 31, 2013)	-127,525	-119,180
Retained earnings	460,750	482,624
Total shareholders’ equity	567,466	593,050
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$843,415	$910,304

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
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	24,372,538	24,356,236
Common stock, shares outstanding	19,148,000	19,363,711
Treasury stock, shares	5,224,538	4,992,525

Consolidated_Statements_Of_Ope

Consolidated Statements Of Operations (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
REVENUES:
Oil and condensate sales	$130,238	$59,608	$56,237
Natural gas sales	112,695	79,289	60,691
Natural gas liquids sales	33,525	25,224	28,940
Total revenues	276,458	164,121	145,868
EXPENSES:
Operating expenses	47,236	36,784	23,720
Exploration expenses	33,387	1,811	51,903
Depreciation, depletion and amortization	156,117	65,529	44,896
Impairment and abandonment of oil and gas properties	47,693	776	14,079
General and administrative expenses	34,045	26,512	11,265
Total expenses	318,478	131,412	145,863
OTHER INCOME (EXPENSE):
Gain from investment in affiliates (net of income taxes)	6,923	2,310	60
Interest income (expense)	-2,658	-1,171	96
Loss on derivatives, net	-153	-1,132	0
Other income (expense)	124	31,785	-463
Total other income (expense)	4,236	31,792	-307
NET INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	-37,784	64,501	-302
Income tax benefit (provision)	15,910	-23,139	-605
Income (loss) from continuing operations	-21,874	41,362	-907
DISCONTINUED OPERATIONS, NET OF INCOME TAX (NOTE 18)			-29
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	($21,874)	$41,362	($936)
Basic
Continuing operations (in dollars per share)	($1.15)	$2.56	($0.06)
Discontinued operations (in dollars per share)			$0
Total (in dollars per share)	($1.15)	$2.56	($0.06)
Earnings Per Share, Diluted [Abstract]
Continuing operations (in dollars per share)	($1.15)	$2.56	($0.06)
Discontinued operations (in dollars per share)			$0
Total (in dollars per share)	($1.15)	$2.56	($0.06)
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic (in shares)	19,059	16,156	15,295
Diluted (in shares)	19,059	16,158	15,295

Consolidated_Statement_Of_Shar

Consolidated Statement Of Shareholders' Equity (USD $)	Common Stock [Member]	Additional Paid-In Capital [Member]	Treasury Stock [Member]	Retained Earnings [Member]	Total
In Thousands, except Share data
Balance at Dec. 31, 2011	$805	$79,279	($108,789)	$472,708	$444,003
Balance, shares at Dec. 31, 2011	15,357,166
Excess tax benefit from exercise of stock options		-254			-254
Treasury shares at cost			-8,374		-8,374
Treasury shares at cost, shares	-162,214				-162,214
Dividends				-30,510	-30,510
Net loss				-936	-936
Balance at Dec. 31, 2012	805	79,025	-117,163	441,262	403,929
Balance, shares at Dec. 31, 2012	15,194,952
Acquisition of Crimson	154	146,414			146,568
Acquisition of Crimson, shares	3,864,039
Exercise of stock options	3	26			29
Exercise of stock options, shares	791				791
Treasury shares at cost			-2,017		-2,017
Treasury shares at cost, shares	-52,370				0
Stock-based compensation		3,179			3,179
Stock-based compensation, shares	356,299
Net loss				41,362	41,362
Balance at Dec. 31, 2013	962	228,644	-119,180	482,624	593,050
Balance, shares at Dec. 31, 2013	19,363,711				19,363,711
Exercise of stock options		120			120
Exercise of stock options, shares	4,165				4,165
Treasury shares at cost			-8,345		-8,345
Treasury shares at cost, shares	-232,013				-205,457
Restricted shares activity	1	-1
Restricted shares activity, shares	12,137
Stock-based compensation		4,515			4,515
Net loss				-21,874	-21,874
Balance at Dec. 31, 2014	$963	$233,278	($127,525)	$460,750	$567,466
Balance, shares at Dec. 31, 2014	19,148,000				19,148,000

Consolidated_Statements_Of_Cas

Consolidated Statements Of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES:
Income (loss) from continuing operations	($21,874)	$41,362	($907)
Income (loss) from discontinued operations, net of taxes			-29
Net income (loss)	-21,874	41,362	-936
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	156,117	65,529	44,896
Impairment of natural gas and oil properties	47,075	767	14,078
Exploration expenses	31,488	-9	51,379
Deferred income taxes	-12,284	13,159	-8,569
Gain on sale of assets		-21,961
Gain from investment in affiliates	-10,651	-3,554	-92
Stock-based compensation	4,515	3,180	-154
Excess tax benefit from exercise of stock options			-254
Unrealized loss (gain) on derivative instruments	-1,131	1,410
Changes in operating assets and liabilities:
Decrease (increase) in accounts receivable and other	28,942	-6,285	19,894
Decrease (increase) in prepaid expenses	-19	30	-347
Decrease in accounts payable and advances from joint owners	-8,322	-4,720	-10,918
Increase (decrease) in other accrued liabilities	-4,236	3,569	-877
Increase (decrease) in income taxes receivable, net	884	11,778	-15,117
Other	-544	782	-2,861
Net cash provided by operating activities	209,960	105,037	90,122
CASH FLOWS FROM INVESTING ACTIVITIES:
Natural gas and oil exploration and development expenditures	-180,422	-62,552	-78,549
Sale of oil and gas properties		20,000
Advance under note receivable			-500
Repayment of note receivable			900
Investments in affiliates		-15,397	-54,765
Distributions from affiliates	5,365	23,154	8,969
Net cash used in investing activities	-175,057	-34,795	-123,945
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings under credit facility	491,257	180,394
Repayments under credit facility	-517,898	-90,394
Payment of long-term debt		-235,373
Cash dividends paid			-30,510
Purchase of common stock	-8,344	-2,017	-8,374
Proceeds from exercised options	120	31
Excess tax benefit from exercise/cancellation of stock options		0	254
Debt issuance costs	-38	-2,370
Net cash used in financing activities	-34,903	-149,729	-38,630
NET DECREASE IN CASH AND CASH EQUIVALENTS		-79,487	-72,453
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD		79,487	151,940
CASH AND CASH EQUIVALENTS, END OF PERIOD	$0		$79,487

Organization_And_Business

Organization And Business	12 Months Ended
	Dec. 31, 2014
Organization And Business [Abstract]
Organization And Business	1. Organization and Business
	Contango Oil & Gas Company (collectively with its subsidiaries, “Contango” or the “Company”) is a Houston, Texas based, independent oil and natural gas company. The Company’s business is to explore, develop, exploit, produce and acquire crude oil and natural gas properties in the shallow waters of the Gulf of Mexico ("GOM") and in the onshore Texas Gulf Coast and Rocky Mountain regions of the United States.
	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, the Company issued approximately 3.9 million shares of common stock in exchange for all of Crimson's outstanding capital stock. See Note 4 - "Merger with Crimson Exploration, Inc." for additional information.
	The Company has historically focused operations in the GOM, but the Merger has given the Company access to lower risk, long life resource plays. In 2014, the Company’s drilling activity focused primarily on the Woodbine oil and liquids-rich play in Madison and Grimes counties, Texas (the Southeast Texas Region), on the Buda Limestone oil and liquids-rich play in Zavala and Dimmit counties, Texas (the South Texas Region), in the Cretaceous Sands in Fayette and Gonzales counties, Texas (also the South Texas Region) and the late 2014 commencement of drilling in Wyoming where the Company is targeting multiple formations. The Company believes these plays provide long-term growth potential from multiple formations that it believes to be productive for oil and natural gas.
	Additionally, the Company has (i) a 37% equity investment in Exaro Energy III LLC (“Exaro”) that is primarily focused on the development of proved natural gas reserves in the Jonah Field in Wyoming; (ii) leasehold positions and minor non-operated producing properties in Louisiana and Mississippi targeting the Tuscaloosa Marine Shale (“TMS”); (iii) operated properties producing from various conventional formations in various counties along the Texas Gulf Coast; (iv) operated producing properties in the Denver Julesburg Basin (“DJ Basin”) in Weld and Adams counties in Colorado, which the Company believes may also be prospective in the Niobrara Shale oil play; (v) operated producing properties in the Haynesville Shale, Mid Bossier and James Lime formations in East Texas; and (vi) six exploratory prospects in the shallow waters of the GOM.

Summary_Of_Significant_Account

Summary Of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Summary Of Significant Accounting Policies [Abstract]
Summary Of Significant Accounting Policies	2. 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, 2014 and 2013 and for the three years ended December 31, 2014 contained herein, include consolidated results of operations of both Contango Oil & Gas Company and Crimson for the period from the closing date of the Merger to December 31, 2014 and only consolidated financial statements of Contango for all other the periods presented herein.
	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.
	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 Other income (expense) line item in the Company's statement of operations and in the investing cash flows in the Company's statement of cash flow 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 its investment in Exaro, while a net loss or payment of dividends decreases its investment. In the consolidated statement of operations, the Company’s proportionate share of Exaro's net income or loss is reported as a single line-item in Gain 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, 2014, 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, 2014, 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, 2014, accounts payable included $12.1 million representing outstanding checks that had not been presented for payment net of cash balance in the bank as of December 31, 2014. 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.
	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, as of December 31, 2014 and 2013, respectively. At December 31, 2014 and 2013 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 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, operating costs and 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. For the year ended December 31, 2014, the Company recorded an impairment expense of approximately $11.4 million related to proved properties. Of this amount, $7.7 million related to South Timbalier 17 and $3.7 million related to TMS. No impairment of proved properties was recognized during the year ended December 31, 2013. 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 the 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 an impairment of the carrying value, and any such impairment is charged to expense in the period.
	On April 29, 2014, the Company reached total depth on its Ship Shoal 255 well, and no commercial hydrocarbons were found. As a result, for the year ended December 31, 2014, the Company recognized $31.5 million in exploration expense for the cost of drilling the well and $15.6 million in impairment expense, including $3.5 million related to leasehold costs and $12.1 million related to the platform located in Ship Shoal 263 block which was expected to be used by the Ship Shoal 255 well had it been successful.
	During the year ended December 31, 2014, the Company also recognized impairment expense of approximately $20.1 million related to impairment and partial impairment of certain unproved properties due to expiring leases and leases not likely to be drilled. Of this amount, approximately $9.7 million relates to undrilled offshore leases and approximately $9.7 million relates to undeveloped TMS acreage.
	For the year ended December 31, 2013, the Company recorded an impairment expense on unproved properties of $0.6 million related to leasehold costs on the Ship Shoal 83 prospect which it relinquished in August 2013, and $0.2 million related to leasehold costs on the Brazos Area 543 prospect. The Company did not recognize any impairment of unproved properties for the year ended December 31, 2012.
	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, 2014. The amount of unrecognized tax benefits did not materially change from December 31, 2013. The amount of unrecognized tax benefits may change in the next twelve months; however, the Company does not expect the change to have a significant impact on its 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 1998 – 2014, and state tax returns for 2009 – 2014, 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 years ended December 31, 2014 and 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 requisite service period, which generally aligns with 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. As of December 31, 2014, the Company has not entered into any derivative contracts to reduce exposure to interest rate risk. However, 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 "Loss on derivatives, net" on the consolidated statements of operations for the years ended December 31, 2014 and 2013. The Company did not have any derivative instruments or hedging activities for the year ending December 31, 2012. 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. As of December 31, 2014, there were no commodity hedges in place.
	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 in order to conform to the presentation for the years ended December 31, 2014 and 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 the Company’s 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 January 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2015-01: Income Statement – Extraordinary and Unusual Items (Subtopic 225-20): Simplifying Income Statement Presentation by Eliminating the Concept of Extraordinary Items (ASU 2015-01). ASU 2015-01 is part of an initiative to reduce complexity in accounting standards. This update eliminates from generally accepted accounting principles the concept of extraordinary items, which eliminates the requirements for reporting entities to consider whether an underlying event or transaction is extraordinary. However, this will not result in a loss of information as the presentation and disclosure guidance for items that are unusual in nature or occur infrequently will be retained. ASU 2015-01 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015; early application is permitted. The provisions of this accounting update are not expected to have a material impact on the Company’s financial position or results of operations.
	In November 2014, the FASB issued Accounting Standards Update No. 2014-17: Business Combinations (Topic 805): Pushdown Accounting (ASU 2014-17). ASU 2014-17 addresses the limited guidance available for determining whether and at what threshold pushdown accounting should be established in an acquired entity’s separate financial statements. Thus, the amendments in this update provide an acquired entity with an option to apply pushdown accounting upon occurrence of an event in which an acquirer obtains control of the acquired entity. Furthermore, the amendments in this update provide specific guidance on pushdown accounting for all entities, and the threshold for pushdown accounting is consistent with the threshold for change-in-control events in Topic 805, Business Combinations, and Topic 810, Consolidation. ASU 2014-17 became effective on November 18, 2014. The provisions of this accounting update are not expected to have a material impact on the Company’s financial position or results of operations.
	In August 2014, the FASB issued Accounting Standards Update No. 2014-15: Presentation of Financial Statements – Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (ASU 2014-15). ASU 2014-15 asserts that management should evaluate whether there are relevant condition or events that are known and reasonably knowable that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date the financial statements are issued or are available to be issued when applicable. If conditions or events at the date the financial statements are issued raise substantial doubt about an entity’s ability to continue as a going concern, disclosures are required which will enable users of the financial statements to understand the conditions or events as well as management’s evaluation and plan. ASU 2014-15 is effective for the annual period ending after December 15, 2016, and for annual and interim periods thereafter; early application is permitted. The provisions of this accounting update are not expected to have a material impact on the Company’s financial position or results of operations.
	In May 2014, the FASB and the International Accounting Standards Board (“IASB”) jointly issued new accounting guidance for recognition of revenue Accounting Standards Update No. 2014-09: Revenue from Contracts with Customers (Topic 606) (ASU 2014-09). This new guidance replaces virtually all existing US GAAP and IFRS guidance on revenue recognition. ASU 2014-09 is effective for fiscal years beginning after December 15, 2016. This new guidance applies to all periods presented. Therefore, when the Company issues its financial statements on Forms 10-Q and 10-K for periods included in its year ended December 31, 2017, its comparative periods that are presented from the years ended December 31, 2015 and 2016, must be retrospectively presented in compliance with this new guidance. Early adoption is not allowed for US GAAP. The new guidance requires companies to make more estimates and use more judgment than under current accounting guidance. The Company does not anticipate that this new guidance will have a material impact on the Company’s consolidated financial position or results of operations for the periods presented.
	In April 2014, the FASB issued Accounting Standards Update No. 2014-08: Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity (ASU 2014-08). ASU 2014-08 changes the criteria for reporting discontinued operations while enhancing disclosures in this area. The amended guidance requires that a disposal representing a strategic shift that has (or will have) a major effect on an entity’s financial results or a business activity classified as held for sale should be reported as discontinued operations. The amendments also expand the disclosure requirements for discontinued operations and add new disclosures for individually significant dispositions that do not qualify as discontinued operations. ASU 2014-08 is effective for annual and interim periods beginning after December 15, 2014 (early adoption is permitted only for disposals that have not been previously reported). The implementation of the amended guidance of ASU 2014-08 is not expected to have a material impact on the Company’s consolidated financial position or results of operations.
	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. The Company implemented the changes required by the new COSO framework during the year ended December 31, 2014. The Company will continue to assess the impact, if any, it may have on its internal control structure.
	In February 2013, the 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. The Company evaluated the provisions of this accounting update and does not believe it has a material impact on its 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 2015 and beyond, including, but not limited to, 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, 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, 2014
Concentration Of Credit Risk [Abstract]
Concentration Of Credit Risk	3. Concentration of Credit Risk
	The customer base for the Company is concentrated in the natural gas and oil industry. Major purchasers of the Company’s natural gas, oil and natural gas liquids for the year ended December 31, 2014 were ConocoPhillips Company (31%), Sunoco Inc. (27%), Shell Trading US Company (10%), ExxonMobil Oil Corp. (7%) and Enterprise Products Operating LLC (5%). The Company’s sales to these companies are not secured with letters of credit and in the event of non-payment, the Company could lose up to two months of revenues. The loss of two months of revenues would have a material adverse effect on the Company’s financial position. There are numerous other potential purchasers of the Company’s production.

Merger_With_Crimson_Exploratio

Merger With Crimson Exploration Inc.	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Merger With Crimson Exploration Inc.	4. 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 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.
	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 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		12,967
	Amount attributable to liabilities assumed		308,464
	Total consideration including liabilities assumed	$	455,038
	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		416,433
	Other non-current assets		208
	Amount attributable to net assets acquired	$	455,038
	Goodwill	$	—
	As of December 31, 2013, estimates of the fair value of assets acquired and liabilities assumed were preliminary and based on information available at that time. The fair value estimate of certain of Crimson's assets and liabilities, including asset retirement obligations and current and deferred tax balances, could not be finalized at December 31, 2013 due to information not being available to the Company. During the quarter ended June 30, 2014, the Company completed an analysis of Crimson’s asset retirement obligations as of the acquisition date. Based on this analysis, the Company recorded a measurement period adjustment of $2.5 million to increase the asset retirement obligations liability. As of September 30, 2014, the Company had finalized the purchase price allocation for the Merger.
	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 was 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 the Company’s 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 $143.4 million and pre-tax income of $4.9 million to the Company for the year ended December 31, 2014. 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 and $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, 2014
Business Combinations [Abstract]
Acquisitions, Dispositions And Gains From Affiliates	5. Acquisitions, Dispositions and Gains from Affiliates
	Acquisition of Additional Interest in Dutch
	In December 2013, the Company 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. During 2014, a purchase price adjustment of approximately $4.1 million reduced the purchase price to a total of $14.7 million, net to the Company.
	Southeast Texas Disposition
	On December 31, 2013, the Company sold to an independent oil and gas company approximately 7.1% of its interest in all developed and undeveloped properties in Madison and Grimes Counties for $20 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 31, 2013. A preliminary estimated adjustment to the sales price of approximately $0.4 million to increase the purchase price was recorded in 2013, and an adjustment of approximately $0.1 million to reduce the purchase price was recorded in 2014 resulting in final proceeds of $20.3 million. A loss of approximately $0.2 million and a gain of approximately $6.6 million related to this sale were recognized in the years ended December 31, 2014 and 2013, respectively.
	Proceeds from Alta
	In August 2013, Alta sold its interest in the liquids-rich Kaybob Duvernay, which closed in October 2013 for 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 during 2014. The Company expects to receive the remaining $2.0 million within the next twelve months. The total distributions from Alta are expected to exceed the Company’s original investment by $15.3 million.

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2014
Fair Value Measurements [Abstract]
Fair Value Measurements	6. 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	$	—
	The Company did not have any outstanding commodity price contracts as of December 31, 2014.
	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 "Gain (loss) on derivatives, net" 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 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 these 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 compares 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 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 and expected lives of the related reserves.

Derivative_Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2014
Derivative Instruments [Abstract]
Derivative Instruments	7. 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. Recently, the Company had hedged a substantial, but varying, portion of anticipated oil and natural gas production for future periods. The Company believes that these derivative arrangements, although not free of risk, allowed 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, the Company’s derivative arrangements applied only to a portion of its production and provided only partial protection against declines in commodity prices. Such arrangements may expose us to risk of financial loss in certain circumstances. The Company continuously reevaluates its hedging programs in light of changes in production, market conditions, and commodity price forecasts.
	As of December 31, 2014, the Company did not have any outstanding derivative positions. 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 previous derivative contracts were 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 "Gain (loss) on derivatives, net" on the consolidated statements of operations. See Note 6 – “Fair Value Measurements” for additional information.
	There was no activity or outstanding derivative contracts during the year ended December 31, 2012.
	The following summarizes the fair value of commodity derivatives outstanding on a gross and net basis as of December 31, 2013 (in thousands):
			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 years ended December 31, 2014 and 2013 (in thousands):
			Year ended December 31,
	Contract Type		2014		2013
	Crude oil contracts		$	276	$	180
	Natural gas contracts			-1,560		98
	Realized gain (loss)		$	-1,284	$	278
	Crude oil contracts		$	1,183	$	-1,179
	Natural gas contracts			-52		-231
	Unrealized gain (loss)		$	1,131	$	-1,410
	Gain (loss) on derivatives, net		$	-153	$	-1,132
	There were no gains or losses related to derivative instruments for the year ended December 31, 2012.

StockBased_Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2014
Stock-Based Compensation [Abstract]
Stock-Based Compensation	8. Stock Based Compensation
	As of December 31, 2014, 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 Amended and Restated 2009 Incentive 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.
	Amended and Restated 2009 Incentive Compensation Plan
	On September 15, 2009, the Company’s Board of Directors (the “Board”) adopted the Contango Oil & Gas Company Equity Compensation Plan (the “Original 2009 Plan”). On April 10, 2014, the Board amended and restated the Original 2009 Plan thorugh the adoption of the Contango Oil & Gas Company Amended and Restated 2009 Incentive Compensation Plan. The 2009 Plan provides for both cash awards and equity awards (such as restricted stock and options) 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 terms of the 2009 Plan, up to 1,500,000 shares of the Company’s common stock may be issued for plan awards. Stock options under the 2009 Plan must have 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.
	As of December 31, 2014, the Company had approximately 1.1 million shares of common stock and stock options available for future grant under the 2009 Plan. On February 24, 2014, the Company granted 1,103 restricted stock awards under the 2009 Plan.
	Effective January 1, 2014, the Company implemented performance-based long-term bonus plans under the 2009 Plan for the benefit of all employees through a Cash Incentive Bonus Plan (“CIBP”) and a Long-Term Incentive Plan (“LTIP”). The specific targeted performance measures under these sub-plans are approved by the Compensation Committee and/or the Board. Upon achieving the performance levels established each year, bonus awards under the CIBP and LTIP will be calculated as a percentage of base salary of each employee for the plan year. The CIBP and LTIP plan awards for each year are expected to be disbursed in the first quarter of the following year. Employees must be employed by the Company at the time that awards are disbursed to be eligible.
	The CIBP awards will be paid in cash while LTIP awards will consist of restricted common stock and/or stock options. The stock and/or option awards 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 will be determined based upon the fair market value of the common stock on the date of the grant.
	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 eligible 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.
	As of December 31, 2014, there were 7,030 shares of common stock and stock options available to be granted under the 2005 Plan. On February 24, 2015, the Company granted 7,030 restricted stock awards under the 2005 Plan to a new employee. This plan expired on February 25, 2015.
	1999 Stock Incentive Plan
	The Company’s 1999 Stock Incentive Plan (the “1999 Plan”) expired in August 2009. The final 45,000 outstanding options issued under the 1999 Plan were exercised and sold to the Company in February 2012.
	Stock Options
	During the year ended December 31, 2014, the Company did not issue any stock options. However, 4,165 stock options that were previously issued were exercised and the resulting shares of common stock were sold in the open market, leaving 129,934 stock options vested and exercisable at December 31, 2014, with exercise prices ranging from $25.70 to $60.33 per share, with an average remaining contractual life of six years.
	During the year ended December 31, 2013, employees exercised 791 stock options to purchase shares of the Company’s common stock that were sold in the open market.
	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, 2014,  2013, and 2012 is presented in the table below (dollars in thousands, except per share data):
		Year Ended December 31,
		2014					2013				2012
					Weighted				Weighted				Weighted
			Shares		Average		Shares		Average		Shares		Average
			Under		Exercise		Under		Exercise		Under		Exercise
			Options		Price		Options		Price		Options		Price
	Outstanding, beginning of the period		135,107		$	53.00		—	$	—		45,000	$	54.21
	Options assumed due to Merger		—		$	—		135,898	$	52.90		—	$	—
	Exercised		-4,165		$	28.93		-791	$	36.16		—	$	—
	Canceled / Forfeited (1)		-1,008		$	42.39		—	$	—		-45,000	$	54.21
	Outstanding, end of year		129,934		$	53.85		135,107	$	53.00		—	$	—
	Aggregate intrinsic value	$	4				$	459			$	—
	Exercisable, end of year		129,934		$	53.85		135,107	$	53.00		—	$	—
	Aggregate intrinsic value	$	4				$	459			$	—
	Available for grant, end of the period		1,143,006					1,162,173				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 year ended December 31, 2014, there was an insignificant excess tax benefit recognized. For the year ended December 31, 2013, there was 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, respectively. 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.
	During the years ended December 31, 2014 and 2013, the Company did not recognize any stock option expense. 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, 2014, 2013 and 2012 was approximately $59,009,  $7,721 and $0.5 million, respectively.
	Restricted Stock
	During the year ended December 31, 2014, the Company issued 10,714 restricted stock awards to new and existing employees, which vest over four years, plus an additional 15,672 restricted stock awards to the board of directors which vest on the one-year anniversary of the date of grant. The weighted average fair value of the restricted shares granted during the year, was $40.83 with a total fair value of approximately $1.1 million after adjustment for estimated weighted average forfeiture rate of 2.2%.
	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 the Company’s new director compensation plan which vest on the one-year anniversary of the date of grant. The weighted average fair value of the restricted shares granted during the fourth quarter of 2013, was $44.10 with a total fair value of approximately $8.1 million after adjustment for estimated weighted average forfeiture rate of 5.7%.
	The Company did not grant any shares of restricted stock for the year ended December 31, 2012 and did not have any restricted shares outstanding as of December 31, 2012.
	Restricted stock activity as of December 31, 2014 and 2013 and for the years then ended is presented in the table below (dollars in thousands, except per share data):
			2014							2013
					Weighted						Weighted
			Restricted		Average		Aggregate			Restricted	Average		Aggregate
			Shares		Fair Value		Intrinsic Value			Shares	Fair Value		Intrinsic Value
	Outstanding, beginning of the period		292,632		$	44.38	$	13,830		—	$	—	$	—
	Granted		26,386			40.83		1,073		356,299		44.10		15,723
	Vested		-94,807			44.11		3,454		-63,667		42.80		2,725
	Canceled / Forfeited		-14,249			47.30		579		—		—		—
	Not vested, end of the period		209,962			43.86		6,139		292,632		44.38		13,830
	Vested, end of the period		—			—		—		—		—		—
	Expected to vest, end of the period		192,570			43.84		5,631		260,359		44.36		12,305
	During the year ended December 31, 2014, the Company recognized approximately $4.5 million in stock compensation expense. 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 $7.7 million of compensation expense will be recognized over the remaining vesting period.

Share_Repurchase_Programs

Share Repurchase Programs	12 Months Ended
	Dec. 31, 2014
Share Repurchase Programs [Abstract]
Share Repurchase Programs	9. Share Repurchase Program
	In September 2011, the Company’s board of directors approved a $50 million share repurchase program. All shares are to be purchased in the open market or through privately negotiated transactions. Purchases are made subject to market conditions and certain volume, pricing and timing restrictions to minimize the impact of the purchases upon the market, and when the Company believes its 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. During the year ended December 31, 2014, the Company purchased 205,457 shares at an average price of $35.89 per share, for a total of approximately $7.4 million. 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.
	As of December 31, 2014, the Company had invested $18.2 million in this share repurchase program to purchase 403,334 shares and net-settled 45,000 stock options from two officers, leaving $31.8 million available for future purchases.
	In October 2014, the Company amended its revolving credit facility with Royal Bank of Canada to, among other things, allow for share repurchases subject to certain conditions. The Company is currently in compliance with these additional restrictions.

Other_Financial_Information

Other Financial Information	12 Months Ended
	Dec. 31, 2014
Other Financial Information [Abstract]
Other Financial Information
	10. 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,		December 31,
		2014		2013
	Accounts receivable:
	Trade receivable	$	13,926	$	42,196
	Receivable for Alta Resources distribution		1,993		7,358
	Joint interest billing		4,096		5,172
	Income taxes receivable		3,274		4,293
	Other receivables		2,610		2,172
	Allowance for doubtful accounts		-590		-578
	Total accounts receivable	$	25,309	$	60,613
	Prepaid expenses and other:
	Prepaid insurance	$	1,242	$	1,113
	Other		699		918
	Total prepaid expenses and other	$	1,941	$	2,031
	Accounts payable and accrued liabilities:
	Royalties and revenue payable	$	31,653	$	44,933
	Accrued exploration and development		26,538		17,803
	Trade payable		17,282		11,589
	Advances from partners		8,334		6,538
	Accrued general and administrative expenses		6,258		10,872
	Other accounts payable and accrued liabilities		2,827		5,098
	Total accounts payable and accrued liabilities	$	92,892	$	96,833
	Included in the table below is supplemental information about non-cash transactions during the years ended December 31, 2014, 2013 and 2012, in thousands:
		Year Ended December 31,
		2014		2013		2012
	Cash payments:
	Interest payments	$	2,786	$	1,056	$	71
	Income tax payments, net of cash refunds		241		341		24,307
	Non-cash items excluded from investing activities in the consolidated statements of cash flows:
	Increase in accrued capital expenditures		8,735		7,004		1,192
	Assets acquired & liabilities assumed in the Merger:
	Accounts receivable		—		12,955		—
	Prepaids		—		639		—
	Proved natural gas and oil properties		2,517		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		-2,517		-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, 2014
Investment In Exaro Energy III LLC [Abstract]
Investment In Exaro Energy III LLC	11. 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 investors was approximately $183 million. The Company did not make any contributions during the year ended December 31, 2014. As of December 31, 2014, the Company had invested approximately $46.9 million.
	The following table presents condensed balance sheet data for Exaro as of December 31, 2014 and December 31, 2013. The balance sheet data was derived from the Exaro balance sheet as of December 31, 2014 and December 31, 2013 and was not adjusted to represent Contango’s percentage of ownership interest in Exaro. Contango’s share in the equity of Exaro at December 31, 2014 was approximately $61.2 million.
		December 31,		December 31,
		2014		2013
	Current assets	$	35,013	$	30,284
	Non-current assets:
	Net property and equipment		233,997		182,226
	Restricted cash escrow account		577		8,732
	Other non-current assets		1,779		1,103
	Total non-current assets		236,353		192,061
	Total assets	$	271,366	$	222,345
	Current liabilities	$	9,405	$	13,717
	Non-current liabilities:
	Long-term debt		94,500		70,000
	Other non-current liabilities		1,084		923
	Total non-current liabilities		95,584		70,923
	Members' equity		166,377		137,705
	Total liabilities & members' equity	$	271,366	$	222,345
	The following table presents the condensed results of operations for Exaro for the years ended December 31, 2014 and 2013 and for the period from the inception of Exaro, March 19, 2012, to December 31, 2012. The results of operations for the years ended December 31, 2014 and 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 Contango’s 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, 2014, 2013 and 2012 was a gain of $6.9 million, net of tax expense of $3.8 million; 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,				Period from inception to December 31,
		2014		2013		2012
	Oil and natural gas sales	$	79,536	$	52,698	$	7,514
	Other gain (loss)		5,069		-544		-3,269
	Less:
	Lease operating expenses		22,452		16,136		2,035
	Depreciation, depletion, amortization & accretion		26,036		16,058		2,350
	General & administrative expense		3,484		3,294		2,872
	Income (loss) from continuing operations		32,633		16,666		-3,012
	Net interest income (expense)		-3,861		-3,536		25
	Net income (loss)	$	28,772	$	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, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	12. 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, 2014 and 2013 were as follows (in thousands):
		Year ended December 31,
		2014		2013
	Balance as of the beginning of the period	$	23,334	$	8,678
	Liabilities incurred during period		3,123		14,145
	Liabilities settled during period		-1,963		-207
	Accretion		1,303		660
	Sales		-69		—
	Change in estimate		18		58
	Balance as of the end of the period	$	25,746	$	23,334
	Of the total liabilities incurred during the year ended December 31, 2014, $2.5 million was due to a purchase price adjustment for the merger with Crimson and $0.6 million related to new wells drilled during the period. All of the total liabilities settled during the year ended December 31, 2014 related to wells plugged and abandoned during the period.
	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 Gains from Affiliates."

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2014
Long-Term Debt [Abstract]
Long-Term Debt	13. Long-Term Debt
	RBC Credit Facility
	In connection with the Merger during 2013, 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, which was reaffirmed on October 28, 2014 and is effective through May 1, 2015. The borrowing base under the RBC Credit Facility is redetermined each November 1 and May 1. 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, 2014, the Company had $63.4 million outstanding under the RBC Credit Facility, which is due by October 1, 2017, and $1.9 million in outstanding letters of credit. 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, 2014 borrowing availability under the RBC Credit Facility was $209.7 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 years ended December 31, 2014 and 2013 was approximately $2.7 million and $1.2 million, respectively.
	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, 2014, the Company was 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 the Compnay’s 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 and 2012 was approximately $37,000 and $50,000, respectively.

Commitments_And_Contingencies

Commitments And Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments And Contingencies[Abstract]
Commitments And Contingencies	14. Commitments and Contingencies
	Contango pays delay rentals on its offshore leases and leases its office space and certain other equipment. Effective October 1, 2013, the Company moved its corporate offices to 717 Texas Avenue in downtown Houston, Texas, under a lease that expires March 31, 2019. The Company remains responsible for the rent at its previous corporate office at 3700 Buffalo Speedway in Houston, Texas, through February 29, 2016; however, effective January 1, 2014, it subleased the previous corporate offices through February 29, 2016 and expects to recover the substantial majority of the rent it pays at that location.
	As of December 31, 2014, minimum future lease payments for delay rentals and operating leases for Contango’s fiscal years are as follows (in thousands):
	Fiscal years ending December 31,
	2015	$	3,867
	2016		2,158
	2017		1,948
	2018		1,694
	2019		416
	2020 and thereafter		—
	Total	$	10,083
	The amount incurred under operating leases and delay rentals during the years ended December 31, 2014, 2013, and 2012 were approximately $6.0 million, $1.0 million and $0.5 million, respectively. As of December 31, 2014, the Company’s 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 to incentivize the individuals to remain with the Company. The final portion of these bonuses were paid on June 30, 2014.
	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 during 2013.
	Legal Proceedings
	From time to time, the Company is involved in legal proceedings relating to claims associated with its 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 the Company’s ownership of an interest in the wells at issue, although the Company may have assumed liability otherwise attributable to its predecessors-in-interest through the acquisition documents relating to the acquisition of the Company’s interest in these wells. The Company and its co-defendants obtained a favorable judgment from the trial court following a bench trial. On October 1, 2014, the Louisiana Third Circuit Court of Appeals issued an opinion reversing the trial court’s rulings and rendering judgment in favor of the plaintiffs for approximately $13.4 million. The decision by the court of appeals did not allocate liability among the defendants although the Company would likely be responsible for at least one-half, and possibly as much as two-thirds, of the judgment if it stands. The Company and its co-defendants have filed an application for a writ of certiorari to the Louisiana Supreme Court seeking review of this case by the state’s highest court. While there is uncertainty whether the Louisiana Supreme Court will accept the Company’s application and, if accepted, rule in its favor, the Company believes that the decision by the court of appeals presents issues that will resonate with the Louisiana Supreme Court and are of precedential significance sufficient to warrant review by that court. The Company and its co-defendants are vigorously defending this lawsuit and believe that they have a meritorious position. A companion case involving the same set of facts was filed in the same trial court on April 19, 2013 on behalf of additional mineral interest owners but has been inactive pending the appeal of the original case. The Company’s potential exposure in this companion case is expected to be affected by the outcome of the Company’s appeal of the original case.
	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 the Company had granted indemnification rights. In dispute is whether ownership rights were transferred through a number of decade-old poorly documented transactions. Based on prior summary judgments, the trial court recently entered a final judgment in the case in favor of the plaintiffs for approximately $5.3 million, plus post-judgment interest. The Company is vigorously defending this lawsuit, believes that it has meritorious defenses and is appealing the trial court’s decision to the applicable state Court of Appeals.
	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 the 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). The Company has 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. The plaintiff previously alleged damages of approximately $10.7 million although the plaintiff’s claim increases as additional hydrocarbons are produced from the subject wells. The Company is vigorously defending this lawsuit and believes that it has meritorious defenses. The Company believes if this matter were to be determined adversely, amounts owed to the plaintiff could be partially offset by recoupment rights the Company may have against other working interest and/or royalty interest owners in the unit.
	In connection with the Merger, several class action lawsuits were brought by Crimson stockholders in Delaware and Texas seeking damages and injunctive relief. Each of these merger-related cases has now been dismissed by the respective court without liability to the Company.
	In February 2011, a subsidiary of the Company and certain of its working interest partners and insurance carriers brought suit against a marine construction, dredging and tunneling company and an instrumentality of the United States of America in the U.S. District Court for the Southern District of Texas – Houston Division seeking monetary damages for damage to an offshore pipeline which was struck by a dredge. Following a bench trial in December 2013, the Company and its co-defendants obtained a favorable judgment from the trial court. The defendants are appealing the trial court’s judgment to the U.S. Court of Appeals for the 5th Circuit.
	While many of these matters involve inherent uncertainty and the Company is unable at the date of this filing to estimate an amount of possible loss with respect to certain of these matters, the Company believes 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 its consolidated financial position as a whole or on its liquidity, capital resources or future annual results of operations. The Company maintains various insurance policies that may provide coverage when certain types of legal proceedings are determined adversely.
	Employment Agreements
	As a result of successfully completing the Merger, Mr. Joseph J. Romano, the Company's Chairman and former Chief Executive Officer received a $4.0 million bonus payment 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 replaced 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, these employee agreements provide that 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, these employee agreements provide that 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.

Net_Income_Loss_Per_Common_Sha

Net Income (Loss) Per Common Share	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Net Income (Loss) Per Common Share	15. 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, 2014, 2013 and 2012 is presented below (in thousands):
		Year Ended December 31, 2014
		Net Loss		Shares	Per Share
	Basic Earnings per Share:
	Net loss attributable to common stock	$	-21,874	19,059	$	-1.15
	Diluted Earnings per Share:
	Effect of potential dilutive securities:
	Stock options, weighted average of incremental shares		—	—		—
	Net loss attributable to common stock	$	-21,874	19,059	$	-1.15
		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		—
	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		—
	Net loss attributable to common stock	$	-936	15,295	$	-0.06
	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, including both stock options and restricted shares, would have been 339,896 shares for the year ended December 31, 2014. The potentially dilutive shares would have been 187,302 shares for the year ended December 31, 2013. The Company had no potentially dilutive securities for the year ended December 31, 2012.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Taxes [Abstract]
Income Taxes	16. 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,
		2014						2013					2012
	Provision/(benefit) at statutory tax rate	$	-11,920		35.00	%		$	23,011		35.00	%	$	-94	35.00	%
	State income tax provision, net of federal benefit		1,028		-3	%			2,928		4.45	%		654	-241.84	%
	Permanent differences		202		-0.6	%			-1,559		-2.37	%		450	-166.34	%
	State depletion deductions		-1,723		5.10	%			—		—	%		—	—	%
	Other		230		-0.7	%			4		0.01	%		-373	137.65	%
	Income tax provision /(benefit)	$	-12,183		35.80	%		$	24,384		37.09	%	$	637	-235.53	%
	The effective tax rate for December 31, 2014 varies from the statutory rate primarily due to the effect of state income tax expenses. During 2014, the Company reassessed depletion deductions for Louisiana income tax purposes for all tax years open under the Louisiana statute of limitations. These additional deductions allowed under the Louisiana state statutes resulted in a reduction of cash taxes of $1.7 million. The effective tax rate for December 31, 2013 varied from the statutory rate due to the effect of state income taxes and a benefit for tax exempt life insurance proceeds of $10 million offset by non-deductible merger related expenses of $3.0 million and non-deductible compensation expenses of $1.4 million.
	The provision (benefit) for income taxes from continuing operations for the periods indicated are comprised of the following (in thousands):
			Year Ended December 31,
			2014			2013			2012
	Current tax provision (benefit):
	Federal		$	-392		$	8,739		$	7,038
	State			478			3,857			2,168
	Total		$	86		$	12,596		$	9,206
	Deferred tax provision (benefit):
	Federal		$	-11,518		$	11,361		$	-8,343
	State			-751			427			-226
	Total		$	-12,269		$	11,788		$	-8,569
	Total tax provision (benefit):
	Federal		$	-11,910		$	20,100		$	-1,305
	State			-273			4,284			1,942
	Total		$	-12,183		$	24,384		$	637
	Included in gain from investment in affiliates		$	3,727		$	1,245		$	32
	Total income tax provision (benefit)		$	-15,910		$	23,139		$	605
	The net deferred tax liability is comprised of the following (in thousands):
			December 31,
			2014			2013
	Deferred tax assets:
	Net operating loss carryforward		$	39,085		$	49,204
	Income tax credits			661			2,676
	Derivative instruments			165			564
	Deferred compensation			465			406
	Other			1,953			1,165
	Total deferred tax assets before valuation allowance		$	42,329		$	54,015
	Valuation allowance			-2,161			-2,552
	Net deferred tax assets		$	40,168		$	51,463
	Deferred tax liability:
	Oil and gas properties		$	-104,209		$	-133,894
	Investment in affiliates			-28,287			-21,681
	Other			—			-518
	Deferred tax liability		$	-132,496		$	-156,093
	Total net deferred tax liability		$	-92,328		$	-104,630
	In assessing the realizability of deferred tax assets, the Company considers 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. The Company considers 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, the Company believes it is more likely than not that it will realize the benefits of these deductible differences of a $6.2 million valuation allowance.
	As of December 31, 2014, the Company had federal net operating loss (“NOL") carryforwards of approximately $112.3 million and state NOLs of $10.2 million. All NOL carryforwards were acquired in a Merger with Crimson. These NOLs are available to reduce future taxable income and the related income tax liability of the combined company. At the date of the Merger, Crimson had a 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 allowances of approximately $29.2 million, or $10.2 million tax-adjusted. The 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 NOLs acquired by Crimson in previous acquisitions. As of December 31, 2014 the remaining valuation allowance decreased to $6.2 million, or $2.2 million tax-adjusted, due to an adjustment to reflect expired NOLs of $1.1 million. The utilization of NOL carryforwards acquired in the Merger with Crimson is limited by Section 382 as discussed below.
	Federal NOL carryforwards of $112.3 million expire at various dates beginning in 2018 and ending in 2034. NOL carryforwards of $6.2 million impacted by Crimson's Section 382 limitations, which are not expected to be realized, will expire in 2018 through 2020. Federal NOL carryforwards of $106.1 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 2029 and ending in 2033. The Company believes that it will be able to utilize all 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 result of the Merger, the Company 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, 2013		$	518
	Additions based on tax positions related to the current year			—
	Additions based on tax positions related to prior years			—
	Additions due to acquisitions			—
	Reductions due to a lapse of the applicable statute of limitations			—
	Balance at December 31, 2014		$	518
	The Company's policy is to recognize interest and penalties related to uncertain tax positions as income tax benefit (expense) in the Company’s Consolidated Statements of Operations. The Company had no interest or penalties related to unrecognized tax benefits for the year ended December 31, 2014 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. The Company does not anticipate that the total unrecognized tax benefits will significantly change due to the settlement of audits and the expiration of statute of limitations prior to December 31, 2014.
	Generally, the Company's income tax years of 1998 through the current year remain open and subject to examination by Federal tax authorities, and the tax years of 2009 through current remain open and subject to examination by the tax authorities in Texas and Louisiana which are the jurisdictions where the Company carries its principal operations.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions	17. 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 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. Pursuant to the First Right Agreement, JEX was to be paid an annual fee of $0.5 million. 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 provided advisory services to Contaro in connection with Contaro's investment in Exaro, and Mr. Juneau served on the Board of Managers of Exaro and performed such duties as described in the limited liability company operating agreement of Exaro. Pursuant to the Contaro Advisory Agreement, JEX was paid a monthly fee of $10,000 and was entitled to receive a one percent (1%) fee of the cash profit earned by Contaro.
	On March 19, 2014, Mr. Juneau resigned from the board of directors and no longer provides services under the Contaro Advisory Agreement. As a result, the Contaro Advisory Agreement was terminated effective as of March 19, 2014.
	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 continued as 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 its 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, 2014, Contango, Olympic, JEX, REX and JEX employees owned the following interests in the Company's offshore wells.
			Olympic		JEX		REX		JEX Employees
			WI	NRI	WI	NRI	WI	NRI	ORRI
	Dutch #1 - #5		3.53%	2.84%	1.88%	1.51%	—%	—%	2.02%
	Mary Rose #1		3.61%	2.70%	2.01%	1.51%	—%	—%	2.79%
	Mary Rose #2 - #3		3.61%	2.58%	2.01%	1.44%	—%	—%	2.79%
	Mary Rose #4		2.34%	1.70%	1.31%	0.95%	—%	—%	1.82%
	Mary Rose #5		2.56%	1.87%	1.43%	1.04%	—%	—%	1.54%
	Ship Shoal 263		—%	—%	—%	—%	—%	—%	3.33%
	Vermilion 170		—%	—%	4.30%	3.35%	12.50%	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:
			Olympic		JEX
			WI	NRI	WI	NRI
	Dutch #1 - #5		3.02%	2.42%	1.61%	1.29%
	During the year ended December 31, 2014, Mr. Romano earned $105 thousand and Mr. Juneau earned $12 thousand in cash, for their service as a director of the Company. In April 2014, the board of directors accelerated the vesting of Mr. Juneau’s 1,622 shares which would have otherwise been forfeited upon his resignation in March 2014. The Company recognized compensation expense of approximately $71 thousand related to the shares granted to Mr. Juneau for the three months ended March 31, 2014. Additionally, during the year ended December 31, 2014, Mr. Romano received 2,612 shares of restricted stock, which vest 100% on the one-year anniversary of the date of grant, as part of his board of director compensation. Below is a summary of transactions between the Company, Olympic, JEX, and REX during the years ended December 31, 2014, 2013 and 2012.
		·		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 July 2011, the Company recompleted its Eloise South well uphole in the Cib-Op sands as its 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 its 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 interest (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. JEX will receive a carried working interest of 10% in certain of the Company’s TMS wells, 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% ORRI was granted to the geologist who generated the TMS prospect for us. The geologist has subsequently been employed by Contango.
		·		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 its rental liability for that space.
	Below is a summary of payments the Company received from (paid to) Olympic, JEX, and REX in the ordinary course of business in its 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,
			2014						2013						2012
			Olympic		JEX		REX		Olympic		JEX		REX		Olympic		JEX		REX
	Revenue payments as well owners		$	-7,349	$	-4,882	$	-2,270	$	-6,859	$	-4,628	$	-1,932	$	-6,888	$	-5,230	$	-4,308
	Joint interest billing receipts			673		521		322		945		1,201		2,090		1,081		724		885
	Mary Rose well cost adjustment			—		—		—		—		—		—		-201		118		-1,185
	Below is a summary of payments the Company 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,
			2014						2013						2012
			Olympic		JEX		REX		Olympic		JEX		REX		Olympic		JEX		REX
	Reimbursement of certain costs		$	-54	$	-29	$	—	$	—	$	-115	$	-4	$	—	$	-496	$	-9
	Rent received for sublease			—		142		—		—		—		—		—		—		—
	Prospect fees			—		—		—		—		-1,000		—		—		—		—
	Advisory Agreements			—		—		—		—		-361		—		—		-1,530		—
	REX distribution to members			—		—		—		—		—		-197		—		—		1,469
	As of December 31, 2014 and 2013, the Company's consolidated balance sheets reflected the following balances (in thousands):
			31-Dec-14						31-Dec-13
			Olympic		JEX		REX		Olympic		JEX		REX
	Accounts receivable:
	Joint interest billing			48		42		12		34		87		116
	Accounts payable:
	Royalties and revenue payable			-1,006		-620		-175		-1,293		-877		-466
	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, 2014, an affiliate of Oaktree earned $64 thousand in cash and 2,612 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.
In November 2011, the Company executed a $1.0 million Revolving Line of Credit Promissory Note to lend money to Contango ORE, Inc. (the “CORE Note”). The Company and Contango ORE, Inc. (“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.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2014
Subsequent Events [Abstract]
Subsequent Events	18. Subsequent Events
	The Company has 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 was 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, 2014
Summary Of Significant Accounting Policies [Abstract]
Basis Of Presentation	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, 2014 and 2013 and for the three years ended December 31, 2014 contained herein, include consolidated results of operations of both Contango Oil & Gas Company and Crimson for the period from the closing date of the Merger to December 31, 2014 and only consolidated financial statements of Contango for all other the periods presented herein.
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.
Other Investments, cost method	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 Other income (expense) line item in the Company's statement of operations and in the investing cash flows in the Company's statement of cash flow 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 its investment in Exaro, while a net loss or payment of dividends decreases its investment. In the consolidated statement of operations, the Company’s proportionate share of Exaro's net income or loss is reported as a single line-item in Gain 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. As of December 31, 2014, 2013 and 2012, the Company had no significant imbalances.
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. As of December 31, 2014, 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, 2014, accounts payable included $12.1 million representing outstanding checks that had not been presented for payment net of cash balance in the bank as of December 31, 2014. 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.
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.
	Accounts receivable allowance for bad debt was $0.6 million, as of December 31, 2014 and 2013, respectively. At December 31, 2014 and 2013 the carrying value of the Company’s accounts receivable approximated fair value.
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 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, operating costs and 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. For the year ended December 31, 2014, the Company recorded an impairment expense of approximately $11.4 million related to proved properties. Of this amount, $7.7 million related to South Timbalier 17 and $3.7 million related to TMS. No impairment of proved properties was recognized during the year ended December 31, 2013. 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 the 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 an impairment of the carrying value, and any such impairment is charged to expense in the period.
	On April 29, 2014, the Company reached total depth on its Ship Shoal 255 well, and no commercial hydrocarbons were found. As a result, for the year ended December 31, 2014, the Company recognized $31.5 million in exploration expense for the cost of drilling the well and $15.6 million in impairment expense, including $3.5 million related to leasehold costs and $12.1 million related to the platform located in Ship Shoal 263 block which was expected to be used by the Ship Shoal 255 well had it been successful.
	During the year ended December 31, 2014, the Company also recognized impairment expense of approximately $20.1 million related to impairment and partial impairment of certain unproved properties due to expiring leases and leases not likely to be drilled. Of this amount, approximately $9.7 million relates to undrilled offshore leases and approximately $9.7 million relates to undeveloped TMS acreage.
	For the year ended December 31, 2013, the Company recorded an impairment expense on unproved properties of $0.6 million related to leasehold costs on the Ship Shoal 83 prospect which it relinquished in August 2013, and $0.2 million related to leasehold costs on the Brazos Area 543 prospect. The Company did not recognize any impairment of unproved properties for the year ended December 31, 2012.
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. See Note 12 - "Asset Retirement Obligations" for additional information.
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, 2014. The amount of unrecognized tax benefits did not materially change from December 31, 2013. The amount of unrecognized tax benefits may change in the next twelve months; however, the Company does not expect the change to have a significant impact on its 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 1998 – 2014, and state tax returns for 2009 – 2014, 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. See Note 3 - "Concentration of Credit Risk" for additional information.
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 years ended December 31, 2014 and 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 requisite service period, which generally aligns with 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. As of December 31, 2014, the Company has not entered into any derivative contracts to reduce exposure to interest rate risk. However, 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 "Loss on derivatives, net" on the consolidated statements of operations for the years ended December 31, 2014 and 2013. The Company did not have any derivative instruments or hedging activities for the year ending December 31, 2012. 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. As of December 31, 2014, there were no commodity hedges in place.
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 in order to conform to the presentation for the years ended December 31, 2014 and 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 the Company’s 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 January 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2015-01: Income Statement – Extraordinary and Unusual Items (Subtopic 225-20): Simplifying Income Statement Presentation by Eliminating the Concept of Extraordinary Items (ASU 2015-01). ASU 2015-01 is part of an initiative to reduce complexity in accounting standards. This update eliminates from generally accepted accounting principles the concept of extraordinary items, which eliminates the requirements for reporting entities to consider whether an underlying event or transaction is extraordinary. However, this will not result in a loss of information as the presentation and disclosure guidance for items that are unusual in nature or occur infrequently will be retained. ASU 2015-01 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015; early application is permitted. The provisions of this accounting update are not expected to have a material impact on the Company’s financial position or results of operations.
	In November 2014, the FASB issued Accounting Standards Update No. 2014-17: Business Combinations (Topic 805): Pushdown Accounting (ASU 2014-17). ASU 2014-17 addresses the limited guidance available for determining whether and at what threshold pushdown accounting should be established in an acquired entity’s separate financial statements. Thus, the amendments in this update provide an acquired entity with an option to apply pushdown accounting upon occurrence of an event in which an acquirer obtains control of the acquired entity. Furthermore, the amendments in this update provide specific guidance on pushdown accounting for all entities, and the threshold for pushdown accounting is consistent with the threshold for change-in-control events in Topic 805, Business Combinations, and Topic 810, Consolidation. ASU 2014-17 became effective on November 18, 2014. The provisions of this accounting update are not expected to have a material impact on the Company’s financial position or results of operations.
	In August 2014, the FASB issued Accounting Standards Update No. 2014-15: Presentation of Financial Statements – Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (ASU 2014-15). ASU 2014-15 asserts that management should evaluate whether there are relevant condition or events that are known and reasonably knowable that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date the financial statements are issued or are available to be issued when applicable. If conditions or events at the date the financial statements are issued raise substantial doubt about an entity’s ability to continue as a going concern, disclosures are required which will enable users of the financial statements to understand the conditions or events as well as management’s evaluation and plan. ASU 2014-15 is effective for the annual period ending after December 15, 2016, and for annual and interim periods thereafter; early application is permitted. The provisions of this accounting update are not expected to have a material impact on the Company’s financial position or results of operations.
	In May 2014, the FASB and the International Accounting Standards Board (“IASB”) jointly issued new accounting guidance for recognition of revenue Accounting Standards Update No. 2014-09: Revenue from Contracts with Customers (Topic 606) (ASU 2014-09). This new guidance replaces virtually all existing US GAAP and IFRS guidance on revenue recognition. ASU 2014-09 is effective for fiscal years beginning after December 15, 2016. This new guidance applies to all periods presented. Therefore, when the Company issues its financial statements on Forms 10-Q and 10-K for periods included in its year ended December 31, 2017, its comparative periods that are presented from the years ended December 31, 2015 and 2016, must be retrospectively presented in compliance with this new guidance. Early adoption is not allowed for US GAAP. The new guidance requires companies to make more estimates and use more judgment than under current accounting guidance. The Company does not anticipate that this new guidance will have a material impact on the Company’s consolidated financial position or results of operations for the periods presented.
	In April 2014, the FASB issued Accounting Standards Update No. 2014-08: Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity (ASU 2014-08). ASU 2014-08 changes the criteria for reporting discontinued operations while enhancing disclosures in this area. The amended guidance requires that a disposal representing a strategic shift that has (or will have) a major effect on an entity’s financial results or a business activity classified as held for sale should be reported as discontinued operations. The amendments also expand the disclosure requirements for discontinued operations and add new disclosures for individually significant dispositions that do not qualify as discontinued operations. ASU 2014-08 is effective for annual and interim periods beginning after December 15, 2014 (early adoption is permitted only for disposals that have not been previously reported). The implementation of the amended guidance of ASU 2014-08 is not expected to have a material impact on the Company’s consolidated financial position or results of operations.
	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. The Company implemented the changes required by the new COSO framework during the year ended December 31, 2014. The Company will continue to assess the impact, if any, it may have on its internal control structure.
	In February 2013, the 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. The Company evaluated the provisions of this accounting update and does not believe it has a material impact on its 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 2015 and beyond, including, but not limited to, 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, 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.

Merger_With_Crimson_Exploratio1

Merger With Crimson Exploration Inc. (Tables)	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Schedule Of Assets Acquired And Liabilities Assumed
	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		12,967
	Amount attributable to liabilities assumed		308,464
	Total consideration including liabilities assumed	$	455,038
	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		416,433
	Other non-current assets		208
	Amount attributable to net assets acquired	$	455,038
	Goodwill	$	—
Schedule Of Consolidated Pro Forma Information
			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, 2014
Fair Value Measurements [Abstract]
Schedule Of Fair Value Of Financial Assets And (Liabilities)
		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, 2014
Derivative Instruments [Abstract]
Schedule Of Fair Value Of Commodity Derivatives
			Gross		Netting (1)		Total
	Assets		$	76	$	-76	$	—
	Liabilities		$	-1,207	$	76	$	-1,131
		-1		Represents counterparty netting under agreements governing such derivatives
Schedule Of Derivative Contracts On Operations
			Year ended December 31,
	Contract Type		2014		2013
	Crude oil contracts		$	276	$	180
	Natural gas contracts			-1,560		98
	Realized gain (loss)		$	-1,284	$	278
	Crude oil contracts		$	1,183	$	-1,179
	Natural gas contracts			-52		-231
	Unrealized gain (loss)		$	1,131	$	-1,410
	Gain (loss) on derivatives, net		$	-153	$	-1,132

Stock_Based_Compensation_Table

Stock Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2014
Stock-Based Compensation [Abstract]
Summary Of Stock Options Granted
		Year Ended December 31,
		2014					2013				2012
					Weighted				Weighted				Weighted
			Shares		Average		Shares		Average		Shares		Average
			Under		Exercise		Under		Exercise		Under		Exercise
			Options		Price		Options		Price		Options		Price
	Outstanding, beginning of the period		135,107		$	53.00		—	$	—		45,000	$	54.21
	Options assumed due to Merger		—		$	—		135,898	$	52.90		—	$	—
	Exercised		-4,165		$	28.93		-791	$	36.16		—	$	—
	Canceled / Forfeited (1)		-1,008		$	42.39		—	$	—		-45,000	$	54.21
	Outstanding, end of year		129,934		$	53.85		135,107	$	53.00		—	$	—
	Aggregate intrinsic value	$	4				$	459			$	—
	Exercisable, end of year		129,934		$	53.85		135,107	$	53.00		—	$	—
	Aggregate intrinsic value	$	4				$	459			$	—
	Available for grant, end of the period		1,143,006					1,162,173				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
			2014							2013
					Weighted						Weighted
			Restricted		Average		Aggregate			Restricted	Average		Aggregate
			Shares		Fair Value		Intrinsic Value			Shares	Fair Value		Intrinsic Value
	Outstanding, beginning of the period		292,632		$	44.38	$	13,830		—	$	—	$	—
	Granted		26,386			40.83		1,073		356,299		44.10		15,723
	Vested		-94,807			44.11		3,454		-63,667		42.80		2,725
	Canceled / Forfeited		-14,249			47.30		579		—		—		—
	Not vested, end of the period		209,962			43.86		6,139		292,632		44.38		13,830
	Vested, end of the period		—			—		—		—		—		—
	Expected to vest, end of the period		192,570			43.84		5,631		260,359		44.36		12,305

Other_Financial_Information_Ta

Other Financial Information (Tables)	12 Months Ended
	Dec. 31, 2014
Other Financial Information [Abstract]
Schedule Of Additional Financial Details
		December 31,		December 31,
		2014		2013
	Accounts receivable:
	Trade receivable	$	13,926	$	42,196
	Receivable for Alta Resources distribution		1,993		7,358
	Joint interest billing		4,096		5,172
	Income taxes receivable		3,274		4,293
	Other receivables		2,610		2,172
	Allowance for doubtful accounts		-590		-578
	Total accounts receivable	$	25,309	$	60,613
	Prepaid expenses and other:
	Prepaid insurance	$	1,242	$	1,113
	Other		699		918
	Total prepaid expenses and other	$	1,941	$	2,031
	Accounts payable and accrued liabilities:
	Royalties and revenue payable	$	31,653	$	44,933
	Accrued exploration and development		26,538		17,803
	Trade payable		17,282		11,589
	Advances from partners		8,334		6,538
	Accrued general and administrative expenses		6,258		10,872
	Other accounts payable and accrued liabilities		2,827		5,098
	Total accounts payable and accrued liabilities	$	92,892	$	96,833
Schedule Of Supplemental Disclosures
		Year Ended December 31,
		2014		2013		2012
	Cash payments:
	Interest payments	$	2,786	$	1,056	$	71
	Income tax payments, net of cash refunds		241		341		24,307
	Non-cash items excluded from investing activities in the consolidated statements of cash flows:
	Increase in accrued capital expenditures		8,735		7,004		1,192
	Assets acquired & liabilities assumed in the Merger:
	Accounts receivable		—		12,955		—
	Prepaids		—		639		—
	Proved natural gas and oil properties		2,517		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		-2,517		-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, 2014
Investment In Exaro Energy III LLC [Abstract]
Schedule Of Condensed Balance Sheet Data
		December 31,		December 31,
		2014		2013
	Current assets	$	35,013	$	30,284
	Non-current assets:
	Net property and equipment		233,997		182,226
	Restricted cash escrow account		577		8,732
	Other non-current assets		1,779		1,103
	Total non-current assets		236,353		192,061
	Total assets	$	271,366	$	222,345
	Current liabilities	$	9,405	$	13,717
	Non-current liabilities:
	Long-term debt		94,500		70,000
	Other non-current liabilities		1,084		923
	Total non-current liabilities		95,584		70,923
	Members' equity		166,377		137,705
	Total liabilities & members' equity	$	271,366	$	222,345
Schedule Of Condensed Income Statement Data
		Year Ended December 31,				Period from inception to December 31,
		2014		2013		2012
	Oil and natural gas sales	$	79,536	$	52,698	$	7,514
	Other gain (loss)		5,069		-544		-3,269
	Less:
	Lease operating expenses		22,452		16,136		2,035
	Depreciation, depletion, amortization & accretion		26,036		16,058		2,350
	General & administrative expense		3,484		3,294		2,872
	Income (loss) from continuing operations		32,633		16,666		-3,012
	Net interest income (expense)		-3,861		-3,536		25
	Net income (loss)	$	28,772	$	13,130	$	-2,987

Asset_Retirement_Obligation_Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation
		Year ended December 31,
		2014		2013
	Balance as of the beginning of the period	$	23,334	$	8,678
	Liabilities incurred during period		3,123		14,145
	Liabilities settled during period		-1,963		-207
	Accretion		1,303		660
	Sales		-69		—
	Change in estimate		18		58
	Balance as of the end of the period	$	25,746	$	23,334

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments And Contingencies[Abstract]
Schedule of Minimum Future Lease Operating Leases
	Fiscal years ending December 31,
	2015	$	3,867
	2016		2,158
	2017		1,948
	2018		1,694
	2019		416
	2020 and thereafter		—
	Total	$	10,083

Net_Income_Loss_Per_Common_Sha1

Net Income (Loss) Per Common Share (Tables)	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Components Of Basic And Diluted Net Income Per Share Of Common Stock
		Year Ended December 31, 2014
		Net Loss		Shares	Per Share
	Basic Earnings per Share:
	Net loss attributable to common stock	$	-21,874	19,059	$	-1.15
	Diluted Earnings per Share:
	Effect of potential dilutive securities:
	Stock options, weighted average of incremental shares		—	—		—
	Net loss attributable to common stock	$	-21,874	19,059	$	-1.15
		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		—
	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		—
	Net loss attributable to common stock	$	-936	15,295	$	-0.06

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Taxes [Abstract]
Schedule Of Effective Income Tax Rate Reconciliation
		Year Ended December 31,
		2014						2013					2012
	Provision/(benefit) at statutory tax rate	$	-11,920		35.00	%		$	23,011		35.00	%	$	-94	35.00	%
	State income tax provision, net of federal benefit		1,028		-3	%			2,928		4.45	%		654	-241.84	%
	Permanent differences		202		-0.6	%			-1,559		-2.37	%		450	-166.34	%
	State depletion deductions		-1,723		5.10	%			—		—	%		—	—	%
	Other		230		-0.7	%			4		0.01	%		-373	137.65	%
	Income tax provision /(benefit)	$	-12,183		35.80	%		$	24,384		37.09	%	$	637	-235.53	%
Components Of Income Tax Expense (Benefit)
			Year Ended December 31,
			2014			2013			2012
	Current tax provision (benefit):
	Federal		$	-392		$	8,739		$	7,038
	State			478			3,857			2,168
	Total		$	86		$	12,596		$	9,206
	Deferred tax provision (benefit):
	Federal		$	-11,518		$	11,361		$	-8,343
	State			-751			427			-226
	Total		$	-12,269		$	11,788		$	-8,569
	Total tax provision (benefit):
	Federal		$	-11,910		$	20,100		$	-1,305
	State			-273			4,284			1,942
	Total		$	-12,183		$	24,384		$	637
	Included in gain from investment in affiliates		$	3,727		$	1,245		$	32
	Total income tax provision (benefit)		$	-15,910		$	23,139		$	605
Schedule Of Net Deferred Tax Liability
			December 31,
			2014			2013
	Deferred tax assets:
	Net operating loss carryforward		$	39,085		$	49,204
	Income tax credits			661			2,676
	Derivative instruments			165			564
	Deferred compensation			465			406
	Other			1,953			1,165
	Total deferred tax assets before valuation allowance		$	42,329		$	54,015
	Valuation allowance			-2,161			-2,552
	Net deferred tax assets		$	40,168		$	51,463
	Deferred tax liability:
	Oil and gas properties		$	-104,209		$	-133,894
	Investment in affiliates			-28,287			-21,681
	Other			—			-518
	Deferred tax liability		$	-132,496		$	-156,093
	Total net deferred tax liability		$	-92,328		$	-104,630
Schedule Of Unrecognized Tax Benefits
			Unrecognized Tax Benefits
	Balance at December 31, 2013		$	518
	Additions based on tax positions related to the current year			—
	Additions based on tax positions related to prior years			—
	Additions due to acquisitions			—
	Reductions due to a lapse of the applicable statute of limitations			—
	Balance at December 31, 2014		$	518

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Schedule Of Oil and Gas Ownership Interests
		Olympic		JEX		REX		JEX Employees
		WI	NRI	WI	NRI	WI	NRI	ORRI
	Dutch #1 - #5	3.53%	2.84%	1.88%	1.51%	—%	—%	2.02%
	Mary Rose #1	3.61%	2.70%	2.01%	1.51%	—%	—%	2.79%
	Mary Rose #2 - #3	3.61%	2.58%	2.01%	1.44%	—%	—%	2.79%
	Mary Rose #4	2.34%	1.70%	1.31%	0.95%	—%	—%	1.82%
	Mary Rose #5	2.56%	1.87%	1.43%	1.04%	—%	—%	1.54%
	Ship Shoal 263	—%	—%	—%	—%	—%	—%	3.33%
	Vermilion 170	—%	—%	4.30%	3.35%	12.50%	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:
		Olympic		JEX
		WI	NRI	WI	NRI
	Dutch #1 - #5	3.02%	2.42%	1.61%	1.29%
Schedule Of Payments Received From (Made To) Related Parties
		Year ended December 31,
		2014						2013						2012
		Olympic		JEX		REX		Olympic		JEX		REX		Olympic		JEX		REX
	Revenue payments as well owners	$	-7,349	$	-4,882	$	-2,270	$	-6,859	$	-4,628	$	-1,932	$	-6,888	$	-5,230	$	-4,308
	Joint interest billing receipts		673		521		322		945		1,201		2,090		1,081		724		885
	Mary Rose well cost adjustment		—		—		—		—		—		—		-201		118		-1,185
	Below is a summary of payments the Company 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,
		2014						2013						2012
		Olympic		JEX		REX		Olympic		JEX		REX		Olympic		JEX		REX
	Reimbursement of certain costs	$	-54	$	-29	$	—	$	—	$	-115	$	-4	$	—	$	-496	$	-9
	Rent received for sublease		—		142		—		—		—		—		—		—		—
	Prospect fees		—		—		—		—		-1,000		—		—		—		—
	Advisory Agreements		—		—		—		—		-361		—		—		-1,530		—
	REX distribution to members		—		—		—		—		—		-197		—		—		1,469
Schedule Of Related Party Balances
		31-Dec-14						31-Dec-13
		Olympic		JEX		REX		Olympic		JEX		REX
	Accounts receivable:
	Joint interest billing		48		42		12		34		87		116
	Accounts payable:
	Royalties and revenue payable		-1,006		-620		-175		-1,293		-877		-466

Organization_And_Business_Deta

Organization And Business (Details)	0 Months Ended
	Oct. 01, 2013	Dec. 31, 2014	Apr. 30, 2012
		item
GULF OF MEXICO
Gas and Oil Acreage [Line Items]
Exploratory Prospects		6
Crimson [Member]
Gas and Oil Acreage [Line Items]
Acquisition of Crimson, shares	3,864,101
Ownership percentage acquired	20.30%
Exaro Energy III LLC [Member]
Gas and Oil Acreage [Line Items]
Equity method investment, ownership percentage		37.00%	37.00%

Summary_Of_Significant_Account2

Summary Of Significant Accounting Policies (Details) (USD $)	12 Months Ended
Share data in Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Aug. 31, 2013	Apr. 30, 2012
Significant Accounting Policies [Line Items]
Cash and cash equivalents	$0		$79,487,000	$151,940,000
Outstanding checks in accounts payable that have not yet been presented for payment	12,100,000	5,900,000
Allowance for doubtful accounts	590,000	578,000
Impairment of proved properties	11,400,000	0	14,100,000
Impairment charges, unproved properties	15,600,000		0
Exploration expenses	33,387,000	1,811,000	51,903,000
Gas balancing asset (liability)	0	0	0
Weighted average incremental shares		2
Potentially dilutive shares	339,896	187,302	0
Derivative contract	0		0
Commodity Contract [Member] | Designated as Hedging Instrument [Member]
Significant Accounting Policies [Line Items]
Derivative contract	0
RBC Credit Facility [Member]
Significant Accounting Policies [Line Items]
Debt issuance costs incurred		2,200,000
Original term of credit line	4 years
Ship Shoal 263 [Member]
Significant Accounting Policies [Line Items]
Impairment of proved properties			12,000,000
Impairment charges, unproved properties	12,100,000
Eugene Island 24 [Member]
Significant Accounting Policies [Line Items]
Impairment of proved properties			2,100,000
Ship Shoal 83 [Member]
Significant Accounting Policies [Line Items]
Impairment charges, unproved properties		600,000
Brazos 543 [Member]
Significant Accounting Policies [Line Items]
Impairment charges, unproved properties		200,000
Ship Shoal 255 Well [Member]
Significant Accounting Policies [Line Items]
Impairment charges, unproved properties	3,500,000
Exploration expenses	31,500,000
Unproved Properties With Expiring Leases [Member]
Significant Accounting Policies [Line Items]
Impairment charges, unproved properties	20,100,000
South Timbalier 17 [Member]
Significant Accounting Policies [Line Items]
Impairment of proved properties	7,700,000
Undrilled Offshore Leases [Member]
Significant Accounting Policies [Line Items]
Impairment charges, unproved properties	9,700,000
Tuscaloosa Marine Shale [Member]
Significant Accounting Policies [Line Items]
Impairment of proved properties	3,700,000
Impairment charges, unproved properties	$9,700,000
Minimum [Member]
Significant Accounting Policies [Line Items]
Property and equipment depreciation, estimated useful life	3 years
Maximum [Member]
Significant Accounting Policies [Line Items]
Property and equipment depreciation, estimated useful life	13 years
Restricted assets, percent of net assets	25.00%
Moblize, Inc. [Member]
Significant Accounting Policies [Line Items]
Cost method investment ownership percentage	19.50%
Alta Energy [Member]
Significant Accounting Policies [Line Items]
Cost method investment ownership percentage	2.00%				2.00%
Exaro Energy III LLC [Member]
Significant Accounting Policies [Line Items]
Number of seats on Board of Directors	2
Equity method investment, ownership percentage	37.00%					37.00%

Concentration_Of_Credit_Risk_D

Concentration Of Credit Risk (Details)	12 Months Ended
	Dec. 31, 2014
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	31.00%
Sales Revenue, Goods, Net [Member] | Shell Trading US Company [Member] | Customer Concentration Risk [Member]
Concentration Risk [Line Items]
Concentration risk, percentage	10.00%
Sales Revenue, Goods, Net [Member] | Sunoco Inc [Member]
Concentration Risk [Line Items]
Concentration risk, percentage	27.00%
Sales Revenue, Goods, Net [Member] | Enterprise Products Operating LLC [Member] | Customer Concentration Risk [Member]
Concentration Risk [Line Items]
Concentration risk, percentage	5.00%
Sales Revenue, Goods, Net [Member] | Exxon Mobil Oil Corp. [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			3 Months Ended
	Oct. 01, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Jun. 30, 2014	Oct. 28, 2014	Sep. 30, 2013	Oct. 22, 2010
Business Acquisition [Line Items]
Change in estimate of ARO		$18,000	$58,000
Accrued interest and pre-payment penalty	1,800,000
Repayment of long-term debt	127,600,000		235,373,000
Provision/(benefit) at statutory tax rate			37.00%
Pro forma, depletion adjustment			1,900,000	7,500,000
Decrease in interest expense			16,000,000	21,300,000
Pro forma impairment charges			2,900,000	132,000,000
RBC Credit Facility [Member]
Business Acquisition [Line Items]
Revolving credit facility, maximum borrowing capacity	500,000,000
Revolving credit facility, expiration period		4 years
Revolving credit facility, borrowing base	275,000,000						275,000,000
Credit facility fees	2,200,000
Borrowings under new revolving credit facility	110,000,000
Effective interest rate on credit facility					2.20%
Amegy Bank Credit Agreement [Member]
Business Acquisition [Line Items]
Revolving credit facility, maximum borrowing capacity	40,000,000							40,000,000
Revolving credit facility, borrowing base									40,000,000
Barclays [Member]
Business Acquisition [Line Items]
Assumed debt, accrued interest, and prepayment premium	175,000,000
Wells Fargo [Member]
Business Acquisition [Line Items]
Assumed debt, accrued interest, and prepayment premium	58,600,000
Debt Assumed from Crimson Acquisition [Member]
Business Acquisition [Line Items]
Repayment of long-term debt	127,600,000
Crimson [Member]
Business Acquisition [Line Items]
Conversion rate for crimson stock	0.08288
Common stock issued to Crimson stockholders	3,864,101
Ownership percentage, post-merger	20.30%
Change in estimate of ARO						2,500,000
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%
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
Accrued interest and pre-payment penalty	1,800,000
Assumed debt, accrued interest, and prepayment premium	235,373,000
Repayment of long-term debt	235,400,000
Additional deferred tax liability due to basis differences	42,800,000
Change in fair value of deferred tax assets related to valuation allowances	10,200,000
Operating loss carryforwards	110,000,000
Crimson contributed revenue since acquisition		143,400,000			33,400,000
Crimson contributed income (loss) since acquisition		4,900,000			700,000
Stock-based compensation expense			5,700,000
Amortization of debt issuance costs	800,000
Amortization of debt discount	3,700,000
Increase (decrease) in valuation allowance of deferred tax asset	29,200,000		-10,200,000
Crimson [Member] | Barclays [Member]
Business Acquisition [Line Items]
Long-term debt	175,000,000
Accrued interest and pre-payment penalty	1,800,000
Crimson [Member] | Wells Fargo [Member]
Business Acquisition [Line Items]
Long-term debt	58,600,000
Crimson [Member] | Minimum [Member]
Business Acquisition [Line Items]
Average expected term (in years)	2 years 8 months 12 days
Crimson [Member] | Maximum [Member]
Business Acquisition [Line Items]
Average expected term (in years)	4 years 9 months 15 days
General and Administrative Expense [Member] | Crimson [Member]
Business Acquisition [Line Items]
Merger related expenditures			6,800,000
Bankers success fees			2,800,000
Accrued bonus expense			1,300,000
Debt Issuance Costs [Member]
Business Acquisition [Line Items]
Pro forma, depletion adjustment			$600,000	$400,000

Recovered_Sheet1

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	Oct. 01, 2013
Crimson [Member]
Consideration transferred:
Crimson common stock to be acquired by the Company	46,624,721	46,624,721
Exchange ratio of the Company common shares for each Crimson common share	0.08288	0.08288
Common stock issued to Crimson stockholders	3,864,101
Closing price of the Company common stock on October 1, 2013	$37.75	$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	60,124
Long-term debt	235,373	235,373
Asset retirement obligations and other non-current liabilities	12,967	12,967
Amount attributable to liabilities assumed	308,464	308,464
Total consideration including liabilities assumed	455,038	455,038
Fair value of assets acquired:
Current assets	13,492	13,492
Current and non-current deferred tax asset, net	24,905	24,905
Natural gas and oil properties, net	416,433	416,433
Other non-current assets	208	208
Amount attributable to net assets acquired	$455,038	$455,038

Merger_With_Crimson_Exploratio3

Merger With Crimson Exploration Inc. (Schedule Of Consolidated 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	$40,166	($83,912)

Acquisitions_Dispositions_And_1

Acquisitions, Dispositions And Gains From Affiliates (Details) (USD $)	12 Months Ended		1 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2013	Aug. 31, 2013
Alta Energy [Member]
Business Acquisition [Line Items]
Expected proceeds from sale of investment				$30.50
Cost method investment ownership percentage	2.00%			2.00%
Gain on sale of investments	5.4	23.1
Expected future porceeds from sale of investment	2
Accumulated distributions in excess of original investment	15.3
Kaybob Duvernay [Member]
Business Acquisition [Line Items]
Cost method investment ownership percentage				5.00%
Dutch Well [Member]
Business Acquisition [Line Items]
Percentage of working interest acquired			7.84%
Percentage of revenue interest acquired			6.53%
Acquisition purchase price			18.8
Purchase price adjustment (reduction in purchase price)	-4.1
Acquisition purchase price, net	14.7
Developed and Undeveloped Properties in Madison and Grimes Counties, Southeast Texas [Member]
Business Acquisition [Line Items]
Purchase price adjustment (reduction in purchase price)	-0.1	0.4
Acquisition purchase price, net	20.3
Percentage of interest sold		7.10%	7.10%
Aggregate sales price of assets sold		20	20
Gain (loss) on sale of oil and gas property	($0.20)	$6.60

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	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
Commodity price contracts - liabilities		-1,207
Level 1 [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity price contracts - assets
Commodity price contracts - liabilities
Level 2 [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity price contracts - assets		76
Commodity price contracts - liabilities		-1,207
Level 3 [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity price contracts - assets
Commodity price contracts - liabilities

Derivative_Instruments_Schedul

Derivative Instruments (Schedule Of Fair Value Of Commodity Derivatives) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2012	Dec. 31, 2013
Liabilities:
Derivative contract	$0	$0
Commodity Derivatives [Member]
Commodity derivatives
Gross			76,000
Netting			-76,000	[1]
Liabilities:
Gross			-1,207,000
Netting			76,000	[1]
Total			($1,131,000)
[1]	GrossNetting (1)TotalAssets$ 76$ (76)$ —Liabilities$ (1,207)$ 76$ (1,131)Represents counterparty netting under agreements governing such derivatives

Derivative_Instruments_Schedul1

Derivative Instruments (Schedule Of Derivative Contracts On Operations) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Realized gain (loss)	($1,284)	$278
Unrealized gain (loss)	1,131	-1,410
Gain (loss) on derivatives, net	-153	-1,132	0
Crude Oil Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized gain (loss)	276	180
Unrealized gain (loss)	1,183	-1,179
Natural Gas Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized gain (loss)	-1,560	98
Unrealized gain (loss)	($52)	($231)

Stock_Based_Compensation_Narra

Stock Based Compensation (Narrative) (Details) (USD $)

12 Months Ended

3 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Nov. 30, 2013

Dec. 31, 2013

Feb. 24, 2015

Feb. 29, 2012

Oct. 01, 2013

Dec. 31, 2011

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

Options exercised in period (in shares)

4,165

791

Options vested and exercisable (in shares)

129,934

Granted vested options, contractual term

6 years

Excess tax benefit from exercise/cancellation of stock options

$0

$254,000

Stock option expense

0

0

154,000

Aggregate intrinsic value of exercies during period

59,009

7,721

500,000

Share-based Compensation

4,515,000

3,180,000

-154,000

Minimum [Member]

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

Options granted, exercise price (in dollars per share)

$25.70

Maximum [Member]

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

Options granted, exercise price (in dollars per share)

$60.33

Restricted Stock [Member]

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

Share-based Compensation

4,500,000

3,200,000

Restricted stock granted in period (in shares)

26,386

356,299

0

Weighted average fair value of options granted (in dollars per share)

$40.83

$44.10

Value of issued stock after adjustment for estimated forfeiture rate

1,100,000

8,100,000

Weighted average forfeiture rate

2.20%

5.70%

Stock vested in period (in shares)

94,807

63,667

Compensation expense not yet recognized

$7,700,000

Restricted Stock [Member] | Officers And Vice Presidents [Member]

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

Vesting period (in years)

3 years

Restricted stock granted in period (in shares)

254,677

Vesting percentage

25.00%

Restricted Stock [Member] | New And Existing Employees [Member]

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

Vesting period (in years)

4 years

4 years

Restricted stock granted in period (in shares)

10,714

88,466

Restricted Stock [Member] | New Employees [Member]

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

Vesting period (in years)

4 years

Restricted stock granted in period (in shares)

1,802

Restricted Stock [Member] | Board of Directors [Member]

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

Vesting period (in years)

1 year

1 year

Restricted stock granted in period (in shares)

15,672

11,354

2009 Equity Compensation Plan [Member]

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

Common stock or options authorized for grant (in shares)

1,500,000

Shares available for grant

1,100,000

2009 Equity Compensation Plan [Member] | Minimum [Member]

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

Expiration term

5 years

2009 Equity Compensation Plan [Member] | Maximum [Member]

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

Expiration term

10 years

Stock Incentive Plan 2005 [Member]

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

Expiration term

10 years

Shares available for grant

7,030

43,472

Stock Incentive Plan 2005 [Member] | Minimum [Member]

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

Vesting period (in years)

1 year

Stock Incentive Plan 2005 [Member] | Maximum [Member]

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

Vesting period (in years)

4 years

Stock Incentive Plan 2005 [Member] | Employee Stock Options [Member]

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

Options issued and outstanding

135,898

Vested, end of the year (in shares)

135,898

Stock Incentive Plan 2005 [Member] | Restricted Stock [Member]

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

Options issued and outstanding

136,428

Vested, end of the year (in shares)

136,428

1999 Plan, 2009 and 2005 Plan [Member]

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

Options issued and outstanding

129,934

135,107

135,107

135,107

45,000

Shares available for grant

1,143,006

1,162,173

1,475,000

1,162,173

1,162,173

Options exercised in period (in shares)

4,165

791

Options vested and exercisable (in shares)

129,934

135,107

135,107

135,107

Forfeitures during the period (in shares)

1,008

[1]

45,000

[1]

Vested, end of the year (in shares)

129,934

135,107

135,107

135,107

45,000

1999 Plan [Member]

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

Options exercised in period (in shares)

45,000

Restricted stock granted in period (in shares)

7,030

2009 Plan Employees [Member]

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

Restricted stock granted in period (in shares)

1,103

Long-Term Incentive Plan [Member]

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

Vesting percentage

25.00%

Vesting Period 1 [Member] | 2009 Equity Compensation Plan [Member]

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

Vesting period (in years)

2 years

Vesting Period 2 [Member] | 2009 Equity Compensation Plan [Member]

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

Vesting period (in years)

3 years

Vesting Period 3 [Member] | 2009 Equity Compensation Plan [Member]

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

Vesting period (in years)

4 years

[1]

For the year ended December 31, 2012, forfeited options consist of options that were net-settled for cash with the Company.

Stock_Based_Compensation_Summa

Stock Based Compensation (Summary Of Stock Options Granted) (Details) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Exercised (in shares)	-4,165		-791
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Exercisable, end of year (in shares)	129,934
1999 Plan, 2009 and 2005 Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Outstanding, beginning of year (in shares)	135,107			45,000
Options assumed due to merger (in shares)			135,898
Exercised (in shares)	-4,165		-791
Forfeited (in shares)	-1,008	[1]		-45,000	[1]
Outstanding, end of year (in shares)	129,934		135,107
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)	$53			$54.21
Options assumed due to merger (in dollars per share)			$52.90
Exercised (in dollars per share)	$28.93		$36.16
Forfeited (in dollars per share)	$42.39	[1]		$54.21	[1]
Outstanding, end of year (in dollars per share)	$53.85		$53
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Expected to vest, end of the period	$4		$459
Exercisable, end of year (in shares)	129,934		135,107
Exercisable, end of year (in dollars per share)	$53.85		$53
Aggregate intrinsic value ($000), exercisable	$4		$459
Available for grant, end of year (in shares)	1,143,006		1,162,173	1,475,000
[1]	For the year ended December 31, 2012, forfeited options consist of options that were net-settled for cash with the Company.

Stock_Based_Compensation_Summa1

Stock Based Compensation (Summary Of Restricted Stock Activity) (Details) (Restricted Stock [Member], USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Restricted Stock [Member]
Restricted stock activity, shares
Outstanding, beginning of the period (in shares)	292,632
Granted (in shares)	26,386	356,299	0
Vested (in shares)	-94,807	-63,667
Canceled/Forfeited (in shares)	-14,249
Not vested, end of the period (in shares)	209,962	292,632
Expected to vest, end of the period (in shares)	192,570	260,359
Restricted stock activity, weighted average fair value
Outstanding, beginning of the period (in dollars per share)	$44.38
Granted (in dollars per share)	$40.83	$44.10
Vested (in dollars per share)	$44.11	$42.80
Canceled/Forfeited (in dollars per share)	$47.30
Not vested, end of the period (in dollars per share)	$43.86	$44.38
Vested, end of the period (in dollars per share)
Expected to vest (in dollars per share)	$43.84	$44.36
Restricted stock activity, intrinsic value
Outsanding, beginning of the period	$13,830
Granted	1,073	15,723
Vested	3,454	2,725
Canceled/Forfeited	579
Not vested, end of the period	6,139	13,830
Expected to vest, end of the period	$5,631	$12,305

Share_Repurchase_Programs_Deta

Share Repurchase Programs (Details) (USD $)	1 Months Ended	12 Months Ended			36 Months Ended
	Feb. 29, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014	Sep. 30, 2011
	employee			employee	employee
Equity, Class of Treasury Stock [Line Items]
Treasury shares at cost		205,457	0	162,214
Average price of shares repurchased (in dollars per share)		$35.89		$51.62
Stock repurchased value		$7,400,000		$8,400,000
Stock options, net-settled	45,000			45,000
Number of employees net-settled stock options	2			2
Cash used to net-settle awards	465,000			465,000
$50 Million Share Repurchase Program [Member]
Equity, Class of Treasury Stock [Line Items]
Approved share repurchase program value						50,000,000
Stock repurchased value					18,200,000
Stock options, net-settled					45,000
Number of employees net-settled stock options					2
Number of shares repurchased during period					403,334
Value of repurchase program available for future purchases		$31,800,000			$31,800,000

Other_Financial_Information_Sc

Other Financial Information (Schedule Of Additional Financial Details) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Accounts Receivable:
Trade receivable	$13,926	$42,196
Receivable for Alta Resources distribution	1,993	7,358
Joint interest billing	4,096	5,172
Income taxes receivable	3,274	4,293
Other receivables	2,610	2,172
Allowance for doubtful accounts	-590	-578
Total Accounts Receivable	25,309	60,613
Prepaid Expenses and Other:
Prepaid insurance	1,242	1,113
Other	699	918
Total Prepaid Expenses and Other	1,941	2,031
Accounts Payable and Accrued Liabilities:
Royalties and revenue payable	31,653	44,933
Accrued exploration and development	26,538	17,803
Trade payable	17,282	11,589
Advances from partners	8,334	6,538
Accrued general and administrative expenses	6,258	10,872
Other accounts payable and accrued liabilities	2,827	5,098
Total Accounts Payable and Accrued Liabilities	$92,892	$96,833

Other_Financial_Information_Sc1

Other Financial Information (Schedule Of Non-Cash Transactions) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash payments:
Interest payments	$2,786	$1,056	$71
Income tax payments (receipts)	241	341	24,307
Non-cash items excluded from investing activities in the consolidated statements of cash flows:
Increase in accrued capital expenditures	8,735	7,004	1,192
Assets acquired & liabilites assumed in the Merger
Accounts receivable		12,955
Prepaids		639
Proved natural gas and oil properties	2,517	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	-2,517	-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

Recovered_Sheet2

Investment in Exaro Energy III LLC (Narrative) (Details) (USD $)	1 Months Ended	12 Months Ended
	Apr. 30, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Schedule of Equity Method Investments [Line Items]
Gain from investment in affiliates (net of income taxes)		$6,923,000	$2,310,000	$60,000
Tax Expense (Benefit) associated with Equity Method Investment Income/ (loss)		3,727,000	1,245,000	32,000
Exaro Energy III LLC [Member]
Schedule of Equity Method Investments [Line Items]
Investment in affiliate		46,900,000
Equity method investment, ownership percentage	37.00%	37.00%
Total Investment Commitment In Affiliates With Other Parties	183,000,000
Share of equity in investment		61,200,000
Gain from investment in affiliates (net of income taxes)		6,900,000	2,300,000	60,000
Exaro Energy III LLC [Member] | Maximum [Member]
Schedule of Equity Method Investments [Line Items]
Investment in affiliate	$67,500,000

Recovered_Sheet3

Investment in Exaro Energy III LLC (Schedule Of Condensed Balance Sheet Data) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Non-current assets:
Net property and equipment	$748,623	$791,023
Other non-current assets	63,752	53,164
Exaro Energy III LLC [Member]
Equity Method Investment, Summarized Financial Information [Abstract]
Current assets	35,013	30,284
Non-current assets:
Net property and equipment	233,997	182,226
Restricted cash escrow account	577	8,732
Other non-current assets	1,779	1,103
Total non-current assets	236,353	192,061
Total assets	271,366	222,345
Current liabilities	9,405	13,717
Non-current liabilities:
Long-term debt	94,500	70,000
Other non-current liabilities	1,084	923
Total non-current liabilities	95,584	70,923
Member's equity	166,377	137,705
Total liabilities & member's equity	$271,366	$222,345

Investment_in_Exaro_Energy_III2

Investment in Exaro Energy III LLC (Schedule Of Condensed Income Statement Data) (Details) (USD $)	12 Months Ended			9 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2012
Equity Method Investment, Summarized Financial Information, Income Statement [Abstract]
Other gain (loss)	$124	$31,785	($463)
Less:
General & administrative expense	34,045	26,512	11,265
Income (loss) from continuing operations	-21,874	41,362	-907
Exaro Energy III LLC [Member]
Equity Method Investment, Summarized Financial Information, Income Statement [Abstract]
Oil and natural gas sales	79,536	52,698		7,514
Other gain (loss)	5,069	-544		-3,269
Less:
Lease operating expenses	22,452	16,136		2,035
Depreciation, depletion, amortization & accretion	26,036	16,058		2,350
General & administrative expense	3,484	3,294		2,872
Income (loss) from continuing operations	32,633	16,666		-3,012
Net interest income (expense)	-3,861	-3,536		25
Net income (loss)	$28,772	$13,130		($2,987)

Asset_Retirement_Obligation_De

Asset Retirement Obligation (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Business Acquisition [Line Items]
Liabilities incurred during period	$3,123,000	$14,145,000
Liabilities settled	1,963,000	207,000
Crimson [Member]
Business Acquisition [Line Items]
Liabilities incurred during period	2,500,000	11,200,000
New Wells Drilled [Member]
Business Acquisition [Line Items]
Liabilities incurred during period	600,000	2,900,000
Wells Plugged and Abandoned [Member]
Business Acquisition [Line Items]
Liabilities settled		137,000
Developed and Undeveloped Properties in Madison and Grimes Counties, Southeast Texas [Member]
Business Acquisition [Line Items]
Liabilities settled		$70,000

Asset_Retirement_Obligation_Sc

Asset Retirement Obligation (Schedule of Change in Asset Retirement Obligation) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligation [Abstract]
Balance as of the beginning of the period	$23,334	$8,678
Liabilities incurred during period	3,123	14,145
Liabilities settled during period	-1,963	-207
Accretion	1,303	660
Sales	-69
Change in estimate	18	58
Balance as of the end of the period	$25,746	$23,334

LongTerm_Debt_Narrative_Detail

Long-Term Debt (Narrative) (Details) (USD $)	0 Months Ended	12 Months Ended			0 Months Ended
	Oct. 01, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Oct. 22, 2010	Oct. 28, 2014	Sep. 30, 2013
Debt Instrument [Line Items]
Accrued interest and pre-payment penalty	$1,800,000
Repayment of long-term debt	127,600,000		235,373,000
Credit facility amount outstanding	110,000,000
Interest expense		2,658,000	1,171,000	-96,000
RBC Credit Facility [Member]
Debt Instrument [Line Items]
Revolving credit facility, expiration period		4 years
Revolving credit facility, borrowing base	275,000,000					275,000,000
Credit facility fees	2,200,000
Credit facility amount outstanding		63,400,000	90,000,000
Letters of credit amount outstanding		1,900,000	1,900,000
Line of credit, available		209,700,000
Revolving credit facility, maximum borrowing capacity	500,000,000
Interest expense		2,700,000	1,200,000
Arrangement fee			2,200,000
RBC Credit Facility [Member] | Minimum [Member]
Debt Instrument [Line Items]
Commitment fee percentage		0.38%
RBC Credit Facility [Member] | Maximum [Member]
Debt Instrument [Line Items]
Commitment fee percentage		0.50%
Amegy Bank Credit Agreement [Member]
Debt Instrument [Line Items]
Revolving credit facility, borrowing base					40,000,000
Commitment fee percentage					0.13%
Revolving credit facility, maximum borrowing capacity	40,000,000						40,000,000
Interest expense			37,000	50,000
Arrangement fee					300,000
Amegy Bank Credit Agreement [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					2.50%
Amegy Bank Credit Agreement [Member] | Minimum [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate					0.75%
Crimson [Member]
Debt Instrument [Line Items]
Debt assumed with merger	235,373,000
Accrued interest and pre-payment penalty	1,800,000
Repayment of long-term debt	235,400,000
Barclays [Member]
Debt Instrument [Line Items]
Debt assumed with merger	175,000,000
Barclays [Member] | Crimson [Member]
Debt Instrument [Line Items]
Accrued interest and pre-payment penalty	1,800,000
Wells Fargo [Member]
Debt Instrument [Line Items]
Debt assumed with merger	$58,600,000

Recovered_Sheet4

Commitments And Contingencies (Narrative) (Details) (USD $)	12 Months Ended			1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Oct. 31, 2013	Jul. 31, 2014	Oct. 01, 2013
Deferred Compensation Arrangement, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Lease commitment	$6,000,000	$1,000,000	$500,000
Severance payments		400,000
Jefferson Davis Parish Case [Member]
Legal Proceedings
Number of wells involved in litigation	2
Damages sought by plaintiffs	13,400,000
Lavaca County Case [Member]
Legal Proceedings
Number of wells involved in litigation	2
Damages sought by plaintiffs	5,300,000
Litigation Case Filed by Mineral Interest Owner Harris County [Member]
Legal Proceedings
Damages sought by plaintiffs	10,700,000
Additional portion of mineral interest claimed by plaintiff				0.06%
Board of Directors Chairman [Member]
Employment Agreements
Bonus payment						4,000,000
Chief Executive Officer [Member]
Employment Agreements
Base salary under employment agreement							600,000
Chief Executive Officer [Member] | Minimum [Member]
Employment Agreements
Cash bonus awards based on % of salary	50.00%
Stock Option Awards based on % of Salary	75.00%
Chief Executive Officer [Member] | Target [Member]
Employment Agreements
Cash bonus awards based on % of salary	100.00%
Stock Option Awards based on % of Salary	350.00%
Chief Executive Officer [Member] | Maximum [Member]
Employment Agreements
Cash bonus awards based on % of salary	150.00%
Stock Option Awards based on % of Salary	450.00%
Chief Financial Officer [Member]
Employment Agreements
Base salary under employment agreement							400,000
Chief Financial Officer [Member] | Minimum [Member]
Employment Agreements
Cash bonus awards based on % of salary	50.00%
Stock Option Awards based on % of Salary	75.00%
Chief Financial Officer [Member] | Target [Member]
Employment Agreements
Cash bonus awards based on % of salary	90.00%
Stock Option Awards based on % of Salary	250.00%
Chief Financial Officer [Member] | Maximum [Member]
Employment Agreements
Cash bonus awards based on % of salary	130.00%
Stock Option Awards based on % of Salary	450.00%
CEO, CFO And The Three Directors [Member]
Employment Agreements
Employment agreement, initial term					3 years
Employment agreement, extension term					2 years
VPs, Isaac, Mengle & Atkins | Minimum [Member]
Employment Agreements
Cash bonus awards based on % of salary	50.00%
Stock Option Awards based on % of Salary	75.00%
VPs, Isaac, Mengle & Atkins | Target [Member]
Employment Agreements
Cash bonus awards based on % of salary	80.00%
Stock Option Awards based on % of Salary	250.00%
VPs, Isaac, Mengle & Atkins | Maximum [Member]
Employment Agreements
Cash bonus awards based on % of salary	120.00%
Stock Option Awards based on % of Salary	350.00%
VP, Isaac
Employment Agreements
Base salary under employment agreement							320,000
VP, Mengle
Employment Agreements
Base salary under employment agreement							300,000
VP, Atkins
Employment Agreements
Base salary under employment agreement							310,000
Exaro Energy III LLC [Member]
Deferred Compensation Arrangement, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Future planned investments	$20,600,000

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified
Delay Rentals and Operating and Capital Leases [Abstract]
2015	$3,867
2016	2,158
2017	1,948
2018	1,694
2019	416
Total	$10,083

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 Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Earnings Per Share [Abstract]
Income (loss) from continuing operations	($21,874)	$41,362	($907)
Income (loss) from discontinued operations, net of taxes			-29
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	($21,874)	$41,362	($936)
Weighted average shares, basic (in shares)	19,059	16,156	15,295
Stock options, net of shares assumed purchased (in shares)		2
Weighted average shares, diluted (in shares)	19,059	16,158	15,295
Income from continuing operations, basic (in dollars per share)	($1.15)	$2.56	($0.06)
Discontinued operations, net of income taxes, basic (in dollars per share)			$0
Total (in dollars per share)	($1.15)	$2.56	($0.06)
Income from continuing operations, diluted (in dollars per share)	($1.15)	$2.56	($0.06)
Discontinued operations, net of income taxes, diluted (in dollars per share)			$0
Total (in dollars per share)	($1.15)	$2.56	($0.06)
Potentially dilutive shares	339,896	187,302	0

Income_Taxes_Narrative_Details

Income Taxes (Narrative) (Details) (USD $)	12 Months Ended			0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	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
Non-deductible merger related expenses		3,000,000
Non-deductible compensation expenses		1,400,000
Valuation allowance	-2,161,000	-2,552,000
NOL, Valuation allowance	6,200,000
Tax adjusted NOL, Valuation allowance	2,200,000
Operating loss carryforwards, expired during period	1,100,000
Interest and penalties related to unrecognized tax benefits	0
Unrecognized tax benefits that would impact effective tax rate	0
Crimson [Member]
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards				110,000,000
NOL, Valuation allowance				36,400,000
Tax adjusted NOL, Valuation allowance				12,800,000
Increase (decrease) in valuation allowance of deferred tax asset		-10,200,000		29,200,000
Valuation allowance released, tax adjusted				10,200,000
Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards	6,200,000
NOL, Valuation allowance				7,300,000
Tax adjusted NOL, Valuation allowance				2,600,000
Louisiana State Taxing Authority [Member]
Operating Loss Carryforwards [Line Items]
Depletion, tax effect	1,700,000
Federal [Member]
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards	112,300,000
Federal [Member] | Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards	106,100,000
State [Member]
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards	$10,200,000

Income_Taxes_Effective_Income_

Income Taxes (Effective Income Tax Rate Reconciliation) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Provision/(benefit) at statutory tax rate	($11,920)	$23,011	($94)
State income tax provision, net of federal benefit	1,028	2,928	654
Permanent differences	202	-1,559	450
State depletion deductions	-1,723
Other	230	4	-373
Total	($12,183)	$24,384	$637
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	-3.00%	4.45%	-241.84%
Permanent differences	-0.60%	-2.37%	-166.34%
State depletion deductions	5.10%
Other	-0.70%	0.01%	137.65%
Income tax provision /(benefit)	35.80%	37.09%	-235.53%

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, 2014	Dec. 31, 2013	Dec. 31, 2012
Current:
Federal	($392)	$8,739	$7,038
State	478	3,857	2,168
Total	86	12,596	9,206
Deferred:
Federal	-11,518	11,361	-8,343
State	-751	427	-226
Total	-12,269	11,788	-8,569
Total:
Federal	-11,910	20,100	-1,305
State	-273	4,284	1,942
Total	-12,183	24,384	637
Included in gain (loss) from investment in affiliates	3,727	1,245	32
Income tax benefit (provision)	($15,910)	$23,139	$605

Income_Taxes_Net_Deferred_Tax_

Income Taxes (Net Deferred Tax Liability) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Deferred tax assets:
Net operating loss carryforward	$39,085	$49,204
Income tax credits	661	2,676
Derivative instruments	165	564
Deferred compensation	465	406
Other	1,953	1,165
Total deferred tax assets before valuation allowance	42,329	54,015
Valuation allowance	-2,161	-2,552
Net deferred tax assets	40,168	51,463
Deferred tax liability:
Oil and gas properties	-104,209	-133,894
Investment in affiliates	-28,287	-21,681
Other		-518
Deferred tax liability	-132,496	-156,093
Total net deferred tax liability	($92,328)	($104,630)

Income_Taxes_Unrecognized_Tax_

Income Taxes (Unrecognized Tax Benefits) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Reconciliation of Unrecognized Tax Benefits [Roll Forward]
Beginning Balance	$518	$518
Ending Balance	$518	$518

Related_Party_Transactions_JEX

Related Party Transactions (JEX, Olympic Energy Partners, And REX) (Narrative) (Details) (USD $)	1 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2014	Apr. 30, 2012
JEX [Member]
Related Party Transaction, Oil and Gas Properties [Abstract]
Annual advisory payment			$2,000,000
First Rights Agreement payment	500,000
JEX [Member] | Contaro Advisory [Member]
Related Party Transaction, Oil and Gas Properties [Abstract]
Related party, monthly advisory fee	$10,000
Percentage fee of cash profits	1.00%
REX [Member]
Related Party Transaction, Oil and Gas Properties [Abstract]
Ownership interest in REX		32.30%
Maximum [Member] | Contango Offshore Exploration LLC [Member]
Related Party Transaction, Oil and Gas Properties [Abstract]
Overriding royalty interest, employee benefit		3.33%
All Future Projects Generated by REX [Member] | JEX Employees [Member]
Related Party Transaction, Oil and Gas Properties [Abstract]
Overriding royalty interest, employee benefit		3.33%
JEX [Member] | REX [Member]
Related Party Transaction, Oil and Gas Properties [Abstract]
Ownership interest in REX		34.40%
Third Party [Member] | REX [Member]
Related Party Transaction, Oil and Gas Properties [Abstract]
Ownership interest in REX		33.30%

Related_Party_Transactions_Sch

Related Party Transactions (Schedule Of Oil and Gas Ownership Interests) (Details)	Dec. 31, 2014	Nov. 30, 2013	Jan. 31, 2012
Dutch Number 1 - 5 [Member] | Olympic [Member]
Related Party Transaction [Line Items]
Working interests	3.53%	3.02%
Net revenue interest	2.84%	2.42%
Dutch Number 1 - 5 [Member] | JEX [Member]
Related Party Transaction [Line Items]
Working interests	1.88%	1.61%
Net revenue interest	1.51%	1.29%
Dutch Number 1 - 5 [Member] | JEX Employees [Member]
Related Party Transaction [Line Items]
Overriding royalty interest, employee benefit	2.02%
Mary Rose Number 1 [Member] | Olympic [Member]
Related Party Transaction [Line Items]
Working interests	3.61%
Net revenue interest	2.70%
Mary Rose Number 1 [Member] | JEX [Member]
Related Party Transaction [Line Items]
Working interests	2.01%
Net revenue interest	1.51%
Mary Rose Number 1 [Member] | JEX Employees [Member]
Related Party Transaction [Line Items]
Overriding royalty interest, employee benefit	2.79%
Mary Rose Number 2-3 [Member] | Olympic [Member]
Related Party Transaction [Line Items]
Working interests	3.61%
Net revenue interest	2.58%
Mary Rose Number 2-3 [Member] | JEX [Member]
Related Party Transaction [Line Items]
Working interests	2.01%
Net revenue interest	1.44%
Mary Rose Number 2-3 [Member] | JEX Employees [Member]
Related Party Transaction [Line Items]
Overriding royalty interest, employee benefit	2.79%
Mary Rose Number 4 [Member] | Olympic [Member]
Related Party Transaction [Line Items]
Working interests	2.34%
Net revenue interest	1.70%
Mary Rose Number 4 [Member] | JEX [Member]
Related Party Transaction [Line Items]
Working interests	1.31%
Net revenue interest	0.95%
Mary Rose Number 4 [Member] | JEX Employees [Member]
Related Party Transaction [Line Items]
Overriding royalty interest, employee benefit	1.82%
Mary Rose Number 5 [Member]
Related Party Transaction [Line Items]
Working interests			37.80%
Mary Rose Number 5 [Member] | Olympic [Member]
Related Party Transaction [Line Items]
Working interests	2.56%		2.56%
Net revenue interest	1.87%
Mary Rose Number 5 [Member] | JEX [Member]
Related Party Transaction [Line Items]
Working interests	1.43%		1.40%
Net revenue interest	1.04%
Mary Rose Number 5 [Member] | JEX Employees [Member]
Related Party Transaction [Line Items]
Overriding royalty interest, employee benefit	1.54%
Ship Shoal 263 [Member] | JEX Employees [Member]
Related Party Transaction [Line Items]
Overriding royalty interest, employee benefit	3.33%
Vermilion 170 [Member] | JEX [Member]
Related Party Transaction [Line Items]
Working interests	4.30%
Net revenue interest	3.35%
Vermilion 170 [Member] | REX [Member]
Related Party Transaction [Line Items]
Working interests	12.50%
Net revenue interest	9.74%
Vermilion 170 [Member] | JEX Employees [Member]
Related Party Transaction [Line Items]
Overriding royalty interest, employee benefit	3.33%

Related_Party_Transactions_Sum

Related Party Transactions (Summary Of Transactions) (Narrative) (Details) (USD $)

12 Months Ended

1 Months Ended

3 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Apr. 30, 2014

Mar. 31, 2014

Feb. 28, 2011

Jul. 31, 2012

Jun. 20, 2012

Mar. 20, 2013

Jun. 30, 2013

Jul. 31, 2011

Jan. 31, 2012

Related Party Transaction [Line Items]

Stock-based compensation

$4,515,000

$3,180,000

($154,000)

Mr. Romano [Member]

Related Party Transaction [Line Items]

Director Compensation for Related Party

105,000

Restricted stock granted in period (in shares)

2,612

Vesting percentage

100.00%

Vesting period (in years)

1 year

Mr. Juneau [Member]

Related Party Transaction [Line Items]

Director Compensation for Related Party

12,000

Number of shares accelerated

1,622

Stock-based compensation

71,000

JEX [Member]

Related Party Transaction [Line Items]

Annual sublease rental income

100,000

Vermilion 170 [Member]

Related Party Transaction [Line Items]

Ownership interest in oil and gas well

100.00%

Vermilion 170 [Member] | JEX [Member]

Related Party Transaction [Line Items]

Working interests

4.30%

Net revenue interest

3.35%

Prospect fees

250,000

Vermilion 170 [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

12.50%

Net revenue interest

9.74%

Vermilion 170 [Member] | JEX Employees [Member]

Related Party Transaction [Line Items]

Overriding royalty interest, employee benefit

3.33%

Vermilion 170 [Member] | Until Casing Point [Member]

Related Party Transaction [Line Items]

Working interests

100.00%

Vermilion 170 [Member] | After Casing Point [Member] | JEX [Member]

Related Party Transaction [Line Items]

Working interests

2.60%

Vermilion 170 [Member] | After Casing Point [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

7.50%

Vermilion 170 [Member] | First Production [Member] | JEX [Member]

Related Party Transaction [Line Items]

Working interests

1.70%

Vermilion 170 [Member] | First Production [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

5.00%

Vermilion 170 [Member] | Final [Member] | JEX [Member]

Related Party Transaction [Line Items]

Working interests

4.30%

Vermilion 170 [Member] | Final [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

12.50%

Dutch Number 5 [Member]

Related Party Transaction [Line Items]

Working interests

47.05%

Dutch Number 5 [Member] | JEX [Member]

Related Party Transaction [Line Items]

Working interests

1.60%

Dutch Number 5 [Member] | Olympic [Member]

Related Party Transaction [Line Items]

Working interests

3.02%

Eloise South [Member]

Related Party Transaction [Line Items]

Working interests

23.80%

Eloise South [Member] | Olympic [Member]

Related Party Transaction [Line Items]

Working interests

3.33%

Eloise South [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

9.60%

Mary Rose Number 5 [Member]

Related Party Transaction [Line Items]

Working interests

37.80%

Mary Rose Number 5 [Member] | JEX [Member]

Related Party Transaction [Line Items]

Working interests

1.43%

1.40%

Net revenue interest

1.04%

Mary Rose Number 5 [Member] | Olympic [Member]

Related Party Transaction [Line Items]

Working interests

2.56%

2.56%

Net revenue interest

1.87%

Mary Rose Number 5 [Member] | JEX Employees [Member]

Related Party Transaction [Line Items]

Overriding royalty interest, employee benefit

1.54%

Eloise North [Member]

Related Party Transaction [Line Items]

Working interests

35.80%

Eloise North [Member] | JEX [Member]

Related Party Transaction [Line Items]

Working interests

0.10%

Eloise North [Member] | Olympic [Member]

Related Party Transaction [Line Items]

Working interests

4.79%

Eloise North [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

13.20%

Ship Soal 134 [Member]

Related Party Transaction [Line Items]

Ownership interest in oil and gas well

100.00%

Ship Soal 134 [Member] | JEX [Member]

Related Party Transaction [Line Items]

Prospect fees

250,000

South Timbalier 75 [Member]

Related Party Transaction [Line Items]

Working interests

100.00%

South Timbalier 75 [Member] | JEX [Member]

Related Party Transaction [Line Items]

Prospect fees

250,000

Lease Block Purchase One [Member]

Related Party Transaction [Line Items]

Number of lease blocks, oil and gas

5

Period required to drill oil prospects

48 months

Lease Block Purchase One [Member] | JEX [Member]

Related Party Transaction [Line Items]

Prospect fees

250,000

Lease Block Purchase One [Member] | JEX Employees [Member]

Related Party Transaction [Line Items]

Overriding royalty interest, employee benefit

3.33%

Lease Block Purchase One [Member] | First Production [Member]

Related Party Transaction [Line Items]

Working interests

100.00%

Lease Block Purchase One [Member] | Final [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

22.50%

Net revenue interest

17.50%

Lease Block Purchase One [Member] | Through Production [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

10.00%

Lease Block Purchase One [Member] | Payout of Post Casing Point Costs [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

12.50%

Lease Block Purchase Two [Member]

Related Party Transaction [Line Items]

Number of lease blocks, oil and gas

1

Lease Block Purchase Two [Member] | JEX [Member]

Related Party Transaction [Line Items]

Prospect fees

250,000

Lease Block Purchase Two [Member] | JEX Employees [Member]

Related Party Transaction [Line Items]

Overriding royalty interest, employee benefit

3.33%

Lease Block Purchase Two [Member] | First Production [Member]

Related Party Transaction [Line Items]

Working interests

10.00%

Lease Block Purchase Three [Member]

Related Party Transaction [Line Items]

Number of prospect fees paid

2

Number of lease blocks, oil and gas

3

Period required to drill oil prospects

48 months

Lease Block Purchase Three [Member] | JEX [Member]

Related Party Transaction [Line Items]

Prospect fees

250,000

Lease Block Purchase Three [Member] | JEX Employees [Member]

Related Party Transaction [Line Items]

Overriding royalty interest, employee benefit

3.33%

Lease Block Purchase Three [Member] | First Production [Member]

Related Party Transaction [Line Items]

Working interests

100.00%

Lease Block Purchase Three [Member] | Final [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

22.50%

Net revenue interest

17.50%

Lease Block Purchase Three [Member] | Through Production [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

10.00%

Lease Block Purchase Three [Member] | Payout of Post Casing Point Costs [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

12.50%

South Timbalier 17 [Member] | JEX [Member]

Related Party Transaction [Line Items]

Prospect fees

$250,000

South Timbalier 17 [Member] | JEX Employees [Member]

Related Party Transaction [Line Items]

Overriding royalty interest, employee benefit

0.00%

South Timbalier 17 [Member] | Payout of All Costs [Member]

Related Party Transaction [Line Items]

Working interests

75.00%

South Timbalier 17 [Member] | After Payout [Member]

Related Party Transaction [Line Items]

Working interests

56.30%

Net revenue interest

39.90%

South Timbalier 17 [Member] | After Payout [Member] | REX [Member]

Related Party Transaction [Line Items]

Working interests

9.40%

Net revenue interest

6.70%

Tuscaloosa Marine Shale [Member] | First Production [Member]

Related Party Transaction [Line Items]

Working interests

100.00%

Tuscaloosa Marine Shale [Member] | Through Production [Member] | Mr. Juneau [Member]

Related Party Transaction [Line Items]

Overriding royalty interest, employee benefit

0.75%

Tuscaloosa Marine Shale [Member] | Through Production [Member] | JEX [Member]

Related Party Transaction [Line Items]

Working interests

10.00%

Tuscaloosa Marine Shale [Member] | Through Production [Member] | JEX Employees [Member]

Related Party Transaction [Line Items]

Overriding royalty interest, employee benefit

2.00%

Tuscaloosa Marine Shale [Member] | Through Production [Member] | Geologist, Tuscaloosa Marine Shale [Member]

Related Party Transaction [Line Items]

Overriding royalty interest, employee benefit

2.00%

Related_Party_Transactions_Pay

Related Party Transactions (Payments Received From (Paid To) Related Parties In Ordinary Course of Business) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Olympic [Member]
Related Party Transaction [Line Items]
Revenue payments as well owners	($7,349)	($6,859)	($6,888)
Joint interest billing receipts	673	945	1,081
JEX [Member]
Related Party Transaction [Line Items]
Revenue payments as well owners	-4,882	-4,628	-5,230
Joint interest billing receipts	521	1,201	724
REX [Member]
Related Party Transaction [Line Items]
Revenue payments as well owners	-2,270	-1,932	-4,308
Joint interest billing receipts	322	2,090	885
Mary Rose Well [Member] | Olympic [Member]
Related Party Transaction [Line Items]
Well cost adjustment			-201
Mary Rose Well [Member] | JEX [Member]
Related Party Transaction [Line Items]
Well cost adjustment			118
Mary Rose Well [Member] | REX [Member]
Related Party Transaction [Line Items]
Well cost adjustment			($1,185)

Related_Party_Transactions_Pay1

Related Party Transactions (Payments Received From (Paid To) Related Parties In Specific Transactions) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Olympic [Member]
Related Party Transaction [Line Items]
Reimbursement of certain costs	($54,000)
JEX [Member]
Related Party Transaction [Line Items]
Reimbursement of certain costs	-29,000	-115,000	-496,000
Annual sublease rental income	100,000
Rent received from sublease	142,000
Prospect fees		-1,000,000
Advisory Agreements		-361,000	-1,530,000
REX [Member]
Related Party Transaction [Line Items]
Reimbursement of certain costs		-4,000	-9,000
REX distribution to members		($197,000)	$1,469,000

Related_Party_Transactions_Sch1

Related Party Transactions (Schedule Of Related Party Balances) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Accounts receivable:
Joint interest billing	$4,096	$5,172
Olympic [Member]
Accounts receivable:
Joint interest billing	48	34
Accounts payable:
Royalties and revenue payable	-1,006	-1,293
JEX [Member]
Accounts receivable:
Joint interest billing	42	87
Accounts payable:
Royalties and revenue payable	-620	-877
REX [Member]
Accounts receivable:
Joint interest billing	12	116
Accounts payable:
Royalties and revenue payable	($175)	($466)

Related_Party_Transactions_Oak

Related Party Transactions (Oaktree, Contango ORE, And Equity Compensation) (Narrative) (Details) (USD $)	1 Months Ended	12 Months Ended		1 Months Ended
	Feb. 29, 2012	Dec. 31, 2012	Dec. 31, 2014	Mar. 30, 2012	Oct. 01, 2013	Nov. 30, 2011
	employee	employee
Related Party Transaction [Line Items]
Accrued interest and pre-payment penalty					$1,800,000
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	465,000
Crimson [Member]
Related Party Transaction [Line Items]
Accrued interest and pre-payment penalty					1,800,000
Oaktree Capital Partners [Member]
Related Party Transaction [Line Items]
Ownership Percentage in Company's Stock			6.70%
Director Compensation for Related Party			64,000
Director Compensation for Related Party, Shares			2,612
Vesting period (in years)			1 year
Revolving Credit Facility [Member] | Contango ORE, Inc. [Member]
Related Party Transaction [Line Items]
Revolving line of credit promissory note, maximum borrowing capacity						1,000,000
Revolving line of credit promissory note, interest rate						10.00%
Repayment of advance under the CORE note				500,000
Interest received on CORE note				15,000
Barclays [Member] | Crimson [Member]
Related Party Transaction [Line Items]
Long-term debt					175,000,000
Accrued interest and pre-payment penalty					$1,800,000