Magnum Hunter Resources 10-Q 8 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Nov. 07, 2013
Document and Entity Information [Abstract]	'	'
Entity Registrant Name	'MAGNUM HUNTER RESOURCES CORP	'
Entity Central Index Key	'0001335190	'
Document Type	'10-Q	'
Document Period End Date	30-Sep-13	'
Amendment Flag	'false	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	170,969,355
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
CURRENT ASSETS	'	'
Cash and cash equivalents	$55,283	$57,623
Restricted cash	0	1,500
Accounts receivable, net of allowance for doubtful accounts of $315 and $448 as of September 30, 2013 and December 31, 2012, respectively	73,486	124,861
Derivative assets	1,079	5,146
Inventory	11,957	9,162
Investments	2,237	3,278
Prepaid expenses and other assets	4,732	2,249
Assets held for sale	10,380	500
Total current assets	159,154	204,319
PROPERTY, PLANT AND EQUIPMENT	'	'
Oil and natural gas properties, successful efforts method of accounting	1,347,147	1,908,118
Accumulated depletion, depreciation, and accretion	-133,993	-185,615
Total oil and natural gas properties, net	1,213,154	1,722,503
Gas transportation, gathering and processing equipment and other, net	258,797	201,910
Total property, plant and equipment, net	1,471,951	1,924,413
OTHER ASSETS	'	'
Deferred financing costs, net of amortization of $10,560 and $8,024 as of September 30, 2013 and December 31, 2012, respectively	21,169	23,862
Derivative assets, long-term	392	0
Intangible assets, net	7,048	8,981
Goodwill	30,602	30,602
Assets held for sale	193,255	0
Other assets	2,245	6,455
Total assets	1,885,816	2,198,632
CURRENT LIABILITIES	'	'
Current portion of notes payable	4,144	3,991
Accounts payable	148,754	196,515
Accrued liabilities	57,898	11,212
Revenue payable	12,728	20,394
Derivative liabilities	5,913	3,501
Liabilities associated with assets held for sale	16,139	0
Other liabilities	7,336	8,043
Total current liabilities	252,912	243,656
Long-term debt	749,131	886,769
Asset retirement obligations	19,902	28,322
Deferred tax liabilities	32,858	74,258
Derivative liabilities, long-term	75,997	47,524
Other long-term liabilities	2,450	5,573
Long-term liabilities associated with assets held for sale	14,601	0
Total liabilities	1,147,851	1,286,102
COMMITMENTS AND CONTINGENCIES (Note 13)	'	'
REDEEMABLE PREFERRED STOCK	'	'
Redeemable preferred stock	228,871	200,878
SHAREHOLDERS’ EQUITY	'	'
Common stock	1,716	1,700
Additional paid in capital	728,551	715,033
Accumulated deficit	-525,157	-307,484
Accumulated other comprehensive loss	-16,910	-8,889
Treasury stock, at cost	-1,914	-1,914
Total Magnum Hunter Resources Corporation shareholders’ equity	500,569	701,513
Non-controlling interest	8,525	10,139
Total shareholders’ equity	509,094	711,652
Total liabilities and shareholders’ equity	1,885,816	2,198,632
Series C Cumulative Perpetual Preferred Stock	'	'
REDEEMABLE PREFERRED STOCK	'	'
Redeemable preferred stock	100,000	100,000
Series A Preferred Units	'	'
REDEEMABLE PREFERRED STOCK	'	'
Redeemable preferred stock	128,871	100,878
Series D Cumulative Perpetual Preferred Stock	'	'
SHAREHOLDERS’ EQUITY	'	'
Preferred Stock	221,244	210,441
Series E Cumulative Convertible Preferred Stock	'	'
SHAREHOLDERS’ EQUITY	'	'
Preferred Stock	95,069	94,371
Treasury stock, at cost	-2,030	-1,750
Exchangeable Common Stock	'	'
SHAREHOLDERS’ EQUITY	'	'
Common stock	$0	$5

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	9 Months Ended	12 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
Accounts receivable, allowance for doubtful accounts	$315,000	$448,000
Amortization of deferred financing costs	10,560,000	8,024,000
Preferred stock, shares authorized	10,000,000	10,000,000
Common stock, par value (in dollars per share)	$0.01	$0.01
Common stock, shares authorized	350,000,000	250,000,000
Common stock, shares issued	171,602,272	170,032,999
Common stock, shares outstanding	170,687,320	169,118,047
Treasury stock, shares	914,952	914,952
Series C Cumulative Perpetual Preferred Stock	'	'
Cumulative dividend rate (as a percent)	10.25%	10.25%
Preferred stock, shares authorized	4,000,000	4,000,000
Preferred stock, shares issued	4,000,000	4,000,000
Preferred stock, shares outstanding	4,000,000	4,000,000
Preferred stock, liquidation preference (in dollars per share)	$25	$25
Series A Preferred Units	'	'
Cumulative dividend rate (as a percent)	8.00%	8.00%
Preferred stock, shares issued	9,391,227	7,672,892
Preferred stock, shares outstanding	9,391,227	7,672,892
Preferred stock, liquidation preference	$190,766	$167,403
Series D Cumulative Perpetual Preferred Stock	'	'
Preferred stock, shares authorized	5,750,000	5,750,000
Cumulative dividend rate for cumulative preferred stock (as a percent)	8.00%	8.00%
Preferred stock, shares issued	4,424,889	4,208,821
Preferred Stock, Shares Outstanding	4,424,889	4,208,821
Preferred stock, liquidation preference (in dollars per share)	$50	$50
Series E Cumulative Convertible Preferred Stock	'	'
Preferred stock, shares authorized	12,000	12,000
Cumulative dividend rate for cumulative preferred stock (as a percent)	8.00%	8.00%
Preferred stock, shares issued	3,803	3,775
Preferred Stock, Shares Outstanding	3,722	3,705
Preferred stock, liquidation preference (in dollars per share)	$25,000	$25,000
Treasury stock, shares	81	70
Exchangeable Common Stock	'	'
Common stock, par value (in dollars per share)	$0.01	$0.01
Common stock, shares issued	505,835	505,835
Common stock, shares outstanding	505,835	505,835

UNAUDITED_CONSOLIDATED_STATEME

UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	3 Months Ended				9 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
REVENUES AND OTHER	'		'		'		'
Oil and natural gas sales	$54,018		$29,983		$138,242		$78,532
Natural gas transportation, gathering, processing, and marketing	12,545		5,058		42,415		10,418
Oilfield services	6,423		1,504		13,728		6,118
Other revenue	46		-164		789		-144
Total revenue	73,032		36,381		195,174		94,924
OPERATING EXPENSES	'		'		'		'
Lease operating expenses	15,145		6,100		38,027		18,291
Severance taxes and marketing	5,465		2,530		12,313		6,618
Exploration	40,123		3,299		73,402		18,143
Impairment of proved oil and gas properties	0		0		9,968		0
Natural gas transportation, gathering, processing, and marketing	8,985		2,288		35,830		4,379
Oilfield services	4,527		3,366		11,928		6,933
Depletion, depreciation, amortization and accretion	28,293		15,146		71,956		42,199
Loss on sale of assets, net	40,952		328		42,116		528
General and administrative	22,218		12,222		58,559		38,226
Total operating expenses	165,708		45,279		354,099		135,317
OPERATING LOSS	-92,676		-8,898		-158,925		-40,393
OTHER INCOME (EXPENSE)	'		'		'		'
Interest income	34		132		172		216
Interest expense	-15,689		-14,405		-53,203		-40,595
Gain (loss) on derivative contracts, net	-29,553		-10,151		-30,644		9,056
Other income	8,540		27		7,860		90
Total other expense, net	-36,668		-24,397		-75,815		-31,233
LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX	-129,344		-33,295		-234,740		-71,626
Income tax benefit	-3,255		1,983		40,944		9,143
LOSS FROM CONTINUING OPERATIONS, NET OF TAX	-132,599		-31,312		-193,796		-62,483
Income (loss) from discontinued operations, net of tax	-80,554	[1]	-1,102	[1]	-71,455	[1]	2,832	[1]
Gain (loss) on disposal of discontinued operations, net of tax	-84,454	[2]	0	[2]	87,998	[2]	2,224	[2]
NET LOSS	-297,607		-32,414		-177,253		-57,427
Net loss (income) attributed to non-controlling interests	725		-49		1,614		-71
LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	-296,882		-32,463		-175,639		-57,498
Dividends on preferred stock	-14,417		-9,820		-42,034		-22,680
NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS	-311,299		-42,283		-217,673		-80,178
Weighted average number of common shares outstanding, basic and diluted	169,953,997		168,897,700		169,752,042		151,225,832
Loss from continuing operations per share, basic and diluted	($0.86)		($0.24)		($1.38)		($0.56)
Income (loss) from discontinued operations per share, basic and diluted	($0.97)		($0.01)		$0.10		$0.03
NET LOSS PER COMMON SHARE, BASIC AND DILUTED	($1.83)		($0.25)		($1.28)		($0.53)
Loss from continuing operations, net of tax	-131,874		-31,361		-192,182		-62,554
Income (loss) from discontinued operations, net of tax	-165,008		-1,102		16,543		5,056
Net loss	($296,882)		($32,463)		($175,639)		($57,498)
[1]
[2]	Income tax expense associated with gain/(loss) on sale of discontinued operations was $6.6 million for the nine months ended September 30, 2013.

UNAUDITED_CONSOLIDATED_STATEME1

UNAUDITED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Statement of Other Comprehensive Income [Abstract]	'	'	'	'
Net loss	($297,607)	($32,414)	($177,253)	($57,427)
OTHER COMPREHENSIVE INCOME (LOSS)	'	'	'	'
Foreign currency translation gain (loss)	3,856	7,245	-7,943	6,628
Unrealized gain (loss) on available for sale investments before reclassifications	3,735	-35	8,184	-301
Amounts reclassified from accumulated other comprehensive income upon sale of available for sale securities	-8,262	0	-8,262	0
Total other comprehensive income (loss)	-671	7,210	-8,021	6,327
COMPREHENSIVE LOSS	-298,278	-25,204	-185,274	-51,100
Comprehensive loss (income) attributable to non-controlling interests	725	-49	1,614	-71
COMPREHENSIVE LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	($297,553)	($25,253)	($183,660)	($51,171)

UNAUDITED_CONSOLIDATED_STATEME2

UNAUDITED CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY (USD $)

Total

Common Stock

Exchangeable Common Stock

Additional Paid in Capital

Accumulated Deficit

Accumulated Other Comprehensive Income

Treasury Stock

Non - controlling Interest

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

In Thousands, except Share data, unless otherwise specified

Preferred Stock

Additional Paid in Capital

Preferred Stock

Additional Paid in Capital

Treasury Stock

BALANCE at Dec. 31, 2012

$711,652

$1,700

$5

$715,033

($307,484)

($8,889)

($3,664)

$10,139

'

$210,441

'

'

$94,371

'

'

BALANCE (in shares) at Dec. 31, 2012

'

170,033,000

506,000

'

'

'

'

'

'

4,209,000

'

'

4,000

'

'

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share based compensation (in shares)

'

157,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Share based compensation

11,834

2

'

11,832

'

'

'

'

'

'

'

'

'

'

'

Stock Issued, During Period, Shares, 401k Matching Contribution

'

221,170

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued for 401k matching contributions

1,192

2

'

1,190

'

'

'

'

'

'

'

'

'

'

'

Issued shares of common stock for cash (in shares)

'

'

'

'

'

'

'

'

'

216,000

'

'

'

'

'

Issued shares of common stock for cash

'

'

'

'

'

'

'

'

9,591

10,803

-1,212

590

698

-108

'

Dividends on preferred stock

-42,034

'

'

'

-42,034

'

'

'

'

'

'

'

'

'

'

Issued shares of common stock upon exchange of MHR Exchangeco Corporation's exchangeable shares (in shares)

'

-506,000

-506,000

'

'

'

'

'

'

'

'

'

'

'

'

Issued shares of common stock upon exchange of MHR Exchangeco Corporation's exchangeable shares

0

5

-5

'

'

'

'

'

'

'

'

'

'

'

'

Fees on equity issuance

'

'

'

'

'

'

'

'

'

'

'

-109

'

-109

'

Depositary shares representing Series E Preferred Stock returned from escrow

'

'

'

'

'

'

'

'

'

'

'

-280

'

'

-280

Stock Issued During Period, Shares, Conversion of Convertible Securities

'

684,950

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Value, Conversion of Convertible Securities

'

7

'

1,925

'

'

'

'

'

'

'

1,932

'

'

'

Net loss

-177,253

'

'

'

-175,639

'

'

-1,614

'

'

'

'

'

'

'

Foreign currency translation gain (loss)

-7,943

'

'

'

'

-7,943

'

'

'

'

'

'

'

'

'

Unrealized gain on available for sale securities

-78

'

'

'

'

-78

'

'

'

'

'

'

'

'

'

BALANCE at Sep. 30, 2013

$509,094

$1,716

$0

$728,551

($525,157)

($16,910)

($3,944)

$8,525

'

$221,244

'

'

$95,069

'

'

BALANCE (in shares) at Sep. 30, 2013

'

171,602,000

0

'

'

'

'

'

'

4,425,000

'

'

4,000

'

'

UNAUDITED_CONSOLIDATED_STATEME3

UNAUDITED CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	9 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Statement of Cash Flows [Abstract]	'	'	'
Net loss	($177,253)	($57,427)	'
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:	'	'	'
Depletion, depreciation, amortization and accretion	107,624	90,462	'
Exploration	91,533	25,564	'
Impairment of proved oil and gas properties	88,504	0	'
Impairment of other operating assets	263	'	0
Share based compensation	11,834	14,758	'
Cash paid for plugging wells	-14	-101	'
Gain on sale of assets	-50,063	-2,900	'
Unrealized (gain) loss on derivative contracts	23,757	-1,094	'
Unrealized loss on investments	1,043	301	'
Amortization and write-off of deferred financing costs and discount on Senior Notes included in interest expense	3,660	10,725	'
Deferred tax benefit	-54,465	-5,748	'
Changes in operating assets and liabilities:	'	'	'
Accounts receivable, net	-703	-36,984	'
Inventory	77	-5,283	'
Prepaid expenses and other current assets	-3,095	-1,219	'
Accounts payable	23,303	-4,592	'
Revenue payable	-3,027	8,795	'
Accrued liabilities	16,219	11,562	'
Net cash provided by operating activities	79,197	46,819	'
CASH FLOWS FROM INVESTING ACTIVITIES	'	'	'
Capital expenditures and advances	-418,245	-360,498	'
Cash paid in acquisitions	0	-433,865	'
Change in restricted cash	1,500	0	'
Change in deposits and other long-term assets	571	-147	'
Proceeds from sales of assets	460,997	823	'
Net cash provided by (used in) investing activities	44,823	-793,687	'
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Net proceeds from sale of common shares	0	148,329	'
Net proceeds from sale of preferred shares	10,181	119,469	'
Equity issuance costs	-109	0	'
Proceeds from sale of Series A convertible preferred units in Eureka Hunter Holdings, LLC	27,440	128,251	'
Proceeds from exercise of warrants and options	1,932	1,336	'
Preferred stock dividend	-29,911	-17,536	'
Repayments of debt	-379,504	-481,557	'
Proceeds from borrowings on debt	245,991	430,977	'
Proceeds from issuance of Senior Notes	0	443,971	'
Deferred financing costs	-1,184	-19,414	'
Change in other long-term liabilities	-1,103	335	'
Net cash provided by (used in) financing activities	-126,267	754,161	'
Effect of changes in exchange rate on cash	-93	-146	'
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	-2,340	7,147	'
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	57,623	14,851	14,851
CASH AND CASH EQUIVALENTS, END OF PERIOD	$55,283	$21,998	$57,623

ORGANIZATION_AND_NATURE_OF_OPE

ORGANIZATION AND NATURE OF OPERATIONS	9 Months Ended
	Sep. 30, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
ORGANIZATION AND NATURE OF OPERATIONS	'
	NOTE 1 - ORGANIZATION AND NATURE OF OPERATIONS
	Magnum Hunter Resources Corporation, a Delaware corporation, operating directly and indirectly through its subsidiaries (together with its subsidiaries, the “Company” or “Magnum Hunter”), is a Houston, Texas based independent exploration and production company engaged in the acquisition and development of producing properties and undeveloped acreage and the production of oil and natural gas, along with certain midstream and oil field services activities, in the United States ("U.S.").

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
	NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	Presentation of Consolidated Financial Statements
	The accompanying unaudited interim consolidated financial statements of Magnum Hunter have been prepared in accordance with accounting principles generally accepted in the U.S. and the rules of the Securities and Exchange Commission ("SEC"), for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X and should be read in conjunction with the audited financial statements and notes thereto contained in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012, as revised for certain discontinued operations as reflected in the Company's Registration Statement on Form S-4 declared effective by the SEC on October 8, 2013 (the "Form S-4 Registration Statement").  In the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary for a fair statement of the financial position and the results of operations for the interim periods presented have been reflected herein.  The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year.  The year-end balance sheet data were derived from audited financial statements, but do not include all disclosures required by accounting principles generally accepted in the U.S.
	Notes to the consolidated financial statements that would substantially duplicate the disclosures contained in the audited consolidated financial statements as reported in the Company's Form S-4 Registration Statement have been omitted.
	Reclassification of Prior-Year Balances
	Certain prior period balances have been reclassified to correspond with current-year presentation.  As a result of the sale of the Company's wholly-owned subsidiary, Eagle Ford Hunter, Inc. ("Eagle Ford Hunter"), to an affiliate of Penn Virginia Corporation (“Penn Virginia”) on April 24, 2013, and the Company's adoption of a plan in September 2013 to dispose of certain of its U.S. and Canadian properties, all prior operating income and expense for these operations were reclassified as discontinued operations for all periods presented. See "Note 5 - Divestitures and Discontinued Operations".
	Non-Controlling Interest in Consolidated Subsidiaries
	The Company has consolidated PRC Williston, LLC ("PRC Williston") in which it owned 87.5% and Eureka Hunter Holdings, LLC (“Eureka Hunter Holdings”) in which it owned 57.38% as of September 30, 2013 and 61.0% as of December 31, 2012. Eureka Hunter Holdings owns, directly or indirectly, 100% of the equity interests of Eureka Hunter Pipeline, LLC ("Eureka Hunter Pipeline"), TransTex Hunter, LLC ("TransTex Hunter"), and Eureka Hunter Land, LLC.
	Net Income or Loss per Share Data
	Basic income or loss per common share is computed by dividing the income or loss attributable to common shareholders by the weighted average number of shares of common stock outstanding during the period. Diluted income or loss per common share considers the impact to net income and common shares for the potential dilution from stock options, common stock purchase warrants and any outstanding convertible securities.
	The Company has issued potentially dilutive instruments in the form of common stock options, common stock purchase warrants, Series E Preferred Stock, and restricted common stock granted and not yet issued. The potentially dilutive securities were excluded from the calculation of diluted loss per share during all of the periods presented, because their effect would have been anti-dilutive due to the Company's losses during those periods.
	The following table summarizes the potentially dilutive securities outstanding as of September 30, 2013 and 2012:
		September 30,
		2013			2012
		(in thousands of shares)
	Dilutive:
	Common stock options	13,878			2,424
	Warrants	—			69
	Total dilutive	13,878			2,493
	Anti-dilutive:
	Common stock options	4,480			13,330
	Warrants	30,407			13,376
	Series E Preferred Stock	11,185			—
	Total anti-dilutive	46,072			26,707
	Cash and Cash Equivalents
	Cash and cash equivalents include cash in banks and highly liquid debt securities that have original maturities of three months or less. At September 30, 2013, the Company had cash deposits in excess of FDIC-insured limits at various financial institutions.
	Financial Instruments
	The carrying amounts of financial instruments including cash and cash equivalents, accounts receivable, notes receivable, accounts payable and accrued liabilities, derivatives, and certain long-term debt approximate fair value as of September 30, 2013 and December 31, 2012. See "Note 3 - Fair Value of Financial Instruments".
	Inventory
	The Company’s materials inventory is primarily frac sand used in the completion process of hydraulic fracturing. Frac sand is acquired for use in future well completion operations and is carried at the lower of cost or market, on a first-in, first-out cost basis. Commodities inventory consists of crude oil held in storage and is carried at the lower of average cost or market, on a first-in, first-out basis.
	The following table sets forth the Company's inventory as of September 30, 2013 and December 31, 2012:
			September 30, 2013				December 31, 2012
			(in thousands)
	Materials and supplies		$	11,029			$	8,066
	Commodities		928				1,096
	Inventory		$	11,957			$	9,162
	Materials included in other long term assets		$	—			$	3,464
	Oil and Natural Gas Properties
	The Company utilizes the successful efforts method of accounting for its oil and natural gas producing activities. Costs to acquire mineral interests in oil and natural gas properties and to drill and equip new development wells and related asset retirement costs are capitalized. Costs to acquire mineral interests and drill exploratory wells are also capitalized pending determination of whether the wells have proved reserves or not. However, if the Company determines that the exploratory wells do not have proved reserves or leases acquired are not prospective or expire, the costs are expensed to exploration expense. Geological and geophysical costs, including seismic studies and related costs of carrying and retaining unproved properties, are charged to exploration expense as incurred.
	On the sale or retirement of a field, the cost and related accumulated depletion and depreciation is eliminated from the property accounts, and the resultant gain or loss is recognized. On the sale or retirement of an insignificant portion of a field, the cost is charged to accumulated depletion with no resulting gain or loss recognized in income.
	Gas Transportation, Gathering, and Processing Equipment
	The Company's processing plant and equipment are carried at cost. Depreciation of the plant and equipment is provided using the straight line method over an estimated useful life of 5 to 20 years. Gain or loss on sale or retirement or other disposition of assets is included in income in the period of disposition.
	The Company sells and leases gas treating and processing equipment, much of which is leased to third party operators for treating gas at the wellhead.  The leases generally have a term of three years or less.  The equipment under leases in place as of September 30, 2013, had a net carrying value of $16.5 million, and the terms of such leases provide for future lease payments to the Company extending up to July 2016.  As of September 30, 2013, primarily all the leases to third parties were non-cancelable, with future minimum aggregate base rentals payable to the Company of $5.5 million over the twelve months ending September 30, 2014 and $1.4 million thereafter.
	Depreciation expense for gas transportation, gathering, and processing equipment was $3.2 million and $9.1 million for the three and nine months ended September 30, 2013, respectively, and $1.2 million and $2.9 million for the three and nine months ended September 30, 2012, respectively.
	Goodwill
	Goodwill represents the excess of the purchase price of an entity over the estimated fair value of the assets acquired and the liabilities assumed. The Company has goodwill related to the midstream segment as a result of the acquisition of the assets of TransTex Gas Services, LP as of April 1, 2012.
	Goodwill is assessed for impairment whenever events or circumstances indicate that impairment of the carrying value of goodwill is likely, but no less than annually. If the carrying value of goodwill is determined to be impaired, it is reduced for the impaired value with a corresponding charge to pretax earnings in the period in which it is determined to be impaired. The Company performed its annual assessment of goodwill impairment in April 2013 and concluded that goodwill had not been impaired. As of September 30, 2013, the Company was not aware of any matters that would indicate an impairment of goodwill was necessary.
	Intangible Assets
	Intangible assets consist primarily of the fair value of the acquired gas gathering and processing contracts and customer relationships in the TransTex Gas Services, LP assets acquisition completed in April 2012.  These assets are being amortized over a weighted average term of 8.5 years. At September 30, 2013, intangible assets were not impaired.
	Asset Retirement Obligations
	The Company records a liability for the fair value of an asset’s retirement obligation ("ARO") in the period in which it is incurred and the corresponding cost is capitalized by increasing the carrying amount of the related long-lived asset.  The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the estimated economic life of the related asset.  The Company has included estimated future costs of abandonment and dismantlement in its successful efforts amortization base and amortizes these costs as a component of its depreciation, depletion, amortization and accretion expense in the accompanying consolidated financial statements.
	Oil and Natural Gas Sales
	During the three and nine months ended September 30, 2013 and 2012, the Company recognized sales from oil, natural gas, and NGL as follows:
			Three Months Ended							Nine Months Ended
			September 30,							September 30,
			2013				2012			2013			2012
			(in thousands)
	Oil		$	39,119			$	21,319		$	97,813		$	51,416
	Natural gas		9,805				8,389			31,068			26,743
	NGL		5,094				275			9,361			373
	Total oil and natural gas sales		$	54,018			$	29,983		$	138,242		$	78,532
	Other Comprehensive Income (Loss)
	The functional currency of the Company's operations in Canada (which operations are reflected in these financial statements as discontinued operations) is the Canadian dollar.  The Company translates the assets and liabilities of its Canadian subsidiary into U.S. dollars at current exchange rates while revenues and expenses are translated at the average rates in effect for the period.  The related translation gains and losses are included in accumulated other comprehensive income, net of tax.
As of September 30, 2013, the Company had completed the sale of all of the shares of the Penn Virginia common stock it acquired in connection with its sale of Eagle Ford Hunter in April 2013. The Company received gross proceeds of $50.6 million, resulting in a reclassification out of comprehensive income of $8.3 million, which is classified within other income.
Unrealized gains and losses on changes in fair value of common and preferred stock of publicly traded companies are included in accumulated other comprehensive income.
Exploration
Exploration expense consists primarily of abandonment charges and impairment reserves for capitalized leasehold costs associated with unproved properties that the Company has no further exploration or development plans, exploratory dry holes, and geological and geophysical costs.
During the three and nine months ended September 30, 2013 and 2012, the Company recognized exploration expense as follows:
	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013		2012
	(in thousands)
Leasehold impairments - Williston Basin	38,829			2,954			71,454		12,687
Leasehold impairments - Appalachia Basin	940			—			940		4,975
Geological and geophysical	354			345			1,008		481
Total	40,123			3,299			73,402		18,143
Impairment of Proved Oil and Natural Gas Properties (Continuing operations)
Proved oil and natural gas properties are reviewed for impairment on a field-by-field basis when events and circumstances indicate a possible decline in the recoverability of the carrying amount of such property. The Company estimates the expected future cash flows of its oil and natural gas properties and compares these undiscounted cash flows to the carrying amount of the oil and natural gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, the Company will write down the carrying amount of the oil and natural gas properties to fair value. The factors used to determine fair value include, but are not limited to, estimates of reserves, future commodity prices, future lease operating expense, future production estimates, estimated future capital expenditures and discount rates commensurate with the risk associated with realizing the projected cash flows.
During the three and nine months ended September 30, 2013 and 2012, the Company recorded proved property impairments as follows:
	Three Months Ended							Nine Months Ended
	September 30,							September 30,
	2013				2012			2013			2012
	(in thousands)
Impairment of Proved Oil & Natural Gas Properties	$	—			$	—		$	9,968		$	—
Recently Issued Accounting Standards
Accounting standards-setting organizations frequently issue new or revised accounting rules.  The Company regularly reviews all new pronouncements to determine their impact, if any, on its financial statements.
In February 2013, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2013-2, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This amendment to the accounting guidance for the reporting of amounts reclassified out of accumulated other comprehensive income (“AOCI”) expands the existing disclosure by requiring entities to present information about significant items reclassified out of AOCI by component. In addition, an entity is required to provide information about the effects on net income of significant amounts reclassified out of each component of AOCI to net income either on the face of the statement where net income is presented or as a separate disclosure in the notes of the financial statements. The amendment is effective prospectively for annual or interim reporting periods beginning after December 15, 2012. The adoption of this accounting pronouncement did not have a material impact on our financial statement disclosures.
In July 2013, the FASB issued ASU 2013-11, Presentation of Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists, an amendment to FASB Accounting Standards Codification ("ASC") Topic 740, Income Taxes ("FASB ASC Topic 740"). This update clarifies that an unrecognized tax benefit, or a portion of an unrecognized tax benefit, should be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward if such settlement is required or expected in the event the uncertain tax position is disallowed. In situations where a net operating loss carryforward, a similar tax loss, or a tax credit carryforward is not available at the reporting date under the tax law of the applicable jurisdiction or the tax law of the jurisdiction does not require, and the entity does not intend to use, the deferred tax asset for such purpose, the unrecognized tax benefit should be presented in the financial statements as a liability and should not be combined with deferred tax assets. This ASU is effective prospectively for fiscal years, and interim periods within those years, beginning after December 15, 2013. Retrospective application is permitted. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.

FAIR_VALUE_OF_FINANCIAL_INSTRU

FAIR VALUE OF FINANCIAL INSTRUMENTS	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
FAIR VALUE OF FINANCIAL INSTRUMENTS	'
	NOTE 3 - FAIR VALUE OF FINANCIAL INSTRUMENTS
	Accounting standards define 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.  The standards also establish a framework for measuring fair value and a valuation hierarchy based upon the transparency of inputs used in the valuation of an asset or liability.  Classification within the hierarchy is based upon the lowest level of input that is significant to the fair value measurement.  The valuation hierarchy contains three levels:
	•	Level 1 — Quoted prices (unadjusted) for identical assets or liabilities in active markets
	•	Level 2 — Quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets or liabilities in markets that are not active; and model-derived valuations whose inputs or significant value drivers are observable
	•	Level 3 — Significant inputs to the valuation model are unobservable
	The Company used the following fair value measurements for certain of the Company's assets and liabilities at September 30, 2013 and December 31, 2012:
	Level 1 Classification:
	Available for Sale Securities
	At September 30, 2013 and December 31, 2012, the Company held common and preferred stock of publicly traded companies with quoted prices in an active market.  Accordingly, the fair market value measurements of these securities have been classified as Level 1.
	Level 2 Classification:
	Commodity Derivative Instruments
	The Company does not designate its derivative instruments as hedges and therefore does not apply hedge accounting.  The estimated fair value amounts of the Company’s derivative instruments have been determined at discrete points in time based on relevant market information which resulted in the Company classifying such derivatives as Level 2.  Although the Company’s derivative instruments are valued using public indices, the instruments themselves are traded with unrelated counterparties and are not openly traded on an exchange. See "Note 4 - Financial Instruments and Derivatives."
	As of September 30, 2013 and December 31, 2012, the Company’s derivative contracts were with financial institutions, all of which were either senior lenders to the Company or affiliates of such senior lenders, and some of which had investment grade credit ratings. All of the counterparties are believed to have minimal credit risk.  Although the Company is exposed to credit risk to the extent of nonperformance by the counterparties to these derivative contracts, the Company does not anticipate such nonperformance and monitors the credit worthiness of its counterparties on an ongoing basis.
	Level 3 Classification:
	Preferred Stock Embedded Derivative
	At September 30, 2013 and December 31, 2012, the Company had preferred stock embedded derivative liabilities resulting from certain conversion features, redemption options, and other features of its Series A Convertible Preferred Units of Eureka Hunter Holdings. See "Note 10 - Redeemable Preferred Stock."
	The fair value of the bifurcated conversion feature was valued using the “with and without” analysis in a simulation model. The key assumptions used in the model to determine fair value at September 30, 2013 were a volatility of 25%, credit spread of 15.9%, and a total enterprise value of Eureka Hunter Holdings of $544.0 million.
	Convertible Security Embedded Derivative
	The Company recognized an embedded derivative asset resulting from the fair value of the bifurcated conversion feature associated with the convertible note it received in February 2012 as partial consideration upon the sale of Hunter Disposal, LLC (“Hunter Disposal”) to GreenHunter Resources, Inc. ("GreenHunter"), a related party. See "Note 5 - Divestitures and Discontinued Operations." The embedded derivative was valued using a Black-Scholes model valuation of the conversion option.
	The key inputs used in the Black-Scholes option pricing model were as follows:
		30-Sep-13
	Life	3.4 years
	Risk-free interest rate	0.91		%
	Estimated volatility	40		%
	Dividend	—
	GreenHunter stock price at end of period	$	1.13
	The following table presents a reconciliation of the financial derivative asset and liability measured at fair value using significant unobservable inputs for the nine month period ended September 30, 2013:
		Preferred Stock Embedded				Convertible Security Embedded
		Derivative Liability				Derivative Asset
		(in thousands)
	Fair value at December 31, 2012	$	(43,548	)		$	264
	Issuance of derivative liability	(10,803		)		—
	Decrease in fair value recognized in other income (expense)	(20,809		)		(185		)
	Fair value as of September 30, 2013	$	(75,160	)		$	79
	The following tables present recurring financial assets and liabilities which are carried at fair value at September 30, 2013 and December 31, 2012:
		Fair Value Measurements on a Recurring Basis
		30-Sep-13
		(in thousands)
	Assets	Level 1				Level 2				Level 3
	Available for sale securities	$	1,825			$	—			$	—
	Commodity derivative assets	—				1,392				—
	Convertible security derivative assets	—				—				79
	Total assets at fair value	$	1,825			$	1,392			$	79
	Liabilities
	Commodity derivative liabilities	$	—			$	6,750			$	—
	Convertible preferred stock derivative liabilities	—				—				75,160
	Total liabilities at fair value	$	—			$	6,750			$	75,160
		Fair Value Measurements on a Recurring Basis
		31-Dec-12
		(in thousands)
	Assets	Level 1				Level 2				Level 3
	Available for sale securities	$	1,958			$	—			$	—
	Commodity derivative assets	—				4,882				—
	Convertible security derivative assets	—				—				264
	Total assets at fair value	$	1,958			$	4,882			$	264
	Liabilities
	Commodity derivative liabilities	$	—			$	7,477			$	—
	Convertible preferred stock derivative liabilities	—				—				43,548
	Total liabilities at fair value	$	—			$	7,477			$	43,548
	Other Fair Value Measurements
	The carrying value of the Company's senior revolving credit facility (the “MHR Senior Revolving Credit Facility") approximates fair value as it is subject to short-term floating interest rates that approximate the rates available to us for those periods.  The fair value hierarchy for the MHR Senior Revolving Credit Facility is Level 3.
	The fair value of the Company's Senior Notes is based on quoted market prices available for our senior notes.  The estimated fair value of the Company's Senior Notes as of September 30, 2013 and December 31, 2012 was $622.3 million and $613.5 million, respectively.  The fair value hierarchy for the Company's Senior Notes is Level 2 (quoted prices for similar assets in active markets).
	The fair value of Eureka Hunter Pipeline's second lien term loan is the estimated cost to acquire the debt, including a credit spread for the difference between the issue rate and the period end market rate.  The credit spread is the Company’s default or repayment risk.  The credit spread (premium or discount) is determined by comparing the Company’s fixed-rate notes and credit facility to new issuances (secured and unsecured) and secondary trades of similar size and credit statistics for both public and private debt.  The fair value of all fixed-rate notes and the credit facility is based on interest rates currently available to the Company.  Eureka Hunter Pipeline's second lien term loan is valued using an income approach and classified as Level 3 in the fair value hierarchy.
The Company uses available market data and valuation methodologies to estimate the fair value of debt.  The carrying amounts and fair values of long-term debt are as follows:
				30-Sep-13							31-Dec-12
		Fair Value Hierarchy		Carrying Amount				Estimated Fair Value			Carrying Amount		Estimated Fair Value
				(in thousands)
Senior Notes (1)		Level 2		$	597,216			$	622,320		$	597,212	$	613,500
MHR Senior Revolving Credit Facility (2)		Level 3		$	90,000			$	90,000		$	225,000	$	225,000
Eureka Hunter Pipeline, LLC second lien term loan (3)		Level 3		$	50,000			$	59,832		$	50,000	$	58,550
Equipment notes payable (3)		Level 3		$	16,059			$	15,412		$	18,548	$	17,450
_________________________________
(1)     The fair value of the Company's Senior Notes is based on quoted market prices available to us for those periods.
-2	The carrying value of the MHR Senior Revolving Credit Facility approximates fair value as it is subject to short-term floating interest rates that approximate the rates available to us at such date.
-3	The fair value of each of (a) Eureka Hunter Pipeline's second lien term loan and (b) the equipment notes payable is the estimated cost to acquire the debt, including a credit spread for the difference between the issue rate and the period end market rate.
Fair Value on a Non-Recurring Basis
The Company follows the provisions of ASC 820-10 for non-financial assets and liabilities measured at fair value on a non-recurring basis. As it relates to the Company, ASC 820-10 applies to certain non-financial assets and liabilities as may be acquired in a business combination and thereby measured at fair value; measurements of impairments; and the initial recognition of asset retirement obligations, for which fair value is used. These ARO estimates are derived from historical costs as well as management's expectation of future cost environments. As there is no corroborating market activity to support the assumptions used, the Company has designated these measurements as Level 3.

FINANCIAL_INSTRUMENTS_AND_DERI

FINANCIAL INSTRUMENTS AND DERIVATIVES	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
FINANCIAL INSTRUMENTS AND DERIVATIVES	'
	NOTE 4 - FINANCIAL INSTRUMENTS AND DERIVATIVES
	The Company periodically enters into certain commodity derivative instruments such as futures contracts, swaps, collars, and basis swap contracts, which are effective in mitigating commodity price risk associated with a portion of the Company's future monthly natural gas and crude oil production and related cash flows. The Company has not designated any commodity derivatives as hedges.
	In a commodities swap agreement, the Company trades the fluctuating market prices of oil or natural gas at specific delivery points over a specified period, for fixed prices. As a producer of oil and natural gas, the Company holds these commodity derivatives to protect the operating revenues and cash flows related to a portion of its future natural gas and crude oil sales from the risk of significant declines in commodity prices, which helps reduce exposure to price risk and improves the likelihood of funding its capital budget.  If the price of a commodity rises above what the Company has agreed to receive in the swap agreement, the amount that it agrees to pay the counterparty would theoretically be offset by the increased amount it received for its production.
	As of September 30, 2013, the Company had the following commodity derivative instruments:
					Weighted Average
	Natural Gas	Period	MMBtu/day		Price per MMBtu
	Collars (1)	Oct 2013 - Dec 2013	12,500		$4.50 - $5.96
	Swaps	Oct 2013 - Dec 2013	25,500		$3.64
		Jan 2014 - Dec 2014	10,000		$4.13
	Ceilings purchased (call)	Oct 2013 - Dec 2013	10,000		$6.00
		Jan 2014 - Dec 2014	10,000		$6.15
	Ceilings sold (call)	Jan 2014 - Dec 2014	26,000		$5.47
	Floors purchased (put)	Jan 2014 - Dec 2014	10,000		$4.25
	Floors sold (put)	Jan 2014 - Dec 2014	10,000		$3.75
					Weighted Average
	Crude Oil	Period	Bbl/day		Price per Bbl
	Collars (1)	Oct 2013 - Dec 2013	2,763		$81.38 - $97.61
		Jan 2014 - Dec 2014	663		$85.00 - $91.25
		Jan 2015 - Dec 2015	259		$85.00 - $91.25
	Traditional three-way collars (2)	Oct 2013 - Dec 2013	2,000		$60.63 - $80.00 - $100.00
		Jan 2014 - Dec 2014	4,000		$64.94 - $85.00 - $102.50
	Conservative three-way collar (3)	Oct 2013 - Dec 2013	763		$65.00 - $91.25 - $101.25
	Swaps	Oct 2013 - Dec 2013	5,450		$92.72
	Ceilings purchased (call)	Oct 2013 - Dec 2013	2,250		$100.00
	Ceilings sold (call)	Jan 2015 - Dec 2015	1,570		$120.00
	Floors purchased (put)	Oct 2013 - Dec 2013	1,750		$90.00
	Floors sold (put)	Oct 2013 - Dec 2013	5,438		$76.03
		Jan 2014 - Dec 2014	663		$65.00
		Jan 2015 - Dec 2015	259		$70.00
	________________________________
	(1) A collar is a sold call and a purchased put. Some collars are "costless" collars with the premiums netting to approximately zero.
	(2) These three-way collars are a combination of three options: a sold call, a purchased put and a sold put.
	(3) These three-way collars are a combination of three options: a sold call, a purchased call and a sold put.
	Currently, Bank of America, Bank of Montreal, KeyBank National Association, Credit Suisse Energy, LLC, UBS AG London Branch, Deutsche Bank AG London Branch, Citibank, N.A., and J. Aron & Company are the only counterparties to the Company's commodity derivatives positions.  The Company is exposed to credit losses in the event of nonperformance by the counterparties; however, it does not anticipate nonperformance by the counterparties over the term of the commodity derivatives positions.  All counterparties or their affiliates are participants in the MHR Senior Revolving Credit Facility, and the collateral for the outstanding borrowings under the MHR Senior Revolving Credit Facility is used as collateral for its commodity derivatives with those counterparties.
	At September 30, 2013, the Company had preferred stock derivative liabilities resulting from certain conversion features, redemption options, and other features of its Series A Convertible Preferred Units of Eureka Hunter Holdings. See "Note 3 - Fair Value of Financial Instruments" and "Note 10 - Redeemable Preferred Stock."
	At September 30, 2013, the Company also had a convertible security embedded derivative asset primarily due to the conversion feature of the promissory note received as partial consideration for the sale of Hunter Disposal. See "Note 3 - Fair Value of Financial Instruments," "Note 5 - Divestitures and Discontinued Operations," and "Note 12 - Related Party Transactions".
	The following table summarizes the fair value of the Company's commodity and financial derivative contracts as of the dates indicated:
					Gross Derivative Assets								Gross Derivative Liabilities
	Derivatives not designated as hedging instruments		Balance Sheet Classification		30-Sep-13				31-Dec-12				30-Sep-13				31-Dec-12
					(in thousands)
	Commodity
			Derivative assets		$	1,000			$	4,882			$	—			$	—
			Derivative assets - long term		392				—				—				—
			Derivative liabilities		—				—				(5,913		)		(3,501		)
			Derivative liabilities - long term		—				—				(837		)		(3,976		)
	Total commodity				$	1,392			$	4,882			$	(6,750	)		$	(7,477	)
	Financial
			Derivative assets		$	79			$	264			$	—			$	—
			Derivative liabilities - long term		—				—				(75,160		)		(43,548		)
	Total financial				$	79			$	264			$	(75,160	)		$	(43,548	)
	Total derivatives				$	1,471			$	5,146			$	(81,910	)	—	$	(51,025	)
	The following table summarizes the realized and unrealized gains and losses on change in fair value of the Company's derivative contracts as of the dates indicated:
		Three Months Ended								Nine Months Ended
		September 30,								September 30,
		2013				2012				2013				2012
		(in thousands)
	Realized gain (loss)	$	(6,582	)		$	2,224			$	(6,887	)		$	7,962
	Unrealized gain (loss)	(22,971		)		(12,375		)		(23,757		)		1,094
	Net gain (loss)	$	(29,553	)		$	(10,151	)		$	(30,644	)		$	9,056

DIVESTITURES_AND_DISCONTINUED_

DIVESTITURES AND DISCONTINUED OPERATIONS	9 Months Ended
	Sep. 30, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
DIVESTITURES AND DISCONTINUED OPERATIONS	'
	NOTE 5 - DIVESTITURES AND DISCONTINUED OPERATIONS
	Discontinued Operations
	Planned Divestitures of Magnum Hunter Production and Williston Hunter Canada
	In September 2013, the Company adopted a plan to divest all of its interests in (i) Magnum Hunter Production, Inc. (“MHP”), a wholly-owned subsidiary of the Company whose oil and natural gas operations are located primarily in the Southern Appalachian Basin in Kentucky and Tennessee, and (ii) the Canadian operations of Williston Hunter Canada, Inc., a wholly-owned subsidiary of the Company ("WHI Canada"). The Company is actively marketing these interests and anticipates completing the divestitures by the second quarter of 2014. The Company has reclassified the associated assets and liabilities to assets and liabilities held for sale and the operations are reflected as discontinued operations for all periods presented. The Company has recorded an impairment expense of $72.5 million and $78.5 million for the three and nine months ended September 30, 2013, respectively, relating to the discontinued operations which is recorded in income (loss) from discontinued operations and an expense of $84.5 million to reflect the net assets at their estimated selling prices, less costs to sell, which is recorded in loss on disposal of discontinued operations for the three and nine months ended September 30, 2013.
	Sale of Eagle Ford Hunter
	On April 24, 2013, the Company closed on the sale of all of its ownership interest in its wholly-owned subsidiary, Eagle Ford Hunter to an affiliate of Penn Virginia for a total purchase price of approximately $422.1 million paid to the Company in the form of $379.8 million in cash (after estimated customary initial purchase price adjustments) and 10.0 million shares of common stock of Penn Virginia valued at approximately $42.3 million (based on the closing market price of the stock of $4.23 as of April 24, 2013). The effective date of the sale was January 1, 2013. The Company has recognized a preliminary gain on the sale of $172.5 million, net of tax. On August 24, 2013, the Company presented Penn Virginia with the Company’s estimate of the final settlement of the adjustments to the cash portion of the purchase price, to which Penn Virginia responded on October 21, 2013 with its calculation of the final adjustment amounts. The Company is currently in the process of reviewing Penn Virginia’s calculation of the final adjustment amounts. As of the date of filing of this Quarterly Report on Form 10-Q, the Company estimated that the final settlement of the adjustment amounts may result in a payable to Penn Virginia ranging from $22 million to $33 million, after taxes, but such estimate is subject to further review by the Company and discussions with Penn Virginia.  Therefore, the Company has recorded a liability for its revised estimate of the final settlement of the adjustment amounts, after taxes, as a reduction in the gain on disposal of discontinued operations of Eagle Ford Hunter.  Upon closing of the sale, $325.0 million of sale proceeds were used to pay down outstanding borrowings under the MHR Senior Revolving Credit Facility. As of September 30, 2013, the Company had completed the sale of all of its Penn Virginia common stock for gross proceeds of $50.6 million, recognizing a gain of $8.3 million in other income.
	Sale of Hunter Disposal
	On February 17, 2012, the Company, through its wholly-owned subsidiary, Triad Hunter, LLC ("Triad Hunter"), sold 100% of its equity ownership interest in Hunter Disposal to an affiliate of GreenHunter, for total consideration of $9.3 million, comprised of cash of $2.2 million, 1,846,722 common shares of GreenHunter valued at $2.6 million based on a closing price of $1.79 per share at February 17, 2012 (discounted for restrictions), 88,000 shares of GreenHunter 10% Series C Preferred Stock, valued at $1.9 million based on a stated value of $25.00 per share, and a promissory note of $2.2 million (which is convertible, at the option of the Company into 880,000 shares of GreenHunter common stock based on the stated conversion price of $2.50 per share). The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note with fair market value of $405,000. See "Note 3 - Fair Value of Financial Instruments" for additional information. The cash proceeds from the sale were adjusted downward to $783,000 for changes in working capital to reflect the effective date of the sale of December 31, 2011. GreenHunter is a related party as described in "Note 12 - Related Party Transactions".
	The Company included the results of operations of MHP and WHI Canada for all periods presented through September 30, 2013, Eagle Ford Hunter through April 24, 2013, and Hunter Disposal through February 17, 2012 in discontinued operations as follows:
			Three Months Ended September 30,						Nine Months Ended September 30,
			2013			2012			2013			2012
			(in thousands)
	Revenues		$	13,203		$	32,997		$	81,616		$	91,728
	Expenses (2)		(107,958		)	(33,997		)	(166,196		)	(90,216		)
	Other income (expense)		3,621			(76		)	6,777			3,212
	Income tax benefit (expense) (1)		10,580			(26		)	6,348			(1,892		)
	Income (loss) from discontinued operations, net of tax		(80,554		)	(1,102		)	(71,455		)	2,832
	Gain (loss) on sale of discontinued operations, net of taxes (3)		(84,454		)	—			87,998			2,224
	Income (loss) from discontinued operations, net of taxes		$	(165,008	)	$	(1,102	)	$	16,543		$	5,056
	________________________________
	-1	In addition, the Company recognized an alternative minimum tax charge of $1.3 million in connection with the Eagle Ford Hunter sale.
	-2	Includes impairment expense of $72.5 million and $78.5 million for the three and nine months ended September 30, 2013, respectively, and exploration expense of $18.0 million and $19.6 million for the three and nine months ended September 30, 2013, respectively relating to the discontinued operations of MHP and WHI Canada, which is recorded in income (loss) from discontinued operations.
	-3	Income tax expense associated with gain/(loss) on sale of discontinued operations was $6.6 million for the nine months ended September 30, 2013.
	Other Divestiture
	Sale of Certain North Dakota Oil and Natural Gas Properties
	On September 2, 2013, Williston Hunter, Inc., a wholly owned subsidiary of the Company, entered into a purchase and sale agreement with Oasis Petroleum of North America LLC, or Oasis, to sell its non-operated working interest in certain oil and natural gas properties located in Burke County, North Dakota, to Oasis for $32.5 million in cash, subject to customary adjustments. The transaction closed on September 26, 2013, and was effective as of July 1, 2013. The Company recognized a loss of $38.1 million on the sale for the three months ended September 30, 2013.

ASSET_RETIREMENT_OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS	9 Months Ended
	Sep. 30, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
ASSET RETIREMENT OBLIGATIONS	'
	NOTE 6 - ASSET RETIREMENT OBLIGATIONS
	The following table summarizes the Company’s ARO activities during the nine month period ended September 30, 2013:
		Nine Months Ended
		September 30, 2013
		(in thousands)
	Asset retirement obligation at beginning of period	$	30,680
	Assumed in acquisitions	17
	Liabilities incurred	209
	Liabilities settled	(98		)
	Liabilities sold	(2,429		)
	Accretion expense	1,824
	Revisions in estimated liabilities (1)	1,935
	Reclassified as liabilities associated with assets held for sale	(11,148		)
	Effect of foreign currency translation	(73		)
	Asset retirement obligation at end of period	20,917
	Less: current portion (included in other liabilities)	(1,015		)
	Asset retirement obligation at end of period	$	19,902
	________________________________
	(1) $1.5 million of the revisions in estimated liabilities is related to change in assumptions used with respect to certain wells in the Williston Basin in North Dakota.

LONGTERM_DEBT

LONG-TERM DEBT	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
LONG-TERM DEBT	'
	NOTE 7 - LONG-TERM DEBT
	Long-term debt at September 30, 2013 and December 31, 2012 consisted of the following:
		September 30, 2013			December 31, 2012
		(in thousands)
	Senior Notes payable due May 15, 2020, interest rate of 9.75%, net of unamortized net discount of $2.8 million at September 30, 2013 and December 31, 2012	$	597,216		$	597,212
	Various equipment and real estate notes payable with maturity dates January 2015 - April 2021, interest rates of 4.25% - 5.70%	16,059			18,548
	Eureka Hunter Pipeline, LLC second lien term loan due August 16, 2018, interest rate of 12.5%	50,000			50,000
	MHR Senior Revolving Credit Facility due April 13, 2016, interest rate of 2.96%	90,000			225,000
	at September 30, 2013 and 3.56% at December 31, 2012
		753,275			890,760
	Less: current portion	(4,144		)	(3,991		)
	Total long-term debt obligations, net of current portion	$	749,131		$	886,769
	The following table presents the scheduled or expected approximate annual maturities of debt, gross of unamortized discount of $2.8 million:
		(in thousands)
	2013	$	1,034
	2014	4,149
	2015	8,313
	2016	92,563
	2017	—
	Thereafter	650,000
	Total	$	756,059
	MHR Senior Revolving Credit Facility
	On April 13, 2011, the Company entered into a Second Amended and Restated Credit Agreement, referred to, as amended, as the MHR Senior Revolving Credit Facility, by and among the Company, Bank of Montreal, as Administrative Agent, and the lenders party thereto.
	The MHR Senior Revolving Credit Facility provides for an asset‑based, senior secured revolving credit facility maturing on April 13, 2016. The MHR Senior Revolving Credit Facility is governed by a semi-annual borrowing base redetermination derived from the Company's proved crude oil and natural gas reserves, and based on such redeterminations, the borrowing base may be decreased or may be increased up to a maximum commitment level of $750 million. Currently, the next scheduled redetermination of the borrowing base is in November 2013.
	As of September 30, 2013, the borrowing base under this facility was $265.0 million, and $90.0 million of borrowings were outstanding ($225.0 million outstanding as of December 31, 2012). The borrowing base is subject to certain automatic reductions upon the issuance of additional Senior Notes and in certain other circumstances.
	The facility may be used for loans and, subject to a $10 million sublimit, letters of credit. The facility provides for a commitment fee of 0.5% based on the unused portion of the borrowing base under the facility.
	Borrowings under the facility will, at the Company's election, bear interest at either: (i) an alternate base rate, referred to as “ABR,” equal to the higher of (A) the Prime Rate, (B) the Federal Funds Effective Rate plus 0.5% per annum and (C) the London Interbank Offered Rate, “LIBOR,” for a one month interest period on such day plus 1.0%; or (ii) the adjusted LIBOR, which is the rate stated on Reuters British Bankers Association London Interbank Offered Rate, “BBA LIBOR,” market for one, two, three, six or twelve months, as adjusted for statutory reserve requirements for Eurocurrency liabilities, plus, in each of the cases described in clauses (i) and (ii) above, an applicable margin ranging from 1.50% to 2.25% for ABR loans and from 2.50% to 3.25% for adjusted LIBOR loans.
	Upon any payment default, the interest rate then in effect shall be increased on such overdue amount by an additional 2% per annum for the period that the default exists plus the rate applicable to ABR loans.
	The MHR Senior Revolving Credit Facility contains negative covenants that, among other things, restrict the ability of the Company to, with certain exceptions: (1) incur indebtedness; (2) grant liens; (3) make certain restricted payments; (4) change the nature of its business; (5) dispose of its assets; (6) enter into mergers, consolidations or similar transactions; (7) make investments, loans or advances; (8) pay cash dividends, unless certain conditions are met, and subject to a “basket” of $45 million per year available for payment of dividends on preferred stock; and (9) enter into transactions with affiliates.
	The facility also requires the Company to satisfy certain financial covenants, including maintaining (1) a ratio of consolidated current assets to consolidated current liabilities (as defined) of not less than 1.0 to 1.0; (2) a ratio of earnings before interest, taxes, depreciation, depletion, amortization and exploration expenses, or “EBITDAX”, to interest expense of not less than (i) 2.00 to 1.00 for the fiscal quarters ended June 30, 2013 and ending September 30, 2013, (ii) 2.25 to 1.00 for the fiscal quarter ending December 31, 2013 and (iii) 2.50 to 1.00 for the fiscal quarter ending March 31, 2014 and each fiscal quarter ending thereafter; (3) commencing with the fiscal quarter ending June 30, 2014, a ratio of total debt to EBITDAX of not more than (i) 4.50 to 1.0 for the fiscal quarters ending June 30, 2014 and September 30, 2014 and (ii) 4.25 to 1.00 for the fiscal quarter ending December 31, 2014 and for each fiscal quarter ending thereafter, and (4) commencing with the fiscal quarter ended June 30, 2013 through and including the fiscal quarter ending March 31, 2014, a ratio of senior debt to EBITDAX not more than 2.00 to 1.00.
	The obligations of the Company under the facility may be accelerated upon the occurrence of an Event of Default (as such term is defined in the facility). Events of Default include customary events for a financing agreement of this type, including, without limitation, payment defaults, defaults in the performance of affirmative or negative covenants, the inaccuracy of representations or warranties, bankruptcy or related defaults, defaults relating to judgments and the occurrence of a change in control of the Company.
	Subject to certain permitted liens, the Company's obligations under the MHR Senior Revolving Credit Facility have been secured by the grant of a first priority lien on no less than 80% of the value of the proved oil and natural gas properties of the Company and its restricted subsidiaries and a lien on equity interests on certain of the Company’s subsidiaries.
	In connection with the facility, the Company and its restricted subsidiaries also entered into certain customary ancillary agreements and arrangements, which, among other things, provide that the indebtedness, obligations and liabilities of the Company arising under or in connection with the facility are unconditionally guaranteed by such subsidiaries.
	The Company and its restricted subsidiaries are in preliminary discussions with their existing senior lenders to enter into a new senior secured revolving credit facility. Any such facility would replace, and is expected to be on terms substantially similar to, the existing MHR Senior Revolving Credit Facility.
	Eighteenth Amendment to Second Amended and Restated Credit Agreement
	On August 7, 2013, pursuant to the Eighteenth Amendment to Second Amended and Restated Credit Agreement , the MHR Senior Revolving Credit Facility was amended to effect the following changes:
	(i) During the period the total debt to EBITDAX covenant is deferred as described in clause (ii) below, implement a new total senior debt to EBITDAX covenant set at 2.00x EBITDAX;
	(ii) the Company's total debt to EBITDAX covenant is deferred for the period starting June 30, 2013 until June 30, 2014 at which time the total debt to EBITDAX covenant will be reinstated at a level of less than 4.50x EBITDAX , decreasing to less than 4.25x EBITDAX starting December 31, 2014;
	(iii) amend the EBITDAX to interest expense covenant to no less than 2.00x for the quarters ended June 30, 2013 and September 30, 2013, increasing to 2.25x for the quarter ending December 31, 2013 and increasing to 2.50x starting March 31, 2014 and thereafter;
	(iv) allow for up to $32 million in investments in the Company's unrestricted subsidiary Eureka Hunter Holdings provided a) the investments are made before December 31, 2013 and b) the borrowing base has availability of at least $75.0 million at the time of such investment, provided that the Company may also invest in Eureka Hunter Holdings using proceeds from the sale of the Company's common or preferred equity (the Company anticipates that any such investments would be utilized to further expand Eureka Hunter Pipeline);
	(v) reduce the Company's Senior Notes basket to $600 million from $800 million;
	(vi) increase the investment basket for unrestricted subsidiaries (other than Eureka Hunter Holdings) from $7.5 million to $12.5 million for the fiscal year ending December 31, 2013, thereafter the basket shall be reduced back to $7.5 million in any calendar year;
	(vii) establish an acquisition and leasehold expenditures basket commencing August 1, 2013 through the Company's compliance with the financial covenants for the fiscal quarter ending June 30, 2014, which basket shall equal (a) $40.0 million plus (b) if at the time of and after giving effect to any such investment, availability under the borrowing base is equal to or greater than $75.0 million, (i) asset sale proceeds net of any borrowing base reduction resulting from such asset sale and (ii) the net cash proceeds from the offering of common or preferred equity securities by the Company; and
	(viii) increase pricing by 50 basis points to LIBOR plus 250 to 325 basis points from LIBOR plus 200 to 275 basis points based on utilization until the Company demonstrates compliance with the financial covenants for the fiscal quarter ending June 30, 2014.
	At September 30, 2013, the Company was in compliance with all of its covenants, as amended or waived, contained in the MHR Senior Revolving Credit Facility.
	The following table sets forth interest expense for the three and nine month period ended September 30, 2013 and 2012, respectively:
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013		2012
		(in thousands)
	Interest expense incurred on debt	$	14,578		$	13,766		$	49,542	$	29,870
	Amortization and write-off of deferred financing costs	1,111			639			3,661		10,725
	Total Interest Expense	$	15,689		$	14,405		$	53,203	$	40,595

SHAREBASED_COMPENSATION

SHARE-BASED COMPENSATION	9 Months Ended
	Sep. 30, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
SHARE-BASED COMPENSATION	'
	NOTE 8 - SHARE-BASED COMPENSATION
	Under the Company's amended and restated Stock Incentive Plan, the Company may grant unrestricted common stock, restricted common stock, common stock options, and stock appreciation rights to directors, officers, employees and other persons who contribute to the success of Magnum Hunter.  Currently, 27,500,000 shares of the Company's common stock are authorized to be issued under the plan, and 4,525,928 shares had been issued under the plan as of September 30, 2013.
	On January 17, 2013, the Company granted 3,942,575 common stock options to officers and employees of the Company, with an exercise price of $4.16 per share, of which 3,080,000 have a term of 10 years and 862,575 have a term of 5 years. The options vest over a 3-year period with 25% of the options vesting immediately upon grant. On January 17, 2013, the Company also granted 420,000 common stock options to members of the Company's Board of Directors, which options have a term of 10 years and vested immediately.
	On May 15, 2013 the Company granted 175,000 common stock options to an officer of the Company, with an exercise price of $3.40 per share and a term of 5 years, vesting over a 3-year period with 25% vesting immediately. On July 26, 2013 the Company granted 400,000 common stock options to an officer of the Company, with an exercise price of $3.82 per share and a term of 10 years, vesting over a 3-year period with 25% vesting immediately.
	We recognized share-based compensation expense of $3.1 million and $11.8 million for the three and nine months ended September 30, 2013 and $2.2 million and $14.8 million for the three and nine months ended September 30, 2012, respectively.
	A summary of common stock option activity for the nine months ended September 30, 2013 and 2012 is presented below:
		Nine Months Ended
		September 30,
		2013		2012		2013		2012
		(in thousands of shares)				Weighted Average Exercise Price per Share
	Outstanding at beginning of period	14,847		12,566		$	6.01	$	5.64
	Granted	4,938		4,854		$	4.11	$	6.05
	Exercised	(685	)	(843	)	$	2.95	$	1.4
	Forfeited	(742	)	(807	)	$	6	$	7.24
	Outstanding at end of period	18,358		15,770		$	5.61	$	5.91
	Exercisable at end of period	10,512		8,959		$	5.86	$	5.79
	A summary of the Company’s non-vested common stock options and stock appreciation rights for the nine months ended September 30, 2013 and 2012 is presented below:
		Nine Months Ended
		September 30,
		2013		2012
		(in thousands of shares)
	Non-vested at beginning of period	6,163		5,651
	Granted	4,938		4,854
	Vested	(2,867	)	(3,005	)
	Forfeited	(389	)	(688	)
	Non-vested at end of period	7,845		6,811
	Total unrecognized compensation cost related to the non-vested common stock options was $12.9 million and $15.1 million as of September 30, 2013 and 2012, respectively.  The unrecognized cost at September 30, 2013 is expected to be recognized over a weighted-average period of 1.46 years. At September 30, 2013, the weighted average remaining contract life of outstanding options was 6.42 years.
	Total unrecognized compensation cost related to non-vested, restricted shares amounted to $66,000 and $462,000 as of September 30, 2013 and 2012, respectively.  The unrecognized cost at September 30, 2013, is expected to be recognized over a weighted-average period of 0.17 years.
	The assumptions used in the fair value method calculation for the nine months ended September 30, 2013, are:
	Weighted average fair value per option granted during the period (1)	$2.52
	Assumptions: (2), (3)
	Weighted average stock price volatility	80.61%
	Weighted average risk free rate of return	0.78%
	Weighted average expected term	4.65
	________________________________
	-1	Calculated using the Black-Scholes fair value based method for service and performance based grants and the Lattice Model for market based grants.
	-2	The Company's estimated future forfeiture rate is 2.45%.
	-3	The Company does not pay cash dividends on its common stock.

SHAREHOLDERS_EQUITY

SHAREHOLDERS’ EQUITY	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
SHAREHOLDERS’ EQUITY	'
	NOTE 9 - SHAREHOLDERS' EQUITY
	Common Stock
	During the nine months ended September 30, 2013, the Company:
	i) issued 157,271 shares of the Company’s common stock in connection with share-based compensation which had fully vested to senior management and directors of the Company;
	ii) issued 505,835 shares of the Company’s common stock upon exchange of 505,835 exchangeable shares issued by MHR Exchangeco Corporation in connection with the Company’s acquisition of NuLoch Resources, Inc. in May 2011;
	iii) issued 221,170 shares of the Company’s common stock in payment of safe-harbor and discretionary matching contributions to the Company's 401k plan in respect of salary deferrals made by participants in the plan during 2012; and
	iv) issued 684,950 shares of the Company’s common stock upon exercise of fully vested stock options.
	Declared Accumulated Preferred Stock Dividend
	On July 29, 2013, the Company declared cash dividends on the Company's Series C Preferred Stock, Series D Preferred Stock, and Series E Preferred Stock, for the months of April, May, June, July and August 2013, referred to as the "Declared Accumulated Dividend." The Declared Accumulated Dividend was paid on September 3, 2013, to holders of record at the close of business on August 15, 2013.
	Common Stock Dividends - Warrants
	On August 26, 2013, the Company declared a dividend on its outstanding shares of common stock in the form of 17,030,706 warrants to purchase shares of the Company's common stock at $8.50 per share with such warrants having a fair value of $21.6 million as of the declaration date of August 26, 2013. The warrants were issued on October 15, 2013 to shareholders of record on September 16, 2013. Each shareholder of record received one warrant for every ten shares owned as of the record date (with the number of warrants rounded down to the nearest whole number). Each warrant entitles the holder to purchase one share of the Company's common stock at an exercise price of $8.50 per share, subject to certain anti-dilution adjustments, and will expire on April 15, 2016. The warrants will become exercisable on the later of September 1, 2014 or the date that a registration statement has been filed with and declared effective by the SEC with respect to the issuance of the common stock underlying the warrants. The warrants will be subject to redemption at the option of the Company at $0.001 per warrant upon not less than thirty days’ notice to the holders.
	Series D Preferred Stock
	During the nine months ended September 30, 2013, the Company issued under an at-the-market ("ATM") sales agreement 216,068 shares of its Series D Preferred Stock with a liquidation preference of $50.00 per share for net proceeds of approximately $9.6 million, which included sales agent commissions and other issuance costs of approximately $1.2 million.
	The Series D Preferred Stock cannot be converted into common stock of the Company but may be redeemed by the Company, at the Company’s option, on or after March 14, 2014, for its liquidation preference of $50.00 per share (plus accrued and unpaid dividends) or, in certain circumstances, prior to such date as a result of a change in control of the Company.
	Series E Preferred Stock
	Each share of the Company's Series E Preferred Stock has a stated liquidation preference of $25,000 and a dividend rate of 8.0% per annum, based on stated liquidation preference, is convertible at the option of the holder into a number of shares of the Company’s common stock equal to the stated liquidation preference, plus accrued and unpaid dividends, divided by a conversion price of $8.50 per share (subject to anti-dilution adjustments in the case of stock dividends, stock splits and combinations of shares), and is redeemable by the Company under certain circumstances.  The Series E Preferred Stock is junior to the Company’s Series C Preferred Stock and Series D Preferred Stock in respect of dividends and distributions upon liquidation.  Each Depositary Share is a 1/1000th interest in a share of Series E Preferred Stock.  Accordingly, the Depositary Shares have a stated liquidation preference of $25.00 per share and a dividend rate of 8.0% per annum, based on stated liquidation preference, are similarly convertible at the option of the holder into a number of shares of the Company’s common stock equal to the stated liquidation preference, plus accrued and unpaid dividends, divided by a conversion price of $8.50 per share, subject to corresponding anti-dilution adjustments, and are redeemable by the Company under certain circumstances.
	During the nine months ended September 30, 2013, the Company issued under an ATM sales agreement an 27,906 Depositary Shares, each representing a 1/1,000th interest in a share of the Company’s Series E Preferred Stock. The Depositary Shares were sold to the public at an average price of $24.24 per Depositary Share, and net proceeds to the Company were $590,000 after deducting sales agent commissions and other issuance costs.
	Preferred Dividends Incurred
	A summary of the Company's preferred dividends for the three and nine months ended September 30, 2013 and 2012 is presented below:
		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013		2012
		(in thousands)				(in thousands)
	Dividend on Eureka Hunter Holdings Series A Preferred Units	$	3,771	$	2,718	$	10,441	$	5,086
	Accretion of the carrying value of the Eureka Hunter Holdings Series A Preferred Units	1,826		1,307		4,990		2,415
	Dividend on Series C Preferred Stock	2,562		2,562		7,686		7,686
	Dividend on Series D Preferred Stock	4,424		3,233		13,231		7,493
	Dividend on Series E Preferred Stock	1,834		—		5,686		—
	Total dividends on Preferred Stock	$	14,417	$	9,820	$	42,034	$	22,680

REDEEMABLE_PREFERRED_STOCK

REDEEMABLE PREFERRED STOCK	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
REDEEMABLE PREFERRED STOCK	'
	NOTE 10 - REDEEMABLE PREFERRED STOCK
	Eureka Hunter Holdings Series A Preferred Units
	On March 21, 2012, Eureka Hunter Holdings entered into a Series A Convertible Preferred Unit Purchase Agreement (the “Unit Purchase Agreement”) with Magnum Hunter and Ridgeline Midstream Holdings, LLC (“Ridgeline”), an affiliate of ArcLight Capital Partners, LLC ("ArcLight"). Pursuant to this Unit Purchase Agreement, Ridgeline committed, subject to certain conditions, to purchase up to $200.0 million of Series A Convertible Preferred Units, representing membership interests of Eureka Hunter Holdings (the “Series A Preferred Units”), of which $179.8 million had been purchased as of September 30, 2013.
	During the nine months ended September 30, 2013, Eureka Hunter Holdings issued 1,400,000 Series A Preferred Units to Ridgeline for net proceeds of $27.4 million, net of transaction costs. The Series A Preferred Units outstanding at September 30, 2013 represented 40.6% of the ownership of Eureka Hunter Holdings on a basis as converted to Class A Common Units of Eureka Hunter Holdings.
	During the nine months ended September 30, 2013, Eureka Hunter Holdings issued 318,335 Series A Preferred Units as payment of $6.4 million in distributions paid-in-kind to holders of the Series A Preferred Units. The fair value of the embedded derivative feature of the outstanding Eureka Hunter Holdings Series A Preferred Units was determined to be $75.2 million at September 30, 2013.
	Dividend expense included accretion of the Eureka Hunter Holdings Series A Preferred Units of $1.8 million and $5.0 million for the three and nine months ended September 30, 2013, and $1.3 million and $2.4 million for the three and nine months ended September 30, 2012.

TAXES

TAXES	9 Months Ended
	Sep. 30, 2013
Income Tax Disclosure [Abstract]	'
Taxes	'
	NOTE 11 - TAXES
	The Company's income tax benefit from continuing operations for the three and nine months ended September 30, 2013 and 2012 was:
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2013			2012		2013		2012
		(in thousands)
	Deferred	(3,255		)	1,983		40,944		9,143
	Income tax benefit	$	(3,255	)	$	1,983	$	40,944	$	9,143
	We recognize deferred income taxes for the future tax consequences attributable to differences between the financial statement carrying amounts of the existing assets and liabilities and their respective tax basis and net operating loss and credit carryforwards. The valuation allowance will continue to be recognized until the realization of future deferred tax benefits is more likely than not to be utilized. The Company files income tax returns in the U.S., various states and Canada. As of September 30, 2013, no adjustments have been proposed by any tax jurisdiction that would have a significant impact on the Company's liquidity, future results of operations or financial position.
	For the nine months ended September 30, 2013, the parent company, Magnum Hunter Resources, Inc. (“MHR”) provided $17.4 million of deferred U.S. income tax expense in discontinued operations related to income and gains included in discontinued operations related to the Eagle Ford Hunter sale and the MHP losses from discontinued operations.  A deferred Canadian income tax benefit of $17.2 million was also recorded in discontinued operations to recognize the Canadian tax benefits related to WHI Canada’s losses. Because MHR carries a full valuation allowance against its net U.S. deferred tax assets, MHR recognized in continuing operations, a deferred U.S. tax benefit to offset the deferred U.S. tax expense charged to discontinued operations.  Additionally, WHI, which files a separate U.S. tax return, recorded a $23.6 million U.S. deferred tax benefit related to its disposition of its Oasis Assets and expected losses. MHR maintains a full valuation allowance on its nets deferred income tax assets and there was no change in the beginning of year valuation allowance.

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
RELATED PARTY TRANSACTIONS	'
	NOTE 12 - RELATED PARTY TRANSACTIONS
	The following table sets forth the related party transaction activities for the three and nine months ended September 30, 2013 and 2012, respectively:
			Three Months Ended					Nine Months Ended
			September 30,					September 30,
			2013			2012		2013		2012
			(in thousands)
	GreenHunter
		Salt water disposal (1)	$	623		$	618	$	2,069	$	1,600
		Equipment rental (1)	95			244		167		875
		Interest Income from Note Receivable (2)	51			55		159		110
		Dividends earned from Series C shares	73			55		165		136
		Loss on investments (2)	(24		)	97		653		299
	Pilatus Hunter, LLC
		Airplane rental expenses (3)	26			—		94		81
	Alpha Hunter Drilling
		Drilling Revenue (4)				359				359
	Executive of the Company
		Corporate apartment rental (5)	—			5		—		23
	_________________________________
	-1	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman, a major shareholder and former CEO; of which David Krueger, the Company's former Chief Accounting Officer and Senior Vice President, is the former Chief Financial Officer; and of which Ronald D. Ormand, the Company’s former Chief Financial Officer and Executive Vice President, is a former director. Eagle Ford Hunter received, and Triad Hunter and Viking International Resources, Inc. ("Virco"), wholly-owned subsidiaries of the Company, receive services related to brine water and rental equipment from GreenHunter and its affiliated companies, White Top Oilfield Construction, LLC and Black Water Services, LLC. The Company believes that such services were and are provided at competitive market rates and were and are comparable to, or more attractive than, rates that could be obtained from unaffiliated third party suppliers of such services. Prepaid expenses from GreenHunter were $64,748 and $0 at September 30, 2013 and December 31, 2012, respectively. The Company had net accounts payable to GreenHunter of $11,541 and $0 at September 30, 2013 and December 31, 2012, respectively.
	-2	On February 17, 2012, the Company sold its wholly-owned subsidiary, Hunter Disposal, to GreenHunter Water, LLC ("GreenHunter Water"), a wholly-owned subsidiary of GreenHunter.  The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note it received as partial consideration for the sale. The fair market value of the derivative asset was $79,000, and $264,000 at September 30, 2013 and December 31, 2012, respectively.  See "Note 3 - Fair Value of Financial Instruments" for additional information. The Company has recorded interest income as a result of the note receivable from GreenHunter. Also as a result of this transaction, the Company has an equity method investment in GreenHunter that is included in derivatives and other long term assets and an available for sale investment in GreenHunter included in investments.
	-3	The Company rented an airplane for business use for certain members of Company management at various times from Pilatus Hunter, LLC, an entity 100% owned by Mr. Evans. Airplane rental expenses are recorded in general and administrative expense.
	-4	Alpha Hunter Drilling, LLC ("Alpha Hunter Drilling"), a wholly-owned subsidiary of the Company, performed drilling operations for GreenHunter for a fee.
	-5	During the three and nine months ended September 30, 2012, the Company paid rent under a lease for a Houston, Texas corporate apartment from an executive of the Company, which apartment was used by other Company employees when in Houston for Company business.  The lease terminated in May 2012.
	In connection with the sale of Hunter Disposal, Triad Hunter entered into agreements with Hunter Disposal and GreenHunter Water for wastewater hauling and disposal capacity in Kentucky, Ohio, and West Virginia and a five-year tank rental agreement with GreenHunter Water.  See "Note 5 - Divestitures and Discontinued Operations" for additional information.
	Mr. Evans, the Company's Chairman and Chief Executive Officer, was a 4.0% limited partner in TransTex Gas Services, LP ("TransTex Gas"). This limited partnership received total consideration of 622,641 Class A Common Units of Eureka Hunter Holdings and cash of $46.0 million upon the Company's acquisition of certain of its assets. This includes units issued in accordance with the agreement of Eureka Hunter Holdings and TransTex Gas to provide the limited partners of TransTex Gas the opportunity to purchase additional Class A Common Units of Eureka Hunter Holdings in lieu of a portion of the cash distribution they would otherwise receive. Certain limited partners purchased such units, including Mr. Evans, who purchased 27,641 Class A Common Units of Eureka Hunter Holdings for $553,000 which was the same purchase price equivalent offered to all TransTex investors.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENCIES	'
	NOTE 13 - COMMITMENTS AND CONTINGENCIES
	Agreement to Purchase Utica Shale Acreage
	On August 12, 2013, Triad Hunter entered into an asset purchase agreement, with MNW. MNW is an Ohio limited liability company that represents an informal association of various land owners, lessees and sub-lessees of mineral acreage who own or have rights in mineral acreage located in Monroe, Noble and/or Washington Counties, Ohio. Pursuant to the purchase agreement, Triad Hunter has agreed to acquire from MNW up to 32,000 net mineral acres, including currently leased and subleased acreage, located in such counties, over the next 10 months or possibly longer, subject to certain conditions. On October 7, 2013, Triad Hunter purchased 1,156.14 net leasehold acres for $4.9 million from MNW. On October 31, 2013, Triad Hunter purchased an additional 2,050.40 net leasehold acres for $8.7 million from MNW.
	Legal Proceedings
	On April 24, 2013, Horace Carvalho, individually and on behalf of all other persons similarly situated, filed a class action complaint in the U.S. District Court, Southern District of Texas, against the Company and certain of its officers, one of whom also currently serves as a director. Several substantially similar putative class actions have been filed in the Southern District of New York and in the Southern District of Texas. All such cases are collectively referred to as the "Securities Cases". The cases filed in the Southern District of Texas have since been dismissed, but the cases in the Southern District of New York have been consolidated and remain ongoing. The complaints in the Securities Cases allege that the Company made certain false or misleading statements in its filings with the SEC, including statements related to the Company's internal and financial controls, the calculation of non-cash share-based compensation expense, the late filing of the Company's 2012 Form 10-K, the dismissal of Magnum Hunter's previous independent registered accounting firm, and other matters identified in the Company's April 16, 2013 Form 8-K, as amended. The complaints demand that the defendants pay unspecified damages to the class action plaintiffs, including damages allegedly caused by the decline in the Company's stock price between February 22, 2013 and April 22, 2013. The Company and the individual defendants intend to vigorously defend the Securities Cases. It is possible that additional putative class action suits could be filed over these events.
	On June 27, 2013, Timothy Bassett filed a shareholder derivative suit in the Southern District of Texas on behalf of the Company against the Company’s directors and senior officers. On September 16, 2013, Joseph Vitellone was substituted as plaintiff in the Bassett action. Several substantially similar putative derivative suits have been filed in the 151st District Court of Harris County, Texas, in the Southern District of New York and in the District of Delaware. These suits are collectively referred to as the Derivative Cases. The Derivative Cases assert that the individual defendants unjustly enriched themselves and breached their fiduciary duties to the Company by publishing allegedly false and misleading statements to the Company's investors regarding the Company's business and financial position and results, and allegedly failing to maintain adequate internal controls. The complaints demand that the defendants pay unspecified damages to the Company, including damages allegedly sustained by the Company as a result of the alleged breaches of fiduciary duties by the defendants, as well as disgorgement of profits and benefits obtained by the defendants, and reasonable attorneys', accountants' and experts' fees and costs to the plaintiff. The Derivative Cases are in their preliminary stages. It is possible that additional shareholder derivative suits could be filed over these events.
	In addition, the Company received several demand letters from shareholders seeking books and records relating to the allegations in the Securities Cases and the Derivative Cases under Section 220 of the Delaware General Corporation Law.  On September 17, 2013, Anthony Scavo, who is one of the shareholders that made a demand, filed a books and records action in the Delaware Court of Chancery pursuant to Section 220 of the Delaware General Corporation Law (the “Scavo Action”).  The Scavo Action seeks various books and records relating to the claims in the Securities Cases and the Derivative Cases, as well as costs and attorneys’ fees.  The Company has filed an answer in the Scavo Action.  It is possible that additional, similar actions may be filed and that similar shareholder demands could be made.
	The Company believes that these claims are covered by the terms of its directors' and officers' insurance policies, and that the coverage available under these insurance policies will be adequate to cover the costs of these claims, including professional fees and other defense costs. However, the Company cannot provide any assurances regarding the foregoing, and refers you to the risk factors contained in its Annual Report on Form 10-K for the year ended December 31, 2012, as such risk factors have been updated in the Form S-4 Registration Statement, including the risk factor entitled "A pending SEC inquiry and pending third-party litigation may divert the attention of management and other important resources, may expose us to negative publicity and could have a material adverse effect on our business, financial condition, results of operations and cash flows."

SUPPLEMENTAL_CASH_FLOW_INFORMA

SUPPLEMENTAL CASH FLOW INFORMATION (Notes)	9 Months Ended
	Sep. 30, 2013
Supplemental Cash Flow Elements [Abstract]	'
SUPPLEMENTAL CASH FLOW INFORMATION	'
	NOTE 14 - SUPPLEMENTAL CASH FLOW INFORMATION
	The following summarizes cash paid (received) for interest and income taxes, as well as non-cash investing transactions:
		Nine Months Ended September 30,
		2013			2012
		(in thousands)
	Cash paid for interest	$	38,225		$	13,185
	Cash paid for taxes	$	1,200		$	—
	Non-cash transactions
	Common stock issued for acquisitions	$	—		$	1,902
	Common stock issued for 401k matching contributions	$	1,192		$	874
	Non-cash consideration received from sale of assets	$	—		$	7,706
	Change in accrued capital expenditures	$	(5,742	)	$	10,722
	Non-cash additions to asset retirement obligation	$	2,089		$	182
	Eureka Hunter Holdings, LLC Series A convertible preferred unit dividends paid in kind	$	6,367		$	1,658
	Eureka Hunter Holdings, LLC Class A common units issued for an acquisition	$	—		$	12,453

SEGMENT_REPORTING

SEGMENT REPORTING	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
SEGMENT REPORTING	'
	NOTE 15 - SEGMENT REPORTING
	U.S. Upstream, Midstream and Oilfield Services represent the operating segments of the Company.  As of September 30, 2013 the Canadian Upstream segment, comprised of the WHI Canada operations, was classified as assets held for sale and discontinued operations. The factors used to identify these reportable segments are based on the nature of the operations, nationality, operating strategies and management expertise involved in each.  The Upstream segments are organized and operate to explore for and produce crude oil and natural gas within the geographic boundaries of the U.S. and Canada. The Midstream segment markets natural gas and operates a network of pipelines and compression stations that gather natural gas and NGL for transportation to market. The Oilfield Services segment provides drilling services to oil and natural gas exploration and production companies. Midstream and Oilfield Services customers are the Company's subsidiaries and other third-party oil and natural gas companies.
	The following tables set forth operating activities by segment for the three and nine months ended September 30, 2013 and 2012, respectively.
		As of and for the Three Months Ended September 30, 2013
		U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
		Upstream			Upstream						Services			Unallocated			Eliminations
		(in thousands)
	Revenues
	Oil and natural gas sales	$	54,018		$	—		$	—		$	—		$	—		$	—		$	54,018
	Gas transportation, gathering, processing, and marketing	—			—			14,618			—			—			(2,073		)	12,545
	Oilfield services	—			—			—			6,448			—			(25		)	6,423
	Other revenue	46			—			—			—			—			—			46
	Total revenue	54,064			—			14,618			6,448			—			(2,098		)	73,032
	Expenses
	Lease operating expenses	17,217			—			—			—			—			(2,072		)	15,145
	Severance taxes and marketing	5,465			—			—			—			—			—			5,465
	Exploration and abandonments	40,123			—			—			—			—			—			40,123
	Impairment of proved oil and gas properties	—			—			—			—			—			—			—
	Gas transportation, gathering, processing, and marketing	—			—			8,985			—			—			—			8,985
	Oilfield services	—			—			—			4,552			—			(25		)	4,527
	Depletion, depreciation, amortization and accretion	24,400			—			3,173			720			—			—			28,293
	Loss on sale of assets, net	40,952			—			—			—			—			—			40,952
	General and administrative	6,055			—			2,156			379			11,455			2,173			22,218
	Total expenses	134,212			—			14,314			5,651			11,455			76			165,708
	Interest income	35			—			—			—			1,183			(1,184		)	34
	Interest expense	(1,734		)	—			(1,177		)	(141		)	(16,109		)	3,472			(15,689		)
	Gain (loss) on derivative contracts,(net)	26			—			(15,368		)	—			(14,211		)	—			(29,553		)
	Other income (expense)	245			—			(27		)	—			8,322			—			8,540
	Total other income (expense)	(1,428		)	—			(16,572		)	(141		)	(20,815		)	2,288			(36,668		)
	Income (loss) from continuing operations before income tax	(81,576		)	—			(16,268		)	656			(32,270		)	114			(129,344		)
	Income tax benefit (expense)	9,417			926			—			—			(13,598		)	—			(3,255		)
	Net income (loss) from continuing operations	(72,159		)	926			(16,268		)	656			(45,868		)	114			(132,599		)
	Loss from discontinued operations, net of tax	(6,245		)	(77,220		)	—			—			3,025			(114		)	(80,554		)
	Loss on sale of discontinued operations, net of tax	(28,813		)	(55,641		)	—			—			—			—			(84,454		)
	Net income (loss)	$	(107,217	)	$	(131,935	)	$	(16,268	)	$	656		$	(42,843	)	$	—		$	(297,607	)
	Total segment assets	$	1,406,515		$	106,438		$	269,692		$	42,648		$	62,182		$	(1,659	)	$	1,885,816
		As of and for the Three Months Ended September 30, 2012
		U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
		Upstream			Upstream						Services			Unallocated			Eliminations
		(in thousands)
	Revenues
	Oil and natural gas sales	$	29,983		$	—		$	—		$	—		$	—		$	—		$	29,983
	Gas transportation, gathering, processing, and marketing	—			—			5,058			—			—			—			5,058
	Oilfield services	—			—			—			3,533			—			(2,029		)	1,504
	Other revenue	(172		)	—			8			—			—			—			(164		)
	Total revenue	29,811			—			5,066			3,533			—			(2,029		)	36,381
	Expenses
	Lease operating expenses	7,309			—			—			—			—			(1,209		)	6,100
	Severance taxes and marketing	2,530			—			—			—			—			—			2,530
	Exploration and abandonments	3,299			—			—			—			—			—			3,299
	Gas transportation, gathering and processing	—			—			2,288			—			—			—			2,288
	Oilfield services	—			—			—			3,716			—			(350		)	3,366
	Depletion, depreciation, amortization and accretion	13,715			—			1,195			236			—			—			15,146
	(Gain) loss on sale of assets, net	$	(13	)	$	—		$	—		$	341		$	—		$	—		328
	General and administrative	3,061			—			958			145			8,058			—			12,222
	Total expenses	29,901			—			4,441			4,438			8,058			(1,559		)	45,279
	Interest income	140			—			—			—			2,137			(2,145		)	132
	Interest expense	(1,931		)	—			(1,671		)	(63		)	(12,885		)	2,145			(14,405		)
	Gain (loss) on derivative contracts, (net)	80			—			5,340			—			(15,571		)	—			(10,151		)
	Other income (expense)	37			—			(10		)	—			—			—			27
	Total other income (expense)	(1,674		)	—			3,659			(63		)	(26,319		)	—			(24,397		)
	Income (loss) from continuing operations before income tax	(1,764		)	—			4,284			(968		)	(34,377		)	(470		)	(33,295		)
	Income tax benefit (expense)	2,988			(1,005		)	—			—			—			—			1,983
Net income (loss) from continuing operations	1,224			(1,005		)	4,284			(968		)	(34,377		)	(470		)	(31,312		)
Income (loss) from discontinued operations, net of tax	2,758			(3,860		)	—			—			—			—			(1,102		)
Loss on sale of discontinued operations, net of tax	—			—			—			—			—			—			—
Net income (loss)	$	3,982		$	(4,865	)	$	4,284		$	(968	)	$	(34,377	)	$	(470	)	$	(32,414	)
Total segment assets	$	1,411,720		$	275,066		$	182,144		$	15,120		$	51,677		$	(1,759	)	$	1,933,968
	As of and for the Nine Months Ended September 30, 2013
	U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
	Upstream			Upstream						Services			Unallocated			Eliminations
	(in thousands)
Oil and natural gas sales	$	138,242		$	—		$	—		$	—		$	—		$	—		$	138,242
Gas transportation, gathering, processing, and marketing	—			—			48,071			—			—			(5,656		)	42,415
Oilfield services	—			—			—			13,872			—			(144		)	13,728
Other revenue	788			—			—			1			—			—			789
Total revenue	139,030			—			48,071			13,873			—			(5,800		)	195,174
Lease operating expenses	43,720			—			—			—			—			(5,693		)	38,027
Severance taxes and marketing	12,313			—			—			—			—			—			12,313
Exploration and abandonments	73,402			—			—			—			—			—			73,402
Impairment of proved oil and natural gas properties	9,968			—			—			—			—			—			9,968
Gas transportation, gathering, processing, and marketing	—			—			35,830			—			—			—			35,830
Oilfield services	—			—			—			12,034			—			(106		)	11,928
Depletion, depreciation, amortization and accretion	61,235			—			9,142			1,579			—			—			71,956
Loss on sale of assets, net	42,112			—			—			4			—			—			42,116
General and administrative	11,158			—			5,446			850			38,932			2,173			58,559
Total expenses	253,908			—			50,418			14,467			38,932			(3,626		)	354,099
Interest income	171			—			—			—			3,987			(3,986		)	172
Interest expense	(5,802		)	—			(3,215		)	(372		)	(50,088		)	6,274			(53,203		)
Gain (loss) on derivative contracts, (net)	(185		)	—			(20,808		)	—			(9,651		)	—			(30,644		)
Other income (expense)	(324		)	—			(238		)	—			8,422			—			7,860
Total other income (expense)	(6,140		)	—			(24,261		)	(372		)	(47,330		)	2,288			(75,815		)
Loss from continuing operations before income tax	(121,018		)	—			(26,608		)	(966		)	(86,262		)	114			(234,740		)
Income tax benefit (expense)	12,597			—			—			—			28,347			—			40,944
Net loss from continuing operations	(108,421		)	—			(26,608		)	(966		)	(57,915		)	114			(193,796		)
Income (loss) from discontinued operations, net of tax	12,516			(78,429		)	—			—			(5,428		)	(114		)	(71,455		)
Gain (loss) on sale of discontinued operations, net of tax	143,639			(55,641		)	—			—			—			—			87,998
Net income (loss)	$	47,734		$	(134,070	)	$	(26,608	)	$	(966	)	$	(63,343	)	$	—		$	(177,253	)
																			—
Total segment assets	$	1,406,515		$	106,438		$	269,692		$	42,648		$	62,182		$	(1,659	)	$	1,885,816
	As of and for the Nine Months Ended September 30, 2012
	U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
	Upstream			Upstream						Services			Unallocated			Eliminations
	(in thousands)
Oil and natural gas sales	$	78,532		$	—		$	—		$	—		$	—		$	—		$	78,532
Gas transportation, gathering, processing, and marketing	—			—			10,418			—			—			—			10,418
Oilfield services	—			—			—			9,793			—			(3,675		)	6,118
Other revenue	(169		)	—			25			—			—			—			(144		)
Total revenue	78,363			—			10,443			9,793			—			(3,675		)	94,924
Lease operating expenses	21,145			—			—			—			—			(2,854		)	18,291
Severance taxes and marketing	6,618			—			—			—			—			—			6,618
Exploration and abandonments	18,143			—			—			—			—			—			18,143
Gas transportation, gathering, processing, and marketing	—			—			4,379			—			—			—			4,379
Oilfield services	—			—			—			7,283			—			(350		)	6,933
Depletion, depreciation, amortization and accretion	38,662			—			2,853			684			—			—			42,199
(Gain) loss on sale of assets, net	(88		)							616									528
General and administrative	5,954			—			2,065			251			29,956			—			38,226
Total expenses	90,434			—			9,297			8,834			29,956			(3,204		)	135,317
Interest income	169			—			—			—			2,192			(2,145		)	216
Interest expense	(3,461		)	—			(4,678		)	(221		)	(34,380		)	2,145			(40,595		)
Gain (loss) on derivative contracts, (net)	185			—			3,990			—			4,881			—			9,056
Other income (expense)	102			—			(12		)	—			—			—			90
Total other income (expense)	(3,005		)	—			(700		)	(221		)	(27,307		)	—			(31,233		)
Income (loss) from continuing operations before income tax	(15,076		)	—			446			738			(57,263		)	(471		)	(71,626		)
Income tax benefit	10,155			(1,012		)	—			—			—			—			9,143
Net income (loss) from continuing operations	(4,921		)	(1,012		)	446			738			(57,263		)	(471		)	(62,483		)
Income (loss) from discontinued operations	6,997			(4,519		)	—			354			—			—			2,832
Gain on sale of discontinued operations	—			—			—			2,224			—			—			2,224
Net income (loss)	$	2,076		$	(5,531	)	$	446		$	3,316		$	(57,263	)	$	(471	)	$	(57,427	)
Total segment assets	$	1,411,720		$	275,066		$	182,144		$	15,120		$	51,677		$	(1,759	)	$	1,933,968

CONDENSED_CONSOLIDATING_GUARAN

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	9 Months Ended
	Sep. 30, 2013
Guarantees [Abstract]	'
CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	'
	NOTE 16 - CONDENSED CONSOLIDATED GUARANTOR FINANCIAL STATEMENTS
	Senior Notes
	Certain of the Company’s subsidiaries, including Alpha Hunter Drilling, Bakken Hunter, LLC, Eagle Ford Hunter (through April 24, 2013), Hunter Aviation, LLC, Hunter Real Estate, LLC, Magnum Hunter Marketing, LLC, Magnum Hunter Production, Inc., Magnum Hunter Resources, GP, LLC, Magnum Hunter Resources, LP, NGAS Gathering, LLC, NGAS Hunter, LLC, PRC Williston, Triad Hunter, Williston Hunter, Inc., Williston Hunter ND, LLC, and Virco (collectively, "Guarantor Subsidiaries"), have guaranteed, on a joint and several, and senior unsecured, basis, the obligations of the Company under all the Senior Notes issued under the indenture entered into by the Company on May 16, 2012, as supplemented.
	Condensed consolidating financial information for Magnum Hunter Resources Corporation, the Guarantor Subsidiaries and the other subsidiaries of the Company (the “Non Guarantor Subsidiaries”) as of September 30, 2013 and December 31, 2012, and for the three and nine months ended September 30, 2013 and 2012, are as follows:
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
		As of September 30, 2013
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	ASSETS
	Current assets	$	35,827			$	1,555			$	81,644		$	41,787			$	(1,659	)	$	159,154
	Intercompany accounts receivable	838,399				—				—			—				(838,399		)	—
	Property and equipment (using successful efforts method of accounting)	7,516				16,921				1,242,456			205,058				—			1,471,951
	Investment in subsidiaries	460,903				—				102,259			64,423				(627,585		)	—
	Assets held for sale and other	18,838				—				110,535			125,338				—			254,711
	Total Assets	$	1,361,483			$	18,476			$	1,536,894		$	436,606			$	(1,467,643	)	$	1,885,816
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	69,615			$	2,924			$	158,674		$	23,393			$	(1,694	)	$	252,912
	Intercompany accounts payable	—				61,314				707,801			69,252				(838,367		)	—
	Long-term liabilities	691,298				1,351				75,332			126,958				—			894,939
	Redeemable preferred stock	100,000				—				—			128,871				—			228,871
	Shareholders' equity (deficit)	500,570				(47,113		)		595,087			88,132				(627,582		)	509,094
	Total Liabilities and Shareholders' Equity	$	1,361,483			$	18,476			$	1,536,894		$	436,606			$	(1,467,643	)	$	1,885,816
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
		As of December 31, 2012
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	ASSETS
	Current assets	$	63,167			$	703			$	60,552		$	111,126			$	(31,229	)	$	204,319
	Intercompany accounts receivable	803,834				—				—			—				(803,834		)	—
	Property and equipment (using successful efforts method of accounting)	9,596				18,257				1,276,467			620,093				—			1,924,413
	Investment in subsidiaries	763,856				—				101,341			102,354				(967,551		)	—
	Other assets	20,849				—				5,451			43,600				—			69,900
	Total Assets	$	1,661,302			$	18,960			$	1,443,811		$	877,173			$	(1,802,614	)	$	2,198,632
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	28,503			$	2,291			$	117,511		$	125,727			$	(30,376	)	$	243,656
	Intercompany accounts payable	—				58,966				508,254			236,636				(803,856		)	—
	Long-term liabilities	831,286				1,274				97,271			112,615				—			1,042,446
	Redeemable preferred stock	100,000				—				—			100,878				—			200,878
	Shareholders' equity (deficit)	701,513				(43,571		)		720,775			301,317				(968,382		)	711,652
	Total Liabilities and Shareholders' Equity	$	1,661,302			$	18,960			$	1,443,811		$	877,173			$	(1,802,614	)	$	2,198,632
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
		Three Months Ended September 30, 2013
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	Revenues	$	29			$	2,020			$	66,203		$	6,877			$	(2,097	)	$	73,032
	Expenses	35,351				2,876				142,373			23,988				(2,212		)	202,376
	Loss from continuing operations before equity in net income of subsidiaries	(35,322		)		(856		)		(76,170		)	(17,111		)		115			(129,344		)
	Equity in net income of subsidiaries	(236,767		)		—				163			(28,543		)		265,147			—
	Loss from continuing operations before income tax	(272,089		)		(856		)		(76,007		)	(45,654		)		265,262			(129,344		)
	Income tax benefit (expense)	(13,598		)		—				9,400			943				—			(3,255		)
	Loss from continuing operations	(285,687		)		(856		)		(66,607		)	(44,711		)		265,262			(132,599		)
Income from discontinued operations, net of tax	3,027				—				16,396			(99,862		)		(115		)	(80,554		)
Gain on sale of discontinued operations, net of tax	(19,704		)		—				(9,109		)	(55,641		)		—			(84,454		)
Net income (loss)	(302,364		)		(856		)		(59,320		)	(200,214		)		265,147			(297,607		)
Net loss attributable to non-controlling interest	—				—				—			—				725			725
Net loss attributable to Magnum Hunter Resources Corporation	(302,364		)		(856		)		(59,320		)	(200,214		)		265,872			(296,882		)
Dividends on preferred stock	(8,820		)		—				—			(5,597		)		—			(14,417		)
Net income (loss) attributable to common shareholders	$	(311,184	)		$	(856	)		$	(59,320	)	$	(205,811	)		$	265,872		$	(311,299	)
	Three Months Ended September 30, 2012
	Magnum Hunter				PRC Williston, Inc.				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources								Subsidiaries			Subsidiaries							Resources
	Corporation																		Corporation
																			Consolidated
Revenues	$	169			$	1,876			$	31,833		$	4,533			$	(2,030	)	$	36,381
Expenses	33,996				2,348				34,347			544				(1,559		)	69,676
Income (loss) from continuing operations before equity in net income of subsidiaries	(33,827		)		(472		)		(2,514		)	3,989				(471		)	(33,295		)
Equity in net income of subsidiaries	(1,819		)		—				—			(2,691		)		4,510			—
Income (loss) from continuing operations before income tax	(35,646		)		(472		)		(2,514		)	1,298				4,039			(33,295		)
Income tax benefit	—				—				301			1,682				—			1,983
Income (loss) from continuing operations	(35,646		)		(472		)		(2,213		)	2,980				4,039			(31,312		)
Income (loss) from discontinued operations, net of tax	—				—				(2,203		)	1,101				—			(1,102		)
Gain on sale of discontinued operations, net of tax	—				—				—			—				—			—
Net income (loss)	(35,646		)		(472		)		(4,416		)	4,081				4,039			(32,414		)
Net income attributable to non-controlling interest	—				—				—			—				(49		)	(49		)
Net income (loss) attributable to Magnum Hunter Resources Corporation	(35,646		)		(472		)		(4,416		)	4,081				3,990			(32,463		)
Dividends on preferred stock	(5,795		)		—				—			(4,025		)		—			(9,820		)
Net income (loss) attributable to common shareholders	$	(41,441	)		$	(472	)		$	(4,416	)	$	56			$	3,990		$	(42,283	)
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Operations
(in thousands)
	Nine Months Ended September 30, 2013
	Magnum Hunter				PRC Williston, Inc.				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources								Subsidiaries			Subsidiaries							Resources
	Corporation																		Corporation
																			Consolidated
Revenues	$	(134	)		$	5,315			$	175,630		$	20,162			$	(5,799	)	$	195,174
Expenses	91,559				8,857				288,658			46,754				(5,914		)	429,914
Loss from continuing operations before equity in net income of subsidiaries	(91,693		)		(3,542		)		(113,028		)	(26,592		)		115			(234,740		)
Equity in net income of subsidiaries	(274,930		)		—				(479		)	(37,930		)		313,339			—
Loss from continuing operations before income tax	(366,623		)		(3,542		)		(113,507		)	(64,522		)		313,454			(234,740		)
Income tax benefit	28,347				—				12,600			(3		)		—			40,944
Loss from continuing operations	(338,276		)		(3,542		)		(100,907		)	(64,525		)		313,454			(193,796		)
Income from discontinued operations, net of tax	(5,426		)		—				12,530			(78,444		)		(115		)	(71,455		)
Gain on sale of discontinued operations, net of tax	152,748				—				(9,109		)	(55,641		)		—			87,998
Net income (loss)	(190,954		)		(3,542		)		(97,486		)	(198,610		)		313,339			(177,253		)
Net loss attributable to non-controlling interest	—								—			—				1,614			1,614
Net loss attributable to Magnum Hunter Resources Corporation	(190,954		)		(3,542		)		(97,486		)	(198,610		)		314,953			(175,639		)
Dividends on preferred stock	(26,603		)		—				—			(15,431		)		—			(42,034		)
Net income (loss) attributable to common shareholders	$	(217,557	)		$	(3,542	)		$	(97,486	)	$	(214,041	)		$	314,953		$	(217,673	)
	Nine Months Ended September 30, 2012
	Magnum Hunter				PRC Williston, Inc.				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources								Subsidiaries			Subsidiaries							Resources
	Corporation																		Corporation
																			Consolidated
Revenues	$	630			$	6,065			$	81,721		$	10,183			$	(3,675	)	$	94,924
Expenses	56,379				7,923				95,211			10,241				(3,204		)	166,550
Income (loss) from continuing operations before equity in net income of subsidiaries	(55,749		)		(1,858		)		(13,490		)	(58		)		(471		)	(71,626		)
Equity in net income of subsidiaries	(6,847		)		—							(8,573		)		15,420			—
Income (loss) from continuing operations before income tax	(62,596		)		(1,858		)		(13,490		)	(8,631		)		14,949			(71,626		)
Income tax benefit	—				—				3,620			5,523				—			9,143
Income (loss) from continuing operations	(62,596		)		(1,858		)		(9,870		)	(3,108		)		14,949			(62,483		)
Income from discontinued operations, net of tax	—				—				(5,111		)	7,943				—			2,832
Gain on sale of discontinued operations, net of tax	—				—				2,224			—				—			2,224
Net income (loss)	(62,596		)		(1,858		)		(12,757		)	4,835				14,949			(57,427		)
Net income attributable to non-controlling interest	—				—				—			—				(71		)	(71		)
Net income (loss) attributable to Magnum Hunter Resources Corporation	(62,596		)		(1,858		)		(12,757		)	4,835				14,878			(57,498		)
Dividends on preferred stock	(15,179		)		—				—			(7,501		)		—			(22,680		)
Net income (loss) attributable to common shareholders	$	(77,775	)		$	(1,858	)		$	(12,757	)	$	(2,666	)		$	14,878		$	(80,178	)
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Comprehensive Income (Loss)
(in thousands)
	Three Months Ended September 30, 2013
	Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources								Subsidiaries			Subsidiaries							Resources
	Corporation																		Corporation
																			Consolidated
Net income (loss)	$	(302,364	)		$	(856	)		$	(59,320	)	$	(200,214	)		$	265,147		(297,607	)
Foreign currency translation loss	—				—				—			3,856				—			3,856
Unrealized gain (loss) on available for sale securities	3,562				—				173			—				—			3,735
Amounts reclassified from accumulated other comprehensive income	(8,262		)		—				—			—				—			(8,262	)
Comprehensive income (loss)	(307,064		)		(856		)		(59,147		)	(196,358		)		265,147			(298,278	)
Comprehensive loss attributable to non-controlling interest	—				—				—			—				725			725
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(307,064	)		$	(856	)		$	(59,147	)	$	(196,358	)		$	265,872		(297,553	)
	Three Months Ended September 30, 2012
	Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources								Subsidiaries			Subsidiaries							Resources
	Corporation																		Corporation
																			Consolidated
Net income (loss)	$	(35,646	)		$	(472	)		$	(4,416	)	$	4,081			$	4,039		(32,414	)
Foreign currency translation loss	—				—				—			7,245				—			7,245
Unrealized gain (loss) on available for sale securities	—				—				(35		)	—				—			(35	)
Comprehensive income (loss)	(35,646		)		(472		)		(4,451		)	11,326				4,039			(25,204	)
Comprehensive income attributable to non-controlling interest	—				—				—			—				(49		)	(49	)
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(35,646	)		(472		)		(4,451		)	11,326				3,990			(25,253	)
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Comprehensive Income (Loss)
(in thousands)
	Nine Months Ended September 30, 2013
	Magnum Hunter			PRC Williston, LLC			100% Owned Guarantor			Non Guarantor		Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources						Subsidiaries			Subsidiaries					Resources
	Corporation														Corporation
															Consolidated
Net income (loss)	(190,954	)		(3,542	)		(97,486	)		(198,610	)	313,339			(177,253	)
Foreign currency translation loss	—			—			—			(7,943	)	—			(7,943	)
Unrealized gain (loss) on available for sale securities	8,262			—			(78	)		—		—			8,184
Amounts reclassified from accumulated other comprehensive income	(8,262	)		—			—			—		—			(8,262	)
Comprehensive income (loss)	(190,954	)		(3,542	)		(97,564	)		(206,553	)	313,339			(185,274	)
Comprehensive loss attributable to non-controlling interest	—			—			—			—		1,614			1,614
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	(190,954	)		(3,542	)		(97,564	)		(206,553	)	314,953			(183,660	)
	Nine Months Ended September 30, 2012
	Magnum Hunter			PRC Williston, LLC			100% Owned Guarantor			Non Guarantor		Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources						Subsidiaries			Subsidiaries					Resources
	Corporation														Corporation
															Consolidated
Net income (loss)	(62,596	)		(1,858	)		(12,757	)		4,835		14,949			(57,427	)
Foreign currency translation loss	—			—			—			6,628		—			6,628
Unrealized gain (loss) on available for sale securities	—			—			(301	)		—		—			(301	)
Comprehensive income (loss)	(62,596	)		(1,858	)		(13,058	)		11,463		14,949			(51,100	)
Comprehensive income attributable to non-controlling interest	—			—			—			—		(71	)		(71	)
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	(62,596	)		(1,858	)		(13,058	)		11,463		14,878			(51,171	)
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Cash Flows
(in thousands)
	Nine Months Ended September 30, 2013
	Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources								Subsidiaries			Subsidiaries							Resources
	Corporation																		Corporation
																			Consolidated
Cash flow from operating activities	$	(264,051	)		$	882			$	236,112		$	106,254			$	—		$	79,197
Cash flow from investing activities	422,056				(882		)		(245,179		)	(131,172		)		—			44,823
Cash flow from financing activities	(152,265		)		—				2,105			23,893				—			(126,267		)
Effect of exchange rate changes on cash	—				—				—			(93		)		—			(93		)
Net increase (decrease) in cash	5,740				—				(6,962		)	(1,118		)		—			(2,340		)
Cash at beginning of period	26,872				—				(4,187		)	34,938				—			57,623
Cash at end of period	$	32,612			$	—			$	(11,149	)	$	33,820			$	—		$	55,283
	Nine Months Ended September 30, 2012
	Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources								Subsidiaries			Subsidiaries							Resources
	Corporation																		Corporation
																			Consolidated
Cash flow from operating activities	$	(304,365	)		$	48			$	209,620		$	141,516			$	—		$	46,819
Cash flow from investing activities	(308,625		)		(48		)		(207,814		)	(277,200		)		—			(793,687		)
Cash flow from financing activities	612,579				—				(2,346		)	143,928				—			754,161
Effect of exchange rate changes on cash												(146		)		—			(146		)
Net increase (decrease) in cash	(411		)		—				(540		)	8,098				—			7,147
Cash at beginning of period	18,758				—				(546		)	(3,361		)		—			14,851
Cash at end of period	$	18,347			$	—			$	(1,086	)	$	4,737			$	—		$	21,998

SUBSEQUENT_EVENTS

SUBSEQUENT EVENTS	9 Months Ended
	Sep. 30, 2013
Subsequent Events [Abstract]	'
SUBSEQUENT EVENTS	'
	NOTE 17 - SUBSEQUENT EVENTS
	Purchase of Utica Shale Acreage
	On October 4, 2013, Triad Hunter purchased certain undeveloped leasehold acreage in the Utica Shale in Ohio for $4.9 million under its previously reported asset purchase agreement dated August 12, 2013 with MNW Energy, LLC ("MNW"). On October 31, 2013, Triad Hunter purchased certain additional undeveloped leasehold acreage in the Utica Shale in Ohio for $8.7 million from MNW under that same agreement.
	Issuance of Warrants
	On October 15, 2013, the Company entered into a Warrants Agreement (the “Warrants Agreement”) with American Stock Transfer & Trust Company, LLC (“AST”) which governs the terms of warrants (the “Warrants”) to purchase the Company’s common stock that were issued as a dividend on October 15, 2013 to common stockholders of record on September 16, 2013. Each record holder of common stock received one Warrant for every ten shares of common stock owned as of the record date (with the number of Warrants received rounded down to the nearest whole number and without the payment of cash in lieu of Warrants to purchase fractional shares). Each Warrant represents the right to purchase one fully paid and non-assessable share of common stock at an initial exercise price of $8.50 per share, subject to certain adjustments to the exercise price and the number of shares of common stock issuable upon exercise of the Warrants as set forth in the Warrants Agreement.
	Issuance of Series A Preferred Units of Eureka Hunter Holdings
	On October 30, 2013, Eureka Hunter Holdings issued 93,821 Series A Preferred Units with a redemption value of $1.9 million as dividends paid-in-kind for the quarter ended September 30, 2013. The balance of the dividend paid for the quarter ended September 30, 2013 of $1.9 million was paid in cash. As of the date of filing of this Quarterly Report on Form 10-Q, the Series A Preferred Units outstanding represented 41% of the ownership of Eureka Hunter Holdings on a basis as converted to Class A Common Units of Eureka Hunter Holdings.
	Declared Dividends
	On October 1, 2013, the Company announced that it had declared cash dividends on the Company's Series C Preferred Stock, Series D Preferred Stock, and Series E Preferred Stock, for the month of October 2013, payable on October 31, 2013, to holders of record at the close of business on October 15, 2013. On November 1, 2013, the Company announced that it had declared cash dividends on the Company's Series C Preferred Stock, Series D Preferred Stock, and Series E Preferred Stock, for the month of November 2013, payable on December 2, 2013, to holders of record at the close of business on November 15, 2013.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Principles of Consolidation and Presentation	'
	Presentation of Consolidated Financial Statements
	The accompanying unaudited interim consolidated financial statements of Magnum Hunter have been prepared in accordance with accounting principles generally accepted in the U.S. and the rules of the Securities and Exchange Commission ("SEC"), for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X and should be read in conjunction with the audited financial statements and notes thereto contained in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012, as revised for certain discontinued operations as reflected in the Company's Registration Statement on Form S-4 declared effective by the SEC on October 8, 2013 (the "Form S-4 Registration Statement").  In the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary for a fair statement of the financial position and the results of operations for the interim periods presented have been reflected herein.  The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year.  The year-end balance sheet data were derived from audited financial statements, but do not include all disclosures required by accounting principles generally accepted in the U.S.
	Notes to the consolidated financial statements that would substantially duplicate the disclosures contained in the audited consolidated financial statements as reported in the Company's Form S-4 Registration Statement have been omitted.
Reclassification of Prior-Year Balances	'
	Reclassification of Prior-Year Balances
	Certain prior period balances have been reclassified to correspond with current-year presentation.  As a result of the sale of the Company's wholly-owned subsidiary, Eagle Ford Hunter, Inc. ("Eagle Ford Hunter"), to an affiliate of Penn Virginia Corporation (“Penn Virginia”) on April 24, 2013, and the Company's adoption of a plan in September 2013 to dispose of certain of its U.S. and Canadian properties, all prior operating income and expense for these operations were reclassified as discontinued operations for all periods presented.
Non-controlling Interest in Consolidated Subsidiaries	'
	Non-Controlling Interest in Consolidated Subsidiaries
	The Company has consolidated PRC Williston, LLC ("PRC Williston") in which it owned 87.5% and Eureka Hunter Holdings, LLC (“Eureka Hunter Holdings”) in which it owned 57.38% as of September 30, 2013 and 61.0% as of December 31, 2012. Eureka Hunter Holdings owns, directly or indirectly, 100% of the equity interests of Eureka Hunter Pipeline, LLC ("Eureka Hunter Pipeline"), TransTex Hunter, LLC ("TransTex Hunter"), and Eureka Hunter Land, LLC.
Loss per Common Share	'
	Net Income or Loss per Share Data
	Basic income or loss per common share is computed by dividing the income or loss attributable to common shareholders by the weighted average number of shares of common stock outstanding during the period. Diluted income or loss per common share considers the impact to net income and common shares for the potential dilution from stock options, common stock purchase warrants and any outstanding convertible securities.
	The Company has issued potentially dilutive instruments in the form of common stock options, common stock purchase warrants, Series E Preferred Stock, and restricted common stock granted and not yet issued. The potentially dilutive securities were excluded from the calculation of diluted loss per share during all of the periods presented, because their effect would have been anti-dilutive due to the Company's losses during those periods.
Cash and cash equivalents	'
	Cash and Cash Equivalents
	Cash and cash equivalents include cash in banks and highly liquid debt securities that have original maturities of three months or less.
Financial Instruments	'
	Financial Instruments
	The carrying amounts of financial instruments including cash and cash equivalents, accounts receivable, notes receivable, accounts payable and accrued liabilities, derivatives, and certain long-term debt approximate fair value as of September 30, 2013 and December 31, 2012.
Inventory	'
	Inventory
	The Company’s materials inventory is primarily frac sand used in the completion process of hydraulic fracturing. Frac sand is acquired for use in future well completion operations and is carried at the lower of cost or market, on a first-in, first-out cost basis. Commodities inventory consists of crude oil held in storage and is carried at the lower of average cost or market, on a first-in, first-out basis.
Oil and Gas Properties	'
	Oil and Natural Gas Properties
	The Company utilizes the successful efforts method of accounting for its oil and natural gas producing activities. Costs to acquire mineral interests in oil and natural gas properties and to drill and equip new development wells and related asset retirement costs are capitalized. Costs to acquire mineral interests and drill exploratory wells are also capitalized pending determination of whether the wells have proved reserves or not. However, if the Company determines that the exploratory wells do not have proved reserves or leases acquired are not prospective or expire, the costs are expensed to exploration expense. Geological and geophysical costs, including seismic studies and related costs of carrying and retaining unproved properties, are charged to exploration expense as incurred.
	On the sale or retirement of a field, the cost and related accumulated depletion and depreciation is eliminated from the property accounts, and the resultant gain or loss is recognized. On the sale or retirement of an insignificant portion of a field, the cost is charged to accumulated depletion with no resulting gain or loss recognized in income.
Goodwill	'
	Goodwill
	Goodwill represents the excess of the purchase price of an entity over the estimated fair value of the assets acquired and the liabilities assumed. The Company has goodwill related to the midstream segment as a result of the acquisition of the assets of TransTex Gas Services, LP as of April 1, 2012.
	Goodwill is assessed for impairment whenever events or circumstances indicate that impairment of the carrying value of goodwill is likely, but no less than annually. If the carrying value of goodwill is determined to be impaired, it is reduced for the impaired value with a corresponding charge to pretax earnings in the period in which it is determined to be impaired.
Intangible Assets	'
	Intangible Assets
	Intangible assets consist primarily of the fair value of the acquired gas gathering and processing contracts and customer relationships in the TransTex Gas Services, LP assets acquisition completed in April 2012.  These assets are being amortized over a weighted average term of 8.5 years.
Other Comprehensive Income (Loss)	'
	Other Comprehensive Income (Loss)
	The functional currency of the Company's operations in Canada (which operations are reflected in these financial statements as discontinued operations) is the Canadian dollar.  The Company translates the assets and liabilities of its Canadian subsidiary into U.S. dollars at current exchange rates while revenues and expenses are translated at the average rates in effect for the period.  The related translation gains and losses are included in accumulated other comprehensive income, net of tax.
Exploration and Abandonments	'
	Exploration
	Exploration expense consists primarily of abandonment charges and impairment reserves for capitalized leasehold costs associated with unproved properties that the Company has no further exploration or development plans, exploratory dry holes, and geological and geophysical costs.
Impairment of Proved Oil & Gas Properties	'
	Impairment of Proved Oil and Natural Gas Properties (Continuing operations)
	Proved oil and natural gas properties are reviewed for impairment on a field-by-field basis when events and circumstances indicate a possible decline in the recoverability of the carrying amount of such property. The Company estimates the expected future cash flows of its oil and natural gas properties and compares these undiscounted cash flows to the carrying amount of the oil and natural gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, the Company will write down the carrying amount of the oil and natural gas properties to fair value. The factors used to determine fair value include, but are not limited to, estimates of reserves, future commodity prices, future lease operating expense, future production estimates, estimated future capital expenditures and discount rates commensurate with the risk associated with realizing the projected cash flows.
Recently Issued Accounting Standards	'
	Recently Issued Accounting Standards
	Accounting standards-setting organizations frequently issue new or revised accounting rules.  The Company regularly reviews all new pronouncements to determine their impact, if any, on its financial statements.
	In February 2013, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2013-2, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This amendment to the accounting guidance for the reporting of amounts reclassified out of accumulated other comprehensive income (“AOCI”) expands the existing disclosure by requiring entities to present information about significant items reclassified out of AOCI by component. In addition, an entity is required to provide information about the effects on net income of significant amounts reclassified out of each component of AOCI to net income either on the face of the statement where net income is presented or as a separate disclosure in the notes of the financial statements. The amendment is effective prospectively for annual or interim reporting periods beginning after December 15, 2012. The adoption of this accounting pronouncement did not have a material impact on our financial statement disclosures.

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Schedule of dilutive securities outstanding	'
	The following table summarizes the potentially dilutive securities outstanding as of September 30, 2013 and 2012:
		September 30,
		2013			2012
		(in thousands of shares)
	Dilutive:
	Common stock options	13,878			2,424
	Warrants	—			69
	Total dilutive	13,878			2,493
	Anti-dilutive:
	Common stock options	4,480			13,330
	Warrants	30,407			13,376
	Series E Preferred Stock	11,185			—
	Total anti-dilutive	46,072			26,707
Schedule of Inventory, Current and Noncurrent	'
	The following table sets forth the Company's inventory as of September 30, 2013 and December 31, 2012:
			September 30, 2013				December 31, 2012
			(in thousands)
	Materials and supplies		$	11,029			$	8,066
	Commodities		928				1,096
	Inventory		$	11,957			$	9,162
	Materials included in other long term assets		$	—			$	3,464
Schedule of Oil Natural Gas And NGL Revenue	'
	During the three and nine months ended September 30, 2013 and 2012, the Company recognized sales from oil, natural gas, and NGL as follows:
			Three Months Ended							Nine Months Ended
			September 30,							September 30,
			2013				2012			2013			2012
			(in thousands)
	Oil		$	39,119			$	21,319		$	97,813		$	51,416
	Natural gas		9,805				8,389			31,068			26,743
	NGL		5,094				275			9,361			373
	Total oil and natural gas sales		$	54,018			$	29,983		$	138,242		$	78,532
Schedule of the Company's geological and geophysical costs and leasehold abandonments expense	'
	During the three and nine months ended September 30, 2013 and 2012, the Company recognized exploration expense as follows:
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013		2012
		(in thousands)
	Leasehold impairments - Williston Basin	38,829			2,954			71,454		12,687
	Leasehold impairments - Appalachia Basin	940			—			940		4,975
	Geological and geophysical	354			345			1,008		481
	Total	40,123			3,299			73,402		18,143
Schedule of Proved Property Impairments	'
	During the three and nine months ended September 30, 2013 and 2012, the Company recorded proved property impairments as follows:
		Three Months Ended							Nine Months Ended
		September 30,							September 30,
		2013				2012			2013			2012
		(in thousands)
	Impairment of Proved Oil & Natural Gas Properties	$	—			$	—		$	9,968		$	—

FAIR_VALUE_OF_FINANCIAL_INSTRU1

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Schedule of inputs used to calculated fair value of convertible security embedded derivative	'
	The key inputs used in the Black-Scholes option pricing model were as follows:
		30-Sep-13
	Life	3.4 years
	Risk-free interest rate	0.91		%
	Estimated volatility	40		%
	Dividend	—
	GreenHunter stock price at end of period	$	1.13
Schedule of reconciliation of derivative assets and (liabilities) measured at fair value using significant unobservable inputs	'
	The following table presents a reconciliation of the financial derivative asset and liability measured at fair value using significant unobservable inputs for the nine month period ended September 30, 2013:
		Preferred Stock Embedded				Convertible Security Embedded
		Derivative Liability				Derivative Asset
		(in thousands)
	Fair value at December 31, 2012	$	(43,548	)		$	264
	Issuance of derivative liability	(10,803		)		—
	Decrease in fair value recognized in other income (expense)	(20,809		)		(185		)
	Fair value as of September 30, 2013	$	(75,160	)		$	79
Fair value measurements on a recurring basis	'
	The following tables present recurring financial assets and liabilities which are carried at fair value at September 30, 2013 and December 31, 2012:
		Fair Value Measurements on a Recurring Basis
		30-Sep-13
		(in thousands)
	Assets	Level 1				Level 2				Level 3
	Available for sale securities	$	1,825			$	—			$	—
	Commodity derivative assets	—				1,392				—
	Convertible security derivative assets	—				—				79
	Total assets at fair value	$	1,825			$	1,392			$	79
	Liabilities
	Commodity derivative liabilities	$	—			$	6,750			$	—
	Convertible preferred stock derivative liabilities	—				—				75,160
	Total liabilities at fair value	$	—			$	6,750			$	75,160
		Fair Value Measurements on a Recurring Basis
		31-Dec-12
		(in thousands)
	Assets	Level 1				Level 2				Level 3
	Available for sale securities	$	1,958			$	—			$	—
	Commodity derivative assets	—				4,882				—
	Convertible security derivative assets	—				—				264
	Total assets at fair value	$	1,958			$	4,882			$	264
	Liabilities
	Commodity derivative liabilities	$	—			$	7,477			$	—
	Convertible preferred stock derivative liabilities	—				—				43,548
	Total liabilities at fair value	$	—			$	7,477			$	43,548
Carrying amounts and fair values of long-term debt	'
	The Company uses available market data and valuation methodologies to estimate the fair value of debt.  The carrying amounts and fair values of long-term debt are as follows:
					30-Sep-13							31-Dec-12
			Fair Value Hierarchy		Carrying Amount				Estimated Fair Value			Carrying Amount		Estimated Fair Value
					(in thousands)
	Senior Notes (1)		Level 2		$	597,216			$	622,320		$	597,212	$	613,500
	MHR Senior Revolving Credit Facility (2)		Level 3		$	90,000			$	90,000		$	225,000	$	225,000
	Eureka Hunter Pipeline, LLC second lien term loan (3)		Level 3		$	50,000			$	59,832		$	50,000	$	58,550
	Equipment notes payable (3)		Level 3		$	16,059			$	15,412		$	18,548	$	17,450
	_________________________________
	(1)     The fair value of the Company's Senior Notes is based on quoted market prices available to us for those periods.
	-2	The carrying value of the MHR Senior Revolving Credit Facility approximates fair value as it is subject to short-term floating interest rates that approximate the rates available to us at such date.
	-3	The fair value of each of (a) Eureka Hunter Pipeline's second lien term loan and (b) the equipment notes payable is the estimated cost to acquire the debt, including a credit spread for the difference between the issue rate and the period end market rate.

FINANCIAL_INSTRUMENTS_AND_DERI1

FINANCIAL INSTRUMENTS AND DERIVATIVES (Tables)	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Estimated fair values of commodity derivatives	'
	As of September 30, 2013, the Company had the following commodity derivative instruments:
					Weighted Average
	Natural Gas	Period	MMBtu/day		Price per MMBtu
	Collars (1)	Oct 2013 - Dec 2013	12,500		$4.50 - $5.96
	Swaps	Oct 2013 - Dec 2013	25,500		$3.64
		Jan 2014 - Dec 2014	10,000		$4.13
	Ceilings purchased (call)	Oct 2013 - Dec 2013	10,000		$6.00
		Jan 2014 - Dec 2014	10,000		$6.15
	Ceilings sold (call)	Jan 2014 - Dec 2014	26,000		$5.47
	Floors purchased (put)	Jan 2014 - Dec 2014	10,000		$4.25
	Floors sold (put)	Jan 2014 - Dec 2014	10,000		$3.75
					Weighted Average
	Crude Oil	Period	Bbl/day		Price per Bbl
	Collars (1)	Oct 2013 - Dec 2013	2,763		$81.38 - $97.61
		Jan 2014 - Dec 2014	663		$85.00 - $91.25
		Jan 2015 - Dec 2015	259		$85.00 - $91.25
	Traditional three-way collars (2)	Oct 2013 - Dec 2013	2,000		$60.63 - $80.00 - $100.00
		Jan 2014 - Dec 2014	4,000		$64.94 - $85.00 - $102.50
	Conservative three-way collar (3)	Oct 2013 - Dec 2013	763		$65.00 - $91.25 - $101.25
	Swaps	Oct 2013 - Dec 2013	5,450		$92.72
	Ceilings purchased (call)	Oct 2013 - Dec 2013	2,250		$100.00
	Ceilings sold (call)	Jan 2015 - Dec 2015	1,570		$120.00
	Floors purchased (put)	Oct 2013 - Dec 2013	1,750		$90.00
	Floors sold (put)	Oct 2013 - Dec 2013	5,438		$76.03
		Jan 2014 - Dec 2014	663		$65.00
		Jan 2015 - Dec 2015	259		$70.00
	________________________________
	(1) A collar is a sold call and a purchased put. Some collars are "costless" collars with the premiums netting to approximately zero.
	(2) These three-way collars are a combination of three options: a sold call, a purchased put and a sold put.
	(3) These three-way collars are a combination of three options: a sold call, a purchased call and a sold put.
Schedule of fair value of commodity derivative contracts	'
	The following table summarizes the fair value of the Company's commodity and financial derivative contracts as of the dates indicated:
					Gross Derivative Assets								Gross Derivative Liabilities
	Derivatives not designated as hedging instruments		Balance Sheet Classification		30-Sep-13				31-Dec-12				30-Sep-13				31-Dec-12
					(in thousands)
	Commodity
			Derivative assets		$	1,000			$	4,882			$	—			$	—
			Derivative assets - long term		392				—				—				—
			Derivative liabilities		—				—				(5,913		)		(3,501		)
			Derivative liabilities - long term		—				—				(837		)		(3,976		)
	Total commodity				$	1,392			$	4,882			$	(6,750	)		$	(7,477	)
	Financial
			Derivative assets		$	79			$	264			$	—			$	—
			Derivative liabilities - long term		—				—				(75,160		)		(43,548		)
	Total financial				$	79			$	264			$	(75,160	)		$	(43,548	)
	Total derivatives				$	1,471			$	5,146			$	(81,910	)	—	$	(51,025	)
Schedule of the realized and unrealized gain (loss) on derivatives	'
	The following table summarizes the realized and unrealized gains and losses on change in fair value of the Company's derivative contracts as of the dates indicated:
		Three Months Ended								Nine Months Ended
		September 30,								September 30,
		2013				2012				2013				2012
		(in thousands)
	Realized gain (loss)	$	(6,582	)		$	2,224			$	(6,887	)		$	7,962
	Unrealized gain (loss)	(22,971		)		(12,375		)		(23,757		)		1,094
	Net gain (loss)	$	(29,553	)		$	(10,151	)		$	(30,644	)		$	9,056

DIVESTITURES_AND_DISCONTINUED_1

DIVESTITURES AND DISCONTINUED OPERATIONS (Tables)	9 Months Ended
	Sep. 30, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Schedule of discontinued operations	'
	The Company included the results of operations of MHP and WHI Canada for all periods presented through September 30, 2013, Eagle Ford Hunter through April 24, 2013, and Hunter Disposal through February 17, 2012 in discontinued operations as follows:
			Three Months Ended September 30,						Nine Months Ended September 30,
			2013			2012			2013			2012
			(in thousands)
	Revenues		$	13,203		$	32,997		$	81,616		$	91,728
	Expenses (2)		(107,958		)	(33,997		)	(166,196		)	(90,216		)
	Other income (expense)		3,621			(76		)	6,777			3,212
	Income tax benefit (expense) (1)		10,580			(26		)	6,348			(1,892		)
	Income (loss) from discontinued operations, net of tax		(80,554		)	(1,102		)	(71,455		)	2,832
	Gain (loss) on sale of discontinued operations, net of taxes (3)		(84,454		)	—			87,998			2,224
	Income (loss) from discontinued operations, net of taxes		$	(165,008	)	$	(1,102	)	$	16,543		$	5,056
	________________________________
	-1	In addition, the Company recognized an alternative minimum tax charge of $1.3 million in connection with the Eagle Ford Hunter sale.
	-2	Includes impairment expense of $72.5 million and $78.5 million for the three and nine months ended September 30, 2013, respectively, and exploration expense of $18.0 million and $19.6 million for the three and nine months ended September 30, 2013, respectively relating to the discontinued operations of MHP and WHI Canada, which is recorded in income (loss) from discontinued operations.

ASSET_RETIREMENT_OBLIGATIONS_T

ASSET RETIREMENT OBLIGATIONS (Tables)	9 Months Ended
	Sep. 30, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Summary of asset retirement obligation	'
	The following table summarizes the Company’s ARO activities during the nine month period ended September 30, 2013:
		Nine Months Ended
		September 30, 2013
		(in thousands)
	Asset retirement obligation at beginning of period	$	30,680
	Assumed in acquisitions	17
	Liabilities incurred	209
	Liabilities settled	(98		)
	Liabilities sold	(2,429		)
	Accretion expense	1,824
	Revisions in estimated liabilities (1)	1,935
	Reclassified as liabilities associated with assets held for sale	(11,148		)
	Effect of foreign currency translation	(73		)
	Asset retirement obligation at end of period	20,917
	Less: current portion (included in other liabilities)	(1,015		)
	Asset retirement obligation at end of period	$	19,902
	________________________________
	(1) $1.5 million of the revisions in estimated liabilities is related to change in assumptions used with respect to certain wells in the Williston Basin in North Dakota.

LONGTERM_DEBT_Tables

LONG-TERM DEBT (Tables)	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Schedule of long-term debt	'
	Long-term debt at September 30, 2013 and December 31, 2012 consisted of the following:
		September 30, 2013			December 31, 2012
		(in thousands)
	Senior Notes payable due May 15, 2020, interest rate of 9.75%, net of unamortized net discount of $2.8 million at September 30, 2013 and December 31, 2012	$	597,216		$	597,212
	Various equipment and real estate notes payable with maturity dates January 2015 - April 2021, interest rates of 4.25% - 5.70%	16,059			18,548
	Eureka Hunter Pipeline, LLC second lien term loan due August 16, 2018, interest rate of 12.5%	50,000			50,000
	MHR Senior Revolving Credit Facility due April 13, 2016, interest rate of 2.96%	90,000			225,000
	at September 30, 2013 and 3.56% at December 31, 2012
		753,275			890,760
	Less: current portion	(4,144		)	(3,991		)
	Total long-term debt obligations, net of current portion	$	749,131		$	886,769
Schedule of expected approximate annual maturities of debt	'
	The following table presents the scheduled or expected approximate annual maturities of debt, gross of unamortized discount of $2.8 million:
		(in thousands)
	2013	$	1,034
	2014	4,149
	2015	8,313
	2016	92,563
	2017	—
	Thereafter	650,000
	Total	$	756,059
Schedule of Interest Expense	'
	The following table sets forth interest expense for the three and nine month period ended September 30, 2013 and 2012, respectively:
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2013			2012			2013		2012
		(in thousands)
	Interest expense incurred on debt	$	14,578		$	13,766		$	49,542	$	29,870
	Amortization and write-off of deferred financing costs	1,111			639			3,661		10,725
	Total Interest Expense	$	15,689		$	14,405		$	53,203	$	40,595

SHAREBASED_COMPENSATION_Tables

SHARE-BASED COMPENSATION (Tables)	9 Months Ended
	Sep. 30, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Summary of common stock option and stock appreciation rights	'
	A summary of common stock option activity for the nine months ended September 30, 2013 and 2012 is presented below:
		Nine Months Ended
		September 30,
		2013		2012		2013		2012
		(in thousands of shares)				Weighted Average Exercise Price per Share
	Outstanding at beginning of period	14,847		12,566		$	6.01	$	5.64
	Granted	4,938		4,854		$	4.11	$	6.05
	Exercised	(685	)	(843	)	$	2.95	$	1.4
	Forfeited	(742	)	(807	)	$	6	$	7.24
	Outstanding at end of period	18,358		15,770		$	5.61	$	5.91
	Exercisable at end of period	10,512		8,959		$	5.86	$	5.79
Summary of non-vested shares	'
	A summary of the Company’s non-vested common stock options and stock appreciation rights for the nine months ended September 30, 2013 and 2012 is presented below:
		Nine Months Ended
		September 30,
		2013		2012
		(in thousands of shares)
	Non-vested at beginning of period	6,163		5,651
	Granted	4,938		4,854
	Vested	(2,867	)	(3,005	)
	Forfeited	(389	)	(688	)
	Non-vested at end of period	7,845		6,811
Assumptions used in fair value method calculation	'
	The assumptions used in the fair value method calculation for the nine months ended September 30, 2013, are:
	Weighted average fair value per option granted during the period (1)	$2.52
	Assumptions: (2), (3)
	Weighted average stock price volatility	80.61%
	Weighted average risk free rate of return	0.78%
	Weighted average expected term	4.65
	________________________________
	-1	Calculated using the Black-Scholes fair value based method for service and performance based grants and the Lattice Model for market based grants.
	-2	The Company's estimated future forfeiture rate is 2.45%.
	-3	The Company does not pay cash dividends on its common stock.

SHAREHOLDERS_EQUITY_Tables

SHAREHOLDERS' EQUITY (Tables)	9 Months Ended
	Sep. 30, 2013
Equity [Abstract]	'
Schedule of dividends paid	'
	A summary of the Company's preferred dividends for the three and nine months ended September 30, 2013 and 2012 is presented below:
		Three Months Ended September 30,				Nine Months Ended September 30,
		2013		2012		2013		2012
		(in thousands)				(in thousands)
	Dividend on Eureka Hunter Holdings Series A Preferred Units	$	3,771	$	2,718	$	10,441	$	5,086
	Accretion of the carrying value of the Eureka Hunter Holdings Series A Preferred Units	1,826		1,307		4,990		2,415
	Dividend on Series C Preferred Stock	2,562		2,562		7,686		7,686
	Dividend on Series D Preferred Stock	4,424		3,233		13,231		7,493
	Dividend on Series E Preferred Stock	1,834		—		5,686		—
	Total dividends on Preferred Stock	$	14,417	$	9,820	$	42,034	$	22,680

TAXES_Tables

TAXES (Tables)	9 Months Ended
	Sep. 30, 2013
Income Tax Disclosure [Abstract]	'
Schedule of Components of Income Tax Expense (Benefit)	'
	The Company's income tax benefit from continuing operations for the three and nine months ended September 30, 2013 and 2012 was:
		Three Months Ended					Nine Months Ended
		September 30,					September 30,
		2013			2012		2013		2012
		(in thousands)
	Deferred	(3,255		)	1,983		40,944		9,143
	Income tax benefit	$	(3,255	)	$	1,983	$	40,944	$	9,143

RELATED_PARTY_TRANSACTIONS_REL

RELATED PARTY TRANSACTIONS RELATED PARTY TRANSACTIONS (Tables)	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Schedule of Related Party Transactions	'
	The following table sets forth the related party transaction activities for the three and nine months ended September 30, 2013 and 2012, respectively:
			Three Months Ended					Nine Months Ended
			September 30,					September 30,
			2013			2012		2013		2012
			(in thousands)
	GreenHunter
		Salt water disposal (1)	$	623		$	618	$	2,069	$	1,600
		Equipment rental (1)	95			244		167		875
		Interest Income from Note Receivable (2)	51			55		159		110
		Dividends earned from Series C shares	73			55		165		136
		Loss on investments (2)	(24		)	97		653		299
	Pilatus Hunter, LLC
		Airplane rental expenses (3)	26			—		94		81
	Alpha Hunter Drilling
		Drilling Revenue (4)				359				359
	Executive of the Company
		Corporate apartment rental (5)	—			5		—		23
	_________________________________
	-1	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman, a major shareholder and former CEO; of which David Krueger, the Company's former Chief Accounting Officer and Senior Vice President, is the former Chief Financial Officer; and of which Ronald D. Ormand, the Company’s former Chief Financial Officer and Executive Vice President, is a former director. Eagle Ford Hunter received, and Triad Hunter and Viking International Resources, Inc. ("Virco"), wholly-owned subsidiaries of the Company, receive services related to brine water and rental equipment from GreenHunter and its affiliated companies, White Top Oilfield Construction, LLC and Black Water Services, LLC. The Company believes that such services were and are provided at competitive market rates and were and are comparable to, or more attractive than, rates that could be obtained from unaffiliated third party suppliers of such services. Prepaid expenses from GreenHunter were $64,748 and $0 at September 30, 2013 and December 31, 2012, respectively. The Company had net accounts payable to GreenHunter of $11,541 and $0 at September 30, 2013 and December 31, 2012, respectively.
	-2	On February 17, 2012, the Company sold its wholly-owned subsidiary, Hunter Disposal, to GreenHunter Water, LLC ("GreenHunter Water"), a wholly-owned subsidiary of GreenHunter.  The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note it received as partial consideration for the sale. The fair market value of the derivative asset was $79,000, and $264,000 at September 30, 2013 and December 31, 2012, respectively.  See "Note 3 - Fair Value of Financial Instruments" for additional information. The Company has recorded interest income as a result of the note receivable from GreenHunter. Also as a result of this transaction, the Company has an equity method investment in GreenHunter that is included in derivatives and other long term assets and an available for sale investment in GreenHunter included in investments.
	-3	The Company rented an airplane for business use for certain members of Company management at various times from Pilatus Hunter, LLC, an entity 100% owned by Mr. Evans. Airplane rental expenses are recorded in general and administrative expense.
	-4	Alpha Hunter Drilling, LLC ("Alpha Hunter Drilling"), a wholly-owned subsidiary of the Company, performed drilling operations for GreenHunter for a fee.
	-5	During the three and nine months ended September 30, 2012, the Company paid rent under a lease for a Houston, Texas corporate apartment from an executive of the Company, which apartment was used by other Company employees when in Houston for Company business.  The lease terminated in May 2012.

SUPPLEMENTAL_CASH_FLOW_INFORMA1

SUPPLEMENTAL CASH FLOW INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2013
Supplemental Cash Flow Elements [Abstract]	'
Schedule of Cash Flow, Supplemental Disclosures	'
	The following summarizes cash paid (received) for interest and income taxes, as well as non-cash investing transactions:
		Nine Months Ended September 30,
		2013			2012
		(in thousands)
	Cash paid for interest	$	38,225		$	13,185
	Cash paid for taxes	$	1,200		$	—
	Non-cash transactions
	Common stock issued for acquisitions	$	—		$	1,902
	Common stock issued for 401k matching contributions	$	1,192		$	874
	Non-cash consideration received from sale of assets	$	—		$	7,706
	Change in accrued capital expenditures	$	(5,742	)	$	10,722
	Non-cash additions to asset retirement obligation	$	2,089		$	182
	Eureka Hunter Holdings, LLC Series A convertible preferred unit dividends paid in kind	$	6,367		$	1,658
	Eureka Hunter Holdings, LLC Class A common units issued for an acquisition	$	—		$	12,453

SEGMENT_REPORTING_Tables

SEGMENT REPORTING (Tables)	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Details of operating activities by segment	'
	The following tables set forth operating activities by segment for the three and nine months ended September 30, 2013 and 2012, respectively.
		As of and for the Three Months Ended September 30, 2013
		U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
		Upstream			Upstream						Services			Unallocated			Eliminations
		(in thousands)
	Revenues
	Oil and natural gas sales	$	54,018		$	—		$	—		$	—		$	—		$	—		$	54,018
	Gas transportation, gathering, processing, and marketing	—			—			14,618			—			—			(2,073		)	12,545
	Oilfield services	—			—			—			6,448			—			(25		)	6,423
	Other revenue	46			—			—			—			—			—			46
	Total revenue	54,064			—			14,618			6,448			—			(2,098		)	73,032
	Expenses
	Lease operating expenses	17,217			—			—			—			—			(2,072		)	15,145
	Severance taxes and marketing	5,465			—			—			—			—			—			5,465
	Exploration and abandonments	40,123			—			—			—			—			—			40,123
	Impairment of proved oil and gas properties	—			—			—			—			—			—			—
	Gas transportation, gathering, processing, and marketing	—			—			8,985			—			—			—			8,985
	Oilfield services	—			—			—			4,552			—			(25		)	4,527
	Depletion, depreciation, amortization and accretion	24,400			—			3,173			720			—			—			28,293
	Loss on sale of assets, net	40,952			—			—			—			—			—			40,952
	General and administrative	6,055			—			2,156			379			11,455			2,173			22,218
	Total expenses	134,212			—			14,314			5,651			11,455			76			165,708
	Interest income	35			—			—			—			1,183			(1,184		)	34
	Interest expense	(1,734		)	—			(1,177		)	(141		)	(16,109		)	3,472			(15,689		)
	Gain (loss) on derivative contracts,(net)	26			—			(15,368		)	—			(14,211		)	—			(29,553		)
	Other income (expense)	245			—			(27		)	—			8,322			—			8,540
	Total other income (expense)	(1,428		)	—			(16,572		)	(141		)	(20,815		)	2,288			(36,668		)
	Income (loss) from continuing operations before income tax	(81,576		)	—			(16,268		)	656			(32,270		)	114			(129,344		)
	Income tax benefit (expense)	9,417			926			—			—			(13,598		)	—			(3,255		)
	Net income (loss) from continuing operations	(72,159		)	926			(16,268		)	656			(45,868		)	114			(132,599		)
	Loss from discontinued operations, net of tax	(6,245		)	(77,220		)	—			—			3,025			(114		)	(80,554		)
	Loss on sale of discontinued operations, net of tax	(28,813		)	(55,641		)	—			—			—			—			(84,454		)
	Net income (loss)	$	(107,217	)	$	(131,935	)	$	(16,268	)	$	656		$	(42,843	)	$	—		$	(297,607	)
	Total segment assets	$	1,406,515		$	106,438		$	269,692		$	42,648		$	62,182		$	(1,659	)	$	1,885,816
		As of and for the Three Months Ended September 30, 2012
		U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
		Upstream			Upstream						Services			Unallocated			Eliminations
		(in thousands)
	Revenues
	Oil and natural gas sales	$	29,983		$	—		$	—		$	—		$	—		$	—		$	29,983
	Gas transportation, gathering, processing, and marketing	—			—			5,058			—			—			—			5,058
	Oilfield services	—			—			—			3,533			—			(2,029		)	1,504
	Other revenue	(172		)	—			8			—			—			—			(164		)
	Total revenue	29,811			—			5,066			3,533			—			(2,029		)	36,381
	Expenses
	Lease operating expenses	7,309			—			—			—			—			(1,209		)	6,100
	Severance taxes and marketing	2,530			—			—			—			—			—			2,530
	Exploration and abandonments	3,299			—			—			—			—			—			3,299
	Gas transportation, gathering and processing	—			—			2,288			—			—			—			2,288
	Oilfield services	—			—			—			3,716			—			(350		)	3,366
	Depletion, depreciation, amortization and accretion	13,715			—			1,195			236			—			—			15,146
	(Gain) loss on sale of assets, net	$	(13	)	$	—		$	—		$	341		$	—		$	—		328
	General and administrative	3,061			—			958			145			8,058			—			12,222
	Total expenses	29,901			—			4,441			4,438			8,058			(1,559		)	45,279
	Interest income	140			—			—			—			2,137			(2,145		)	132
	Interest expense	(1,931		)	—			(1,671		)	(63		)	(12,885		)	2,145			(14,405		)
	Gain (loss) on derivative contracts, (net)	80			—			5,340			—			(15,571		)	—			(10,151		)
	Other income (expense)	37			—			(10		)	—			—			—			27
	Total other income (expense)	(1,674		)	—			3,659			(63		)	(26,319		)	—			(24,397		)
	Income (loss) from continuing operations before income tax	(1,764		)	—			4,284			(968		)	(34,377		)	(470		)	(33,295		)
	Income tax benefit (expense)	2,988			(1,005		)	—			—			—			—			1,983
	Net income (loss) from continuing operations	1,224			(1,005		)	4,284			(968		)	(34,377		)	(470		)	(31,312		)
	Income (loss) from discontinued operations, net of tax	2,758			(3,860		)	—			—			—			—			(1,102		)
Loss on sale of discontinued operations, net of tax	—			—			—			—			—			—			—
Net income (loss)	$	3,982		$	(4,865	)	$	4,284		$	(968	)	$	(34,377	)	$	(470	)	$	(32,414	)
Total segment assets	$	1,411,720		$	275,066		$	182,144		$	15,120		$	51,677		$	(1,759	)	$	1,933,968
	As of and for the Nine Months Ended September 30, 2013
	U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
	Upstream			Upstream						Services			Unallocated			Eliminations
	(in thousands)
Oil and natural gas sales	$	138,242		$	—		$	—		$	—		$	—		$	—		$	138,242
Gas transportation, gathering, processing, and marketing	—			—			48,071			—			—			(5,656		)	42,415
Oilfield services	—			—			—			13,872			—			(144		)	13,728
Other revenue	788			—			—			1			—			—			789
Total revenue	139,030			—			48,071			13,873			—			(5,800		)	195,174
Lease operating expenses	43,720			—			—			—			—			(5,693		)	38,027
Severance taxes and marketing	12,313			—			—			—			—			—			12,313
Exploration and abandonments	73,402			—			—			—			—			—			73,402
Impairment of proved oil and natural gas properties	9,968			—			—			—			—			—			9,968
Gas transportation, gathering, processing, and marketing	—			—			35,830			—			—			—			35,830
Oilfield services	—			—			—			12,034			—			(106		)	11,928
Depletion, depreciation, amortization and accretion	61,235			—			9,142			1,579			—			—			71,956
Loss on sale of assets, net	42,112			—			—			4			—			—			42,116
General and administrative	11,158			—			5,446			850			38,932			2,173			58,559
Total expenses	253,908			—			50,418			14,467			38,932			(3,626		)	354,099
Interest income	171			—			—			—			3,987			(3,986		)	172
Interest expense	(5,802		)	—			(3,215		)	(372		)	(50,088		)	6,274			(53,203		)
Gain (loss) on derivative contracts, (net)	(185		)	—			(20,808		)	—			(9,651		)	—			(30,644		)
Other income (expense)	(324		)	—			(238		)	—			8,422			—			7,860
Total other income (expense)	(6,140		)	—			(24,261		)	(372		)	(47,330		)	2,288			(75,815		)
Loss from continuing operations before income tax	(121,018		)	—			(26,608		)	(966		)	(86,262		)	114			(234,740		)
Income tax benefit (expense)	12,597			—			—			—			28,347			—			40,944
Net loss from continuing operations	(108,421		)	—			(26,608		)	(966		)	(57,915		)	114			(193,796		)
Income (loss) from discontinued operations, net of tax	12,516			(78,429		)	—			—			(5,428		)	(114		)	(71,455		)
Gain (loss) on sale of discontinued operations, net of tax	143,639			(55,641		)	—			—			—			—			87,998
Net income (loss)	$	47,734		$	(134,070	)	$	(26,608	)	$	(966	)	$	(63,343	)	$	—		$	(177,253	)
																			—
Total segment assets	$	1,406,515		$	106,438		$	269,692		$	42,648		$	62,182		$	(1,659	)	$	1,885,816
	As of and for the Nine Months Ended September 30, 2012
	U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
	Upstream			Upstream						Services			Unallocated			Eliminations
	(in thousands)
Oil and natural gas sales	$	78,532		$	—		$	—		$	—		$	—		$	—		$	78,532
Gas transportation, gathering, processing, and marketing	—			—			10,418			—			—			—			10,418
Oilfield services	—			—			—			9,793			—			(3,675		)	6,118
Other revenue	(169		)	—			25			—			—			—			(144		)
Total revenue	78,363			—			10,443			9,793			—			(3,675		)	94,924
Lease operating expenses	21,145			—			—			—			—			(2,854		)	18,291
Severance taxes and marketing	6,618			—			—			—			—			—			6,618
Exploration and abandonments	18,143			—			—			—			—			—			18,143
Gas transportation, gathering, processing, and marketing	—			—			4,379			—			—			—			4,379
Oilfield services	—			—			—			7,283			—			(350		)	6,933
Depletion, depreciation, amortization and accretion	38,662			—			2,853			684			—			—			42,199
(Gain) loss on sale of assets, net	(88		)							616									528
General and administrative	5,954			—			2,065			251			29,956			—			38,226
Total expenses	90,434			—			9,297			8,834			29,956			(3,204		)	135,317
Interest income	169			—			—			—			2,192			(2,145		)	216
Interest expense	(3,461		)	—			(4,678		)	(221		)	(34,380		)	2,145			(40,595		)
Gain (loss) on derivative contracts, (net)	185			—			3,990			—			4,881			—			9,056
Other income (expense)	102			—			(12		)	—			—			—			90
Total other income (expense)	(3,005		)	—			(700		)	(221		)	(27,307		)	—			(31,233		)
Income (loss) from continuing operations before income tax	(15,076		)	—			446			738			(57,263		)	(471		)	(71,626		)
Income tax benefit	10,155			(1,012		)	—			—			—			—			9,143
Net income (loss) from continuing operations	(4,921		)	(1,012		)	446			738			(57,263		)	(471		)	(62,483		)
Income (loss) from discontinued operations	6,997			(4,519		)	—			354			—			—			2,832
Gain on sale of discontinued operations	—			—			—			2,224			—			—			2,224
Net income (loss)	$	2,076		$	(5,531	)	$	446		$	3,316		$	(57,263	)	$	(471	)	$	(57,427	)
Total segment assets	$	1,411,720		$	275,066		$	182,144		$	15,120		$	51,677		$	(1,759	)	$	1,933,968

CONDENSED_CONSOLIDATING_GUARAN1

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Tables)	9 Months Ended
	Sep. 30, 2013
Condensed Financial Statements, Captions [Line Items]	'
Schedule of Comprehensive Income (Loss)	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Comprehensive Income (Loss)
	(in thousands)
		Three Months Ended September 30, 2013
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	Net income (loss)	$	(302,364	)		$	(856	)		$	(59,320	)	$	(200,214	)		$	265,147		(297,607	)
	Foreign currency translation loss	—				—				—			3,856				—			3,856
	Unrealized gain (loss) on available for sale securities	3,562				—				173			—				—			3,735
	Amounts reclassified from accumulated other comprehensive income	(8,262		)		—				—			—				—			(8,262	)
	Comprehensive income (loss)	(307,064		)		(856		)		(59,147		)	(196,358		)		265,147			(298,278	)
	Comprehensive loss attributable to non-controlling interest	—				—				—			—				725			725
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(307,064	)		$	(856	)		$	(59,147	)	$	(196,358	)		$	265,872		(297,553	)
		Three Months Ended September 30, 2012
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	Net income (loss)	$	(35,646	)		$	(472	)		$	(4,416	)	$	4,081			$	4,039		(32,414	)
	Foreign currency translation loss	—				—				—			7,245				—			7,245
	Unrealized gain (loss) on available for sale securities	—				—				(35		)	—				—			(35	)
	Comprehensive income (loss)	(35,646		)		(472		)		(4,451		)	11,326				4,039			(25,204	)
	Comprehensive income attributable to non-controlling interest	—				—				—			—				(49		)	(49	)
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(35,646	)		(472		)		(4,451		)	11,326				3,990			(25,253	)
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Comprehensive Income (Loss)
	(in thousands)
		Nine Months Ended September 30, 2013
		Magnum Hunter			PRC Williston, LLC			100% Owned Guarantor			Non Guarantor		Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources						Subsidiaries			Subsidiaries					Resources
		Corporation														Corporation
																Consolidated
	Net income (loss)	(190,954	)		(3,542	)		(97,486	)		(198,610	)	313,339			(177,253	)
	Foreign currency translation loss	—			—			—			(7,943	)	—			(7,943	)
	Unrealized gain (loss) on available for sale securities	8,262			—			(78	)		—		—			8,184
	Amounts reclassified from accumulated other comprehensive income	(8,262	)		—			—			—		—			(8,262	)
	Comprehensive income (loss)	(190,954	)		(3,542	)		(97,564	)		(206,553	)	313,339			(185,274	)
	Comprehensive loss attributable to non-controlling interest	—			—			—			—		1,614			1,614
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	(190,954	)		(3,542	)		(97,564	)		(206,553	)	314,953			(183,660	)
		Nine Months Ended September 30, 2012
		Magnum Hunter			PRC Williston, LLC			100% Owned Guarantor			Non Guarantor		Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources						Subsidiaries			Subsidiaries					Resources
		Corporation														Corporation
																Consolidated
	Net income (loss)	(62,596	)		(1,858	)		(12,757	)		4,835		14,949			(57,427	)
	Foreign currency translation loss	—			—			—			6,628		—			6,628
	Unrealized gain (loss) on available for sale securities	—			—			(301	)		—		—			(301	)
	Comprehensive income (loss)	(62,596	)		(1,858	)		(13,058	)		11,463		14,949			(51,100	)
	Comprehensive income attributable to non-controlling interest	—			—			—			—		(71	)		(71	)
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	(62,596	)		(1,858	)		(13,058	)		11,463		14,878			(51,171	)
Debt Securities Under Universal Shelf Registration Statement Form S-4	'
Condensed Financial Statements, Captions [Line Items]	'
Schedule of condensed consolidating balance sheets	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
		As of September 30, 2013
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	ASSETS
	Current assets	$	35,827			$	1,555			$	81,644		$	41,787			$	(1,659	)	$	159,154
	Intercompany accounts receivable	838,399				—				—			—				(838,399		)	—
	Property and equipment (using successful efforts method of accounting)	7,516				16,921				1,242,456			205,058				—			1,471,951
	Investment in subsidiaries	460,903				—				102,259			64,423				(627,585		)	—
	Assets held for sale and other	18,838				—				110,535			125,338				—			254,711
	Total Assets	$	1,361,483			$	18,476			$	1,536,894		$	436,606			$	(1,467,643	)	$	1,885,816
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	69,615			$	2,924			$	158,674		$	23,393			$	(1,694	)	$	252,912
	Intercompany accounts payable	—				61,314				707,801			69,252				(838,367		)	—
	Long-term liabilities	691,298				1,351				75,332			126,958				—			894,939
	Redeemable preferred stock	100,000				—				—			128,871				—			228,871
	Shareholders' equity (deficit)	500,570				(47,113		)		595,087			88,132				(627,582		)	509,094
	Total Liabilities and Shareholders' Equity	$	1,361,483			$	18,476			$	1,536,894		$	436,606			$	(1,467,643	)	$	1,885,816
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
		As of December 31, 2012
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	ASSETS
	Current assets	$	63,167			$	703			$	60,552		$	111,126			$	(31,229	)	$	204,319
	Intercompany accounts receivable	803,834				—				—			—				(803,834		)	—
	Property and equipment (using successful efforts method of accounting)	9,596				18,257				1,276,467			620,093				—			1,924,413
	Investment in subsidiaries	763,856				—				101,341			102,354				(967,551		)	—
	Other assets	20,849				—				5,451			43,600				—			69,900
	Total Assets	$	1,661,302			$	18,960			$	1,443,811		$	877,173			$	(1,802,614	)	$	2,198,632
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	28,503			$	2,291			$	117,511		$	125,727			$	(30,376	)	$	243,656
	Intercompany accounts payable	—				58,966				508,254			236,636				(803,856		)	—
	Long-term liabilities	831,286				1,274				97,271			112,615				—			1,042,446
	Redeemable preferred stock	100,000				—				—			100,878				—			200,878
	Shareholders' equity (deficit)	701,513				(43,571		)		720,775			301,317				(968,382		)	711,652
	Total Liabilities and Shareholders' Equity	$	1,661,302			$	18,960			$	1,443,811		$	877,173			$	(1,802,614	)	$	2,198,632
Schedule of condensed consolidating statements of operations	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
		Three Months Ended September 30, 2013
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	Revenues	$	29			$	2,020			$	66,203		$	6,877			$	(2,097	)	$	73,032
	Expenses	35,351				2,876				142,373			23,988				(2,212		)	202,376
	Loss from continuing operations before equity in net income of subsidiaries	(35,322		)		(856		)		(76,170		)	(17,111		)		115			(129,344		)
	Equity in net income of subsidiaries	(236,767		)		—				163			(28,543		)		265,147			—
	Loss from continuing operations before income tax	(272,089		)		(856		)		(76,007		)	(45,654		)		265,262			(129,344		)
	Income tax benefit (expense)	(13,598		)		—				9,400			943				—			(3,255		)
	Loss from continuing operations	(285,687		)		(856		)		(66,607		)	(44,711		)		265,262			(132,599		)
	Income from discontinued operations, net of tax	3,027				—				16,396			(99,862		)		(115		)	(80,554		)
	Gain on sale of discontinued operations, net of tax	(19,704		)		—				(9,109		)	(55,641		)		—			(84,454		)
	Net income (loss)	(302,364		)		(856		)		(59,320		)	(200,214		)		265,147			(297,607		)
	Net loss attributable to non-controlling interest	—				—				—			—				725			725
	Net loss attributable to Magnum Hunter Resources Corporation	(302,364		)		(856		)		(59,320		)	(200,214		)		265,872			(296,882		)
	Dividends on preferred stock	(8,820		)		—				—			(5,597		)		—			(14,417		)
	Net income (loss) attributable to common shareholders	$	(311,184	)		$	(856	)		$	(59,320	)	$	(205,811	)		$	265,872		$	(311,299	)
		Three Months Ended September 30, 2012
		Magnum Hunter				PRC Williston, Inc.				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	Revenues	$	169			$	1,876			$	31,833		$	4,533			$	(2,030	)	$	36,381
	Expenses	33,996				2,348				34,347			544				(1,559		)	69,676
	Income (loss) from continuing operations before equity in net income of subsidiaries	(33,827		)		(472		)		(2,514		)	3,989				(471		)	(33,295		)
	Equity in net income of subsidiaries	(1,819		)		—				—			(2,691		)		4,510			—
	Income (loss) from continuing operations before income tax	(35,646		)		(472		)		(2,514		)	1,298				4,039			(33,295		)
	Income tax benefit	—				—				301			1,682				—			1,983
	Income (loss) from continuing operations	(35,646		)		(472		)		(2,213		)	2,980				4,039			(31,312		)
	Income (loss) from discontinued operations, net of tax	—				—				(2,203		)	1,101				—			(1,102		)
	Gain on sale of discontinued operations, net of tax	—				—				—			—				—			—
	Net income (loss)	(35,646		)		(472		)		(4,416		)	4,081				4,039			(32,414		)
	Net income attributable to non-controlling interest	—				—				—			—				(49		)	(49		)
	Net income (loss) attributable to Magnum Hunter Resources Corporation	(35,646		)		(472		)		(4,416		)	4,081				3,990			(32,463		)
	Dividends on preferred stock	(5,795		)		—				—			(4,025		)		—			(9,820		)
	Net income (loss) attributable to common shareholders	$	(41,441	)		$	(472	)		$	(4,416	)	$	56			$	3,990		$	(42,283	)
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
		Nine Months Ended September 30, 2013
		Magnum Hunter				PRC Williston, Inc.				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	Revenues	$	(134	)		$	5,315			$	175,630		$	20,162			$	(5,799	)	$	195,174
	Expenses	91,559				8,857				288,658			46,754				(5,914		)	429,914
	Loss from continuing operations before equity in net income of subsidiaries	(91,693		)		(3,542		)		(113,028		)	(26,592		)		115			(234,740		)
	Equity in net income of subsidiaries	(274,930		)		—				(479		)	(37,930		)		313,339			—
	Loss from continuing operations before income tax	(366,623		)		(3,542		)		(113,507		)	(64,522		)		313,454			(234,740		)
	Income tax benefit	28,347				—				12,600			(3		)		—			40,944
	Loss from continuing operations	(338,276		)		(3,542		)		(100,907		)	(64,525		)		313,454			(193,796		)
	Income from discontinued operations, net of tax	(5,426		)		—				12,530			(78,444		)		(115		)	(71,455		)
	Gain on sale of discontinued operations, net of tax	152,748				—				(9,109		)	(55,641		)		—			87,998
	Net income (loss)	(190,954		)		(3,542		)		(97,486		)	(198,610		)		313,339			(177,253		)
	Net loss attributable to non-controlling interest	—								—			—				1,614			1,614
	Net loss attributable to Magnum Hunter Resources Corporation	(190,954		)		(3,542		)		(97,486		)	(198,610		)		314,953			(175,639		)
	Dividends on preferred stock	(26,603		)		—				—			(15,431		)		—			(42,034		)
	Net income (loss) attributable to common shareholders	$	(217,557	)		$	(3,542	)		$	(97,486	)	$	(214,041	)		$	314,953		$	(217,673	)
	Nine Months Ended September 30, 2012
	Magnum Hunter				PRC Williston, Inc.				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources								Subsidiaries			Subsidiaries							Resources
	Corporation																		Corporation
																			Consolidated
Revenues	$	630			$	6,065			$	81,721		$	10,183			$	(3,675	)	$	94,924
Expenses	56,379				7,923				95,211			10,241				(3,204		)	166,550
Income (loss) from continuing operations before equity in net income of subsidiaries	(55,749		)		(1,858		)		(13,490		)	(58		)		(471		)	(71,626		)
Equity in net income of subsidiaries	(6,847		)		—							(8,573		)		15,420			—
Income (loss) from continuing operations before income tax	(62,596		)		(1,858		)		(13,490		)	(8,631		)		14,949			(71,626		)
Income tax benefit	—				—				3,620			5,523				—			9,143
Income (loss) from continuing operations	(62,596		)		(1,858		)		(9,870		)	(3,108		)		14,949			(62,483		)
Income from discontinued operations, net of tax	—				—				(5,111		)	7,943				—			2,832
Gain on sale of discontinued operations, net of tax	—				—				2,224			—				—			2,224
Net income (loss)	(62,596		)		(1,858		)		(12,757		)	4,835				14,949			(57,427		)
Net income attributable to non-controlling interest	—				—				—			—				(71		)	(71		)
Net income (loss) attributable to Magnum Hunter Resources Corporation	(62,596		)		(1,858		)		(12,757		)	4,835				14,878			(57,498		)
Dividends on preferred stock	(15,179		)		—				—			(7,501		)		—			(22,680		)
Net income (loss) attributable to common shareholders	$	(77,775	)		$	(1,858	)		$	(12,757	)	$	(2,666	)		$	14,878		$	(80,178	)
Schedule of condensed consolidating statements of cash flows	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Cash Flows
	(in thousands)
		Nine Months Ended September 30, 2013
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	Cash flow from operating activities	$	(264,051	)		$	882			$	236,112		$	106,254			$	—		$	79,197
	Cash flow from investing activities	422,056				(882		)		(245,179		)	(131,172		)		—			44,823
	Cash flow from financing activities	(152,265		)		—				2,105			23,893				—			(126,267		)
	Effect of exchange rate changes on cash	—				—				—			(93		)		—			(93		)
	Net increase (decrease) in cash	5,740				—				(6,962		)	(1,118		)		—			(2,340		)
	Cash at beginning of period	26,872				—				(4,187		)	34,938				—			57,623
	Cash at end of period	$	32,612			$	—			$	(11,149	)	$	33,820			$	—		$	55,283
		Nine Months Ended September 30, 2012
		Magnum Hunter				PRC Williston, LLC				100% Owned Guarantor			Non Guarantor				Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources								Subsidiaries			Subsidiaries							Resources
		Corporation																		Corporation
																				Consolidated
	Cash flow from operating activities	$	(304,365	)		$	48			$	209,620		$	141,516			$	—		$	46,819
	Cash flow from investing activities	(308,625		)		(48		)		(207,814		)	(277,200		)		—			(793,687		)
	Cash flow from financing activities	612,579				—				(2,346		)	143,928				—			754,161
	Effect of exchange rate changes on cash												(146		)		—			(146		)
	Net increase (decrease) in cash	(411		)		—				(540		)	8,098				—			7,147
	Cash at beginning of period	18,758				—				(546		)	(3,361		)		—			14,851
	Cash at end of period	$	18,347			$	—			$	(1,086	)	$	4,737			$	—		$	21,998

SUMMARY_OF_SIGNIFICANT_ACCOUNT3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	3 Months Ended		9 Months Ended
Share data in Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Inventory	'	'	'	'	'
Materials and supplies	$11,029,000	'	$11,029,000	'	$8,066,000
Commodities	928,000	'	928,000	'	1,096,000
Inventory	11,957,000	'	11,957,000	'	9,162,000
Materials included in other long term assets	0	'	0	'	3,464,000
Property subject to or available for operating lease, net	16,500,000	'	16,500,000	'	'
Capital leases, future minimum payments receivable, current	5,500,000	'	5,500,000	'	'
Capital leases, future minimum payments receivable, thereafter	1,400,000	'	1,400,000	'	'
Depletion, depreciation, amortization and accretion	28,293,000	15,146,000	71,956,000	42,199,000	'
Weighted average amortization period	'	'	'8 years 6 months 15 days	'	'
Oil and natural gas sales	54,018,000	29,983,000	138,242,000	78,532,000	'
Amounts reclassified from accumulated other comprehensive income	-8,262,000	0	-8,262,000	0	'
Exploration Expense	'	'	'	'	'
Geological and Geophysical Expense	354,000	345,000	1,008,000	481,000	'
Exploration Expense	40,123,000	3,299,000	73,402,000	18,143,000	'
Impairment of proved oil and gas properties	0	0	9,968,000	0	'
Williston Basin	'	'	'	'	'
Exploration Expense	'	'	'	'	'
Leasehold impairments	38,829,000	2,954,000	71,454,000	12,687,000	'
Appalachian	'	'	'	'	'
Exploration Expense	'	'	'	'	'
Leasehold impairments	940,000	0	940,000	4,975,000	'
Oil [Member]	'	'	'	'	'
Inventory	'	'	'	'	'
Oil and natural gas sales	39,119,000	21,319,000	97,813,000	51,416,000	'
Natural Gas	'	'	'	'	'
Inventory	'	'	'	'	'
Oil and natural gas sales	9,805,000	8,389,000	31,068,000	26,743,000	'
Crude Oil and NGL [Member]	'	'	'	'	'
Inventory	'	'	'	'	'
Oil and natural gas sales	5,094,000	275,000	9,361,000	373,000	'
Penn Virginia	'	'	'	'	'
Inventory	'	'	'	'	'
Cash consideration received	'	'	50,600,000	'	'
Midstream and Marketing	'	'	'	'	'
Inventory	'	'	'	'	'
Depletion, depreciation, amortization and accretion	3,173,000	1,195,000	9,142,000	2,853,000	'
Oil and natural gas sales	0	0	0	0	'
Exploration Expense	'	'	'	'	'
Impairment of proved oil and gas properties	0	'	0	'	'
Dilutive	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Outstanding potential antidilutive securities (in shares)	'	'	13,878	2,493	'
Dilutive | Common stock options	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Outstanding potential antidilutive securities (in shares)	'	'	13,878	2,424	'
Dilutive | Warrants	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Outstanding potential antidilutive securities (in shares)	'	'	0	69	'
Antidilutive	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Outstanding potential antidilutive securities (in shares)	'	'	46,072	26,707	'
Antidilutive | Common stock options	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Outstanding potential antidilutive securities (in shares)	'	'	4,480	13,330	'
Antidilutive | Warrants	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Outstanding potential antidilutive securities (in shares)	'	'	30,407	13,376	'
Antidilutive | Series E Preferred Stock	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Outstanding potential antidilutive securities (in shares)	'	'	11,185	0	'
PRC Williston, LLC (PRC)	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Consolidated controlling interest (as a percent)	87.50%	'	87.50%	'	87.50%
Eureka Hunter Holdings, LLC	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Consolidated controlling interest (as a percent)	57.38%	'	57.38%	'	61.00%
Energy Hunter Securities, Inc. (EHS)	'	'	'	'	'
Exploration Expense	'	'	'	'	'
Net capital	'	'	'	'	61,000,000
Aggregate indebtedness	'	'	'	'	$39,000,000
Eureka Hunter Pipeline, LLC	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Consolidated entities ownership percentage in entity (as a percent)	100.00%	'	100.00%	'	'
Tran Tex Hunter, LLC	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Consolidated entities ownership percentage in entity (as a percent)	100.00%	'	100.00%	'	'
Eureka Hunter Land, LLC	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Consolidated entities ownership percentage in entity (as a percent)	100.00%	'	100.00%	'	'
Minimum	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Property, Plant and Equipment, Useful Life	'	'	'5 years	'	'
Maximum	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Property, Plant and Equipment, Useful Life	'	'	'20 years	'	'
Assets Held under Capital Leases [Member]	'	'	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'
Property, Plant and Equipment, Useful Life	'	'	'3 years	'	'

FAIR_VALUE_OF_FINANCIAL_INSTRU2

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) (Recurring, USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Level 1

Level 1

Level 1

Level 1

Level 1

Level 1

Level 1

Level 1

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Maximum

Commodity derivative assets

Commodity derivative assets

Convertible security derivative assets

Convertible security derivative assets

Convertible preferred stock derivative liabilities

Convertible preferred stock derivative liabilities

Commodity derivative assets

Commodity derivative assets

Convertible security derivative assets

Convertible security derivative assets

Convertible preferred stock derivative liabilities

Convertible preferred stock derivative liabilities

Commodity derivative assets

Commodity derivative assets

Convertible security derivative assets

Convertible security derivative assets

Convertible preferred stock derivative liabilities

Convertible preferred stock derivative liabilities

Level 3

Convertible preferred stock derivative liabilities

Fair Value of Financial Instruments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit spread rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15.90%

Total enterprise value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$544,000,000

'

'

Assumptions and methodology used for calculating fair value of assets and liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years 4 months 24 days

'

'

'

'

Risk-free interest rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.91%

'

'

'

'

Estimated volatility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40.00%

'

'

'

25.00%

Dividend

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.00%

'

'

'

'

GreenHunter stock price at end of period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1.13

'

'

'

'

Fair value measurements on a Recurring Basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available for sale securities

1,825,000

1,958,000

'

'

'

'

'

'

0

0

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

Derivative assets

'

'

0

'

0

0

'

'

'

'

1,392,000

4,882,000

0

0

'

'

'

'

0

'

79,000

264,000

'

'

'

Total assets at fair value

1,825,000

1,958,000

'

'

'

'

'

'

1,392,000

4,882,000

'

'

'

'

'

'

79,000

264,000

'

'

'

'

'

'

'

Derivative liabilities

'

'

0

0

'

'

0

0

'

'

6,750,000

7,477,000

'

'

0

0

'

'

0

0

'

'

75,160,000

43,548,000

'

Total liabilities at fair value

$0

$0

'

'

'

'

'

'

$6,750,000

$7,477,000

'

'

'

'

'

'

$75,160,000

$43,548,000

'

'

'

'

'

'

'

FAIR_VALUE_OF_FINANCIAL_INSTRU3

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 2) (Level 3, USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013
Preferred Stock Embedded Derivative Liability | Embedded Derivatives, Liabilities	'
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'
31-Dec-12	($43,548)
Issuance of derivative liability	-10,803
Decrease in fair value recognized in other income (expense)	-20,809
30-Sep-13	-75,160
Embedded Derivatives, Assets | Convertible Security Embedded Derivative Financial Instruments [Member]	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'
Fair value at December 31, 2012 Convertible Security Embedded Derivative Asset	264
Issuance of derivative liability Convertible Security Embedded Derivative Asset	0
Decrease in fair value recognized in other (expense) Convertible Security Embedded Derivative Asset	-185
Fair value as of September 30, 2013 Convertible Security Embedded Derivative Asset	$79

FAIR_VALUE_OF_FINANCIAL_INSTRU4

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 4) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Level 2 | Senior Notes	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of senior notes	$622,300		$613,500
Level 2 | Carrying Amount | Senior Notes	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of senior notes	597,216	[1]	597,212	[1]
Level 2 | Estimated Fair Value | Senior Notes	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of senior notes	622,320	[1]	613,500	[1]
Level 3 | Carrying Amount | Senior Revolving Credit Facility	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of senior notes	90,000	[2]	225,000	[2]
Level 3 | Carrying Amount | Eureka Hunter Pipeline, LLC second lien term loan	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of senior notes	50,000	[3]	50,000	[3]
Level 3 | Carrying Amount | Equipment note payable	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of senior notes	16,059	[3]	18,548	[3]
Level 3 | Estimated Fair Value | Senior Revolving Credit Facility	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of senior notes	90,000	[2]	225,000	[2]
Level 3 | Estimated Fair Value | Eureka Hunter Pipeline, LLC second lien term loan	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of senior notes	59,832	[3]	58,550	[3]
Level 3 | Estimated Fair Value | Equipment note payable	'		'
Carrying amounts and fair values of long-term debt	'		'
Fair value of senior notes	$15,412	[3]	$17,450	[3]
[1]	The fair value of the Company's Senior Notes is based on quoted market prices available to us for those periods.
[2]	The carrying value of the MHR Senior Revolving Credit Facility approximates fair value as it is subject to short-term floating interest rates that approximate the rates available to us at such date.
[3]	The fair value of each of (a) Eureka Hunter Pipeline's second lien term loan and (b) the equipment notes payable is the estimated cost to acquire the debt, including a credit spread for the difference between the issue rate and the period end market rate.

FINANCIAL_INSTRUMENTS_AND_DERI2

FINANCIAL INSTRUMENTS AND DERIVATIVES (Details)	Sep. 30, 2013
	MMBTU
Period | Collars | Natural Gas	'
Derivative Instruments	'
Commodity derivatives contract units per day (MMBTU)	12,500	[1]
Period | Collars | Natural Gas | Minimum price per unit	'
Derivative Instruments	'
Price per unit	4.5	[2]
Period | Collars | Natural Gas | Maximum price per unit	'
Derivative Instruments	'
Price per unit	5.96	[2]
Period | Collars | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	2,763
Period | Collars | Crude Oil | Minimum price per unit	'
Derivative Instruments	'
Price per unit	81.38	[2]
Period | Collars | Crude Oil | Maximum price per unit	'
Derivative Instruments	'
Price per unit	97.61	[2]
Period | Swaps | Natural Gas	'
Derivative Instruments	'
Commodity derivatives contract units per day (MMBTU)	25,500
Price per unit	3.64
Period | Swaps | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	5,450
Price per unit	92.72
Period | Ceilings purchased (call) | Natural Gas	'
Derivative Instruments	'
Commodity derivatives contract units per day (MMBTU)	10,000
Price per unit	6
Period | Ceilings purchased (call) | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	2,250
Price per unit	100
Period | Traditional three-way collars | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	2,000	[3]
Price per unit	80	[4]
Period | Traditional three-way collars | Crude Oil | Minimum price per unit	'
Derivative Instruments	'
Price per unit	60.63	[4]
Period | Traditional three-way collars | Crude Oil | Maximum price per unit	'
Derivative Instruments	'
Price per unit	100	[4]
Period | Conservative three-way collars | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	763	[5]
Price per unit	91.25	[6]
Period | Conservative three-way collars | Crude Oil | Minimum price per unit	'
Derivative Instruments	'
Price per unit	65	[6]
Period | Conservative three-way collars | Crude Oil | Maximum price per unit	'
Derivative Instruments	'
Price per unit	101.25	[6]
Period | Floors purchased (put) | Natural Gas	'
Derivative Instruments	'
Commodity derivatives contract units per day (MMBTU)	10,000
Price per unit	4.25
Period | Floors purchased (put) | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	1,750
Price per unit	90
Period | Floors sold (put) | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	5,438
Price per unit	76.03
Jan 2014 - Dec 2014 | Collars | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	663
Jan 2014 - Dec 2014 | Collars | Crude Oil | Minimum price per unit	'
Derivative Instruments	'
Price per unit	85	[2]
Jan 2014 - Dec 2014 | Collars | Crude Oil | Maximum price per unit	'
Derivative Instruments	'
Price per unit	91.25	[2]
Jan 2014 - Dec 2014 | Swaps | Natural Gas	'
Derivative Instruments	'
Commodity derivatives contract units per day (MMBTU)	10,000
Price per unit	4.13
Jan 2014 - Dec 2014 | Ceilings purchased (call) | Natural Gas	'
Derivative Instruments	'
Commodity derivatives contract units per day (MMBTU)	10,000
Price per unit	6.15
Jan 2014 - Dec 2014 | Ceilings sold (call) | Natural Gas	'
Derivative Instruments	'
Commodity derivatives contract units per day (MMBTU)	26,000
Price per unit	5.47
Jan 2014 - Dec 2014 | Traditional three-way collars | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	4,000
Price per unit	85	[4]
Jan 2014 - Dec 2014 | Traditional three-way collars | Crude Oil | Minimum price per unit	'
Derivative Instruments	'
Price per unit	64.94	[4]
Jan 2014 - Dec 2014 | Traditional three-way collars | Crude Oil | Maximum price per unit	'
Derivative Instruments	'
Price per unit	102.5	[4]
Jan 2014 - Dec 2014 | Floors sold (put) | Natural Gas	'
Derivative Instruments	'
Commodity derivatives contract units per day (MMBTU)	10,000
Price per unit	3.75
Jan 2014 - Dec 2014 | Floors sold (put) | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	663
Price per unit	65
Jan 2015 - Dec 2015 | Collars | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	259
Jan 2015 - Dec 2015 | Collars | Crude Oil | Minimum price per unit	'
Derivative Instruments	'
Price per unit	85	[2]
Jan 2015 - Dec 2015 | Collars | Crude Oil | Maximum price per unit	'
Derivative Instruments	'
Price per unit	91.25	[2]
Jan 2015 - Dec 2015 | Ceilings sold (call) | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	1,570
Price per unit	120
Jan 2015 - Dec 2015 | Floors sold (put) | Crude Oil	'
Derivative Instruments	'
Commodity derivatives contract units per day (Bbls)	259
Price per unit	70
[1]	The fair value of the Company's Senior Notes is based on quoted market prices available to us for those periods.
[2]	A collar is a sold call and a purchased put. Some collars are "costless" collars with the premiums netting to approximately zero.
[3]	The carrying value of the MHR Senior Revolving Credit Facility approximates fair value as it is subject to short-term floating interest rates that approximate the rates available to us at such date.
[4]	These three-way collars are a combination of three options: a sold call, a purchased put and a sold put.
[5]	The fair value of each of (a) Eureka Hunter Pipeline's second lien term loan and (b) the equipment notes payable is the estimated cost to acquire the debt, including a credit spread for the difference between the issue rate and the period end market rate.
[6]	These three-way collars are a combination of three options: a sold call, a purchased call and a sold put.

FINANCIAL_INSTRUMENTS_AND_DERI3

FINANCIAL INSTRUMENTS AND DERIVATIVES (Details 2) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value	'	'
Gross Derivative Assets	$1,471	$5,146
Gross Derivative Liabilities	-81,910	-51,025
Commodity	'	'
Derivatives, Fair Value	'	'
Gross Derivative Assets	1,392	4,882
Gross Derivative Liabilities	-6,750	-7,477
Financial	'	'
Derivatives, Fair Value	'	'
Gross Derivative Assets	79	264
Gross Derivative Liabilities	-75,160	-43,548
Derivative assets | Commodity	'	'
Derivatives, Fair Value	'	'
Gross Derivative Assets	1,000	4,882
Derivative assets | Financial	'	'
Derivatives, Fair Value	'	'
Gross Derivative Assets	79	264
Derivative assets - long term | Commodity	'	'
Derivatives, Fair Value	'	'
Gross Derivative Assets	392	0
Derivative liabilities | Commodity	'	'
Derivatives, Fair Value	'	'
Gross Derivative Liabilities	-5,913	-3,501
Derivative liabilities - long term | Commodity	'	'
Derivatives, Fair Value	'	'
Gross Derivative Liabilities	-837	-3,976
Derivative liabilities - long term | Financial	'	'
Derivatives, Fair Value	'	'
Gross Derivative Liabilities	($75,160)	($43,548)

FINANCIAL_INSTRUMENTS_AND_DERI4

FINANCIAL INSTRUMENTS AND DERIVATIVES (Details 3) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Summary of net gain (loss) on derivative contracts	'	'	'	'
Realized gain (loss)	($6,582)	$2,224	($6,887)	$7,962
Unrealized gain (loss)	-22,971	-12,375	-23,757	1,094
Net gain (loss)	($29,553)	($10,151)	($30,644)	$9,056

DIVESTITURES_AND_DISCONTINUED_2

DIVESTITURES AND DISCONTINUED OPERATIONS (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

0 Months Ended

3 Months Ended

1 Months Ended

9 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Feb. 17, 2012

Feb. 29, 2012

Dec. 31, 2011

Feb. 29, 2012

Feb. 17, 2012

Sep. 26, 2013

Sep. 30, 2013

Apr. 24, 2013

Sep. 30, 2013

Sep. 30, 2013

GreenHunter Resources, Inc.

GreenHunter Resources, Inc.

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production, Inc.

Hunter Disposal, LLC

Hunter Disposal, LLC

Hunter Disposal, LLC

Hunter Disposal, LLC

Hunter Disposal, LLC

Hunter Disposal, LLC

Williston Hunter Inc

Williston Hunter Inc

Eagle Ford Hunter, Inc.

Eagle Ford Hunter, Inc.

Eagle Ford Hunter, Inc.

GreenHunter Resources, Inc.

GreenHunter Resources, Inc.

GreenHunter Resources, Inc.

GreenHunter Resources, Inc.

GreenHunter Resources, Inc.

Minimum

Series C Preferred Stock

Series C Preferred Stock

Discontinued operations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total consideration received

'

'

'

'

'

'

'

'

'

'

$9,300,000

'

'

'

'

'

'

$422,100,000

'

'

Cash consideration received

'

'

'

'

'

'

'

'

'

'

2,200,000

'

'

'

'

32,500,000

'

379,800,000

'

'

Consideration received, number of shares of common stock received

'

'

'

'

'

'

'

'

'

'

1,846,722

'

'

'

'

'

'

10,000,000

'

'

Consideration received, value of common stock received

'

'

'

'

'

'

'

'

'

'

2,600,000

'

'

'

'

'

'

42,300,000

'

'

Discontinued Operation, Amount of Adjustment to Prior Period Gain (Loss) on Disposal, Net of Tax

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-22,000,000

Equity ownership interest sold (as a percent)

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

Consideration received, value of common stock (price per share)

'

'

'

'

'

'

'

'

'

'

$1.79

'

'

'

'

'

'

'

'

'

Consideration received, number of shares of preferred stock received

'

'

'

'

'

'

'

'

'

'

88,000

'

'

'

'

'

'

'

'

'

Cumulative dividend rate for cumulative preferred stock (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

Consideration received, value of preferred stock received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,900,000

'

'

'

'

'

Acquirer preferred stock value per share (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$25

'

'

'

'

'

Consideration received, value of promissory notes convertible into common stock

'

'

'

'

'

'

'

'

'

'

2,200,000

'

'

'

'

'

'

'

'

'

Consideration received, value of promissory notes convertible into common stock (in shares)

'

'

'

'

'

'

'

'

'

'

'

880,000

'

'

'

'

'

'

'

'

Consideration received, value of promissory notes convertible into common stock, conversion price (in dollars per share)

'

'

'

'

'

'

'

'

'

'

$2.50

'

'

'

'

'

'

'

'

'

Fair value of embedded derivative asset

'

'

'

'

79,000

264,000

'

'

'

'

405,000

'

'

'

'

'

'

'

'

'

Adjusted cash proceeds for changes in working capital to reflect the effective date of the sale

'

'

'

'

'

'

'

'

'

'

'

'

783,000

'

'

'

'

'

'

'

Results reclassified to discontinued operations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

13,203,000

32,997,000

81,616,000

91,728,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expenses

-107,958,000

[1]

-33,997,000

[1]

-166,196,000

[1]

-90,216,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other income (expense)

3,621,000

-76,000

6,777,000

3,212,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income tax benefit (expense)

10,580,000

[2]

-26,000

[2]

6,348,000

[2]

-1,892,000

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income (loss) from discontinued operations, net of tax

-80,554,000

[3]

-1,102,000

[3]

-71,455,000

[3]

2,832,000

[3]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain (loss) on disposal of discontinued operations, net of tax

-84,454,000

[4]

0

[4]

87,998,000

[4]

2,224,000

[4]

'

'

-84,500,000

'

-84,500,000

'

'

'

'

'

'

'

-38,100,000

'

172,500,000

'

Income (loss) from discontinued operations, net of taxes

-165,008,000

-1,102,000

16,543,000

5,056,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Alternative minimum tax charge from the sale

'

'

'

'

'

'

'

'

'

1,300,000

'

'

'

'

'

'

'

'

'

'

Impairment expense from discontinued operations

'

'

'

'

'

'

72,500,000

78,500,000

'

'

'

'

'

'

'

'

'

'

'

'

Disposal Group Including Discontinued Operations Exploration Expense

'

'

'

'

'

'

18,000,000

19,600,000

'

'

'

'

'

'

'

'

'

'

'

'

Income tax associated with discontinued operations

'

'

'

'

'

'

'

'

'

($6,600,000)

'

'

'

'

'

'

'

'

'

'

[1]

Includes impairment expense of $72.5 million and $78.5 million for the three and nine months ended September 30, 2013, respectively, and exploration expense of $18.0 million and $19.6 million for the three and nine months ended September 30, 2013, respectively relating to the discontinued operations of MHP and WHI Canada, which is recorded in income (loss) from discontinued operations.

[2]

In addition, the Company recognized an alternative minimum tax charge of $1.3 million in connection with the Eagle Ford Hunter sale.

[3]

[4]

Income tax expense associated with gain/(loss) on sale of discontinued operations was $6.6 million for the nine months ended September 30, 2013.

DIVESTITURES_AND_DISCONTINUED_3

DIVESTITURES AND DISCONTINUED OPERATIONS (Sale of Eagle Ford Hunter) (Details) (USD $)

3 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Apr. 24, 2013

Sep. 30, 2013

Sep. 30, 2013

Apr. 24, 2013

Sep. 30, 2013

Sep. 30, 2013

Eagle Ford Hunter, Inc.

Eagle Ford Hunter, Inc.

Penn Virginia

Senior Revolving Credit Facility

Minimum

Maximum

Eagle Ford Hunter, Inc.

Eagle Ford Hunter, Inc.

Eagle Ford Hunter, Inc.

Discontinued operations

'

'

'

'

'

'

'

'

'

'

Total consideration received

'

'

'

'

$422,100,000

'

'

'

'

'

Cash consideration received

'

'

'

'

379,800,000

'

50,600,000

'

'

'

Noncash or Part Noncash Divestiture Amount of Consideration Received Common Stock Shares

'

'

'

'

10,000,000

'

'

'

'

'

Noncash or Part Noncash Divestiture Amount of Consideration Received Common Stock Value

'

'

'

'

42,300,000

'

'

'

'

'

Sale of Stock, Price Per Share

'

'

'

'

$4.23

'

'

'

'

'

Gain (loss) on disposal of discontinued operations, net of tax

-84,454,000

[1]

0

[1]

87,998,000

[1]

2,224,000

[1]

'

172,500,000

8,300,000

'

'

'

Discontinued Operation, Amount of Adjustment to Prior Period Gain (Loss) on Disposal, Net of Tax

'

'

'

'

'

'

'

'

22,000,000

33,000,000

Extinguishment of debt

'

'

'

'

'

'

'

$325,000,000

'

'

[1]

Income tax expense associated with gain/(loss) on sale of discontinued operations was $6.6 million for the nine months ended September 30, 2013.

ASSET_RETIREMENT_OBLIGATIONS_D

ASSET RETIREMENT OBLIGATIONS (Details) (USD $)	9 Months Ended
	Sep. 30, 2013		Dec. 31, 2012
Summary of asset retirement obligation	'		'
Asset retirement obligation at beginning of period	$30,680,000		'
Assumed in acquisitions	17,000		'
Liabilities incurred	209,000		'
Liabilities settled	-98,000		'
Liabilities sold	-2,429,000		'
Accretion expense	1,824,000		'
Revisions in estimated liabilities	1,935,000	[1]	'
Reclassified as liabilities associated with assets held for sale	-11,148,000		'
Effect of foreign currency translation	-73,000		'
Asset retirement obligation at end of period	20,917,000		'
Less: current portion (included in other liabilities)	-1,015,000		'
Asset retirement obligation at end of period	19,902,000		28,322,000
Revision of estimate due to change in assumptions	$1,500,000		'
[1]	$1.5 million of the revisions in estimated liabilities is related to change in assumptions used with respect to certain wells in the Williston Basin in North Dakota.

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)	9 Months Ended	12 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
Total long-term debt, outstanding	$753,275,000	$890,760,000
Less: current portion	-4,144,000	-3,991,000
Total long-term debt obligations, net of current portion	749,131,000	886,769,000
Senior Notes Payable due May 15, 2020	'	'
Debt Instrument [Line Items]	'	'
Total long-term debt, outstanding	597,216,000	597,212,000
Long-term debt, stated interest rate	9.75%	9.75%
Long-term debt, unamortized discount	2,800,000	2,800,000
Various equipment and real estate notes payable with maturity January 2015 - April 2021	'	'
Debt Instrument [Line Items]	'	'
Total long-term debt, outstanding	16,059,000	18,548,000
Long-term debt, stated interest rate, minimum	4.25%	4.25%
Long-term debt, stated interest rate, maximum	5.70%	5.70%
Second lien term loan due August 16,2018	'	'
Debt Instrument [Line Items]	'	'
Total long-term debt, outstanding	50,000,000	50,000,000
Second lien term loan due August 16,2018 | Eureka Hunter Pipeline, LLC	'	'
Debt Instrument [Line Items]	'	'
Long-term debt, stated interest rate	12.50%	12.50%
Senior revolving credit facility due April 13, 2016	'	'
Debt Instrument [Line Items]	'	'
Total long-term debt, outstanding	$90,000,000	$225,000,000
Long-term debt, stated interest rate	2.96%	3.56%

LONGTERM_DEBT_Details_2

LONG-TERM DEBT (Details 2) (USD $)	Sep. 30, 2013
In Thousands, unless otherwise specified
Summary of approximate annual maturities of debt	'
2013	$1,034
2014	4,149
2015	8,313
2016	92,563
2017	0
Thereafter	650,000
Total long-term debt, outstanding	$756,059

LONGTERM_DEBT_Details_3

LONG-TERM DEBT (Details 3) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Debt Instrument [Line Items]	'	'	'	'	'
Long-term debt	$753,275,000	'	$753,275,000	'	$890,760,000
Interest expense incurred on debt	14,578,000	13,766,000	49,542,000	29,870,000	'
Amortization and write-off of deferred financing costs	1,111,000	639,000	3,661,000	10,725,000	'
Total Interest Expense	15,689,000	14,405,000	53,203,000	40,595,000	'
Senior Revolving Credit Facility	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Line of credit facility, maximum borrowing capacity	750,000,000	'	750,000,000	'	'
Credit facility amount outstanding	90,000,000	'	90,000,000	'	225,000,000
Line of credit facility, commitment fee percentage	'	'	0.50%	'	'
Debt instrument, additional interest rate upon payment default	'	'	2.00%	'	'
Debt instrument, maximum amount of dividends on preferred stock to be paid out per year	'	'	45,000,000	'	'
Ratio of consolidated current assets to consolidated current liabilities	'	'	1	'	'
Percentage of the value of the proved oil and natural gas properties	'	'	80.00%	'	'
Borrowing base	265,000,000	'	265,000,000	'	'
Senior Revolving Credit Facility | Quarter Ended June 30, 2013 and September 30, 2013	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Ratio of earnings before interest, taxes, depreciation, depletion, amortization and exploration expenses, or “EBITDAX”, to interest expense	'	'	2	'	'
Senior Revolving Credit Facility | Fiscal Quarter Ending December 31, 2013	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Ratio of earnings before interest, taxes, depreciation, depletion, amortization and exploration expenses, or “EBITDAX”, to interest expense	'	'	2.25	'	'
Senior Revolving Credit Facility | Fiscal Quarter Ending March 31, 2014	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Ratio of earnings before interest, taxes, depreciation, depletion, amortization and exploration expenses, or “EBITDAX”, to interest expense	'	'	2.5	'	'
Ratio of senior debt to EBITDAX	'	'	2	'	'
Senior Revolving Credit Facility | Fiscal Quarters Ending June 30, 2014 and September 30, 2014	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Ratio of total debt to EBITDAX	'	'	4.5	'	'
Senior Revolving Credit Facility | Fiscal Quarter Ended December 31, 2014	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Ratio of total debt to EBITDAX	'	'	4.25	'	'
Senior Revolving Credit Facility | Minimum | Option 1	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Debt instrument, additional interest rate	'	'	1.50%	'	'
Senior Revolving Credit Facility | Maximum | Option 1	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Debt instrument, additional interest rate	'	'	2.25%	'	'
Senior Revolving Credit Facility | Federal Funds Rate | Option 1	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Debt instrument, basis spread on variable rate	0.50%	'	0.50%	'	'
Senior Revolving Credit Facility | LIBOR | Option 1	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Debt instrument, basis spread on variable rate	1.00%	'	1.00%	'	'
Senior Revolving Credit Facility | BBA LIBOR | Minimum | Option 2	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Debt instrument, basis spread on variable rate	2.50%	'	2.50%	'	'
Senior Revolving Credit Facility | BBA LIBOR | Maximum | Option 2	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Debt instrument, basis spread on variable rate	3.25%	'	3.25%	'	'
Letter of Credit | Senior Revolving Credit Facility	'	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'	'
Line of credit facility, maximum borrowing capacity	$10,000,000	'	$10,000,000	'	'

LONGTERM_DEBT_Details_4

LONG-TERM DEBT (Details 4) (USD $)

Aug. 07, 2013

Sep. 30, 2013

Aug. 07, 2013

Sep. 30, 2013

Aug. 06, 2013

Sep. 30, 2013

Sep. 30, 2013

Aug. 07, 2013

Aug. 06, 2013

Aug. 07, 2013

Aug. 06, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

In Millions, unless otherwise specified

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Period August 1, 2013 and Thereafter

All Subsidiaries Except Eureka Hunter Holdings, LLC

All Subsidiaries Except Eureka Hunter Holdings, LLC

All Subsidiaries Except Eureka Hunter Holdings, LLC

Minimum

Minimum

Maximum

Maximum

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Fiscal Year Ending December 31, 2013

Period January 1, 2014 and Thereafter

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Fiscal Quarter Ending March 31, 2014

Fiscal Period Ending December 31, 2014

Fiscal Quarter Ending September 30, 2013

Fiscal Quarter Ending December 31, 2013

Fiscal Period Starting March 31, 2014 and Thereafter

Eureka Hunter Holdings, LLC

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Eighteenth Amendment to Second Amended and Restated Credit Agreement

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Senior Revolving Credit Facility

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt to EBITDAX ratio

'

'

'

'

'

'

'

'

'

'

'

2

4.5

4.25

'

'

'

'

EBITDAX to interest expense ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

2.25

2.5

'

Investments in subsidiary (up to $32 million before December 31, 2013)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$32

Debt instrument covenant minimum borrowing base required to invest in subsidiary

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

75

Senior note basket after amendment

'

600

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior note basket prior to amendment

'

800

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment basket for unrestricted subsidiaries

'

'

'

'

7.5

12.5

7.5

'

'

'

'

'

'

'

'

'

'

'

Leasehold capital expenditures

'

'

'

40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base limit

$75

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument increase in basis points from amendment

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, basis spread on variable rate

'

'

'

'

'

'

'

250.00%

200.00%

325.00%

275.00%

'

'

'

'

'

'

'

SHAREBASED_COMPENSATION_Detail

SHARE-BASED COMPENSATION (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

0 Months Ended

In Thousands, except Share data, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Jan. 17, 2013

Jan. 17, 2013

Jan. 17, 2013

Jan. 17, 2013

Jul. 26, 2013

15-May-13

Jul. 26, 2013

15-May-13

Stock options and stock appreciation rights

Stock options and stock appreciation rights

Restricted stock

Restricted stock

Common stock options

Officers executives and employees

Officers executives and employees

Officers executives and employees

Board of directors

Officer

Officer

Officer

Officer

Stock Option 1

Stock Option 2

Common stock options

Common stock options

Share Based Compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares authorized under the 2006 Stock Incentive Plan

27,500,000

'

27,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares issued under the 2006 Stock Incentive Plan

4,525,928

'

4,525,928

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock options, granted

'

'

'

'

'

'

'

'

'

3,942,575

3,080,000

862,575

420,000

400,000

175,000

'

'

Options, grants in period, weighted average exercise price

'

'

'

'

'

'

'

'

'

$4.16

'

'

'

'

'

'

'

Expiration term

'

'

'

'

'

'

'

'

'

'

'10 years

'5 years

'10 years

'

'

'

'

Award vesting period

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

'

'3 years

'3 years

Vesting rights percentage

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Exercise Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$3.82

$3.40

Share Based Compensation Arrangement By Share-based Payment Award, Shares Vesting Immediately Upon Grant

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

25.00%

Share based compensation

$3,100

$2,200

$11,834

$14,759

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at beginning of period (in shares)

'

'

'

'

14,847,000

12,566,000

'

'

'

'

'

'

'

'

'

'

'

Granted (in shares)

'

'

'

'

4,938,000

4,854,000

'

'

'

'

'

'

'

'

'

'

'

Exercised (in shares)

'

'

'

'

-685,000

-843,000

'

'

'

'

'

'

'

'

'

'

'

Cancelled (in shares)

'

'

'

'

-742,000

-807,000

'

'

'

'

'

'

'

'

'

'

'

Outstanding at end of period (in shares)

'

'

'

'

18,358,000

15,770,000

'

'

'

'

'

'

'

'

'

'

'

Exercisable at end of period (in shares)

'

'

'

'

10,512,000

8,959,000

'

'

'

'

'

'

'

'

'

'

'

Weighted Average Exercise Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at beginning of period (in dollars per share)

'

'

'

'

$6.01

$5.64

'

'

'

'

'

'

'

'

'

'

'

Granted (in dollars per share)

'

'

'

'

$4.11

$6.05

'

'

'

'

'

'

'

'

'

'

'

Exercised (in dollars per share)

'

'

'

'

$2.95

$1.40

'

'

'

'

'

'

'

'

'

'

'

Cancelled (in dollars per share)

'

'

'

'

$6

$7.24

'

'

'

'

'

'

'

'

'

'

'

Outstanding at end of period (in dollars per share)

'

'

'

'

$5.61

$5.91

'

'

'

'

'

'

'

'

'

'

'

Exercisable at end of period (in dollars per share)

'

'

'

'

$5.86

$5.79

'

'

'

'

'

'

'

'

'

'

'

Non-vested Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-vested at beginning of period (in shares)

'

'

'

'

6,163,000

5,651,000

'

'

'

'

'

'

'

'

'

'

'

Granted (in shares)

'

'

'

'

4,938,000

4,854,000

'

'

'

'

'

'

'

'

'

'

'

Vested (in shares)

'

'

'

'

-2,867,000

-3,005,000

'

'

'

'

'

'

'

'

'

'

'

Cancelled (in shares)

'

'

'

'

-389,000

-688,000

'

'

'

'

'

'

'

'

'

'

'

Non-vested at end of period (in shares)

'

'

'

'

7,845,000

6,811,000

'

'

'

'

'

'

'

'

'

'

'

Additional disclosures

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecognized compensation cost

'

'

'

'

$12,900

$15,100

$66

$462

'

'

'

'

'

'

'

'

'

Weighted average period for recognition of compensation cost

'

'

'

'

'1 year 5 months 16 days

'

'2 months 1 day

'

'

'

'

'

'

'

'

'

'

Remaining contractual term

'

'

'

'

'6 years 5 months 1 day

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average fair value per option granted during the period (in dollars per share)

'

'

'

'

'

'

'

'

$2.52

[1]

'

'

'

'

'

'

'

'

Assumptions:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average stock price volatility

'

'

'

'

'

'

'

'

80.61%

[2],[3]

'

'

'

'

'

'

'

'

Weighted average risk free rate of return

'

'

'

'

'

'

'

'

0.78%

[2],[3]

'

'

'

'

'

'

'

'

Weighted average expected term

'

'

'

'

'

'

'

'

'4 years 7 months 24 days

[2],[3]

'

'

'

'

'

'

'

'

Estimated future forfeiture rate

'

'

2.45%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Calculated using the Black-Scholes fair value based method for service and performance based grants and the Lattice Model for market based grants.

[2]

The Company does not pay cash dividends on its common stock.

[3]

estimated future forfeiture rate is 2.45%.

SHAREHOLDERS_EQUITY_Details

SHAREHOLDERS’ EQUITY (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Aug. 26, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Exchangeable Common Stock

Common Stock

Common Stock

Depositary Shares

Class A Preferred Units

Class A Preferred Units

Class A Preferred Units

Class A Preferred Units

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Common Stock

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Class of Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares issued in connection with share-based compensation

'

'

157,271

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares of common stock issued upon exchange of MHR Exchangeco Corporation's exchangeable shares

'

'

'

'

505,835

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

506,000

Stock Issued, During Period, Shares, 401k Matching Contribution

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

221,170

Stock Issued During Period, Shares, Conversion of Convertible Securities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

684,950

Class of Warrant or Right, Warrants Issued

'

'

'

'

'

17,030,706

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Warrants Fair Value

'

'

'

'

'

$21,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends, ratio of warrants received per common stock

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Exercise Price of Warrants or Rights

'

'

'

'

'

'

8.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right, Redemption Price

'

'

'

'

'

0.001

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Class of Warrant or Right Number Of Days Notice Required For Redemption By Company

'

'

'30 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stocks issued (in Shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

216,068

'

'

'

'

'

'

'

'

Cumulative dividend rate for cumulative preferred stock (as a percent)

'

'

'

'

'

'

'

8.00%

'

'

'

'

'

'

'

'

'

'

8.00%

'

8.00%

'

'

8.00%

'

8.00%

'

Liquidation preference (in dollars per share)

'

'

'

'

'

'

'

$25

'

'

'

'

'

'

'

'

$50

'

$50

'

$50

$25,000

'

$25,000

'

$25,000

'

Proceeds from stock issuance

'

'

10,181,000

119,469,000

'

'

'

590,000

'

'

'

'

'

'

'

'

'

'

9,600,000

'

'

'

'

'

'

'

'

Approximate offering expenses

'

'

109,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,212,263

'

'

'

'

'

'

'

'

Conversion price (in dollars per share)

'

'

'

'

'

'

'

$8.50

'

'

'

'

'

'

'

'

'

'

'

'

'

$8.50

'

$8.50

'

'

'

Interest in share of Series E Preferred Stock per Depository Share

'

'

'

'

'

'

'

0.001

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued in connection with acquisition (in shares)

'

'

'

'

'

'

'

27,906

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consideration received, value of common stock (price per share)

'

'

'

'

'

'

'

$24.24

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock dividends

14,417,000

9,820,000

42,034,000

22,680,000

'

'

'

'

3,771,000

2,718,000

10,441,000

5,086,000

2,562,000

2,562,000

7,686,000

7,686,000

4,424,000

3,233,000

13,231,000

7,493,000

'

1,834,000

0

5,686,000

0

'

'

Accretion of the difference between the carrying value and the redemption value of preferred stock included in dividends

$1,826,000

$1,307,000

$4,990,000

$2,415,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

REDEEMABLE_PREFERRED_STOCK_Det

REDEEMABLE PREFERRED STOCK (Details) (USD $)	3 Months Ended		9 Months Ended						9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Mar. 21, 2012
					Level 3	Level 3	Series A Preferred Units	Series A Preferred Units	Series A Preferred Units	Series A Preferred Units	Series A Preferred Units
					Derivative Financial Instruments, Liabilities	Derivative Financial Instruments, Liabilities			Eureka Hunter Holdings, LLC	Eureka Hunter Holdings, LLC	Eureka Hunter Holdings, LLC
					Preferred Stock Embedded Derivative Liability	Preferred Stock Embedded Derivative Liability				Ridgeline Midstream Holdings, LLC	Ridgeline Midstream Holdings, LLC
Class of Stock [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Preferred stock, maximum purchase commitment pursuant to Unit Purchase Agreement	'	'	'	'	'	'	'	'	'	'	$200,000,000
Proceeds from sale of Series A convertible preferred units in Eureka Hunter Holdings, LLC	'	'	27,440,000	128,251,000	'	'	'	'	'	179,800,000	'
Preferred stock, shares issued	'	'	'	'	'	'	9,391,227	7,672,892	'	1,400,000	'
Subsidiary preferred units value	'	'	'	'	'	'	'	'	'	27,400,000	'
Ownership percentage	'	'	'	'	'	'	'	'	40.60%	'	'
Preferred stock issued as in-kind payment (in shares)	'	'	'	'	'	'	'	'	318,335	'	'
Preferred stock, dividends paid-in-kind	'	'	6,367,000	1,658,000	'	'	'	'	6,400,000	'	'
Embedded derivative, fair value	'	'	'	'	75,160,000	43,548,000	'	'	'	'	'
Accretion of the difference between the carrying value and the redemption value of preferred stock included in dividends	$1,826,000	$1,307,000	$4,990,000	$2,415,000	'	'	'	'	'	'	'

TAXES_Details

TAXES (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Income Tax Expense (Benefit), Continuing Operations [Abstract]	'	'	'	'
Deferred	($3,255)	$1,983	$40,944	$9,143
Income tax benefit	($3,255)	$1,983	$40,944	$9,143

TAXES_Disposal_Details

TAXES (Disposal) (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Discontinued operations	'	'	'	'
Deferred income tax expense (benefit)	$3,255,000	($1,983,000)	($40,944,000)	($9,143,000)
Williston Hunter Inc	'	'	'	'
Discontinued operations	'	'	'	'
Deferred income tax expense (benefit)	'	'	23,600,000	'
Magnum Hunter Resources Corporation	'	'	'	'
Discontinued operations	'	'	'	'
Deferred income tax expesne in discontinued operations	'	'	17,400,000	'
Foreign Tax Authority	'	'	'	'
Discontinued operations	'	'	'	'
Deferred income tax expense (benefit)	'	'	($17,200,000)	'

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (USD $)	3 Months Ended				9 Months Ended
	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012		Dec. 31, 2012
Related Party Transaction	'		'		'		'		'
Related Party Transaction Rental Agreement Term	'		'		'5 years		'		'
GreenHunter Resources, Inc.	'		'		'		'		'
Related Party Transaction	'		'		'		'		'
Loss related to investment	($24,000)	[1]	$97,000	[1]	$653,000	[1]	$299,000	[1]	'
Fair value of embedded derivative asset	79,000		'		79,000		'		264,000
GreenHunter Resources, Inc. | Eagle Ford Hunter, Triad Hunter LLC, Inc and Viking International Resources, Inc.	'		'		'		'		'
Related Party Transaction	'		'		'		'		'
Prepaid Expense	64,748		'		64,748		'		0
Accounts payable, related parties	11,541		'		11,541		'		0
GreenHunter Resources, Inc. | Water disposal costs	'		'		'		'		'
Related Party Transaction	'		'		'		'		'
Related party expenses	623,000	[2]	618,000	[2]	2,069,000	[2]	1,600,000	[2]	'
GreenHunter Resources, Inc. | Equipment Rental Expense	'		'		'		'		'
Related Party Transaction	'		'		'		'		'
Related party expenses	95,000	[2]	244,000	[2]	167,000	[2]	875,000	[2]	'
GreenHunter Resources, Inc. | Interest Income from Note Receivable	'		'		'		'		'
Related Party Transaction	'		'		'		'		'
Drilling revenues	51,000	[1]	55,000	[1]	159,000	[1]	110,000	[1]	'
Pilatus Hunter	'		'		'		'		'
Related Party Transaction	'		'		'		'		'
Percentage of owned in subsidiary	'		'		100.00%		'		'
Pilatus Hunter | Airplane Rental Expenses	'		'		'		'		'
Related Party Transaction	'		'		'		'		'
Related party expenses	26,000	[3]	0	[3]	94,000	[3]	81,000	[3]	'
Alpha Hunter Drilling Llc | Drilling Revenues	'		'		'		'		'
Related Party Transaction	'		'		'		'		'
Drilling revenues	'		359,000	[4]	'		359,000	[4]	'
Executive Officer | Corporate Apartment Rental	'		'		'		'		'
Related Party Transaction	'		'		'		'		'
Related party expenses	0	[5]	5,000	[5]	0	[5]	23,000	[5]	'
Chief Executive Officer	'		'		'		'		'
Related Party Transaction	'		'		'		'		'
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	'		'		4.00%		'		'
Related Party Transaction, Shares Issued for Acquisition of Assets	'		'		622,641		'		'
Related Party Transaction, Cash Paid for Acquisition of Assets	'		'		46,000,000		'		'
Related Party Transaction, Shares Purchased by Related Party from Agreement for Acquisition of Assets	'		'		27,641		'		'
Share Value Purchased by Related Party from Agreement for Acquisition of Assets	'		'		553,000		'		'
Series C Cumulative Perpetual Preferred Stock | GreenHunter Resources, Inc.	'		'		'		'		'
Related Party Transaction	'		'		'		'		'
Proceeds from Dividends Received	$73,000		$55,000		$165,000		$136,000		'
[1]	On February 17, 2012, the Company sold its wholly-owned subsidiary, Hunter Disposal, to GreenHunter Water, LLC ("GreenHunter Water"), a wholly-owned subsidiary of GreenHunter. The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note it received as partial consideration for the sale. The fair market value of the derivative asset was $79,000, and $264,000 at September 30, 2013 and December 31, 2012, respectively. See "Note 3 - Fair Value of Financial Instruments" for additional information. The Company has recorded interest income as a result of the note receivable from GreenHunter. Also as a result of this transaction, the Company has an equity method investment in GreenHunter that is included in derivatives and other long term assets and an available for sale investment in GreenHunter included in investments.
[2]	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman, a major shareholder and former CEO; of which David Krueger, the Company's former Chief Accounting Officer and Senior Vice President, is the former Chief Financial Officer; and of which Ronald D. Ormand, the Company’s former Chief Financial Officer and Executive Vice President, is a former director. Eagle Ford Hunter received, and Triad Hunter and Viking International Resources, Inc. ("Virco"), wholly-owned subsidiaries of the Company, receive services related to brine water and rental equipment from GreenHunter and its affiliated companies, White Top Oilfield Construction, LLC and Black Water Services, LLC. The Company believes that such services were and are provided at competitive market rates and were and are comparable to, or more attractive than, rates that could be obtained from unaffiliated third party suppliers of such services. Prepaid expenses from GreenHunter were $64,748 and $0 at September 30, 2013 and December 31, 2012, respectively. The Company had net accounts payable to GreenHunter of $11,541 and $0 at September 30, 2013 and December 31, 2012, respectively.
[3]	The Company rented an airplane for business use for certain members of Company management at various times from Pilatus Hunter, LLC, an entity 100% owned by Mr. Evans. Airplane rental expenses are recorded in general and administrative expense.
[4]	Alpha Hunter Drilling, LLC ("Alpha Hunter Drilling"), a wholly-owned subsidiary of the Company, performed drilling operations for GreenHunter for a fee.
[5]	During the three and nine months ended September 30, 2012, the Company paid rent under a lease for a Houston, Texas corporate apartment from an executive of the Company, which apartment was used by other Company employees when in Houston for Company business. The lease terminated in May 2012.

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES Commitments and Contingencies (Details) (Triad Hunter [Member], USD $)	0 Months Ended
In Millions, unless otherwise specified	Aug. 12, 2013	Oct. 31, 2013	Oct. 07, 2013
	acre	Subsequent Event	Subsequent Event
		acre	acre
Subsequent Event [Line Items]	'	'	'
Number of mineral acres acquired	'	2,050.40	1,156.14
Acquisition of oil and gas properties	'	$8.70	$4.90
Number of mineral acres agreed to acquire	32,000	'	'
Minimum term of asset purchase agreement	'10 months	'	'

SUPPLEMENTAL_CASH_FLOW_INFORMA2

SUPPLEMENTAL CASH FLOW INFORMATION (Details) (USD $)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Supplemental Cash Flow Elements [Abstract]	'	'
Cash paid for interest	$38,225,000	$13,185,000
Cash paid for taxes	1,200,000	0
Non-cash transactions	'	'
Common stock issued for acquisitions	'	1,902,000
Common stock issued for 401k matching contributions	1,192,000	874,000
Non-cash consideration received from sale of assets	'	7,706,000
Change in accrued capital expenditures	-5,742,000	10,722,000
Non-cash additions to asset retirement obligation	2,089,000	182,000
Eureka Hunter Holdings, LLC Series A convertible preferred unit dividends paid in kind	6,367,000	1,658,000
Eureka Hunter Holdings, LLC Class A common units issued for an acquisition	$0	$12,453,000

SEGMENT_REPORTING_Details

SEGMENT REPORTING (Details) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012		Dec. 31, 2012
Details of operating activities by segment	'		'		'		'		'
Oil and natural gas sales	$54,018		$29,983		$138,242		$78,532		'
Natural gas transportation, gathering, processing, and marketing	12,545		5,058		42,415		10,418		'
Oilfield services	6,423		1,504		13,728		6,118		'
Other revenue	46		-164		789		-144		'
Total revenue	73,032		36,381		195,174		94,924		'
Lease operating expenses	15,145		6,100		38,027		18,291		'
Severance taxes and marketing	5,465		2,530		12,313		6,618		'
Exploration	40,123		3,299		73,402		18,143		'
Impairment of proved oil and gas properties	0		0		9,968		0		'
Natural gas transportation, gathering, processing, and marketing	8,985		2,288		35,830		4,379		'
Oilfield services	4,527		3,366		11,928		6,933		'
Depletion, depreciation, amortization and accretion	28,293		15,146		71,956		42,199		'
Loss on sale of assets, net	40,952		328		42,116		528		'
General and administrative	22,218		12,222		58,559		38,226		'
Total operating expenses	165,708		45,279		354,099		135,317		'
Interest income	34		132		172		216		'
Interest expense	-15,689		-14,405		-53,203		-40,595		'
Gain (loss) on derivative contracts,(net)	-29,553		-10,151		-30,644		9,056		'
Other income (expense)	8,540		27		7,860		90		'
Total other expense, net	-36,668		-24,397		-75,815		-31,233		'
Income (loss) from continuing operations before income tax	-129,344		-33,295		-234,740		-71,626		'
Income tax benefit	-3,255		1,983		40,944		9,143		'
Net income (loss) from continuing operations	-132,599		-31,312		-193,796		-62,483		'
Income (loss) from discontinued operations, net of tax	-80,554	[1]	-1,102	[1]	-71,455	[1]	2,832	[1]	'
Gain (loss) on disposal of discontinued operations, net of tax	-84,454	[2]	0	[2]	87,998	[2]	2,224	[2]	'
Net income (loss)	-297,607		-32,414		-177,253		-57,427		'
Total segment assets	1,885,816		1,933,968		1,885,816		1,933,968		2,198,632
U.S. Upstream	'		'		'		'		'
Details of operating activities by segment	'		'		'		'		'
Oil and natural gas sales	54,018		29,983		138,242		78,532		'
Natural gas transportation, gathering, processing, and marketing	0		0		0		0		'
Oilfield services	0		0		0		0		'
Other revenue	46		-172		788		-169		'
Total revenue	54,064		29,811		139,030		78,363		'
Lease operating expenses	17,217		7,309		43,720		21,145		'
Severance taxes and marketing	5,465		2,530		12,313		6,618		'
Exploration	40,123		3,299		73,402		18,143		'
Impairment of proved oil and gas properties	0		'		9,968		'		'
Natural gas transportation, gathering, processing, and marketing	0		0		0		0		'
Oilfield services	0		0		0		0		'
Depletion, depreciation, amortization and accretion	24,400		13,715		61,235		38,662		'
Loss on sale of assets, net	40,952		-13		42,112		-88		'
General and administrative	6,055		3,061		11,158		5,954		'
Total operating expenses	134,212		29,901		253,908		90,434		'
Interest income	35		140		171		169		'
Interest expense	-1,734		-1,931		-5,802		-3,461		'
Gain (loss) on derivative contracts,(net)	26		80		-185		185		'
Other income (expense)	245		37		-324		102		'
Total other expense, net	-1,428		-1,674		-6,140		-3,005		'
Income (loss) from continuing operations before income tax	-81,576		-1,764		-121,018		-15,076		'
Income tax benefit	9,417		2,988		12,597		10,155		'
Net income (loss) from continuing operations	-72,159		1,224		-108,421		-4,921		'
Income (loss) from discontinued operations, net of tax	-6,245		2,758		12,516		6,997		'
Gain (loss) on disposal of discontinued operations, net of tax	-28,813		0		143,639		0		'
Net income (loss)	-107,217		3,982		47,734		2,076		'
Total segment assets	1,406,515		1,411,720		1,406,515		1,411,720		'
Canadian Upstream	'		'		'		'		'
Details of operating activities by segment	'		'		'		'		'
Oil and natural gas sales	0		0		0		0		'
Natural gas transportation, gathering, processing, and marketing	0		0		0		0		'
Oilfield services	0		0		0		0		'
Other revenue	0		0		0		0		'
Total revenue	0		0		0		0		'
Lease operating expenses	0		0		0		0		'
Severance taxes and marketing	0		0		0		0		'
Exploration	0		0		0		0		'
Impairment of proved oil and gas properties	0		'		0		'		'
Natural gas transportation, gathering, processing, and marketing	0		0		0		0		'
Oilfield services	0		0		0		0		'
Depletion, depreciation, amortization and accretion	0		0		0		0		'
Loss on sale of assets, net	0		0		0		'		'
General and administrative	0		0		0		0		'
Total operating expenses	0		0		0		0		'
Interest income	0		0		0		0		'
Interest expense	0		0		0		0		'
Gain (loss) on derivative contracts,(net)	0		0		0		0		'
Other income (expense)	0		0		0		0		'
Total other expense, net	0		0		0		0		'
Income (loss) from continuing operations before income tax	0		0		0		0		'
Income tax benefit	926		-1,005		0		-1,012		'
Net income (loss) from continuing operations	926		-1,005		0		-1,012		'
Income (loss) from discontinued operations, net of tax	-77,220		-3,860		-78,429		-4,519		'
Gain (loss) on disposal of discontinued operations, net of tax	-55,641		0		-55,641		0		'
Net income (loss)	-131,935		-4,865		-134,070		-5,531		'
Total segment assets	106,438		275,066		106,438		275,066		'
Midstream and Marketing	'		'		'		'		'
Details of operating activities by segment	'		'		'		'		'
Oil and natural gas sales	0		0		0		0		'
Natural gas transportation, gathering, processing, and marketing	14,618		5,058		48,071		10,418		'
Oilfield services	0		0		0		0		'
Other revenue	0		8		0		25		'
Total revenue	14,618		5,066		48,071		10,443		'
Lease operating expenses	0		0		0		0		'
Severance taxes and marketing	0		0		0		0		'
Exploration	0		0		0		0		'
Impairment of proved oil and gas properties	0		'		0		'		'
Natural gas transportation, gathering, processing, and marketing	8,985		2,288		35,830		4,379		'
Oilfield services	0		0		0		0		'
Depletion, depreciation, amortization and accretion	3,173		1,195		9,142		2,853		'
Loss on sale of assets, net	0		0		0		'		'
General and administrative	2,156		958		5,446		2,065		'
Total operating expenses	14,314		4,441		50,418		9,297		'
Interest income	0		0		0		0		'
Interest expense	-1,177		-1,671		-3,215		-4,678		'
Gain (loss) on derivative contracts,(net)	-15,368		5,340		-20,808		3,990		'
Other income (expense)	-27		-10		-238		-12		'
Total other expense, net	-16,572		3,659		-24,261		-700		'
Income (loss) from continuing operations before income tax	-16,268		4,284		-26,608		446		'
Income tax benefit	0		0		0		0		'
Net income (loss) from continuing operations	-16,268		4,284		-26,608		446		'
Income (loss) from discontinued operations, net of tax	0		0		0		0		'
Gain (loss) on disposal of discontinued operations, net of tax	0		0		0		0		'
Net income (loss)	-16,268		4,284		-26,608		446		'
Total segment assets	269,692		182,144		269,692		182,144		'
Oilfield Services	'		'		'		'		'
Details of operating activities by segment	'		'		'		'		'
Oil and natural gas sales	0		0		0		0		'
Natural gas transportation, gathering, processing, and marketing	0		0		0		0		'
Oilfield services	6,448		3,533		13,872		9,793		'
Other revenue	0		0		1		0		'
Total revenue	6,448		3,533		13,873		9,793		'
Lease operating expenses	0		0		0		0		'
Severance taxes and marketing	0		0		0		0		'
Exploration	0		0		0		0		'
Impairment of proved oil and gas properties	0		'		0		'		'
Natural gas transportation, gathering, processing, and marketing	0		0		0		0		'
Oilfield services	4,552		3,716		12,034		7,283		'
Depletion, depreciation, amortization and accretion	720		236		1,579		684		'
Loss on sale of assets, net	0		341		4		616		'
General and administrative	379		145		850		251		'
Total operating expenses	5,651		4,438		14,467		8,834		'
Interest income	0		0		0		0		'
Interest expense	-141		-63		-372		-221		'
Gain (loss) on derivative contracts,(net)	0		0		0		0		'
Other income (expense)	0		0		0		0		'
Total other expense, net	-141		-63		-372		-221		'
Income (loss) from continuing operations before income tax	656		-968		-966		738		'
Income tax benefit	0		0		0		0		'
Net income (loss) from continuing operations	656		-968		-966		738		'
Income (loss) from discontinued operations, net of tax	0		0		0		354		'
Gain (loss) on disposal of discontinued operations, net of tax	0		0		0		2,224		'
Net income (loss)	656		-968		-966		3,316		'
Total segment assets	42,648		15,120		42,648		15,120		'
Corporate Unallocated	'		'		'		'		'
Details of operating activities by segment	'		'		'		'		'
Oil and natural gas sales	0		0		0		0		'
Natural gas transportation, gathering, processing, and marketing	0		0		0		0		'
Oilfield services	0		0		0		0		'
Other revenue	0		0		0		0		'
Total revenue	0		0		0		0		'
Lease operating expenses	0		0		0		0		'
Severance taxes and marketing	0		0		0		0		'
Exploration	0		0		0		0		'
Impairment of proved oil and gas properties	0		'		0		'		'
Natural gas transportation, gathering, processing, and marketing	0		0		0		0		'
Oilfield services	0		0		0		0		'
Depletion, depreciation, amortization and accretion	0		0		0		0		'
Loss on sale of assets, net	0		0		0		'		'
General and administrative	11,455		8,058		38,932		29,956		'
Total operating expenses	11,455		8,058		38,932		29,956		'
Interest income	1,183		2,137		3,987		2,192		'
Interest expense	-16,109		-12,885		-50,088		-34,380		'
Gain (loss) on derivative contracts,(net)	-14,211		-15,571		-9,651		4,881		'
Other income (expense)	8,322		0		8,422		0		'
Total other expense, net	-20,815		-26,319		-47,330		-27,307		'
Income (loss) from continuing operations before income tax	-32,270		-34,377		-86,262		-57,263		'
Income tax benefit	-13,598		0		28,347		0		'
Net income (loss) from continuing operations	-45,868		-34,377		-57,915		-57,263		'
Income (loss) from discontinued operations, net of tax	3,025		0		-5,428		0		'
Gain (loss) on disposal of discontinued operations, net of tax	0		0		0		0		'
Net income (loss)	-42,843		-34,377		-63,343		-57,263		'
Total segment assets	62,182		51,677		62,182		51,677		'
Inter-segment Eliminations	'		'		'		'		'
Details of operating activities by segment	'		'		'		'		'
Oil and natural gas sales	0		0		0		0		'
Natural gas transportation, gathering, processing, and marketing	-2,073		0		-5,656		0		'
Oilfield services	-25		-2,029		-144		-3,675		'
Other revenue	0		0		0		0		'
Total revenue	-2,098		-2,029		-5,800		-3,675		'
Lease operating expenses	-2,072		-1,209		-5,693		-2,854		'
Severance taxes and marketing	0		0		0		0		'
Exploration	0		0		0		0		'
Impairment of proved oil and gas properties	0		'		0		'		'
Natural gas transportation, gathering, processing, and marketing	0		0		0		0		'
Oilfield services	-25		-350		-106		-350		'
Depletion, depreciation, amortization and accretion	0		0		0		0		'
Loss on sale of assets, net	0		0		0		'		'
General and administrative	2,173		0		2,173		0		'
Total operating expenses	76		-1,559		-3,626		-3,204		'
Interest income	-1,184		-2,145		-3,986		-2,145		'
Interest expense	3,472		2,145		6,274		2,145		'
Gain (loss) on derivative contracts,(net)	0		0		0		0		'
Other income (expense)	0		0		0		0		'
Total other expense, net	2,288		0		2,288		0		'
Income (loss) from continuing operations before income tax	114		-470		114		-471		'
Income tax benefit	0		0		0		0		'
Net income (loss) from continuing operations	114		-470		114		-471		'
Income (loss) from discontinued operations, net of tax	-114		0		-114		0		'
Gain (loss) on disposal of discontinued operations, net of tax	0		0		0		0		'
Net income (loss)	0		-470		0		-471		'
Total segment assets	($1,659)		($1,759)		($1,659)		($1,759)		'
[1]
[2]	Income tax expense associated with gain/(loss) on sale of discontinued operations was $6.6 million for the nine months ended September 30, 2013.

CONDENSED_CONSOLIDATING_GUARAN2

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	($297,607)	($32,414)	($177,253)	($57,427)	'
ASSETS	'	'	'	'	'
Current assets	159,154	'	159,154	'	204,319
Property and equipment (using successful efforts method of accounting)	1,471,951	'	1,471,951	'	1,924,413
Total assets	1,885,816	1,933,968	1,885,816	1,933,968	2,198,632
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	252,912	'	252,912	'	243,656
Redeemable preferred stock	228,871	'	228,871	'	200,878
Shareholders’ equity	509,094	'	509,094	'	711,652
Total liabilities and shareholders’ equity	1,885,816	'	1,885,816	'	2,198,632
Magnum Hunter Resources Corporation	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	-302,364	-35,646	-190,954	-62,596	'
PRC Williston, LLC	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	-856	-472	-3,542	-1,858	'
100% Owned Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	-59,320	-4,416	-97,486	-12,757	'
Non Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	-200,214	4,081	-198,610	4,835	'
Eliminations	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	265,147	4,039	313,339	14,949	'
Magnum Hunter Resources Corporation Consolidated	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	-297,607	-32,414	-177,253	-57,427	'
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	-302,364	-35,646	-190,954	-62,596	'
ASSETS	'	'	'	'	'
Current assets	35,827	'	35,827	'	63,167
Intercompany accounts receivable	838,399	'	838,399	'	803,834
Property and equipment (using successful efforts method of accounting)	7,516	'	7,516	'	9,596
Investment in subsidiaries	460,903	'	460,903	'	763,856
Other assets	18,838	'	18,838	'	20,849
Total assets	1,361,483	'	1,361,483	'	1,661,302
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	69,615	'	69,615	'	28,503
Intercompany accounts payable	0	'	0	'	0
Long-term liabilities	691,298	'	691,298	'	831,286
Redeemable preferred stock	100,000	'	100,000	'	100,000
Shareholders’ equity	500,570	'	500,570	'	701,513
Total liabilities and shareholders’ equity	1,361,483	'	1,361,483	'	1,661,302
Debt Securities Under Universal Shelf Registration Statement Form S-4 | PRC Williston, LLC	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	-856	-472	-3,542	-1,858	'
ASSETS	'	'	'	'	'
Current assets	1,555	'	1,555	'	703
Intercompany accounts receivable	'	'	'	'	'
Property and equipment (using successful efforts method of accounting)	16,921	'	16,921	'	18,257
Investment in subsidiaries	'	'	'	'	'
Other assets	'	'	'	'	'
Total assets	18,476	'	18,476	'	18,960
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	2,924	'	2,924	'	2,291
Intercompany accounts payable	61,314	'	61,314	'	58,966
Long-term liabilities	1,351	'	1,351	'	1,274
Redeemable preferred stock	0	'	0	'	0
Shareholders’ equity	-47,113	'	-47,113	'	-43,571
Total liabilities and shareholders’ equity	18,476	'	18,476	'	18,960
Debt Securities Under Universal Shelf Registration Statement Form S-4 | 100% Owned Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	-59,320	-4,416	-97,486	-12,757	'
ASSETS	'	'	'	'	'
Current assets	81,644	'	81,644	'	60,552
Intercompany accounts receivable	'	'	'	'	'
Property and equipment (using successful efforts method of accounting)	1,242,456	'	1,242,456	'	1,276,467
Investment in subsidiaries	102,259	'	102,259	'	101,341
Other assets	110,535	'	110,535	'	5,451
Total assets	1,536,894	'	1,536,894	'	1,443,811
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	158,674	'	158,674	'	117,511
Intercompany accounts payable	707,801	'	707,801	'	508,254
Long-term liabilities	75,332	'	75,332	'	97,271
Redeemable preferred stock	0	'	0	'	0
Shareholders’ equity	595,087	'	595,087	'	720,775
Total liabilities and shareholders’ equity	1,536,894	'	1,536,894	'	1,443,811
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Non Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	-200,214	4,081	-198,610	4,835	'
ASSETS	'	'	'	'	'
Current assets	41,787	'	41,787	'	111,126
Intercompany accounts receivable	'	'	'	'	'
Property and equipment (using successful efforts method of accounting)	205,058	'	205,058	'	620,093
Investment in subsidiaries	64,423	'	64,423	'	102,354
Other assets	125,338	'	125,338	'	43,600
Total assets	436,606	'	436,606	'	877,173
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	23,393	'	23,393	'	125,727
Intercompany accounts payable	69,252	'	69,252	'	236,636
Long-term liabilities	126,958	'	126,958	'	112,615
Redeemable preferred stock	128,871	'	128,871	'	100,878
Shareholders’ equity	88,132	'	88,132	'	301,317
Total liabilities and shareholders’ equity	436,606	'	436,606	'	877,173
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Eliminations	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	265,147	4,039	313,339	14,949	'
ASSETS	'	'	'	'	'
Current assets	-1,659	'	-1,659	'	-31,229
Intercompany accounts receivable	-838,399	'	-838,399	'	-803,834
Property and equipment (using successful efforts method of accounting)	'	'	'	'	'
Investment in subsidiaries	-627,585	'	-627,585	'	-967,551
Other assets	'	'	'	'	'
Total assets	-1,467,643	'	-1,467,643	'	-1,802,614
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	-1,694	'	-1,694	'	-30,376
Intercompany accounts payable	-838,367	'	-838,367	'	-803,856
Long-term liabilities	0	'	0	'	0
Redeemable preferred stock	0	'	0	'	0
Shareholders’ equity	-627,582	'	-627,582	'	-968,382
Total liabilities and shareholders’ equity	-1,467,643	'	-1,467,643	'	-1,802,614
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation Consolidated	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net loss	-297,607	-32,414	-177,253	-57,427	'
ASSETS	'	'	'	'	'
Current assets	159,154	'	159,154	'	204,319
Intercompany accounts receivable	0	'	0	'	0
Property and equipment (using successful efforts method of accounting)	1,471,951	'	1,471,951	'	1,924,413
Investment in subsidiaries	0	'	0	'	0
Other assets	254,711	'	254,711	'	69,900
Total assets	1,885,816	'	1,885,816	'	2,198,632
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	252,912	'	252,912	'	243,656
Intercompany accounts payable	0	'	0	'	0
Long-term liabilities	894,939	'	894,939	'	1,042,446
Redeemable preferred stock	228,871	'	228,871	'	200,878
Shareholders’ equity	509,094	'	509,094	'	711,652
Total liabilities and shareholders’ equity	$1,885,816	'	$1,885,816	'	$2,198,632

CONDENSED_CONSOLIDATING_GUARAN3

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 2) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Condensed consolidating statements of operations	'		'		'		'
Revenues	$73,032		$36,381		$195,174		$94,924
Income (loss) from continuing operations before income taxes	-129,344		-33,295		-234,740		-71,626
Income tax benefit	-3,255		1,983		40,944		9,143
Income (loss) from continuing operations	-132,599		-31,312		-193,796		-62,483
Income (loss) from discontinued operations, net of tax	-80,554	[1]	-1,102	[1]	-71,455	[1]	2,832	[1]
Gain (loss) on disposal of discontinued operations, net of tax	-84,454	[2]	0	[2]	87,998	[2]	2,224	[2]
Net income (loss)	-297,607		-32,414		-177,253		-57,427
Net loss (income) attributed to non-controlling interests	725		-49		1,614		-71
Net income (loss) attributable to Magnum Hunter Resources Corporation	-296,882		-32,463		-175,639		-57,498
Dividends on preferred stock	-14,417		-9,820		-42,034		-22,680
Net income (loss) attributable to common shareholders	-311,299		-42,283		-217,673		-80,178
Magnum Hunter Resources Corporation	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Net income (loss)	-302,364		-35,646		-190,954		-62,596
PRC Williston, LLC	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Net income (loss)	-856		-472		-3,542		-1,858
100% Owned Guarantor Subsidiaries	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Net income (loss)	-59,320		-4,416		-97,486		-12,757
Non Guarantor Subsidiaries	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Net income (loss)	-200,214		4,081		-198,610		4,835
Eliminations	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Net income (loss)	265,147		4,039		313,339		14,949
Magnum Hunter Resources Corporation Consolidated	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Net income (loss)	-297,607		-32,414		-177,253		-57,427
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Revenues	29		169		-134		630
Expenses	35,351		33,996		91,559		56,379
Loss from continuing operations before equity in net income of subsidiary	-35,322		-33,827		-91,693		-55,749
Equity in net income of subsidiary	-236,767		-1,819		-274,930		-6,847
Income (loss) from continuing operations before income taxes	-272,089		-35,646		-366,623		-62,596
Income tax benefit	-13,598		'		28,347		0
Income (loss) from continuing operations	-285,687		-35,646		-338,276		-62,596
Income (loss) from discontinued operations, net of tax	3,027		0		-5,426		0
Gain (loss) on disposal of discontinued operations, net of tax	-19,704		0		152,748		0
Net income (loss)	-302,364		-35,646		-190,954		-62,596
Net loss (income) attributed to non-controlling interests	0		'		0		0
Net income (loss) attributable to Magnum Hunter Resources Corporation	-302,364		-35,646		-190,954		-62,596
Dividends on preferred stock	-8,820		-5,795		-26,603		-15,179
Net income (loss) attributable to common shareholders	-311,184		-41,441		-217,557		-77,775
Debt Securities Under Universal Shelf Registration Statement Form S-4 | PRC Williston, LLC	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Revenues	2,020		1,876		5,315		6,065
Expenses	2,876		2,348		8,857		7,923
Loss from continuing operations before equity in net income of subsidiary	-856		-472		-3,542		-1,858
Equity in net income of subsidiary	0		0		0		0
Income (loss) from continuing operations before income taxes	-856		-472		-3,542		-1,858
Income tax benefit	'		'		0		0
Income (loss) from continuing operations	-856		-472		-3,542		-1,858
Income (loss) from discontinued operations, net of tax	0		0		0		0
Gain (loss) on disposal of discontinued operations, net of tax	0		0		0		0
Net income (loss)	-856		-472		-3,542		-1,858
Net loss (income) attributed to non-controlling interests	0		'		'		0
Net income (loss) attributable to Magnum Hunter Resources Corporation	-856		-472		-3,542		-1,858
Dividends on preferred stock	0		0		0		0
Net income (loss) attributable to common shareholders	-856		-472		-3,542		-1,858
Debt Securities Under Universal Shelf Registration Statement Form S-4 | 100% Owned Guarantor Subsidiaries	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Revenues	66,203		31,833		175,630		81,721
Expenses	142,373		34,347		288,658		95,211
Loss from continuing operations before equity in net income of subsidiary	-76,170		-2,514		-113,028		-13,490
Equity in net income of subsidiary	163		0		-479		'
Income (loss) from continuing operations before income taxes	-76,007		-2,514		-113,507		-13,490
Income tax benefit	9,400		301		12,600		3,620
Income (loss) from continuing operations	-66,607		-2,213		-100,907		-9,870
Income (loss) from discontinued operations, net of tax	16,396		-2,203		12,530		-5,111
Gain (loss) on disposal of discontinued operations, net of tax	-9,109		0		-9,109		2,224
Net income (loss)	-59,320		-4,416		-97,486		-12,757
Net loss (income) attributed to non-controlling interests	0		'		0		0
Net income (loss) attributable to Magnum Hunter Resources Corporation	-59,320		-4,416		-97,486		-12,757
Dividends on preferred stock	0		0		0		0
Net income (loss) attributable to common shareholders	-59,320		-4,416		-97,486		-12,757
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Non Guarantor Subsidiaries	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Revenues	6,877		4,533		20,162		10,183
Expenses	23,988		544		46,754		10,241
Loss from continuing operations before equity in net income of subsidiary	-17,111		3,989		-26,592		-58
Equity in net income of subsidiary	-28,543		-2,691		-37,930		-8,573
Income (loss) from continuing operations before income taxes	-45,654		1,298		-64,522		-8,631
Income tax benefit	943		1,682		-3		5,523
Income (loss) from continuing operations	-44,711		2,980		-64,525		-3,108
Income (loss) from discontinued operations, net of tax	-99,862		1,101		-78,444		7,943
Gain (loss) on disposal of discontinued operations, net of tax	-55,641		0		-55,641		0
Net income (loss)	-200,214		4,081		-198,610		4,835
Net loss (income) attributed to non-controlling interests	0		'		0		0
Net income (loss) attributable to Magnum Hunter Resources Corporation	-200,214		4,081		-198,610		4,835
Dividends on preferred stock	-5,597		-4,025		-15,431		-7,501
Net income (loss) attributable to common shareholders	-205,811		56		-214,041		-2,666
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Eliminations	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Revenues	-2,097		-2,030		-5,799		-3,675
Expenses	-2,212		-1,559		-5,914		-3,204
Loss from continuing operations before equity in net income of subsidiary	115		-471		115		-471
Equity in net income of subsidiary	265,147		4,510		313,339		15,420
Income (loss) from continuing operations before income taxes	265,262		4,039		313,454		14,949
Income tax benefit	'		'		0		0
Income (loss) from continuing operations	265,262		4,039		313,454		14,949
Income (loss) from discontinued operations, net of tax	-115		0		-115		0
Gain (loss) on disposal of discontinued operations, net of tax	0		0		0		0
Net income (loss)	265,147		4,039		313,339		14,949
Net loss (income) attributed to non-controlling interests	725		-49		1,614		-71
Net income (loss) attributable to Magnum Hunter Resources Corporation	265,872		3,990		314,953		14,878
Dividends on preferred stock	0		0		0		0
Net income (loss) attributable to common shareholders	265,872		3,990		314,953		14,878
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation Consolidated	'		'		'		'
Condensed consolidating statements of operations	'		'		'		'
Revenues	73,032		36,381		195,174		94,924
Expenses	202,376		69,676		429,914		166,550
Loss from continuing operations before equity in net income of subsidiary	-129,344		-33,295		-234,740		-71,626
Equity in net income of subsidiary	0		0		0		0
Income (loss) from continuing operations before income taxes	-129,344		-33,295		-234,740		-71,626
Income tax benefit	-3,255		1,983		40,944		9,143
Income (loss) from continuing operations	-132,599		-31,312		-193,796		-62,483
Income (loss) from discontinued operations, net of tax	-80,554		-1,102		-71,455		2,832
Gain (loss) on disposal of discontinued operations, net of tax	-84,454		0		87,998		2,224
Net income (loss)	-297,607		-32,414		-177,253		-57,427
Net loss (income) attributed to non-controlling interests	725		-49		1,614		-71
Net income (loss) attributable to Magnum Hunter Resources Corporation	-296,882		-32,463		-175,639		-57,498
Dividends on preferred stock	-14,417		-9,820		-42,034		-22,680
Net income (loss) attributable to common shareholders	($311,299)		($42,283)		($217,673)		($80,178)
[1]
[2]	Income tax expense associated with gain/(loss) on sale of discontinued operations was $6.6 million for the nine months ended September 30, 2013.

CONDENSED_CONSOLIDATING_GUARAN4

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 3) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	($297,607)	($32,414)	($177,253)	($57,427)
Foreign currency translation loss	3,856	7,245	-7,943	6,628
Unrealized gain (loss) on available for sale securities	3,735	-35	8,184	-301
Amounts reclassified from accumulated other comprehensive income	-8,262	0	-8,262	0
COMPREHENSIVE LOSS	-298,278	-25,204	-185,274	-51,100
Comprehensive loss (income) attributable to non-controlling interests	725	-49	1,614	-71
COMPREHENSIVE LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	-297,553	-25,253	-183,660	-51,171
Magnum Hunter Resources Corporation	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-302,364	-35,646	-190,954	-62,596
Foreign currency translation loss	0	0	0	0
Unrealized gain (loss) on available for sale securities	3,562	0	8,262	0
Amounts reclassified from accumulated other comprehensive income	-8,262	'	-8,262	'
COMPREHENSIVE LOSS	-307,064	-35,646	-190,954	-62,596
Comprehensive loss (income) attributable to non-controlling interests	0	0	0	0
COMPREHENSIVE LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	-307,064	-35,646	-190,954	-62,596
PRC Williston, LLC	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-856	-472	-3,542	-1,858
Foreign currency translation loss	0	0	0	0
Unrealized gain (loss) on available for sale securities	0	0	0	0
Amounts reclassified from accumulated other comprehensive income	0	'	0	'
COMPREHENSIVE LOSS	-856	-472	-3,542	-1,858
Comprehensive loss (income) attributable to non-controlling interests	0	0	0	0
COMPREHENSIVE LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	-856	-472	-3,542	-1,858
100% Owned Guarantor Subsidiaries	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-59,320	-4,416	-97,486	-12,757
Foreign currency translation loss	0	0	0	0
Unrealized gain (loss) on available for sale securities	173	-35	-78	-301
Amounts reclassified from accumulated other comprehensive income	0	'	0	'
COMPREHENSIVE LOSS	-59,147	-4,451	-97,564	-13,058
Comprehensive loss (income) attributable to non-controlling interests	0	0	0	0
COMPREHENSIVE LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	-59,147	-4,451	-97,564	-13,058
Non-Guarantor Subsidiaries [Member]	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-200,214	4,081	-198,610	4,835
Foreign currency translation loss	3,856	7,245	-7,943	6,628
Unrealized gain (loss) on available for sale securities	0	0	0	0
Amounts reclassified from accumulated other comprehensive income	0	'	0	'
COMPREHENSIVE LOSS	-196,358	11,326	-206,553	11,463
Comprehensive loss (income) attributable to non-controlling interests	0	0	0	0
COMPREHENSIVE LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	-196,358	11,326	-206,553	11,463
Eliminations	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	265,147	4,039	313,339	14,949
Foreign currency translation loss	0	0	0	0
Unrealized gain (loss) on available for sale securities	0	0	0	0
Amounts reclassified from accumulated other comprehensive income	0	'	0	'
COMPREHENSIVE LOSS	265,147	4,039	313,339	14,949
Comprehensive loss (income) attributable to non-controlling interests	725	-49	1,614	-71
COMPREHENSIVE LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	265,872	3,990	314,953	14,878
Magnum Hunter Resources Corporation Consolidated	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-297,607	-32,414	-177,253	-57,427
Foreign currency translation loss	3,856	7,245	-7,943	6,628
Unrealized gain (loss) on available for sale securities	3,735	-35	8,184	-301
Amounts reclassified from accumulated other comprehensive income	-8,262	'	-8,262	'
COMPREHENSIVE LOSS	-298,278	-25,204	-185,274	-51,100
Comprehensive loss (income) attributable to non-controlling interests	725	-49	1,614	-71
COMPREHENSIVE LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	($297,553)	($25,253)	($183,660)	($51,171)

CONDENSED_CONSOLIDATING_GUARAN5

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 4) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	$79,197	$46,819
Cash flow from operating activities	44,823	-793,687
Cash flow from investing activities	-126,267	754,161
Effect of changes in exchange rate on cash	-93	-146
Net increase (decrease) in cash	-2,340	7,147
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	57,623	14,851
CASH AND CASH EQUIVALENTS, END OF PERIOD	55,283	21,998
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation	'	'
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	-264,051	-304,365
Cash flow from operating activities	422,056	-308,625
Cash flow from investing activities	-152,265	612,579
Effect of changes in exchange rate on cash	'	'
Net increase (decrease) in cash	5,740	-411
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	26,872	18,758
CASH AND CASH EQUIVALENTS, END OF PERIOD	32,612	18,347
Debt Securities Under Universal Shelf Registration Statement Form S-4 | PRC Williston, LLC	'	'
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	882	48
Cash flow from operating activities	-882	-48
Cash flow from investing activities	'	'
Effect of changes in exchange rate on cash	'	'
Net increase (decrease) in cash	'	'
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	'	'
CASH AND CASH EQUIVALENTS, END OF PERIOD	'	'
Debt Securities Under Universal Shelf Registration Statement Form S-4 | 100% Owned Guarantor Subsidiaries	'	'
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	236,112	209,620
Cash flow from operating activities	-245,179	-207,814
Cash flow from investing activities	2,105	-2,346
Effect of changes in exchange rate on cash	'	'
Net increase (decrease) in cash	-6,962	-540
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	-4,187	-546
CASH AND CASH EQUIVALENTS, END OF PERIOD	-11,149	-1,086
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Non Guarantor Subsidiaries	'	'
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	106,254	141,516
Cash flow from operating activities	-131,172	-277,200
Cash flow from investing activities	23,893	143,928
Effect of changes in exchange rate on cash	-93	-146
Net increase (decrease) in cash	-1,118	8,098
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	34,938	-3,361
CASH AND CASH EQUIVALENTS, END OF PERIOD	33,820	4,737
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Eliminations	'	'
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	'	'
Cash flow from operating activities	'	'
Cash flow from investing activities	'	'
Effect of changes in exchange rate on cash	'	'
Net increase (decrease) in cash	'	'
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	'	'
CASH AND CASH EQUIVALENTS, END OF PERIOD	'	'
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation Consolidated	'	'
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	79,197	46,819
Cash flow from operating activities	44,823	-793,687
Cash flow from investing activities	-126,267	754,161
Effect of changes in exchange rate on cash	-93	-146
Net increase (decrease) in cash	-2,340	7,147
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	57,623	14,851
CASH AND CASH EQUIVALENTS, END OF PERIOD	$55,283	$21,998

SUBSEQUENT_EVENTS_Details

SUBSEQUENT EVENTS (Details) (USD $)

9 Months Ended

9 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Oct. 15, 2013

Oct. 15, 2013

Oct. 15, 2013

Oct. 30, 2013

Oct. 30, 2013

Oct. 31, 2013

Oct. 04, 2013

Common Stock

Depositary Shares

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Series A Preferred Units

Common Stock

Depositary Shares

Series A Preferred Units

Eureka Hunter Holdings, LLC

Undeveloped Leasehold Acreage

Undeveloped Leasehold Acreage

Series A Preferred Units

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends, ratio of warrants received per common stock

'

'

10.00%

'

'

'

'

'

10.00%

'

'

'

'

'

Business combination, consideration transferred

'

'

'

'

'

'

'

'

'

'

'

'

$8,700,000

$4,900,000

Class of warrant or right, number of securities called by each warrant or right

'

'

'

'

'

'

'

1

'

'

'

'

'

'

Conversion price (in dollars per share)

'

'

'

$8.50

'

'

'

'

'

$8.50

'

'

'

'

Preferred stock issued as in-kind payment (in shares)

'

'

'

'

'

'

318,335

'

'

'

93,821

'

'

'

Eureka Hunter Holdings, LLC Series A convertible preferred unit dividends paid in kind

6,367,000

1,658,000

'

'

'

'

6,400,000

'

'

'

1,900,000

'

'

'

Dividends, Preferred Stock

'

'

'

'

'

'

'

'

'

'

$1,900,000

'

'

'

Consolidated controlling interest (as a percent)

'

'

'

'

57.38%

61.00%

'

'

'

'

'

41.00%

'

'