Magnum Hunter Resources 10-Q 7 Nov 14 2014 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2014	Nov. 06, 2014
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-14	'
Amendment Flag	'false	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	199,905,010
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q3	'

CONSOLIDATED_BALANCE_SHEETS_Un

CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
CURRENT ASSETS	'	'
Cash and cash equivalents	$42,667	$41,713
Restricted cash	0	5,000
Oil and natural gas sales	22,276	25,099
Joint interests and other, net of allowance for doubtful accounts of $702 at September 30, 2014 and $196 at December 31, 2013	18,053	30,582
Derivative assets	1,954	608
Inventory	3,039	7,158
Investments	8,230	2,262
Prepaid expenses and other assets	4,832	2,938
Assets held for sale	0	5,366
Total current assets	101,051	120,726
PROPERTY, PLANT AND EQUIPMENT	'	'
Oil and natural gas properties, successful efforts method of accounting, net	1,322,406	1,224,659
Gas transportation, gathering and processing equipment and other, net	468,908	289,420
Total property, plant and equipment, net	1,791,314	1,514,079
OTHER ASSETS	'	'
Deferred financing costs, net of amortization of $18,461 at September 30, 2014 and $9,735 at December 31, 2013	17,511	20,008
Derivative assets, long-term	255	25
Intangible assets, net	5,025	6,530
Goodwill	30,602	30,602
Assets held for sale	86,362	162,687
Other assets	1,445	1,994
Total assets	2,033,565	1,856,651
CURRENT LIABILITIES	'	'
Current portion of notes payable	8,670	3,804
Accounts payable	199,577	107,837
Accounts payable to related parties	355	23
Accrued liabilities	36,895	44,629
Revenue payable	5,911	6,313
Derivative liabilities	48	1,903
Liabilities associated with assets held for sale	0	12,865
Other liabilities	3,786	6,491
Total current liabilities	255,242	183,865
Long-term debt	949,792	876,106
Asset retirement obligations	25,176	16,163
Derivative liabilities, long-term	173,271	76,310
Other long-term liabilities	5,382	2,279
Long-term liabilities associated with assets held for sale	1,619	14,523
Total liabilities	1,410,482	1,169,246
COMMITMENTS AND CONTINGENCIES (Note 16)	'	'
REDEEMABLE PREFERRED STOCK	'	'
Redeemable preferred stock	251,685	236,675
SHAREHOLDERS’ EQUITY	'	'
Common stock, $0.01 par value per share, 350,000,000 shares authorized, and 200,812,979 and 172,409,023 issued, and 199,898,027 and 171,494,071 outstanding as of September 30, 2014 and December 31, 2013, respectively	2,008	1,724
Additional paid in capital	923,679	733,753
Accumulated deficit	-879,005	-586,365
Accumulated other comprehensive loss	-3,566	-19,901
Treasury stock, at cost	-1,914	-1,914
Total Magnum Hunter Resources Corporation shareholders’ equity	355,485	441,580
Non-controlling interest	15,913	9,150
Total shareholders’ equity	371,398	450,730
Total liabilities and shareholders’ equity	2,033,565	1,856,651
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	151,685	136,675
Series D Cumulative Perpetual Preferred Stock	'	'
SHAREHOLDERS’ EQUITY	'	'
Preferred Stock	221,244	221,244
Series E Cumulative Convertible Preferred Stock	'	'
SHAREHOLDERS’ EQUITY	'	'
Preferred Stock	95,069	95,069
Treasury stock, at cost	($2,030)	($2,030)

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	9 Months Ended	12 Months Ended
	Sep. 30, 2014	Dec. 31, 2013
Accounts receivable, allowance for doubtful accounts	$702,000	$196,000
Amortization of deferred financing costs	18,461,000	9,735,000
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	350,000,000
Common stock, shares issued	200,812,979	172,409,023
Common stock, shares outstanding	199,898,027	171,494,071
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	10,592,540	9,885,048
Preferred stock, shares outstanding	10,592,540	9,885,048
Preferred stock, liquidation preference	$271,410	$200,620
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	4,424,889
Preferred Stock, Shares Outstanding	4,424,889	4,424,889
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	3,803
Preferred Stock, Shares Outstanding	3,722	3,722
Preferred stock, liquidation preference (in dollars per share)	$25,000	$25,000
Treasury stock, shares	81	81

UNAUDITED_CONSOLIDATED_STATEME

UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	3 Months Ended			9 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013	Sep. 30, 2014		Sep. 30, 2013
REVENUES AND OTHER	'		'	'		'
Oil and natural gas sales	$62,510		$59,061	$222,247		$156,772
Natural gas transportation, gathering, processing, and marketing	10,285		12,545	90,461		42,854
Oilfield services	5,986		6,423	17,561		13,728
Other revenue	889		262	1,346		1,005
Total revenue	79,670		78,291	331,615		214,359
OPERATING EXPENSES	'		'	'		'
Lease operating expenses	24,482		19,587	64,612		48,689
Severance taxes and marketing	6,163		5,554	18,847		12,983
Exploration	27,284		41,978	52,394		75,257
Impairment of proved oil and gas properties	22,886		23,547	39,798		39,467
Natural gas transportation, gathering, processing, and marketing	4,954		8,985	79,707		35,830
Oilfield services	3,856		4,527	11,892		11,928
Depletion, depreciation, amortization and accretion	36,370		29,127	101,733		80,141
Loss (gain) on sale of assets, net	-8,000		40,952	-4,612		42,114
General and administrative	19,251		23,908	56,027		63,673
Total operating expenses	137,246		198,165	420,398		410,082
OPERATING LOSS	-57,576		-119,874	-88,783		-195,723
OTHER INCOME (EXPENSE)	'		'	'		'
Interest income	40		35	126		217
Interest expense	-18,095		-15,759	-62,473		-53,352
Loss on derivative contracts, net	-49,636		-29,553	-92,125		-30,644
Other income	2,078		12,056	2,102		14,544
Total other expense, net	-65,613		-33,221	-152,370		-69,235
LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX	-123,189		-153,095	-241,153		-264,958
Income tax benefit	0		582	0		47,227
LOSS FROM CONTINUING OPERATIONS, NET OF TAX	-123,189		-152,513	-241,153		-217,731
Income (loss) from discontinued operations, net of tax	0		-75,573	4,561		-62,453
Gain (loss) on disposal of discontinued operations, net of tax	-258		-69,521	-13,983		102,931
NET LOSS	-123,447		-297,607	-250,575		-177,253
Net loss attributed to non-controlling interests	2,764		725	3,653		1,614
LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	-120,683		-296,882	-246,922		-175,639
Dividends on preferred stock	-15,492		-14,417	-45,718		-42,034
NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS	-136,175		-311,299	-292,640		-217,673
Weighted average number of common shares outstanding, basic and diluted	199,448,453		169,953,997	185,440,763		169,752,042
Loss from continuing operations per share, basic and diluted	($0.68)		($0.98)	($1.53)		($1.52)
Income (loss) from discontinued operations per share, basic and diluted	$0		($0.85)	($0.05)		$0.24
NET LOSS PER COMMON SHARE, BASIC AND DILUTED	($0.68)		($1.83)	($1.58)		($1.28)
Loss from continuing operations, net of tax	-120,425		-151,788	-237,500		-216,117
Income (loss) from discontinued operations, net of tax	-258	[1]	-145,094	-9,422	[1]	40,478
Net loss	($120,683)		($296,882)	($246,922)		($175,639)
[1]	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.

UNAUDITED_CONSOLIDATED_STATEME1

UNAUDITED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS (Unaudited) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Statement of Comprehensive Income [Abstract]	'	'	'	'
Net loss	($123,447)	($297,607)	($250,575)	($177,253)
OTHER COMPREHENSIVE INCOME (LOSS)	'	'	'	'
Foreign currency translation gain (loss)	0	3,856	-1,218	-7,943
Unrealized gain (loss) on available for sale investments	-2,583	3,735	-3,188	8,184
Amounts reclassified from accumulated other comprehensive income	0	-8,262	0	-8,262
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	0	20,741	0
Total other comprehensive income (loss)	-2,583	-671	16,335	-8,021
COMPREHENSIVE LOSS	-126,030	-298,278	-234,240	-185,274
Comprehensive loss attributable to non-controlling interests	2,764	725	3,653	1,614
COMPREHENSIVE LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	($123,266)	($297,553)	($230,587)	($183,660)

UNAUDITED_CONSOLIDATED_STATEME2

UNAUDITED CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY (Unaudited) (USD $)

Total

Common Stock

Additional Paid in Capital

Accumulated Deficit

Accumulated Other Comprehensive Income (loss)

Treasury Stock

Non - controlling Interest

Series D Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

In Thousands, except Share data, unless otherwise specified

Preferred Stock

Preferred Stock

Series A Common Stock

Series A Common Stock

Non - controlling Interest

BALANCE at Dec. 31, 2013

$450,730

$1,724

$733,753

($586,365)

($19,901)

($3,944)

$9,150

$221,244

'

$95,069

'

'

BALANCE (in shares) at Dec. 31, 2013

'

172,409,000

'

'

'

'

'

4,425,000

'

4,000

'

'

Increase (Decrease) in Shareholders' Equity

'

'

'

'

'

'

'

'

'

'

'

'

Share based compensation (in shares)

'

71,000

'

'

'

'

'

'

'

'

'

'

Share based compensation

5,674

1

5,673

'

'

'

'

'

'

'

'

'

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

'

249,000

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Value, 401k Matching Contribution

1,593

2

1,591

'

'

'

'

'

'

'

'

'

Sale of common stock (in shares)

'

25,729,000

'

'

'

'

'

'

'

'

'

'

Sale of common stock

178,432

257

178,175

'

'

'

'

'

'

'

8,180

8,180

Dividends on preferred stock

-45,718

'

'

-45,718

'

'

'

'

'

'

'

'

Shares of common stock issued upon exercise of common stock options (in shares)

'

2,355,000

'

'

'

'

'

'

'

'

'

'

Shares of common stock issued upon exercise of common stock options

'

24

9,598

'

'

'

'

'

9,622

'

'

'

Repurchase of non-controlling interest

-2,875

'

-5,111

'

'

'

2,236

'

'

'

'

'

Net loss

-250,575

'

'

-246,922

'

'

-3,653

'

'

'

'

'

Foreign currency translation gain (loss)

-1,218

'

'

'

-1,218

'

'

'

'

'

'

'

Unrealized gain on available for sale securities

-3,188

'

'

'

-3,188

'

'

'

'

'

'

'

Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.

20,741

'

'

'

20,741

'

'

'

'

'

'

'

BALANCE at Sep. 30, 2014

$371,398

$2,008

$923,679

($879,005)

($3,566)

($3,944)

$15,913

$221,244

'

$95,069

'

'

BALANCE (in shares) at Sep. 30, 2014

'

200,813,000

'

'

'

'

'

4,425,000

'

4,000

'

'

UNAUDITED_CONSOLIDATED_STATEME3

UNAUDITED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Statement of Cash Flows [Abstract]	'	'
Net loss	($250,575)	($177,253)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:	'	'
Depletion, depreciation, amortization and accretion	101,733	107,624
Exploration	51,306	91,533
Impairment of proved oil and gas properties	39,798	88,504
Impairment of other operating assets	666	263
Share-based compensation	7,267	11,834
Cash paid for plugging wells	-26	-14
Loss (gain) on sale of assets	9,371	-50,063
Unrealized loss on derivative contracts	88,051	23,757
Unrealized loss on investments	504	1,043
Amortization and write-off of deferred financing costs and discount on Senior Notes included in interest expense	8,809	3,660
Deferred tax benefit	'	-54,465
Changes in operating assets and liabilities:	'	'
Accounts receivable, net	20,742	-703
Inventory	4,681	77
Prepaid expenses and other current assets	-2,766	-3,095
Accounts payable	-50,851	23,303
Revenue payable	-2,336	-3,027
Accrued liabilities	-12,819	16,219
Net cash provided by operating activities	13,555	79,197
CASH FLOWS FROM INVESTING ACTIVITIES	'	'
Capital expenditures and advances	-363,304	-418,245
Change in restricted cash	5,000	1,500
Change in deposits and other long-term assets	310	571
Proceeds from sales of assets	110,690	460,997
Net cash provided by (used in) investing activities	-247,304	44,823
CASH FLOWS FROM FINANCING ACTIVITIES	'	'
Net proceeds from sale of common shares	178,432	0
Net proceeds from sale of preferred shares	'	10,181
Equity issuance costs	0	-109
Proceeds from sale of Eureka Hunter Holdings Series A Preferred Units	11,956	27,440
Proceeds from sale of Eureka Hunter Holdings Series A Common Units	8,180	0
Repurchase of non-controlling interest	-2,875	0
Proceeds from exercise of warrants and options	9,622	1,932
Preferred stock dividend	-36,754	-29,911
Repayments of debt	-208,298	-379,504
Proceeds from borrowings on debt	279,592	245,991
Deferred financing costs	-6,228	-1,184
Change in other long-term liabilities	1,032	-1,103
Net cash provided by (used in) financing activities	234,659	-126,267
Effect of changes in exchange rate on cash	44	-93
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	954	-2,340
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	41,713	57,623
CASH AND CASH EQUIVALENTS, END OF PERIOD	$42,667	$55,283

GENERAL

GENERAL	9 Months Ended
	Sep. 30, 2014
Accounting Policies [Abstract]	'
GENERAL	'
	NOTE 1 - GENERAL
	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 United States in the acquisition and development of producing properties and undeveloped acreage and the production of oil and natural gas, along with certain midstream and oilfield services activities.
	Presentation of Consolidated Financial Statements
	The accompanying unaudited interim consolidated financial statements of Magnum Hunter are presented in U.S. Dollars and have been prepared in accordance with accounting principles generally accepted in the United States ("GAAP"). The preparation of these consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during reporting periods. Actual results could differ materially from those estimates.
	In the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary for the 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 GAAP.
	Certain information and disclosures normally included in the consolidated financial statements prepared in accordance with GAAP that would substantially duplicate the disclosures contained in the audited consolidated financial statements as reported in the Company's Annual Report on Form 10-K have been condensed or omitted. These consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, 2013, as amended.
	Non-Controlling Interest in Consolidated Subsidiaries
	The Company has consolidated Eureka Hunter Holdings, LLC ("Eureka Hunter Holdings") in which it owned 57.5% as of September 30, 2014 and 56.4% as of December 31, 2013. 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.
	On December 30, 2013, PRC Williston, LLC ("PRC Williston"), in which the Company owned 87.5% as of December 31, 2013, sold substantially all of its assets. On July 24, 2014, the Company executed a settlement and release agreement with Drawbridge Special Opportunities Fund LP and Fortress Value Recovery Fund I LLC f/k/a D.B. Zwirn Special Opportunities Fund, L.P. As a result of this settlement agreement, the Company now owns 100% of the equity interests in PRC Williston and has all rights and claims to its remaining assets and liabilities, which are not significant. Consequently, there is no longer any non-controlling interest in PRC Williston's equity reflected in the consolidated financial statements as of September 30, 2014.
	The consolidated financial statements also reflect the interests of our wholly-owned subsidiary Magnum Hunter Production, Inc. ("MHP") in various managed drilling partnerships. The Company accounts for the interests in these managed drilling partnerships using the proportionate consolidation method.
	Reclassification of Prior-Period Balances
	Certain prior period balances have been reclassified to correspond with current-year presentation.  As a result of the Company's decision in September 2014 to withdraw its plan to divest of its 100% equity interest in MHP and cease all marketing efforts, the results of operations of MHP, which had previously been reported as a component of discontinued operations, have been reclassified to continuing operations for all periods presented, and all assets and liabilities of MHP that were previously reported as assets and liabilities held for sale in our consolidated balance sheet have been reclassified to assets and liabilities held for use as of September 30, 2014. See "Note 2 - Divestitures and Discontinued Operations".
	Regulated Activities
	Energy Hunter Securities, Inc. ("Energy Hunter Securities") is a 100%-owned subsidiary and is a registered broker-dealer and member of the Financial Industry Regulatory Authority ("FINRA"). Among other regulatory requirements, it is subject to the net capital provisions of Rule 15c3-1 under the Securities Exchange Act of 1934, as amended. Because it does not hold customer funds or securities or owe money or securities to customers, Energy Hunter Securities is required to maintain minimum net capital equal to the greater of $5,000 or 6.67% of its aggregate indebtedness. As of September 30, 2014 and December 31, 2013, Energy Hunter Securities had net capital of $83,204 and $77,953, respectively, and aggregate indebtedness of $8,494 and $16,657, respectively.
	During the third quarter of 2014, the Company initiated a process to wind down Energy Hunter Securities. This process included making an initial filing with FINRA and will include an audit of Energy Hunter Securities by FINRA which is anticipated to commence during the fourth quarter of 2014. On September 26, 2014, Energy Hunter Securities filed a Uniform Request for Withdrawal From Broker-Dealer Registration with the Securities and Exchange Commission ("SEC"). As of September 30, 2014, Energy Hunter Securities' request was still pending approval from FINRA and the SEC.
	Sentra Corporation, a 100%-owned subsidiary, owns and operates distribution systems for retail sales of natural gas in south central Kentucky. Sentra Corporation's gas distribution billing rates are regulated by the Kentucky Public Service Commission based on recovery of purchased gas costs. The Company accounts for its operations based on the provisions of the Financial Accounting Standards Board's ("FASB") Accounting Standards Codification ("ASC") Subtopic 980-605, Regulated Operations-Revenue Recognition, which requires covered entities to record regulatory assets and liabilities resulting from actions of regulators. During the three and nine months ended September 30, 2014, the Company had gas transmission, compression and processing revenue, which included gas utility sales from Sentra Corporation's regulated operations aggregating $27,656 and $473,555, respectively. During the three and nine months ended September 30, 2013, the Company had revenues of $215,618 related to Sentra Corporation's regulated operations.
	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 March 2013, the FASB issued Accounting Standards Update ("ASU") 2013-05, Parent’s Accounting for the Cumulative Translation Adjustment upon Derecognition of Certain Subsidiaries or Groups of Assets within a Foreign Entity or of an Investment in a Foreign Entity, to provide guidance on whether to release cumulative translation adjustments ("CTA") upon certain derecognition events. ASU 2013-05 requires a parent company to apply the guidance in ASC Subtopic 830-30 when an entity ceases to have a controlling financial interest in a subsidiary or group of assets that is a business within a foreign entity. Consequently, the CTA related to a foreign entity is released into net income only if the transaction results in complete or substantially complete liquidation of the foreign entity in which the subsidiary or group of assets resided; otherwise, no portion of the CTA is released.  The Company adopted this pronouncement prospectively on January 1, 2014. The adoption of this updated standard did not have a material impact on the Company’s consolidated financial statements.
	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 ASC Topic 740, Income Taxes ("FASB ASC Topic 740"). This update clarified 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. The Company adopted this ASU prospectively on January 1, 2014. The adoption of this accounting standard update did not have a material impact on the Company's consolidated financial statements or its financial statement disclosures.
	In April 2014, the FASB issued ASU 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. ASU 2014-08 updates the requirements for reporting discontinued operations in ASC Subtopic 205-20, Presentation of Financial Statements - Discontinued Operations, by requiring classification as discontinued operations of a component of an entity or a group of components of an entity if the disposal represents a strategic shift that has (or will have) a major effect on an entity's operations and financial results when either 1) the component or group of components of an entity meet the criteria to be classified as held for sale, 2) are disposed of by sale, or 3) are disposed of other than by sale (e.g. abandonment or a distribution to owners in a spinoff). The amendments in this update expand the disclosure requirements related to discontinued operations and disposals of individually significant components that do not qualify for discontinued operations presentation in the financial statements. This ASU is effective prospectively for all disposals (or classification as held for sale) of components of an entity that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). ASU 2014-09 supersedes the revenue recognition requirements in ASC Topic 605, Revenue Recognition, and most industry-specific guidance throughout the Industry Topics of the ASC. The core principle of the revised standard is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. To achieve that core principle, an entity should apply the following steps: identify the contract(s) with a customer, identify the performance obligations in the contract, determine the transaction price, allocate the transaction price to the performance obligations in the contract, and recognize revenue when (or as) the entity satisfies a performance obligation. ASU 2014-09 requires entities to disclose both quantitative and qualitative information that enables users of financial statements to understand the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. This amendment is effective for annual reporting periods beginning after December 15, 2016, including interim periods within those reporting periods. The guidance allows for either a "full retrospective" adoption or a "modified retrospective" adoption, however early application is not permitted. The Company is currently evaluating the adoption methods and the impact of this ASU on its consolidated financial statements and financial statement disclosures.
	In June 2014, the FASB issued ASU 2014-12, Compensation - Stock Compensation: Accounting for Share Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period. ASU 2014-12 clarifies that a performance target that affects vesting and that could be achieved after the requisite service period should be treated as a performance condition. An entity should apply existing guidance in ASC Topic 718 as it relates to awards with performance conditions that affect vesting to account for such awards. As such, the performance target should not be reflected in estimating the grant-date fair value of the award. This amendment is effective for annual periods and interim periods within those annual periods beginning after December 15, 2015. Early adoption is permitted. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.
	In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern: Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. This update requires an entity’s management to evaluate for each annual and interim reporting period whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date that the financial statements are issued or available to be issued. The update further requires certain disclosures when substantial doubt is alleviated as a result of consideration of management’s plans, and requires an express statement and other disclosures when substantial doubt is not alleviated. This amendment is effective for the annual period ending after December 15, 2016, and for annual periods and interim periods thereafter. Early application is permitted. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.

DIVESTITURES_AND_DISCONTINUED_

DIVESTITURES AND DISCONTINUED OPERATIONS	9 Months Ended
	Sep. 30, 2014
Discontinued Operations and Disposal Groups [Abstract]	'
DIVESTITURES AND DISCONTINUED OPERATIONS	'
	NOTE 2 - DIVESTITURES AND DISCONTINUED OPERATIONS
	Assets Held for Sale
	On September 17, 2014, Bakken Hunter, LLC, a wholly-owned subsidiary of the Company ("Bakken Hunter") entered into a letter of intent to sell certain non-operated working interests in oil and natural gas properties located in Divide County, North Dakota for cash consideration of approximately $84.8 million, subject to customary purchase price adjustments. Additionally, on September 23, 2014 Triad Hunter, LLC, a wholly-owned subsidiary of the Company ("Triad Hunter") signed two agreements to sell certain non-core working interests in oil and gas properties located primarily in Calhoun and Roane Counties, West Virginia for cash consideration of $1.2 million, subject to customary purchase price adjustments. The sale of interests in the North Dakota oil and natural gas properties closed in October 2014. The sale of interests in the West Virginia oil and natural gas properties closed in November 2014. The Company has classified the associated assets and liabilities contemplated in these agreements as assets and liabilities held for sale in the consolidated balance sheet as of September 30, 2014.
	Discontinued Operations
	In September 2013, the Company adopted a plan to divest all of its interests in (i) MHP, 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. ("WHI Canada"), which was a wholly-owned subsidiary of the Company.
	Planned Divestiture of Magnum Hunter Production
	In connection with the Company’s adoption of a plan to divest of its interest in MHP in September 2013, the Company determined that the planned divestiture met the assets held for sale criteria and the criteria for classification as a discontinued operation. The Company classified the associated assets and liabilities of MHP as assets and liabilities held for sale in the consolidated balance sheet as of September 30, 2013 and reflected the results of MHP’s operations as discontinued operations in the consolidated statements of operations for the three and nine months ended September 2013 and 2012. The Company determined at each interim and annual period subsequent to September 30, 2013, and until September 30, 2014, that the planned divestiture continued to meet the criteria for classification as a discontinued operation based upon its ongoing marketing activities. Consequently, the Company continued to report the results of operations for MHP, including the results of operations of MHP for comparable periods presented from a preceding year, as a component of discontinued operations in the Company's consolidated financial statements for each interim and annual period from September 30, 2013 through June 30, 2014, and reported the assets and liabilities of MHP as assets and liabilities held for sale on the corresponding consolidated balance sheets.
	During the year ended December 31, 2013, the Company recorded an impairment expense of $18.5 million, net of tax, to record MHP at the estimated selling price less costs to sell. Based upon additional information on estimated selling prices obtained through active marketing of the assets, the Company recorded an additional impairment expense during the quarter ended March 31, 2014 of $18.6 million, net of tax, to reflect the net assets at their estimated selling prices, less costs to sell. The Company did not record any impairment for MHP for the three month period ended June 30, 2014.
	Effective September 2014, the Company withdrew its plan to divest MHP to further evaluate the oil and natural gas exploration and development upside opportunities underlying the acreage the Company has access to through MHP's leasehold and mineral interest rights. As a result of this decision the Company ceased all marketing activities for MHP, and consequently MHP no longer met the criteria for classification as a discontinued operation as of September 30, 2014.
	The Company has reclassified the results of MHP’s operations from discontinued operations to continuing operations for all periods presented in these interim consolidated financial statements, and MHP’s assets and liabilities have been reclassified out of assets and liabilities held for sale and included with the Company’s other assets held and used as of September 30, 2014.
	As of September 30, 2014, the Company has measured the carrying value of MHP’s individual long-lived assets previously classified as held for sale at the lesser of (i) their carrying amount before each asset was classified as held for sale, adjusted for any depreciation or amortization expense that would have been recognized had it been continuously classified as held and used, and (ii) their fair value at the date of the subsequent decision not to sell. As a result of this assessment, the Company recorded additional impairments of $1.9 million to the carrying amount of MHP’s unproved oil and natural properties and $17.0 million to the carrying amount of MHP’s proved oil and natural gas properties, which were recorded in exploration expense and impairment of proved oil and gas properties, respectively. In addition, the Company recorded depreciation expense of $1.7 million related to long-lived assets, whose fair value exceeded book value, adjusted for depreciation expense, as of September 30, 2014. In total, the Company recorded approximately $67.6 million of impairment related to MHP from September 30, 2013 through September 30, 2014.
	Williston Hunter Canada Asset Sale
	On April 10, 2014, WHI Canada closed on the sale of certain oil and natural gas properties and assets located in Alberta, Canada for cash consideration of CAD $9.5 million in cash (approximately U.S. $8.7 million at the exchange rate as of the close of business on April 10, 2014). The effective date of the sale was January 1, 2014. The Company recognized a gain of $6.1 million which is recorded in gain (loss) on disposal of discontinued operations.
	Sale of Williston Hunter Canada
	On May 12, 2014, the Company closed on the sale of 100% of its ownership interest in the Company's Canadian subsidiary, WHI Canada, whose assets consisted primarily of oil and natural gas properties located in the Tableland Field in Saskatchewan, Canada, for a purchase price of CAD $75.0 million (approximately U.S. $68.8 million at the exchange rate as of the close of business on May 12, 2014), prior to customary purchase price adjustments, with an effective date of March 1, 2014, of which CAD $18.4 million was placed in escrow pending final approval from the Canadian Revenue Authority. The Company received the cash held in escrow in July 2014. The Company recognized a loss of $12.8 million which is recorded in gain (loss) on disposal of discontinued operations. The loss on disposal of WHI Canada for the nine months ended September 30, 2014 includes $20.7 million in foreign currency translation adjustment which was reclassified out of accumulated other comprehensive income upon closing on the sale of our foreign operation.
	The following shows the Company's assets and liabilities held for sale at September 30, 2014 and December 31, 2013:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Accounts receivable	$	—		$	4,362
	Other current assets	—			1,004
	Oil and natural gas properties, net	86,362			150,770
	Gas transportation, gathering, and processing equipment and other, net	—			11,721
	Other long-term assets	—			196
	Total assets held for sale	$	86,362		$	168,053
	Accounts payable	$	—		$	7,292
	Accrued liabilities and other liabilities	—			5,573
	Asset retirement obligations	1,619			8,678
	Other long-term liabilities	—			5,845
	Total liabilities held for sale	$	1,619		$	27,388
	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, Inc. ("Eagle Ford Hunter") to an affiliate of Penn Virginia Corporation 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. At the date of closing, the Company initially recognized a preliminary gain on the sale of $172.5 million, net of tax, pending final working capital adjustments, which is recorded in gain (loss) on disposal of discontinued operations in the consolidated statements of operations.
	In the months that followed closing, the Company and Penn Virginia were unable to agree upon the final settlement of the working capital adjustments as called for in the purchase and sale agreement and the disagreement was subsequently submitted to arbitration. The determination by the arbitrator was received by the Company on July 25, 2014 and resulted in a downward adjustment of the cash portion of the purchase price of $33.7 million plus accrued interest of $1.3 million. This liability was settled in cash on July 31, 2014. The Company had previously reserved and recognized substantially all of this obligation in its financial statements as of December 31, 2013. For the three and nine months ended September 30, 2013, the Company recorded a downward adjustment to the gain on sale of Eagle Ford Hunter of $13.9 million. For the three and nine months ended September 30, 2014, the Company recorded a downward adjustment to the gain on sale of Eagle Ford Hunter of $0.3 million and $7.3 million, respectively.
	The Company included the results of operations of WHI Canada through May 12, 2014 and Eagle Ford Hunter through April 24, 2013 in discontinued operations. The following presents our discontinued operations.
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in thousands)
	Revenues	$	—		$	7,943		$	8,533		$	62,429
	Expenses	—			(93,755		)	(3,976		)	(128,464		)
	Other income	—			59			4			81
	Income tax benefit	—			10,180			—			3,501
	Income (loss) from discontinued operations, net of tax	—			(75,573		)	4,561			(62,453		)
	Gain (loss) on disposal of discontinued operations, net of taxes	(258		)	(69,521		)	(13,983		)	102,931
	Income (loss) from discontinued operations, net of taxes	$	(258	)	$	(145,094	)	$	(9,422	)	$	40,478
	Other Divestitures
	Sale of Certain Other North Dakota Assets
	On September 30, 2014, Bakken Hunter closed on the sale of certain non-operated working interests in oil and natural gas properties located in Divide County, North Dakota for cash consideration of $23.5 million, subject to customary purchase price adjustments. The effective date of the sale was April 1, 2014. The Company recognized a gain on the sale of $8.2 million.
	Sale of Certain Other Eagle Ford Shale Assets
	On January 28, 2014, the Company, through its wholly-owned subsidiary Shale Hunter LLC ("Shale Hunter") and certain other affiliates, closed on the sale of certain of their oil and natural gas properties and related assets located in the Eagle Ford Shale in South Texas to New Standard Energy Texas LLC ("NSE Texas"), a subsidiary of New Standard Energy Limited ("NSE"), an Australian Securities Exchange-listed Australian company.
	The assets sold consisted primarily of interests in leasehold acreage located in Atascosa County, Texas and working interests in five horizontal wells, of which four were operated by the Company. The effective date of the sale was December 1, 2013. As consideration for the assets sold, the Company received aggregate purchase price consideration of $15.5 million in cash, after customary purchase price adjustments, and 65,650,000 ordinary shares of NSE with a fair value of approximately $9.4 million at January 28, 2014 (based on the closing market price of $0.14 per share on January 28, 2014). These investment holdings represented approximately 17% of the total shares outstanding of NSE as of the closing date, and have been designated as available-for-sale securities, which are recorded at fair value of approximately $5.7 million and included in investments in the consolidated balance sheet as of September 30, 2014. The Company recognized a loss on the sale of the Shale Hunter assets of $4.5 million during the first quarter of 2014.
	In connection with the closing of the sale, Shale Hunter and NSE Texas entered into a transition services agreement which provides that, during a specified transition period ending on July 28, 2015 unless otherwise extended or modified, Shale Hunter will provide NSE Texas with certain transitional services relating to the assets sold for which it is receiving a monthly fee.
	Upon, and as a result of, the closing of the sale on January 28, 2014, the borrowing base under the Company’s asset-based, senior secured revolving credit facility was automatically reduced by $10.0 million as discussed in "Note 10 - Debt".

OIL_NATURAL_GAS_SALES

OIL & NATURAL GAS SALES	9 Months Ended
	Sep. 30, 2014
Other Income and Expenses [Abstract]	'
Oil & Natural Gas Sales	'
	NOTE 3 - OIL & NATURAL GAS SALES
	During the three and nine months ended September 30, 2014 and 2013, the Company recognized sales from oil, natural gas, and natural gas liquids ("NGL") as follows:
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
		(in thousands)
	Oil	$	34,495	$	40,471	$	111,354	$	103,545
	Natural gas	18,247		12,417		74,031		41,145
	NGL	9,768		6,173		36,862		12,082
	Total oil and natural gas sales	$	62,510	$	59,061	$	222,247	$	156,772

PROPERTY_PLANT_EQUIPMENT_Notes

PROPERTY, PLANT, & EQUIPMENT (Notes)	9 Months Ended
	Sep. 30, 2014
Property, Plant and Equipment [Abstract]	'
Property, Plant, & Equipment	'
	NOTE 4 - PROPERTY, PLANT, & EQUIPMENT
	Asset Acquisitions
	On June 18, 2014, the Company entered into an Asset Purchase Agreement ("Ormet Asset Purchase Agreement") with Ormet Corporation for the purchase of certain mineral interests in approximately 1,700 net acres, consisting of 1,375 net acres in Monroe County, Ohio and 325 net acres in Wetzel County, West Virginia. Prior to the execution of the Ormet Asset Purchase Agreement, the Company held leasehold interests in a portion of the subject acreage, which only included leasehold rights to the Marcellus zone, and carried a 12.5% royalty on production to Ormet Corporation. On July 24, 2014, the Company closed on the purchase of the sub-surface mineral interests, including any royalty interests, in the underlying acreage, giving the Company an approximate 100% net revenue interest in and rights to oil, natural gas, and other minerals located in or under and that may be produced from the property, at any depth. The total purchase price for this transaction was approximately $22.7 million cash.
	Oil and Natural Gas Properties
	The following sets forth the net capitalized costs under the successful efforts method for oil and natural gas properties as of:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Mineral interests in properties:
	Unproved mineral rights and leasehold costs	$	510,296		$	469,337
	Proved mineral rights and leasehold costs	282,150			336,357
	Wells and related equipment and facilities	735,947			536,023
	Advances to operators for wells in progress	2,508			13,571
	Total costs	1,530,901			1,355,288
	Less accumulated depletion, depreciation, and amortization	(208,495		)	(130,629		)
	Net capitalized costs	$	1,322,406		$	1,224,659
	Proved oil and natural gas properties are reviewed for impairment on a field-by-field basis bi-annually or when events and circumstances indicate a possible decline in the recoverability of the carrying amount of such property. Impairments of proved property of $22.9 million and $39.8 million were recorded during the three and nine months ended September 30, 2014 and $23.5 million and $39.5 million for the three and nine months ended September 30, 2013, respectively. For the three and nine months ended September 30, 2014, impairment of proved oil and gas properties included write-downs to fair value of MHP's proved oil and natural gas property of $17.1 million and $33.8 million, respectively. The Company recognized write-downs to fair value of MHP's proved oil and natural gas property of $16.4 million for the three and nine months ended September 30, 2013.
	Depletion, depreciation, and amortization expense for proved oil and natural gas properties was $28.0 million and $81.9 million for the three and nine months ended September 30, 2014 and $23.6 million and $58.0 million for the three and nine months ended September 30, 2013, respectively.
	Exploration
	Exploration expense consists primarily of abandonment charges and impairment expense for capitalized leasehold costs associated with unproved properties for which 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, 2014 and 2013, the Company recognized exploration expense as follows:
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014		2013
		(in thousands)
	Leasehold impairments	$	26,922		$	41,624		$	51,305	$	74,249
	Geological and geophysical	362			354			1,089		1,008
	Total exploration expense	$	27,284		$	41,978		$	52,394	$	75,257
	Leasehold impairment expense recorded by the Company during the three and nine months ended September 30, 2014 consisted of $17.8 million and $37.8 million, respectively, in the U.S. upstream segment related to leases in the Williston Basin and $13.5 million during the nine months ended September 30, 2014 in the U.S. upstream segment related to leases in the Appalachian Basin. Leasehold impairment expense of $38.8 million and $71.5 million during the three and nine months ended September 30, 2013 primarily related to leases in the Williston Basin. Impairments of leases in the Williston and Appalachian Basins for all periods presented related to leases that expired undrilled during the period or are expected to expire and that the Company does not plan to develop or extend.
	The Company recognized $1.9 million and $3.8 million in leasehold impairment expense related to fair value write-downs of MHP for the three and nine months ended September 30, 2014. For the same periods in 2013, leasehold impairment expense included $1.9 million in write-downs to fair value related to MHP.
	Capitalized Costs Greater Than a Year
	As of September 30, 2014, the Company had suspended exploratory well costs capitalized for periods greater than one year related to the Farley pad in Washington County, Ohio and the Farley #1305 H well. The Farley pad was constructed to drill multiple horizontal wells into a previously untested zone in the Utica formation. The Company spud the Farley #1305 H in April of 2013, and experienced well pressure instability during the fracture stimulation stage of completion. Further fracture stimulation and evaluation of this well will depend on the outcome of the drilling and completion of the Farley #1306 H and #1304 H wells, which were drilled in 2014 and are expected to be fracture stimulated and tested in 2015 upon completion of a new natural gas pipeline. Aggregate cost incurred through September 30, 2014 for the Farley pad and the Farley #1305 H well were $1.1 million and $13.8 million, respectively.
	Gas Transportation, Gathering, and Processing Equipment and Other
	The historical cost of gas transportation, gathering, and processing equipment and other property, presented on a gross basis with accumulated depreciation, as of September 30, 2014 and December 31, 2013 is summarized as follows:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Gas transportation, gathering and processing equipment and other	$	516,258		$	315,642
	Less accumulated depreciation	(47,350		)	(26,222		)
	Net capitalized costs	$	468,908		$	289,420
	Depreciation expense for gas transportation, gathering, and processing equipment and other property was $6.5 million and $16.1 million for the three and nine months ended September 30, 2014, respectively, and $4.3 million and $11.1 million for the three and nine months ended September 30, 2013, respectively. For the three and nine months ended September 30, 2014, depreciation expense included $1.7 million in depreciation recognized to adjust certain assets of MHP to their adjusted carrying value as if they had been held and used since their initial classification as assets held for sale through the date the Company withdrew their plan to divest of MHP.
	The Company sells and leases gas treating and processing equipment, classified as gas transportation, gathering, and processing equipment and other property and included in the table above, 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, 2014 had a net carrying value of $12.8 million, and the terms of such leases provide for future lease payments to the Company extending up to August 2016.  As of September 30, 2014, primarily all the leases to third parties were non-cancelable, with future minimum aggregate base rentals payable to the Company of $2.9 million over the twelve months ending September 30, 2015 and $0.5 million, in the aggregate, thereafter.

INTANGIBLE_ASSETS

INTANGIBLE ASSETS	9 Months Ended
	Sep. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Intangible Assets	'
	NOTE 5 - INTANGIBLE ASSETS
	Intangible assets consist primarily of gas gathering and processing contracts and customer relationships. The following table summarizes the Company's net intangible assets as of September 30, 2014 and December 31, 2013:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Customer relationships	$	5,434		$	5,434
	Trademark	859			859
	Existing contracts	4,199			4,199
	Total intangible assets	10,492			10,492
	Less: accumulated amortization	(5,467		)	(3,962		)
	Intangible assets, net of accumulated amortization	$	5,025		$	6,530
	Amortization expense for intangible assets was $502,000 and $1.5 million for the three and nine months ended September 30, 2014 and $569,000 and $1.9 million for the three and nine months ended September 30, 2013, respectively.
	The Company performed its annual impairment test of goodwill as of April 1, 2014. As a result of the Company's analysis no impairment of goodwill was indicated.

INVENTORY

INVENTORY	9 Months Ended
	Sep. 30, 2014
Inventory Disclosure [Abstract]	'
Inventory	'
	NOTE 6 - INVENTORY
	The Company’s materials and supplies inventory is primarily comprised of frac sand used in the completion process of hydraulic fracturing. As of September 30, 2014 and December 31, 2013, the frac sand inventory is anticipated to be used in its entirety within the coming year, and is classified in current assets along with other inventory.
	The following table shows the composition of the Company's inventory as of:
		September 30,		December 31,
		2014		2013
		(in thousands)
	Materials and supplies	$	2,228	$	6,790
	Commodities	811		368
	Inventory	$	3,039	$	7,158

ASSET_RETIREMENT_OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS	9 Months Ended
	Sep. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
ASSET RETIREMENT OBLIGATIONS	'
	NOTE 7 - ASSET RETIREMENT OBLIGATIONS
	The following table summarizes the Company’s asset retirement obligation ("ARO") activities during the nine-month period ended September 30, 2014 and for the year ended December 31, 2013:
		30-Sep-14			31-Dec-13
		(in thousands)
	Asset retirement obligation at beginning of period	$	16,216		$	30,680
	Assumed in acquisitions	—			17
	Liabilities incurred	218			253
	Liabilities settled	(26		)	(98		)
	Liabilities sold	(596		)	(7,614		)
	Accretion expense	1,731			2,264
	Revisions in estimated liabilities (1)	2,625			1,935
	Reclassified as liabilities associated with assets held for sale	(1,619		)	(11,148		)
	Reclassified from liabilities associated with assets held for sale	8,109			—
	Effect of foreign currency translation	—			(73		)
	Asset retirement obligation at end of period	26,658			16,216
	Less: current portion (included in other liabilities)	(1,482		)	(53		)
	Asset retirement obligation at end of period	$	25,176		$	16,163
	________________________________
	(1) Revisions in estimated liabilities during 2014 relate to a change in assumptions used with respect to certain wells in the Appalachian Basin in Ohio and West Virginia. Approximately $1.5 million of the revisions in estimated liabilities during 2013 is related to a change in assumptions used with respect to certain wells in the Williston Basin in North Dakota.

FAIR_VALUE_OF_FINANCIAL_INSTRU

FAIR VALUE OF FINANCIAL INSTRUMENTS	9 Months Ended
	Sep. 30, 2014
Fair Value Disclosures [Abstract]	'
FAIR VALUE OF FINANCIAL INSTRUMENTS	'
	NOTE 8 - 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
	Transfers between Levels 1 and 2 occur at the end of the reporting period in which it is determined that the observability of significant inputs has increased or decreased. There were no transfers between levels of the fair value hierarchy during 2014 and 2013. In January 2014, the Company acquired common shares of NSE in partial consideration of an asset sale. The significant inputs used in valuing the NSE common shares, which have a quoted market price in an active market, were designated as Level 1 as of September 30, 2014.
	The Company used the following fair value measurements for certain of the Company's assets and liabilities at September 30, 2014 and December 31, 2013:
	Level 1 Classification:
	Available for Sale Securities
	At September 30, 2014 and December 31, 2013, 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 commodity 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 commodity derivative instruments are valued using public indices, the instruments themselves are traded with unrelated counterparties and are not openly traded on an exchange. 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, 2014 and December 31, 2013, the Company had a preferred stock embedded derivative liability resulting from its Eureka Hunter Holdings Series A Preferred Units, which contain certain conversion features, redemption options, and other features.
	The fair value of the bifurcated conversion feature was valued using the "with and without" analysis in a simulation model based upon management's estimate of the expected life of the conversion feature. The key assumptions used in the model to determine fair value at September 30, 2014 were as follows:
		September 30, 2014
	Volatility	13.7		%
	Credit spread	24		%
	Expected term	1-2 years
	Total enterprise value (in millions)	$	929.7
	The selection of assumptions for expected term and total enterprise value were made based on a weighting of possible outcomes. The term of the conversion feature, which was linked to the terms of the Eureka Hunter Holdings Amended and Restated Limited Liability Company Agreement (the "Eureka Hunter Holdings LLC Agreement"), could range from zero to 6 years. During the three-month period ended September 30, 2014, MSIP II Buffalo Holdings LLC, an affiliate of Morgan Stanley Infrastructure, Inc ("MSI"), entered into an agreement to purchase all of the issued and outstanding Eureka Hunter Holdings Series A Preferred Units and Class A Common Units held by Ridgeline Midstream Holdings, LLC ("Ridgeline"), an affiliate of ArcLight Capital Partners, LLC ("ArcLight"), which constituted all of the issued and outstanding Eureka Hunter Holdings Series A Preferred Units. In making the Company's determination of the total enterprise value for Eureka Hunter Holdings of $929.7 million, the Company considered the purchase price associated with MSI's purchase of the Eureka Hunter Holdings Series A Preferred Units, and its implied value to the enterprise as a whole. The issued and outstanding Eureka Hunter Holdings Series A Preferred Units were subsequently converted to a new class of common equity of Eureka Hunter Holdings. See "Note 13 - Redeemable Preferred Stock" and "Note 20 - Subsequent Events".
	The fair value calculation is sensitive to movements in volatility, estimated remaining term, and the total enterprise value of Eureka Hunter Holdings. A decrease in the estimated term of the conversion feature results in a higher fair value of the conversion feature. During the three-month period ended June 30, 2014, the Company changed the estimated term to 1-2 years due to changes in the Company's expectation of when the conversion feature with respect to the Eureka Hunter Holdings Series A Preferred Units would be exercised. As the implied volatility of the instruments increases so too does the fair value of the derivative liability arising from the conversion and redemption features. Similarly, as the total enterprise value of Eureka Hunter Holdings increases, the fair value of the derivative liability increases. Decreases in volatility and total enterprise value would result in a reduction to the fair value of the derivative liability associated with these instruments.
	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. 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-14
	Life	2.4
	Risk-free interest rate	1.03		%
	Estimated volatility	40		%
	Dividend	—
	GreenHunter stock price at end of period	$	1.52
	The sensitivity of the estimate of volatility used in determining the fair value of the convertible security embedded derivative would not have a significant impact to the Company's financial statements based on the value of the assets as compared to the financial statements as a whole.
	The following tables present the fair value hierarchy levels of the Company's financial assets and liabilities which are measured and carried at fair value on a recurring basis:
		Fair Value Measurements on a Recurring Basis
		30-Sep-14
		(in thousands)
	Assets	Level 1				Level 2			Level 3
	Available for sale securities	$	8,076			$	—		$	—
	Commodity derivative assets	—				2,127			—
	Convertible security derivative assets	—				—			83
	Total assets at fair value	$	8,076			$	2,127		$	83
	Liabilities
	Commodity derivative liabilities	$	—			$	114		$	—
	Convertible preferred stock derivative liabilities	—				—			173,205
	Total liabilities at fair value	$	—			$	114		$	173,205
		Fair Value Measurements on a Recurring Basis
		31-Dec-13
		(in thousands)
	Assets	Level 1				Level 2			Level 3
	Available for sale securities	$	1,819			$	—		$	—
	Commodity derivative assets	—				554			—
	Convertible security derivative assets	—				—			79
	Total assets at fair value	$	1,819			$	554		$	79
	Liabilities
	Commodity derivative liabilities	$	—			$	2,279		$	—
	Convertible preferred stock derivative liabilities	—				—			75,934
	Total liabilities at fair value	$	—			$	2,279		$	75,934
	The following table presents a reconciliation of the financial derivative asset and liability measured at fair value using significant unobservable inputs (Level 3 inputs) for the nine-month period ended September 30, 2014:
		Preferred Stock Embedded				Convertible Security Embedded
		Derivative Liability				Derivative Asset
		(in thousands)
Fair value as of December 31, 2013	$	(75,934	)		$	79
Issuance of redeemable preferred stock	(5,479		)		—
Increase in fair value recognized in gain (loss) on derivative contracts, net	(91,792		)		4
Fair value as of September 30, 2014	$	(173,205	)		$	83
As of September 30, 2014, the valuation of the conversion feature embedded in the Eureka Hunter Holdings Series A Preferred Units increased the fair value of the embedded derivative liability by approximately $91.8 million as a result of changes in the total enterprise value of Eureka Hunter Holdings and the Company's estimate of the expected remaining term of the conversion feature. Management's estimate of the expected remaining term of the conversion option as of September 30, 2014 shortened the time horizon previously estimated by management, resulting in higher fair value of the conversion feature. Management's estimates were based upon several factors, including an estimate of the likelihood of each of the possible settlement options, which included redemption through a call or put option, or a liquidity event that triggers conversion to Class A Common Units of Eureka Hunter Holdings. See "Note 20 - Subsequent Events".
Other Fair Value Measurements
The following table presents the carrying amounts and fair values categorized by fair value hierarchy level of the Company's financial instruments not carried at fair value:
				30-Sep-14						31-Dec-13
		Fair Value Hierarchy		Carrying Amount			Estimated Fair Value			Carrying Amount		Estimated Fair Value
				(in thousands)
Senior Notes		Level 2		$	597,313		$	639,000		$	597,230	$	651,300
MHR Senior Revolving Credit Facility		Level 3		$	256,000		$	256,000		$	218,000	$	218,000
Eureka Hunter Pipeline second lien term loan		Level 3		$	—		$	—		$	50,000	$	58,921
Eureka Hunter Pipeline Credit Agreement		Level 3		$	80,000		$	80,000		$	—	$	—
Equipment Notes Payable		Level 3		$	25,149		$	25,170		$	18,615	$	17,676
The fair value of the Company's Senior Notes is based on quoted market prices available for Magnum Hunter's Senior Notes.  The fair value hierarchy for the Company's Senior Notes is Level 2 (quoted prices for similar assets in active markets).
The carrying values of the Company's senior revolving credit facility (the "MHR Senior Revolving Credit Facility") and the outstanding borrowings under Eureka Hunter Pipeline's credit agreement (the "Eureka Hunter Pipeline Credit Agreement") approximate fair value as they are subject to short-term floating interest rates that approximate the rates available to the Company for those periods.  The fair value hierarchy for the MHR Senior Revolving Credit Facility and the Eureka Hunter Pipeline Credit Agreement is Level 3.
The fair value of Eureka Hunter Pipeline's second lien term loan as of December 31, 2013 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. Eureka Hunter Pipeline's second lien term loan was paid in full in March 2014.
The fair value of all fixed-rate notes and the credit facility is based on interest rates currently available to the Company.
Fair Value on a Non-Recurring Basis
The Company follows the provisions of ASC Topic 820, Fair Value Measurement, for non-financial assets and liabilities measured at fair value on a non-recurring basis. As it relates to the Company, ASC Topic 820 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.
As of September 30, 2014, the Company has measured the carrying value of certain long-lived assets of MHP previously classified as held for sale at their fair value in connection with their reclassification to assets held and used. See "Note 2 - Divestitures and Discontinued Operations". The fair value of these assets were derived using a variety of assumptions including market precedent transactions for similar assets, analyst pricing, and risk-adjusted discount rates for similar transactions. The Company has designated these valuations as Level 3.

FINANCIAL_INSTRUMENTS_AND_DERI

FINANCIAL INSTRUMENTS AND DERIVATIVES	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
FINANCIAL INSTRUMENTS AND DERIVATIVES	'
	NOTE 9 - FINANCIAL INSTRUMENTS AND DERIVATIVES
	Investment Holdings
	Below is a summary of changes in investments for the nine months ended September 30, 2014:
		Available for Sale Securities				Equity Method Investments (1)
		(in thousands)
	Carrying value as of December 31, 2013	$	1,819			$	940
	Securities received as consideration for assets sold	9,447				—
	Equity in net loss recognized in other income (expense)	—				(504		)
	Change in fair value recognized in other comprehensive loss	(3,190		)		—
	Carrying value as of September 30, 2014	$	8,076			$	436
	(1) Equity method investments includes $282,000 classified as long-term other assets.
	The Company's investments have been presented in the consolidated balance sheet as of September 30, 2014 as follows:
		Available for Sale Securities			Equity Method Investments			Total
	Investments - Current	$	8,076		$	154		$	8,230
	Other Assets - Long-Term	—			282			282
	Carrying value as of September 30, 2014	$	8,076		$	436		$	8,512
	The cost for equity securities and their respective fair values as of September 30, 2014 and December 31, 2013 are as follows:
			September 30, 2014
			(in thousands)
			Cost				Gross Unrealized Gains				Gross Unrealized Losses				Fair Value
	Securities available for sale, carried at fair value:
	Equity securities		$	9,875			$	—			$	(4,030	)		$	5,845
	Equity securities - related party (see "Note 15 - Related Party Transactions")		2,200				—				31				2,231
	Total Securities available for sale		$	12,075			$	—			$	(3,999	)		$	8,076
			December 31, 2013
			(in thousands)
			Cost				Gross Unrealized Gains				Gross Unrealized Losses				Fair Value
	Securities available for sale, carried at fair value:
	Equity securities		$	428			$	—			$	(281	)		$	147
	Equity securities - related party (see "Note 15 - Related Party Transactions")		2,200				—				(528		)		1,672
	Total Securities available for sale		$	2,628			$	—			$	(809	)		$	1,819
	The methods of determining the fair values of Magnum Hunter's investments in equity securities are described in "Note 8 - Fair Value of Financial Instruments".
	The Company's investment holdings are concentrated in three issuers whose business activities are related to the oil and natural gas or minerals mining industries. These investments are ancillary to the Company's overall operating strategy and such concentrations of risk related to investment holdings do not pose a substantial risk to the Company's operational performance. The Company evaluates factors that it believes could influence the fair value of the issuers' securities such as management, assets, earnings, cash generation, and capital needs.
	The fair values of equity securities fluctuate based upon changes in market prices. Gross unrealized losses on investments are considered for other-than-temporary impairment when such losses have continued for more than a 12-month period. However, security specific circumstances may arise where an investment is considered impaired when gross unrealized losses have been observed for less than twelve months. As of September 30, 2014 and December 31, 2013, the Company did not hold any equity securities which were in a gross unrealized loss position for greater than a year, and no impairments were recognized for the periods then ended.
	Commodity and Financial Derivative Instruments
	The Company periodically enters into certain commodity derivative instruments such as futures contracts, swaps, collars, and basis swap contracts, to mitigate 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 derivative instruments 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 is intended to help reduce exposure to price risk and improve 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, 2014, the Company had the following commodity derivative instruments:
					Weighted Average
	Natural Gas	Period	MMBtu/day		Price per MMBtu
	Collars (1)	Oct 2014- Dec 2014	15,000		$4.27 - $5.23
	Swaps	Oct 2014 - Dec 2014	41,000		$4.18
		Jan 2015 - Dec 2015	30,000		$4.12
	Ceilings purchased (call)	Oct 2014 - Dec 2014	16,000		$5.91
	Ceilings sold (call)	Oct 2014 - Dec 2014	16,000		$5.91
					Weighted Average
	Crude Oil	Period	Bbl/day		Price per Bbl
	Collars (1)	Oct 2014 - Dec 2014	663		$85.00 - $91.25
		Jan 2015 - Dec 2015	259		$85.00 - $91.25
	Traditional three-way collars (2)	Oct 2014 - Dec 2014	4,000		$64.94 - $85.00 - $102.50
	Ceilings sold (call)	Jan 2015 - Dec 2015	1,570		$120.00
	Floors sold (put)	Oct 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.
	As of September 30, 2014, Bank of America, Bank of Montreal, KeyBank National Association, Credit Suisse Energy, LLC, Citibank, N.A., ABN AMRO, the Royal Bank of Canada, and Goldman Sachs 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.  At September 30, 2014, all counterparties, or their affiliates, were participants in the MHR Senior Revolving Credit Facility, and the collateral for the outstanding borrowings under the MHR Senior Revolving Credit Facility was used as collateral for its commodity derivatives with those counterparties. Certain counterparties to the Company's commodity derivatives positions are no longer participants in the Company's credit facilities following the execution of new new credit agreements on October 22, 2014. See "Note 20 - Subsequent Events".
	At September 30, 2014, the Company had preferred stock derivative liabilities resulting from certain conversion features, redemption options, and other features of its Eureka Hunter Holdings Series A Preferred Units and Class A Common Units held by Ridgeline, which constituted all of the issued and outstanding Eureka Hunter Holdings Series A Preferred Units. See "Note 8 - Fair Value of Financial Instruments" and "Note 13 - Redeemable Preferred Stock". During the three-month period ended September 30, 2014, MSI entered into an agreement to purchase all of the issued and outstanding Eureka Hunter Holdings Series A Preferred Units. Contemporaneous with the closing of MSI's purchase, the Company, MSI, and all minority interest members of Eureka Hunter Holdings entered into the Second Amended and Restated Limited Liability Company Agreement of Eureka Hunter Holdings (the "New LLC Agreement"), which became effective on October 3, 2014. In connection with that amendment, all Eureka Hunter Holdings Series A Preferred Units were converted to a new class of equity. As a result, the preferred stock derivative liability effectively settled on the effective date of the New LLC Agreement through this conversion. See "Note 20 - Subsequent Events".
	At September 30, 2014, 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 8 - Fair Value of Financial Instruments" and "Note 15 - Related Party Transactions".
	The following table summarizes the fair value of the Company's commodity and financial derivative contracts as of the dates indicated:
					Derivative Assets								Derivative Liabilities
	Derivatives not designated as hedging instruments		Balance Sheet Classification		September 30, 2014				December 31, 2013				September 30, 2014				December 31, 2013
					(in thousands)
Commodity
		Derivative assets		$	1,871			$	529			$	—			$	—
		Derivative assets - long-term		255				25				—				—
		Derivative liabilities		—				—				(48		)		(1,903		)
		Derivative liabilities - long-term		—				—				(66		)		(376		)
Total commodity				$	2,126			$	554			$	(114	)		$	(2,279	)
Financial
		Derivative assets		$	83			$	79			$	—			$	—
		Derivative liabilities - long-term		—				—				(173,205		)		(75,934		)
Total financial				$	83			$	79			$	(173,205	)		$	(75,934	)
Total derivatives				$	2,209			$	633			$	(173,319	)		$	(78,213	)
Certain of the Company's derivative instruments are subject to enforceable master netting arrangements that provide for the net settlement of all derivative contracts between the Company and a counterparty in the event of default or upon the occurrence of certain termination events.  The tables below summarize the Company's commodity derivatives and the effect of master netting arrangements on the presentation in the Company's consolidated balance sheets as of:
	September 30, 2014
	Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset on the Consolidated Balance Sheet		Net Amount
	(in thousands)
Current assets:  Fair value of derivative contracts	$	2,399		(528	)	$	1,871
Long-term assets:  Fair value of derivative contracts	377			(122	)	255
Current liabilities:  Fair value of derivative contracts	(576		)	528		(48		)
Long-term liabilities:  Fair value of derivative contracts	(188		)	122		(66		)
	$	2,012		—		$	2,012
	December 31, 2013
	Gross Amounts of Assets and Liabilities			Gross Amounts Offset on the Consolidated Balance Sheet		Net Amount
	(in thousands)
Current assets:  Fair value of derivative contracts	$	4,034		(3,505	)	$	529
Long-term assets:  Fair value of derivative contracts	516			(491	)	25
Current liabilities:  Fair value of derivative contracts	(5,408		)	3,505		(1,903		)
Long-term liabilities:  Fair value of derivative contracts	(867		)	491		(376		)
	$	(1,725	)	—		$	(1,725	)
The following table summarizes the net gain (loss) on all derivative contracts included in gain (loss) on derivative contracts, net on the consolidated statements of operations for the three and nine months ended September 30, 2014 and 2013:
	Three Months Ended September 30,								Nine Months Ended
									September 30,
	2014				2013				2014				2013
	(in thousands)
Gain (loss) on settled transactions	$	477			$	(6,582	)		$	(4,074	)		$	(6,887	)
Loss on open contracts	(50,113		)		(22,971		)		(88,051		)		(23,757		)
Total loss	$	(49,636	)		$	(29,553	)		$	(92,125	)		$	(30,644	)

DEBT

DEBT	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
DEBT	'
	NOTE 10 - DEBT
	Long-term debt at September 30, 2014 and December 31, 2013 consisted of the following:
		September 30, 2014			December 31, 2013
		(in thousands)
	Senior Notes payable due May 15, 2020, interest rate of 9.75%, net of unamortized net discount of $2.7 million at September 30, 2014 and December 31, 2013	$	597,313		$	597,230
	Various equipment and real estate notes payable with maturity dates January 2015 - April 2021, interest rates of 4.25% - 7.94%(1)	25,149			18,615
	Eureka Hunter Pipeline Credit Agreement due March 28, 2018, interest rate of 3.66%	80,000			—
	Eureka Hunter Pipeline second lien term loan due August 16, 2018, interest rate of 12.5%	—			50,000
	MHR Senior Revolving Credit Facility due April 13, 2016, interest rate of 3.06% at September 30, 2014 and 3.56% at December 31, 2013	256,000			218,000
		958,462			883,845
	Less: current portion	(8,670		)	(3,967		)
	Total long-term debt obligations, net of current portion	$	949,792		$	879,878
	_________________________________
	-1	Balance as of December 31, 2013 includes notes classified as liabilities associated with assets held for sale of which $0.2 million is current and $3.8 million is long-term.
	The following table presents the scheduled or expected approximate annual maturities of debt, gross of unamortized discount of $2.7 million:
		(in thousands)
	2014	$	2,565
	2015	7,717
	2016	264,727
	2017	2,548
	2018	80,559
	Thereafter	603,032
	Total	$	961,148
	MHR Senior Revolving Credit Facility and Second Lien Term Loan
	On December 13, 2013, the Company entered into a Third Amended and Restated Credit Agreement (the "Credit Agreement") by and among the Company, Bank of Montreal, as Administrative Agent, the lenders party thereto and the agents party thereto. The Credit Agreement amended and restated that certain Second Amended and Restated Credit Agreement, dated as of April 13, 2011, by and among such parties, as amended (the "Prior Credit Agreement").
	On May 6, 2014, the Company and the other parties to the Credit Agreement entered into the First Amendment to Third Amended and Restated Credit Agreement (the "Amendment"). The Amendment increased the borrowing base from $232.5 million to $325.0 million in connection with the regular semi-annual redetermination of the Company's borrowing base derived from the Company's proved crude oil and natural gas reserves. The borrowing base may be increased or decreased in connection with such redeterminations up to a maximum commitment level of $750.0 million. The Amendment provides that such increased borrowing base shall be reduced (i) by the lesser of $25.0 million or 50% of the net proceeds from issuances by the Company of common equity on or before July 1, 2014 (other than common equity issued pursuant to any stock incentive or stock option plan or any other compensatory arrangements); (ii) by certain specified reductions in connection with certain proposed asset dispositions; (iii) on July 1, 2014 by $25.0 million less any prior adjustment of the borrowing base due to an equity issuance as contemplated by clause (i); and (iv) by $0.25 for each $1.00 of any additional Senior Notes issued by the Company. The Amendment further provides that from May 6, 2014 through July 1, 2014 the Applicable Margin (as defined in the Credit Agreement) component of the interest charged on revolving borrowings under the Credit Agreement shall be 2.75% for ABR Loans (as defined in the Credit Agreement) and 3.75% for Eurodollar Loans (as defined in the Credit Agreement). From and after July 1, 2014 through the date of the Company’s delivery of a certificate for the quarter ended June 30, 2014, with respect to, among other things, the Company’s compliance with the covenants in the Credit Agreement (the "Compliance Certificate"), the Applicable Margin component of interest charged on revolving borrowings under the Credit Agreement will range from 1.50% to 2.25% for ABR Loans and from 2.50% to 3.25% for Eurodollar Loans. From and after the Company’s delivery of the Compliance Certificate, the Applicable Margin component of interest charged on revolving borrowings under the Credit Agreement will range from 1.00% to 1.75% for ABR Loans and from 2.00% to 2.75% for Eurodollar Loans.
	In addition, the Amendment modified certain of the Credit Agreement’s financial covenants, including:
	(i)	permitting the Company to take into account the borrowing base increase as though it occurred on March 31, 2014 for purposes of maintaining a ratio of consolidated current assets to consolidated current liabilities of not less than 1.0 to 1.0;
	(ii)	providing for a ratio of EBITDAX to Interest Expense of not less than (A) 2.00 to 1.0 for the fiscal quarter ended March 31, 2014, (B) 2.25 to 1.0 for the fiscal quarters ending June 30, 2014 and September 30, 2014, and (C) 2.50 to 1.0 for the fiscal quarter ending December 31, 2014 and for each fiscal quarter ending thereafter; and
	(iii)	beginning with the fiscal quarter ended June 30, 2014, providing for a ratio of total Debt to EBITDAX of not more than (A) 4.75 to 1.0 for the fiscal quarters ending June 30, 2014 and September 30, 2014, (B) 4.50 to 1.0 for the fiscal quarter ending December 31, 2014, and (C) 4.25 to 1.0 for the fiscal quarter ending March 31, 2015 and for each fiscal quarter ending thereafter.
	The Amendment also (i) amends the definition of EBITDAX and provides that certain acquisitions and dispositions be given pro forma effect in the calculation of EBITDAX; (ii) increases the letter of credit commitment from $10.0 million to $50.0 million and provides that outstanding letter of credit exposure not be included in certain determinations of Debt; (iii) requires the total value of the Company’s oil and gas properties included in the reserve reports for the borrowing base determinations in which the lenders under the Credit Agreement have perfected liens be increased from 80% to 90%; and (iv) modifies certain covenants in the Credit Agreement with respect to permitted investments by the Company to increase flexibility.
	The Company incurred direct financing costs associated with entering into the Amendment to the Credit Agreement in the amount of $3.1 million, which will be deferred and amortized over the remaining term of the Credit Agreement.
	As of September 30, 2014, the borrowing base under this facility was $265.0 million, and $256.0 million of borrowings were outstanding ($218.0 million outstanding as of December 31, 2013). The borrowing base as of September 30, 2014 reflects reductions in the borrowing base of $25 million, $27.5 million, and $7.5 million related to the issuance of equity in May 2014, the sale of our 100% equity interest in WHI Canada which closed in May 2014, and the sale of certain assets in North Dakota which closed in September 2014, respectively. The borrowing base is subject to further automatic reductions upon the issuance of additional Senior Notes and in certain other circumstances.
	On October 22, 2014, the Company entered into (i) a Fourth Amended and Restated Credit Agreement (the "New Credit Agreement"), by and among the Company, as borrower, Bank of Montreal, as administrative agent, the lenders party thereto and agents party thereto, and (ii) a Second Lien Credit Agreement (the "Second Lien Term Loan Agreement"), by and among the Company, as borrower, Credit Suisse AG, Cayman Islands Branch, as administrative agent and collateral agent, the lenders party thereto and the agents party thereto. The New Credit Agreement amended and restated the Credit Agreement. The proceeds from the New Credit Agreement and the Second Lien Term Loan Agreement were used, in part, to refinance the amounts outstanding under the Credit Agreement on the date of closing.
	As a result of the refinancing of the Credit Agreement with the New Credit Agreement and the Second Lien Term Loan Agreement, the Company was not required to provide compliance certificates for covenants stipulated in the Credit Agreement as of and for the period ended September 30, 2014.  See "Note 20 - Subsequent Events" for additional information.
	Eureka Hunter Pipeline Credit Agreement
	On March 28, 2014, Eureka Hunter Pipeline entered into the Eureka Hunter Pipeline Credit Agreement, by and among Eureka Hunter Pipeline, as borrower, ABN AMRO Capital USA, LLC, as a lender and as administrative agent, and the other lenders party thereto.
	The credit agreement, which has a maturity date of March 28, 2018, provides for a revolving credit facility in an aggregate principal amount of up to $117.0 million (with the potential to increase the aggregate commitment under the credit agreement to an aggregate principal amount of up to $150.0 million, subject to the consent of the lender parties and the satisfaction of certain conditions), secured by a first lien on substantially all of the assets of Eureka Hunter Pipeline and its subsidiaries, which include TransTex Hunter, as well as by Eureka Hunter Pipeline’s pledge of the equity in its subsidiaries. The subsidiaries of Eureka Hunter Pipeline also guarantee Eureka Hunter Pipeline’s obligations under the credit agreement. The credit agreement is non-recourse to Magnum Hunter. The Company incurred deferred financing costs directly associated with entering into the Eureka Hunter Pipeline Credit Agreement in the amount of $1.2 million which will be amortized straight-line over the term of the revolving credit facility. The straight-line method of amortization results in substantially the same periodic amortization as the effective interest method.
	The terms of the credit agreement provide that the borrowings thereunder may be used, among other specified purposes, (1) to refinance existing indebtedness of Eureka Hunter Pipeline outstanding on the credit agreement closing date, including the term loan of $50.0 million in principal amount owed under the Second Lien Term Loan Agreement, dated August 16, 2011, by and among Eureka Hunter Pipeline and Pennant Park Investment Corporation, as a lender, the other lenders party thereto and U.S. Bank National Association, as collateral agent, (2) to finance future expansion activities related to Eureka Hunter Pipeline’s gathering system in West Virginia and Ohio, (3) to finance acquisitions by Eureka Hunter Pipeline and its subsidiaries permitted under the terms of the credit agreement, (4) to refinance from time to time certain letters of credit of Eureka Hunter Pipeline and its subsidiaries, (5) to provide working capital for their operations, and (6) for their other general business purposes.
	The Eureka Hunter Pipeline Credit Agreement provides for a commitment fee based on the unused portion of the commitment under the credit agreement of 0.50% per annum when the consolidated leverage ratio is greater than or equal to 3.0 to 1.0 and a commitment fee of 0.375% when the consolidated leverage ratio is less than 3.0 to 1.0.
	In general terms, borrowings under the credit agreement will, at Eureka Hunter Pipeline’s election, bear interest:
	•	on base rate loans, at the per annum rate equal to the sum of (A) the base rate (defined as the highest of (i) the per annum rate of interest established by JPMorgan Chase Bank, N.A. as its prime rate for U.S. dollar loans, (ii) the Adjusted Eurodollar Rate (as defined in the credit agreement) for an interest period of one-month, plus 1.0%, or (iii) the federal funds rate, plus 0.50% per annum), and (B) a margin of 1.0% to 2.50% per annum; or
	•	on Eurodollar Loans, at the per annum rate equal to the sum of (A) the Eurodollar Rate (as defined in the credit agreement) adjusted for certain statutory reserve requirements for Eurocurrency liabilities, and (B) a margin of 2.0% to 3.50% per annum.
	If an event of default occurs under the credit agreement, generally, the applicable lenders may increase the interest rate then in effect by an additional 2.0% per annum for the period that the default exists.
	The credit agreement contains customary affirmative covenants and negative covenants that, among other things, restrict the ability of each of Eureka Hunter Pipeline and its subsidiaries to, with certain exceptions: (1) incur indebtedness; (2) grant liens; (3) enter into hedging transactions; (4) enter into a merger or consolidation or sell, lease, transfer or otherwise dispose of all or substantially all of its assets or the stock of any of its subsidiaries; (5) issue equity; (6) dispose of any material assets or properties; (7) pay or declare dividends or make certain distributions; (8) invest in, extend credit to or make advances or loans to any person or entity; (9) engage in material transactions with any affiliate; (10) enter into any agreement that restricts or imposes any condition upon the ability of (a) any of Eureka Hunter Pipeline or its subsidiaries to create, incur or permit any lien upon any of its assets or properties, or (b) any such subsidiary to pay dividends or other distributions, to make or repay loans or advances, to guarantee indebtedness or to transfer any of its property or assets to Eureka Hunter Pipeline or its subsidiaries; (11) change the nature of its business; (12) amend its organizational documents or material agreements; (13) change its fiscal year; (14) enter into sale and leaseback transactions; (15) make acquisitions; (16) make certain capital expenditures; or (17) take any action that could result in regulation as a utility.
	The credit agreement requires Eureka Hunter Pipeline to satisfy certain financial covenants, including maintaining:
	•	a maximum leverage ratio (defined as the ratio of (i) consolidated funded debt to (ii) annualized consolidated EBITDA), as of the end of each fiscal quarter, not greater than (A) 4.75 to 1.00 for the fiscal quarters ending March 31, 2014 through September 30, 2014, and (B) 4.50 to 1.00 for the fiscal quarter ending December 31, 2014 and each fiscal quarter ending thereafter; and
	•	a minimum interest coverage ratio (defined as the ratio of (i) annualized consolidated EBITDA to (ii) annualized consolidated interest charges for such period), as of the end of each fiscal quarter, not less than (A) 2.75 to 1.00 for the fiscal quarters ending March 31, 2014 through September 30, 2014, and (B) 2.50 to 1.00 for the fiscal quarter ending December 31, 2014 and each fiscal quarter ending thereafter.
	The obligations of Eureka Hunter Pipeline under the credit agreement may be accelerated upon the occurrence of an event of default. Events of default include customary events for these types of financings, including, among other things, payment defaults, defaults in the performance of affirmative or negative covenants, the inaccuracy of representations or warranties, material defaults under or termination of certain material contracts, defaults relating to judgments, certain bankruptcy proceedings, a change in control and any material adverse change.
	As of September 30, 2014 the maximum amount available under the credit agreement was $90.2 million, and the Company had $80.0 million in borrowings outstanding. The borrowing capacity is subject to certain upward or downward reductions during the term of the credit agreement.
	As of September 30, 2014, Eureka Hunter Pipeline was in compliance with all of its covenants contained in the Eureka Hunter Pipeline Credit Agreement.
	Eureka Hunter Pipeline Credit Facilities
	Upon executing the new Eureka Hunter Pipeline Credit Agreement on March 28, 2014, Eureka Hunter Pipeline terminated its revolving credit agreement with SunTrust Bank and the term loan agreement with Pennant Park (the "Original Eureka Hunter Credit Facilities"). Eureka Hunter Pipeline used proceeds from the Eureka Hunter Pipeline Credit Agreement to pay in full all outstanding obligations related to the termination of the Original Eureka Hunter Credit Facilities, which included the principal outstanding amount of $50.0 million, a prepayment penalty of $2.2 million, and accrued, unpaid interest of $1.5 million.
	Equipment Note Payable
	On January 21, 2014, the Company's wholly owned subsidiary, Alpha Hunter Drilling, LLC, entered into a master loan and security agreement with CIT Finance LLC to borrow $5.6 million at an interest rate of 7.94% over a term of forty-eight months. The note is collateralized by field equipment, and the Company is a guarantor on the note.
	Building Note Payable
	Effective September 30, 2014, MHP refinanced its $3.8 million term loan with Traditional Bank, Inc. that was due to mature in early 2015.  The new loan is collateralized by an office building owned by MHP and carried an initial principal balance of $3.8 million at an interest rate of 4.875% with a maturity date of September 30, 2024.
	Interest Expense
	The following table sets forth interest expense for the three and nine month periods ended September 30, 2014 and 2013, respectively:
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014		2013
		(in thousands)
Interest expense incurred on debt, net of amounts capitalized	$	17,013		$	14,648		$	53,748	$	49,691
Amortization and write-off of deferred financing costs	1,082			1,111			8,725		3,661
Total interest expense	$	18,095		$	15,759		$	62,473	$	53,352
The Company capitalizes interest on expenditures for significant construction projects that last more than six months while activities are in progress to bring the assets to their intended use. The Company capitalized interest on its Eureka Hunter Gas Gathering System of $723,000 and $1.6 million during the three and nine months ended September 30, 2014, respectively, and $582,000 and $2.0 million during the three and nine months ended September 30, 2013, respectively.
For the nine-month period ended September 30, 2014, interest expense incurred on debt includes a $2.2 million prepayment penalty incurred by Eureka Hunter Pipeline as a result of its early termination of the Original Eureka Hunter Credit Facilities on March 28, 2014, which penalty represents an additional cost of borrowing for a period shorter than contractual maturity. In addition, amortization and write-off of deferred financing costs for the nine-month period ended September 30, 2014 includes the write-off of $2.7 million in unamortized deferred financing costs related to those terminated agreements, which costs were expensed at the time of early extinguishment and $1.7 million in unamortized deferred financing costs related to the Amendment of the MHR Senior Revolving Credit Facility.

SHAREBASED_COMPENSATION

SHARE-BASED COMPENSATION	9 Months Ended
	Sep. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
SHARE-BASED COMPENSATION	'
	NOTE 11 - 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 9,274,248 shares had been issued under the plan as of September 30, 2014, of which 1,398,898 shares remained unvested at September 30, 2014. Additionally, 13,294,506 options to purchase shares and stock appreciation rights were outstanding as of September 30, 2014, of which 4,115,833 remained unvested at September 30, 2014.
	The Company recognized share-based compensation expense of $2.3 million and $5.7 million for the three and nine months ended September 30, 2014, respectively, and $3.1 million and $11.8 million for the three and nine months ended September 30, 2013, respectively.
	A summary of common stock option activity for the nine months ended September 30, 2014 and 2013 is presented below:
		Nine Months Ended September 30,
		2014		2013		2014		2013
		(in thousands of shares)				Weighted Average Exercise Price per Share
	Outstanding at beginning of period	16,891		14,847		$	5.69	$	6.01
	Granted	—		4,938		$	—	$	4.11
	Exercised	(2,355	)	(685	)	$	4.09	$	2.95
	Forfeited	(1,241	)	(742	)	$	6.28	$	6
	Outstanding at end of period	13,295		18,358		$	5.91	$	5.61
	Exercisable at end of period	9,179		10,512		$	6.22	$	5.86
	A summary of the Company’s non-vested common stock options and stock appreciation rights for the nine months ended September 30, 2014 and 2013 is presented below:
		Nine Months Ended September 30,
		2014		2013
		(in thousands of shares)
	Non-vested at beginning of period	6,908		6,163
	Granted	—		4,938
	Vested	(1,916	)	(2,867	)
	Forfeited	(876	)	(389	)
	Non-vested at end of period	4,116		7,845
	Total unrecognized compensation cost related to the non-vested common stock options was $4.7 million and $12.9 million as of September 30, 2014 and 2013, respectively.  The unrecognized compensation cost at September 30, 2014 is expected to be recognized over a weighted-average period of 1.1 years. At September 30, 2014, the weighted average remaining contract life of outstanding options was 5.6 years.
	During the nine months ended September 30, 2014, the Company granted 1,486,373 restricted shares of common stock to officers, executives, and employees of the Company which vest over a 3-year period with 33% of the restricted shares vesting one year from the date of the grant. The Company also granted 123,798 restricted shares to the directors of the Company which vest 100% one year from the date of the grant. The shares had a fair value at the time of grant of $10.8 million based on the stock price on grant date and estimated forfeiture rate of 3.4%.
	Total unrecognized compensation cost related to non-vested, restricted shares amounted to $7.1 million and $66,000 as of September 30, 2014 and 2013, respectively.  The unrecognized cost at September 30, 2014, is expected to be recognized over a weighted-average period of 2.1 years.
	Eureka Hunter Holdings, LLC Management Incentive Compensation Plan
	On May 12, 2014, the Board of Directors of Eureka Hunter Holdings approved the Eureka Hunter Holdings, LLC Management Incentive Compensation Plan ("Eureka Hunter Holdings Plan") to provide long-term incentive compensation to attract and retain officers and employees of Eureka Hunter Holdings and its affiliates and allow such individuals to participate in the economic success of Eureka Hunter Holdings and its affiliates.
	The Eureka Hunter Holdings Plan consists of (i) 2,336,905 Class B Common Units representing membership interests in Eureka Hunter Holdings ("Class B Common Units"), and (ii) 2,336,905 Incentive Plan Units issuable pursuant to a management incentive compensation plan, which represent the right to receive a dollar value up to the baseline value of a corresponding Class B Common Unit ("Incentive Plan Units"). The Eureka Hunter Holdings Plan is administered by the Board of Directors of Eureka Hunter Holdings, and, as administrator of the Eureka Hunter Holdings Plan, the board will from time to time make awards under the Eureka Hunter Holdings Plan to selected officers and employees of Eureka Hunter Holdings or its affiliates ("Award Recipients").
	The Class B Common Units are profits interest awards that carry the right to share in the appreciation in the value of the aggregate common equity in Eureka Hunter Holdings over and above a baseline value that is determined on the date of grant of the Class B Common Units. The Class B Common Units vest in five substantially equal annual installments on each of the first five anniversaries of the date of grant, subject to the Award Recipient's continued employment, and automatically vest in full upon the occurrence of a liquidity event (as defined in the Eureka Hunter Holdings Plan) (including if the Award Recipient's employment is terminated by Eureka Hunter Holdings or an affiliate without cause or due to the Award Recipient's death or disability, in each case, within six months prior to the occurrence of a liquidity event). Subject to the Award Recipient's continued employment, the Incentive Plan Units become fully vested upon the occurrence of a liquidity event (including if the Award Recipient's employment is terminated by Eureka Hunter Holdings or an affiliate without cause or due to the Award Recipient's death or disability, in each case, within six months prior to the occurrence of a liquidity event).
	If an Award Recipient’s employment is terminated under any other circumstances, all unvested Class B Common Units and Incentive Plan Units will be forfeited immediately upon the Award Recipient’s termination of employment. In addition, vested Class B Common Units will be forfeited if an Award Recipient’s employment is terminated prior to the occurrence of a liquidity event by Eureka Hunter Holdings or an affiliate for cause or due to the Award Recipient’s resignation. If, following a termination of his or her employment by Eureka Hunter Holdings or an affiliate without cause or due to the Award Recipient’s death or disability, an Award Recipient retains vested Class B Common Units, Eureka Hunter Holdings will have the right, but not the obligation, to repurchase such vested Class B Common Units at fair market value.
	Distributions, if any, with respect to the Class B Common Units issued pursuant to the Class B Common Unit Agreement will be made in accordance with, and subject to, the New LLC Agreement, provided, that, no distributions shall be made with respect to any vested or unvested Class B Common Units unless and until a liquidity event has occurred (other than tax distributions that may be made in accordance with the New LLC Agreement). Payment in respect of vested Class B Common Units and Incentive Plan Units will become due upon the occurrence of a liquidity event and are expected to be settled in cash upon the occurrence of a liquidity event, except in the case of a qualified public offering (as defined in the Eureka Hunter Holdings Plan), in which case settlement will occur partially in cash and partially in shares of the resulting public entity, with the cash portion not to exceed the amount necessary to cover minimum statutory tax withholdings.
	Upon approval of the plan on May 12, 2014, the Board of Directors of Eureka Hunter Holdings granted 894,102 Class B Common Units and 894,102 Incentive Plan Units to key employees of Eureka Hunter Holdings and its subsidiaries. The Class B Common Units and Incentive Plan Units are accounted for in accordance with ASC 718, Compensation - Stock Compensation. In accordance with ASC 718, compensation cost is accrued when the performance condition (i.e. the liquidity event) is probable of being achieved. As of September 30, 2014, a liquidity event, as defined, was not probable, and therefore, no compensation cost has been recognized.

SHAREHOLDERS_EQUITY

SHAREHOLDERS’ EQUITY	9 Months Ended
	Sep. 30, 2014
Equity [Abstract]	'
SHAREHOLDERS’ EQUITY	'
	NOTE 12 - SHAREHOLDERS' EQUITY
	Common Stock
	During the nine months ended September 30, 2014, the Company:
	i)	issued 70,575 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 2,355,000 shares of the Company’s common stock upon exercise of fully vested stock options;
	iii)	issued 4,300,000 shares of the Company's common stock in March 2014 in a private placement at a price of $7.00 per share, with net proceeds to the Company of $28.9 million after deducting sales agent commissions and other issuance costs. The Company subsequently filed a Form S-1 Registration Statement with the SEC which was declared effective on July 23, 2014 to register the resale of these shares by the holders thereof to satisfy the Company's registration obligations under the private placement. A post-effective amendment filed to convert the Form S-1 Registration Statement to a Form S-3 Registration Statement was declared effective by the SEC on September 11, 2014;
	iv)	issued 21,428,580 shares of the Company's common stock in May 2014 in a private placement at a price of $7.00 per share, with net proceeds to the Company of $149.7 million after deducting issuance costs. The Company subsequently filed a Form S-1 Registration Statement with the SEC to register the resale of these shares by the holders thereof to satisfy the Company's registration obligations under the private placement. A post-effective amendment filed to convert the Form S-1 Registration Statement to a Form S-3 Registration Statement was declared effective by the SEC on August 22, 2014; and
	v)	issued 249,531 shares of the Company's common stock to fund safe-harbor and discretionary matching contributions to the Company's 401k plan in respect of salary deferrals made by participants in the plan during 2013.
	Common Stock Warrants
	The Company issued 2,142,858 warrants to purchase common stock with an exercise price of $8.50 per share, subject to certain anti-dilution adjustments, in conjunction with the May 2014 private placement sales of common stock. The warrants became exercisable beginning on May 29, 2014, and will expire on April 15, 2016. The warrants are subject to redemption at the option of the Company at $0.001 per warrant upon not less than thirty days' notice to the holders, only if the Company also redeems the warrants it previously issued pursuant to that certain Warrants Agreement, dated October 15, 2013, by and between the Company and American Stock Transfer & Trust Company, Inc. The warrants were issued in connection with the May 2014 sale of 21,428,580 common shares, and the proceeds for the sale of the common shares and the warrants have been reflected in the Company's capital accounts as increases to common stock and additional paid in capital.
	Preferred Dividends Incurred
	A summary of the Company's preferred dividends for the three and nine months ended September 30, 2014 and 2013 is presented below:
		Three Months Ended September 30,					Nine Months Ended September 30,
		2014			2013		2014		2013
		(in thousands)					(in thousands)
	Dividend on Eureka Hunter Holdings Series A Preferred Units	$	4,338		$	3,771	$	12,619	$	10,441
	Accretion of the carrying value of the Eureka Hunter Holdings Series A Preferred Units	2,306			1,826		6,583		4,990
	Dividend on Series C Preferred Stock	2,562			2,562		7,686		7,686
	Dividend on Series D Preferred Stock	4,424			4,424		13,273		13,231
	Dividend on Series E Preferred Stock	1,862			1,834		5,557		5,686
	Total dividends on Preferred Stock	$	15,492		$	14,417	$	45,718	$	42,034
	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 and stock appreciation rights, common stock purchase warrants and any outstanding convertible securities.
	The Company has issued potentially dilutive instruments in the form of restricted common stock of Magnum Hunter granted and not yet issued, common stock warrants, common stock options granted to the Company's employees and directors, and the Company's Series E Preferred Stock. The Company did not include any of these instruments in its calculation of diluted loss per share during the periods presented, because to include them would be anti-dilutive due to the Company's loss from continuing operations during those periods.
	The following table summarizes the types of potentially dilutive securities outstanding as of September 30, 2014 and 2013:
		September 30,
		2014		2013
		(in thousands of shares)
	Series E Preferred Stock	10,946		11,185
	Warrants	19,214		30,407
	Unvested restricted shares	1,445		—
	Common stock options and stock appreciation rights	13,295		18,358
	Total	44,900		59,950

REDEEMABLE_PREFERRED_STOCK

REDEEMABLE PREFERRED STOCK	9 Months Ended
	Sep. 30, 2014
Equity [Abstract]	'
REDEEMABLE PREFERRED STOCK	'
	NOTE 13 - 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, an affiliate of ArcLight. Pursuant to this Unit Purchase Agreement, Ridgeline committed, subject to certain conditions, to purchase up to $200.0 million of Eureka Hunter Holdings Series A Preferred Units, representing membership interests of Eureka Hunter Holdings, of which $200.0 million had been purchased as of September 30, 2014.
	During the nine months ended September 30, 2014, Eureka Hunter Holdings issued 610,000 Eureka Hunter Holdings Series A Preferred Units to Ridgeline for net proceeds of $12.0 million, net of transaction costs. The Eureka Hunter Holdings Series A Preferred Units outstanding at September 30, 2014 represented 40.9% 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, 2014, Eureka Hunter Holdings issued 97,492 Eureka Hunter Holdings Series A Preferred Units as payment of $1.9 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 $173.2 million at September 30, 2014.
	Dividend expense included accretion of the Eureka Hunter Holdings Series A Preferred Units of $2.3 million and $6.6 million for the three and nine months ended September 30, 2014, and $1.8 million and $5.0 million for the three and nine months ended September 30, 2013, respectively.
	On September 16, 2014, the Company entered into an agreement (the "Transaction Agreement") with MSI relating to a separate purchase agreement between MSI and Ridgeline providing for the purchase by MSI of all convertible preferred and common equity interests in Eureka Hunter Holdings owned by Ridgeline.
	The Transaction Agreement provided for a New LLC Agreement of Eureka Hunter Holdings to be entered into by Magnum Hunter, MSI and the minority interest members of Eureka Hunter Holdings contingent upon and contemporaneously with the closing of MSI's purchase of Ridgeline's equity interests in Eureka Hunter Holdings, which occurred on October 3, 2014. In connection with the first closing on October 3, 2014, all of the Eureka Hunter Holdings Series A Preferred Units and Class A Common Units of Eureka Hunter Holdings acquired by MSI from Ridgeline were converted into a new class of equity interests of Eureka Hunter Holdings, and all equity interests owned by MSI will have a liquidation preference under certain circumstances. The conversion of the Eureka Hunter Holdings Series A Preferred Units to a new class of equity resulted in an extinguishment of the Eureka Hunter Holdings Series A Preferred Units and the issuance of a new class of equity initially recorded at fair value. See "Note 20 - Subsequent Events".

TAXES

TAXES	9 Months Ended
	Sep. 30, 2014
Income Tax Disclosure [Abstract]	'
Taxes	'
	NOTE 14 - TAXES
	The Company's income tax benefit from continuing operations for the three and nine months ended September 30, 2014 and 2013 was:
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
		(in thousands)
	Deferred	$	—	$	582	$	—	$	47,227
	Income tax benefit	$	—	$	582	$	—	$	47,227
	The Company recognizes 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 Company maintains a full valuation allowance on deferred tax assets where the realization of those deferred tax assets is not more likely than not. 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 United States, various states and Canada. As of September 30, 2014, 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.

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	9 Months Ended
	Sep. 30, 2014
Related Party Transactions [Abstract]	'
RELATED PARTY TRANSACTIONS	'
	NOTE 15 - RELATED PARTY TRANSACTIONS
	The following table sets forth the related party balances as of September 30, 2014 and December 31, 2013:
		September 30, 2014				December 31, 2013
		(in thousands)
	Green Hunter (1)
	Accounts payable - net	$	355			$	23
	Derivative assets (2)	$	83			$	79
	Investments (2)	$	2,385			$	2,262
	Notes receivable (2)	$	1,360			$	1,768
	Prepaid expenses	$	—			$	9
	The Company holds investments in a related party consisting of 1,846,722 shares of common stock of GreenHunter with a carrying value of $154,252 as of September 30, 2014 and 88,000 shares of Series C preferred stock of GreenHunter with a carrying value of $2.2 million as of September 30, 2014.
	The following table sets forth the related party transaction activities for the three and nine months ended September 30, 2014 and 2013, respectively:
			Three Months Ended							Nine Months Ended
			September 30,							September 30,
			2014				2013			2014		2013
			(in thousands)
	GreenHunter
		Salt water disposal (1)	$	820			$	623		$	1,754	$	2,069
		Equipment rental (1)	74				95			215		167
		Gas gathering-trucking (1)	132				—			532		—
		MAG tank panels (1)	—				—			800		—
		Office space rental	—				—			36		—
		Interest income from note receivable (2)	38				51			121		159
		Dividends earned from Series C shares	55				73			165		165
		Unrealized gain/(loss) on investments (2)	(38		)		(24		)	123		653
	Pilatus Hunter, LLC
		Airplane rental expenses (3)	49				26			207		94
	_________________________________
	-1	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman, a major shareholder and interim CEO. Eagle Ford Hunter received, and Triad Hunter and Viking International Resources Co., Inc., 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.
	-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.  See "Note 8 - 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.
	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.
	As of September 30, 2014, Mr. Evans, the Company's Chairman and Chief Executive Officer, held 27,641 Class A Common Units of Eureka Hunter Holdings. On October 3, 2014, in connection with the New LLC Agreement, these Class A Common Units were converted into Series A-1 Common Units. See "Note 20 - Subsequent Events".

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENCIES	'
	NOTE 16 - COMMITMENTS AND CONTINGENCIES
	Commitment for Firm Transportation
	On August 18, 2014, Triad Hunter executed a Precedent Agreement for Texas Gas Transmission LLC's ("TGT") Northern Supply Access Line (the "TGT Transportation Services Agreement"). Through executing the TGT Transportation Services Agreement, Triad Hunter committed to purchase 100,000 MMBtu per day of firm transportation capacity on TGT's Northern Supply Access Line. The term of the TGT Transportation Services Agreement will commence with the date the pipeline project is available for service, currently anticipated to be in early 2017, and will end 15 years thereafter. The execution of a Firm Transportation Agreement is contingent upon TGT receiving appropriate approvals from the Federal Energy Regulatory Commission ("FERC") for their pipeline project. Upon executing a Firm Transportation Agreement, the Company will have minimum annual contractual obligations for reservation charges of approximately $12.8 million over the 15 year term of the agreement.
	On October 21, 2014, Triad Hunter executed a Credit Support Agreement with TGT pursuant to which Triad Hunter agreed to provide, at discrete points in time, letters of credit to TGT tied to the expected payments for firm transportation. See "Note 20 - Subsequent Events" for additional information.
	Agreement to Purchase Utica Shale Acreage
	On August 12, 2013, Triad Hunter entered into an asset purchase agreement with MNW Energy, LLC ("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 a period of time, in staggered closings, subject to certain conditions. On December 30, 2013, a lawsuit was filed against the Company, Triad Hunter, MNW and others by Dux Petroleum, LLC ("Dux")asserting certain claims relating to the acreage covered by the asset purchase agreement with MNW. As a result of the litigation, no purchases were made during the first quarter of 2014. On May 28, 2014, the litigation was settled. As part of the settlement, the Company and Triad Hunter agreed to collectively pay Dux the aggregate amount of $500,000. Subsequent to the settlement of the lawsuit, Triad Hunter resumed closings of lease acquisitions from MNW. On June 5, 2014, Triad Hunter closed on the acquisition of 11,128 net leasehold acres for $45.9 million from MNW. To date, under the asset purchase agreement, Triad Hunter has now acquired a total of approximately 17,000 net leasehold acres from MNW, or approximately 53% of the approximately 32,000 total net leasehold acres anticipated under the asset purchase agreement.
	Takeover Bid
	On June 20, 2014, the Company lodged a Bidder’s Statement with the Australian Securities and Investments Commission, through its wholly owned subsidiary, Outback Shale Hunter Pty Ltd, an Australian company, to commence an off-market takeover offer (the "Offer") for Ambassador Oil and Gas Limited, an Australian company listed on the Australian Securities Exchange ("ASX") (ASX: AQO) ("Ambassador").  Pursuant to the Offer, the Company offered one share of its common stock, par value $0.01 per share, for every 23.6 ordinary (or common) shares of Ambassador. The Offer closed on September 5, 2014. Ambassador shareholders holding 23,116 shares of Ambassador ordinary (or common) shares, representing less than 1% of the total number of Ambassador shares outstanding, accepted the Offer. In October 2014, the Company issued a total of 980 shares of its common stock to the Ambassador shareholders who accepted the Offer.
	Settlement Agreement with Seminole Energy Services
	On January 10, 2014, the Company and certain of its subsidiaries entered into an Omnibus Settlement Agreement and Release (the "Settlement Agreement") dated January 9, 2014 with Seminole Energy Services, LLC and certain of its affiliates (collectively, "Seminole"). In connection with and pursuant to the terms of the Settlement Agreement, the Company and Seminole agreed to release and discharge each other from all claims and causes of action alleged in, arising from or related to certain legal proceedings and to terminate, amend and enter into certain new, related agreements effective immediately prior to year-end on December 31, 2013 (the "New Agreements").
	By entering into the New Agreements, the Company and Seminole restructured their existing agreements. The Company obtained a reduction in gas gathering rates it pays for natural gas owned or controlled by the Company that is gathered on the Stone Mountain Gathering System. The Company and Seminole collectively agreed to construct an enhancement of the Rogersville Plant designed to recover less ethane and more propane from the natural gas processed at the Rogersville Plant. The parties also agreed to reduce and extend the Company's contractual horizontal well drilling obligations owed to Seminole. The Company's drilling obligation to Seminole, which required the Company to drill and complete four wells in southern Appalachia, expired on June 30, 2014, and, pursuant to the Settlement Agreement, the Company paid Seminole $450,000 as a result of the Company's decision not to drill two out of the required four wells.
	The Company and Seminole also agreed to modify the natural gas processing rates the Company will pay for processing at the Rogersville Plant, the Company's allocation of NGL recovered from gas processed and the costs of blend stock necessary to blend with the NGL produced from the Rogersville Plant, and certain deductions to the NGL purchase price the Company will pay Seminole for the Company's NGL produced from the Rogersville Plant. Seminole sold to the Company Seminole's 50% interest in a natural gas gathering trunk line and treatment facility located in southwestern Muhlenberg County, Kentucky, which had previously been owned equally by Seminole and the Company.
	Drilling Rig Purchase
	During June 2014, the Company, through its 100% owned subsidiary, Alpha Hunter Drilling, LLC, signed an agreement to purchase a new drilling rig for a total purchase price of approximately $6.5 million, including a $1.3 million deposit due on July 1, 2014 with the remainder due upon delivery on January 15, 2015.
	PVA Arbitration Decision
	On July 25, 2014, the Company received the final determination from the arbitrator in the disagreement related to the final working capital adjustments pertaining to the sale of Eagle Ford Hunter to Penn Virginia in 2013. In accordance with ASC 855, the Company took this final determination into account in estimating its liability as of June 30, 2014. As a result, the Company recorded a total liability of $33.7 million, plus accrued interest of $1.3 million, as of June 30, 2014 based upon the final determination made by the arbitrator. This liability was settled in cash on July 31, 2014. The arbitrator declined to rule, on the basis of lack of authority, on two claims made by Penn Virginia related to working capital adjustments governed by a transition services agreement in the amount of $7.8 million. Any potential liability from these claims cannot currently be estimated.
	Legal Proceedings
	Securities Cases
	On April 23, 2013, Anthony Rosian, individually and on behalf of all other persons similarly situated, filed a class action complaint in the United States District Court, Southern District of New York, against the Company and certain of its officers, two of whom, at that time, also served as directors, and one of whom continues to serve as a director. On April 24, 2013, Horace Carvalho, individually and on behalf of all other persons similarly situated, filed a similar class action complaint in the United States District Court, Southern District of Texas, against the Company and certain of its officers. Several substantially similar putative class actions were 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. The cases filed in the Southern District of New York were consolidated and have since been dismissed. The plaintiffs in the Securities Cases had filed a consolidated amended complaint alleging 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, the Company’s characterization of the auditors’ position with respect to the dismissal, and other matters identified in the Company's April 16, 2013 Form 8-K, as amended. The consolidated amended complaint asserted claims under Sections 10(b) and 20 of the Exchange Act based on alleged false statements made regarding these issues throughout the alleged class period, as well as claims under Sections 11, 12, and 15 of the Securities Act based on alleged false statements and omissions regarding the Company’s internal controls made in connection with a public offering that Magnum Hunter completed on May 14, 2012. The consolidated amended complaint demanded 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. In January 2014, the Company and the individual defendants filed a motion to dismiss the Securities Cases. On June 23, 2014, the United States District Court for the Southern District of New York granted the Company’s and the individual defendants' motion to dismiss the Securities Cases and, accordingly, the Securities Cases have now been dismissed. The plaintiffs have appealed the decision to the U.S. Court of Appeals for the Second Circuit, which the Company intends to vigorously defend. It is possible that additional investor lawsuits could be filed over these events.
	On May 10, 2013, Steven Handshu filed a stockholder derivative suit in the 151st Judicial District Court of Harris County, Texas on behalf of the Company against the Company's directors and senior officers. On June 6, 2013, Zachariah Hanft filed another stockholder derivative suit in the Southern District of New York on behalf of the Company against the Company's directors and senior officers. On June 18, 2013, Mark Respler filed another stockholder derivative suit in the District of Delaware on behalf of the Company against the Company's directors and senior officers. On June 27, 2013, Timothy Bassett filed another stockholder 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, the Southern District of Texas allowed Joseph Vitellone to substitute for Mr. Bassett as plaintiff in that action. On March 19, 2014 Richard Harveth filed another stockholder derivative suit in the 125th District Court of Harris County, Texas.  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. On December 20, 2013, the United States District Court for the Southern District of Texas granted the Company’s motion to dismiss the stockholder derivative case maintained by Joseph Vitellone and entered a final judgment of dismissal. The court held that Mr. Vitellone failed to plead particularized facts demonstrating that pre-suit demand on the Company’s board was excused. In addition, on December 13, 2013, the 151st Judicial District Court of Harris County, Texas dismissed the lawsuit filed by Steven Handshu for want of prosecution after the plaintiff failed to serve any defendant in that matter. On January 21, 2014, the Hanft complaint was dismissed with prejudice after the plaintiff in that action filed a voluntary motion for dismissal. On February 18, 2014, the United States District Judge for the District of Delaware granted the Company’s supplemental motion to dismiss the Derivative Case filed by Mark Respler. All of the Derivative Cases have now been dismissed, except the Derivative Case filed by Richard Harveth, for which the Company is presently seeking dismissal. It is possible that additional stockholder derivative suits could be filed over these events.
	In addition, the Company has received several demand letters from stockholders 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 stockholders 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, which has now been dismissed. It is possible that additional similar actions may be filed and that similar stockholder demands could be made.
	In April 2013, the Company also received a letter from the SEC stating that the SEC's Division of Enforcement was conducting an inquiry regarding the Company's internal controls, change in outside auditors and public statements to investors and asking the Company to preserve documents relating to these matters. The Company is complying with this request. On December 30, 2013, the Company received a document subpoena relating to the issues identified in the April 2013 letter, and the SEC has also issued subpoenas for testimony and has taken testimony from certain individuals. The Company intends to cooperate with the subpoenas.
	Any potential liability from these claims cannot currently be estimated.
	Twin Hickory Matter
	On April 11, 2013, a flash fire occurred at Eureka Hunter Pipeline’s Twin Hickory site located in Tyler County, West Virginia. The incident occurred during a pigging operation at a natural gas receiving station. Two employees of third-party contractors received fatal injuries. Another employee of a third-party contractor was injured.
	In mid-February 2014, the estate of one of the deceased third-party contractor employees sued Eureka Hunter Pipeline and certain other parties in Karen S. Phipps v. Eureka Hunter Pipeline, LLC et al., Civil Action No. 14-C-41, in the Circuit Court of Ohio County, West Virginia. In October 2014, in Exterran Energy Solutions, LP v. Eureka Hunter Pipeline, LLC and Magnum Hunter Resources Corporation, Civil Action No. 2014-63353, in the District Court of Harris County, Texas, Exterran Energy Solutions, LP, one of the co-defendants in the Phipps lawsuit, filed suit against the Company and Eureka Hunter Pipeline seeking a declaratory judgment that Eureka Hunter Pipeline is obligated to indemnify Exterran with respect to the Phipps lawsuit. In April 2014, the estate of the other deceased third-party contractor employee sued the Company, Eureka Hunter Pipeline and certain other parties in Antoinette M. Miller v. Magnum Hunter Resources Corporation et al, Civil Action No. 14-C-111, in the Circuit Court of Ohio County, West Virginia. The plaintiffs allege that Eureka Hunter Pipeline and the other defendants engaged in certain negligent and reckless conduct which resulted in the wrongful death of the third-party contractor employees. The plaintiffs have demanded judgment for an unspecified amount of compensatory, general and punitive damages. Various cross-claims have been asserted. In May 2014, the injured third-party contractor employee sued Magnum Hunter Resources Corporation and certain other parties in Jonathan Whisenhunt v. Magnum Hunter Resources Corporation et al, Civil Action No. 14-C-135, in the Circuit Court of Ohio County, West Virginia. Investigation regarding the incident is ongoing. It is not possible to predict at this juncture the extent to which, if at all, Eureka Hunter Pipeline or any related entities will incur liability or damages because of this incident. However, the Company believes that its insurance coverage will be sufficient to cover any losses or liabilities it may incur as a result of this incident.
	PRC Williston Matter
	On December 16, 2013, Drawbridge Special Opportunities Fund LP and Fortress Value Recovery Fund I LLC f/k/a D.B. Zwirn Special Opportunities Fund, L.P. (together, the "Plaintiffs") filed suit against PRC Williston in the Court of Chancery of the State of Delaware. PRC Williston and the Plaintiffs entered into Participation Agreements in February 2007 in connection with the Plaintiffs extending credit to PRC Williston pursuant to a credit agreement entitling the Plaintiffs to a 12.5% collective interest in any distributions in respect of the equity interests of the members of PRC Williston. Plaintiffs claim that they are entitled to compensation for 12.5% of alleged past distributions on equity from PRC Williston to Magnum Hunter and 12.5% of any transfers of funds to Magnum Hunter from the proceeds of the December 30, 2013 sale of PRC Williston’s assets. On December 23, 2013, the Chancery Court entered a temporary restraining order prohibiting PRC Williston from transferring, assigning, removing, distributing or otherwise displacing to Magnum Hunter, Magnum Hunter’s creditors, or any other person or entity, $5.0 million of the proceeds received by PRC Williston in connection with the sale of its assets. On March 18, 2014, the Court granted Plaintiffs’ motion for a preliminary injunction, extending the relief granted by the temporary restraining order until after a full trial on the merits.
	On July 24, 2014, the Company, PRC Williston, and the Plaintiffs executed a Settlement and Release Agreement ("the Settlement Agreement"). Per the terms of the Settlement Agreement, PRC Williston paid approximately $2.9 million in cash to Drawbridge Special Opportunities Fund LP. As a result of the Settlement Agreement, the Company, PRC Williston, and the Plaintiffs agreed to release each other from all claims, past, present or future, related to the dispute. In addition, with the execution of the Settlement Agreement, the parties agreed to terminate, in all respects, the Participation Agreements and that none of the parties would have any further rights or obligations thereunder. With the cash settlement payment and the termination of the Participation Agreements, the Company now has rights and claims to 100% of the equity interests in PRC Williston and its remaining assets and liabilities. Consequently, there is no longer any non-controlling interest in PRC Williston's equity reflected in our consolidated financial statements.
	General
	We are also a defendant in several other lawsuits that have arisen in the ordinary course of business. While the outcome of these lawsuits cannot be predicted with certainty, management does not expect any of these to have a material adverse effect on our consolidated financial condition or results of operations.

SUPPLEMENTAL_CASH_FLOW_INFORMA

SUPPLEMENTAL CASH FLOW INFORMATION	9 Months Ended
	Sep. 30, 2014
Supplemental Cash Flow Elements [Abstract]	'
SUPPLEMENTAL CASH FLOW INFORMATION	'
	NOTE 17 - SUPPLEMENTAL CASH FLOW INFORMATION
	The following table summarizes cash paid (received) for interest and income taxes, as well as non-cash investing transactions:
		Nine Months Ended September 30,
		2014		2013
		(in thousands)
	Cash paid for interest	$	38,565	$	38,225
	Non-cash transactions
	Common stock issued for 401k matching contributions	$	1,593	$	1,192
	Non-cash consideration received from sale of assets	$	9,447	$	—
	Change in accrued capital expenditures	$	129,778	$	(5,742	)
	Non-cash additions to asset retirement obligation	$	2,439	$	2,089
	Eureka Hunter Holdings Series A Preferred Unit dividends paid in kind	$	1,950	$	6,367

SEGMENT_REPORTING

SEGMENT REPORTING	9 Months Ended
	Sep. 30, 2014
Segment Reporting [Abstract]	'
SEGMENT REPORTING	'
	NOTE 18 - SEGMENT REPORTING
	Magnum Hunter has three reportable current operating segments: U.S. upstream, midstream and marketing, and oilfield services represent the current operating segments of the Company.  Beginning September 30, 2013, the Canadian upstream segment, comprised of the WHI Canada operations, was classified as held for sale on the consolidated balance sheet and as a discontinued operation on the consolidated statement of operations. The Company sold 100% of the equity in WHI Canada in May 2014.
	The following tables set forth operating activities by segment for the three and nine months ended September 30, 2014 and 2013, respectively.
		As of and for the Three Months Ended September 30, 2014
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	63,438		$	—		$	11,845		$	8,176		$	—		$	(3,789	)	$	79,670
	Depletion, depreciation, amortization and accretion	31,217			—			4,224			929			—			—			36,370
	Gain on sale of assets, net	(7,988		)	—			(12		)	—			—			—			(8,000		)
	Other operating expenses	87,035			—			7,350			6,569			11,711			(3,789		)	108,876
	Other income (expense)	1,907			—			(58,078		)	(205		)	(9,237		)	—			(65,613		)
	Income (loss) from continuing operations before income tax	(44,919		)	—			(57,795		)	473			(20,948		)	—			(123,189		)
	Total income (loss) from discontinued operations, net of tax 1	(259		)	—			—			—			1			—			(258		)
	Net income (loss)	$	(45,178	)	$	—		$	(57,795	)	$	473		$	(20,947	)	$	—		$	(123,447	)
	Total assets	$	1,475,305		$	—		$	443,008		$	45,661		$	74,614		$	(5,023	)	$	2,033,565
	Total capital expenditures	$	104,265		$	—		$	88,525		$	3,628		$	21		$	—		$	196,439
	_________________________________
	-1	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.
		As of and for the Three Months Ended September 30, 2013
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	59,325		$	—		$	14,618		$	6,448		$	—		$	(2,100	)	$	78,291
	Depletion, depreciation, amortization and accretion	25,233			—			3,174			720			—			—			29,127
	Loss on sale of assets, net	40,952			—			—			—			—			—			40,952
	Other operating expenses	100,484			—			11,140			4,931			11,457			74			128,086
	Other income (expense)	2,038			—			(16,572		)	(141		)	(20,814		)	2,268			(33,221		)
	Income (loss) from continuing operations before income tax	(105,306		)	—			(16,268		)	656			(32,271		)	94			(153,095		)
	Income tax benefit (expense)	17,794			926			—			—			(18,138		)	—			582
	Total income (loss) from discontinued operations, net of tax	(13,881		)	(132,861		)	—			—			1,742			(94		)	(145,094		)
	Net income (loss)	$	(101,393	)	$	(131,935	)	$	(16,268	)	$	656		$	(48,667	)	$	—		$	(297,607	)
	Total assets	$	1,406,515		$	106,438		$	269,692		$	42,648		$	62,182		$	(1,659	)	$	1,885,816
	Total capital expenditures	$	149,577		$	181		$	19,918		$	5,850		$	504		$	—		$	176,030
		As of and for the Nine Months Ended September 30, 2014
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	223,788		$	—		$	98,697		$	23,882		$	—		$	(14,752	)	$	331,615
	Depletion, depreciation, amortization and accretion	87,345			—			11,831			2,557			—			—			101,733
	Gain on sale of assets, net	(4,231		)	—			(12		)	(369		)	—			—			(4,612		)
	Other operating expenses	197,013			—			86,120			19,643			35,253			(14,752		)	323,277
	Other income (expense)	1,739			—			(98,505		)	(625		)	(54,979		)	—			(152,370		)
	Income (loss) from continuing operations before income tax	(54,600		)	—			(97,747		)	1,426			(90,232		)	—			(241,153		)
	Total income (loss) from discontinued operations, net of tax 1	(7,283		)	10,636			—			—			(12,775		)	—			(9,422		)
	Net income (loss)	$	(61,883	)	$	10,636		$	(97,747	)	$	1,426		$	(103,007	)	$	—		$	(250,575	)
	Total assets	$	1,475,305		$	—		$	443,008		$	45,661		$	74,614		$	(5,023	)	$	2,033,565
	Total capital expenditures	$	320,719		$	305		$	171,152		$	6,575		$	127		$	—		$	498,878
	_________________________________
	-1	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.
		As of and for the Nine Months Ended September 30, 2013
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	158,217		$	—		$	48,071		$	13,873		$	—		$	(5,802	)	$	214,359
	Depletion, depreciation, amortization and accretion	69,420			—			9,142			1,579			—			—			80,141
	Loss on sale of assets, net	42,110			—			—			4			—			—			42,114
	Other operating expenses	198,363			—			41,276			12,884			38,932			(3,628		)	287,827
	Other income (expense)	440			—			(24,261		)	(372		)	(47,330		)	2,288			(69,235		)
	Income (loss) from continuing operations before income tax	(151,236		)	—			(26,608		)	(966		)	(86,262		)	114			(264,958		)
	Income tax benefit	23,560			—			—			—			23,667			—			47,227
	Total income (loss) from discontinued operations, net of tax	181,233			(134,070		)	—			—			(6,571		)	(114		)	40,478
	Net income (loss)	$	53,557		$	(134,070	)	$	(26,608	)	$	(966	)	$	(69,166	)	$	—		$	(177,253	)
	Total assets	$	1,406,515		$	106,438		$	269,692		$	42,648		$	62,182		$	(1,659	)	$	1,885,816
	Total capital expenditures	$	322,768		$	14,317		$	55,003		$	19,971		$	927		$	—		$	412,986

CONDENSED_CONSOLIDATING_GUARAN

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	9 Months Ended
	Sep. 30, 2014
Guarantees [Abstract]	'
CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	'
	NOTE 19 - CONDENSED CONSOLIDATED GUARANTOR FINANCIAL STATEMENTS
	Guarantor Subsidiaries
	Certain of the Company’s subsidiaries, including Alpha Hunter Drilling, LLC, Bakken Hunter, Shale Hunter, Magnum Hunter Marketing, LLC, Magnum Hunter Production, Inc., NGAS Hunter, LLC, Triad Hunter, and Viking International Resources, Co., Inc. (collectively, "Guarantor Subsidiaries"), jointly and severally guarantee on a 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. The Guarantor Subsidiaries also may guarantee any debt of the Company issued pursuant to the Form S-3 Registration Statement filed by the Company with the SEC on August 5, 2014.
	These condensed consolidating guarantor financial statements have been revised to reflect Eagle Ford Hunter and PRC Williston as non-guarantors as the subsidiaries are no longer guarantors of the Company's Senior Notes.
	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, 2014 and December 31, 2013, and for the three and nine months ended September 30, 2014 and 2013, are as follows:
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
		As of September 30, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	ASSETS
	Current assets	$	52,405		$	43,367		$	10,301		$	(5,022	)	$	101,051
	Intercompany accounts receivable	1,084,519			—			—			(1,084,519		)	—
	Property and equipment (using successful efforts method of accounting)	5,614			1,390,673			395,027			—			1,791,314
	Investment in subsidiaries	193,337			100,392			—			(293,729		)	—
	Assets held for sale and other	16,594			87,291			37,315			—			141,200
	Total Assets	$	1,352,469		$	1,621,723		$	442,643		$	(1,383,270	)	$	2,033,565
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	40,822		$	124,895		$	94,550		$	(5,025	)	$	255,242
	Intercompany accounts payable	—			1,044,555			42,201			(1,086,756		)	—
	Long-term liabilities	856,161			45,822			253,257			—			1,155,240
	Redeemable preferred stock	100,000			—			151,685			—			251,685
	Shareholders' equity (deficit)	355,486			406,451			(99,050		)	(291,489		)	371,398
	Total Liabilities and Shareholders' Equity	$	1,352,469		$	1,621,723		$	442,643		$	(1,383,270	)	$	2,033,565
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
		As of December 31, 2013
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	ASSETS
	Current assets	$	53,161		$	43,841		$	27,096		$	(3,372	)	$	120,726
	Intercompany accounts receivable	965,138			—			—			(965,138		)	—
	Property and equipment (using successful efforts method of accounting)	7,214			1,272,027			234,838			—			1,514,079
	Investment in subsidiaries	372,236			102,314			—			(474,550		)	—
	Other assets	17,308			100,894			103,644			—			221,846
	Total Assets	$	1,415,057		$	1,519,076		$	365,578		$	(1,443,060	)	$	1,856,651
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	54,826		$	97,520		$	34,929		$	(3,410	)	$	183,865
	Intercompany accounts payable	—			921,237			43,866			(965,103		)	—
	Long-term liabilities	818,651			39,067			127,663			—			985,381
	Redeemable preferred stock	100,000			—			136,675			—			236,675
	Shareholders' equity (deficit)	441,580			461,252			22,445			(474,547		)	450,730
	Total Liabilities and Shareholders' Equity	$	1,415,057		$	1,519,076		$	365,578		$	(1,443,060	)	$	1,856,651
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
		Three Months Ended September 30, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Revenues	$	10		$	72,809		$	11,141		$	(4,290	)	$	79,670
	Expenses	21,317			115,817			70,015			(4,290		)	202,859
	Income (loss) from continuing operations before equity in net income of subsidiaries	(21,307		)	(43,008		)	(58,874		)	—			(123,189		)
	Equity in net income of subsidiaries	(105,762		)	(1,093		)	—			106,855			—
	Income (loss) from continuing operations before income tax	(127,069		)	(44,101		)	(58,874		)	106,855			(123,189		)
	Income tax benefit (expense)	—			—			—			—			—
Income (loss) from continuing operations	(127,069		)	(44,101		)	(58,874		)	106,855			(123,189		)
Income from discontinued operations, net of tax	—			—			—			—			—
Gain on sale of discontinued operations, net of tax	(259		)	—			1			—			(258		)
Net income (loss)	(127,328		)	(44,101		)	(58,873		)	106,855			(123,447		)
Net income attributable to non-controlling interest	—			—			—			2,764			2,764
Net income (loss) attributable to Magnum Hunter Resources Corporation	(127,328		)	(44,101		)	(58,873		)	109,619			(120,683		)
Dividends on preferred stock	(8,848		)	—			(6,644		)	—			(15,492		)
Net income (loss) attributable to common shareholders	$	(136,176	)	$	(44,101	)	$	(65,517	)	$	109,619		$	(136,175	)
	Three Months Ended September 30, 2013
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Revenues	$	29		$	71,246		$	9,112		$	(2,096	)	$	78,291
Expenses	35,350			171,183			27,045			(2,192		)	231,386
Income (loss) from continuing operations before equity in net income of subsidiaries	(35,321		)	(99,937		)	(17,933		)	96			(153,095		)
Equity in net income of subsidiaries	(236,767		)	163			(28,543		)	265,147			—
Income (loss) from continuing operations before income tax	(272,088		)	(99,774		)	(46,476		)	265,243			(153,095		)
Income tax benefit (expense)	(18,138		)	17,793			927			—			582
Income (loss) from continuing operations	(290,226		)	(81,981		)	(45,549		)	265,243			(152,513		)
Income (loss) from discontinued operations, net of tax	1,743			—			(77,220		)	(96		)	(75,573		)
Gain on sale of discontinued operations, net of tax	(13,880		)	—			(55,641		)	—			(69,521		)
Net income (loss)	(302,363		)	(81,981		)	(178,410		)	265,147			(297,607		)
Net income attributable to non-controlling interest	—			—			—			725			725
Net income (loss) attributable to Magnum Hunter Resources Corporation	(302,363		)	(81,981		)	(178,410		)	265,872			(296,882		)
Dividends on preferred stock	(8,820		)	—			(5,597		)	—			(14,417		)
Net income (loss) attributable to common shareholders	$	(311,183	)	$	(81,981	)	$	(184,007	)	$	265,872		$	(311,299	)
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Operations
(in thousands)
	Nine Months Ended September 30, 2014
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Revenues	$	124		$	313,898		$	32,846		$	(15,253	)	$	331,615
Expenses	92,622			363,587			131,812			(15,253		)	572,768
Income (loss) from continuing operations before equity in net income of subsidiaries	(92,498		)	(49,689		)	(98,966		)	—			(241,153		)
Equity in net income of subsidiaries	(153,569		)	(1,922		)	—			155,491			—
Income (loss) from continuing operations before income tax	(246,067		)	(51,611		)	(98,966		)	155,491			(241,153		)
Income tax benefit (expense)	—			—			—			—			—
Income (loss) from continuing operations	(246,067		)	(51,611		)	(98,966		)	155,491			(241,153		)
Income from discontinued operations, net of tax	—			—			4,561			—			4,561
Gain (loss) on sale of discontinued operations, net of tax	(20,058		)	—			6,075			—			(13,983		)
Net income (loss)	(266,125		)	(51,611		)	(88,330		)	155,491			(250,575		)
Net income attributable to non-controlling interest	—			—			—			3,653			3,653
Net income (loss) attributable to Magnum Hunter Resources Corporation	(266,125		)	(51,611		)	(88,330		)	159,144			(246,922		)
Dividends on preferred stock	(26,516		)	—			(19,202		)	—			(45,718		)
Net income (loss) attributable to common shareholders	$	(292,641	)	$	(51,611	)	$	(107,532	)	$	159,144		$	(292,640	)
	Nine Months Ended September 30, 2013
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Revenues	$	(134	)	$	194,599		$	25,693		$	(5,799	)	$	214,359
Expenses	91,559			337,827			55,845			(5,914		)	479,317
Income (loss) from continuing operations before equity in net income of subsidiaries	(91,693		)	(143,228		)	(30,152		)	115			(264,958		)
Equity in net income of subsidiaries	(274,930		)	(479		)	(37,930		)	313,339			—
Income (loss) from continuing operations before income tax	(366,623		)	(143,707		)	(68,082		)	313,454			(264,958		)
Income tax benefit (expense)	23,667			23,560			—			—			47,227
Income (loss) from continuing operations	(342,956		)	(120,147		)	(68,082		)	313,454			(217,731		)
Income (loss) from discontinued operations, net of tax	(6,570		)	22,661			(78,429		)	(115		)	(62,453		)
Gain on sale of discontinued operations, net of tax	158,572			—			(55,641		)	—			102,931
Net income (loss)	(190,954		)	(97,486		)	(202,152		)	313,339			(177,253		)
Net income attributable to non-controlling interest	—			—			—			1,614			1,614
Net income (loss) attributable to Magnum Hunter Resources Corporation	(190,954		)	(97,486		)	(202,152		)	314,953			(175,639		)
Dividends on preferred stock	(26,603		)	—			(15,431		)	—			(42,034		)
Net income (loss) attributable to common shareholders	$	(217,557	)	$	(97,486	)	$	(217,583	)	$	314,953		$	(217,673	)
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Comprehensive Income (Loss)
(in thousands)
	Three Months Ended September 30, 2014
	Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Net income (loss)	$	(127,328	)	$	(44,101	)	$	(58,873	)	$	106,855		$	(123,447	)
Foreign currency translation gain	—			—			—			—			—
Unrealized loss on available for sale securities	—			(2,583		)	—			—			(2,583		)
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	—			—			—			—			—
Comprehensive income (loss)	(127,328		)	(46,684		)	(58,873		)	106,855			(126,030		)
Comprehensive income attributable to non-controlling interest	—			—			—			2,764			2,764
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(127,328	)	$	(46,684	)	$	(58,873	)	$	109,619		$	(123,266	)
	Three Months Ended September 30, 2013
	Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Net income (loss)	$	(302,363	)	$	(81,981	)	$	(178,410	)	$	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)	(307,063		)	(81,808		)	(174,554		)	265,147			(298,278		)
Comprehensive income attributable to non-controlling interest	—			—			—			725			725
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(307,063	)	$	(81,808	)	$	(174,554	)	$	265,872		$	(297,553	)
	Nine Months Ended September 30, 2014
	Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Net income (loss)	$	(266,125	)	$	(51,611	)	$	(88,330	)	$	155,491		$	(250,575	)
Foreign currency translation loss	—			—			(1,218		)	—			(1,218		)
Unrealized loss on available for sale securities	—			(3,188		)	—			—			(3,188		)
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	20,741			—			—			—			20,741
Comprehensive income (loss)	(245,384		)	(54,799		)	(89,548		)	155,491			(234,240		)
Comprehensive income attributable to non-controlling interest	—			—			—			3,653			3,653
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(245,384	)	$	(54,799	)	$	(89,548	)	$	159,144		$	(230,587	)
	Nine Months Ended September 30, 2013
	Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Net income (loss)	$	(190,954	)	$	(97,486	)	$	(202,152	)	$	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		)	(97,564		)	(210,095		)	313,339			(185,274		)
Comprehensive income attributable to non-controlling interest	—			—			—			1,614			1,614
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(190,954	)	$	(97,564	)	$	(210,095	)	$	314,953		$	(183,660	)
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Cash Flows
(in thousands)
	Nine Months Ended September 30, 2014
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Cash flow from operating activities	$	(261,039	)	$	222,520		$	52,074		$	—		$	13,555
Cash flow from investing activities	63,502			(211,560		)	(99,246		)	—			(247,304		)
Cash flow from financing activities	193,885			2,232			38,542			—			234,659
Effect of exchange rate changes on cash	—			—			44			—			44
Net increase (decrease) in cash	(3,652		)	13,192			(8,586		)	—			954
Cash at beginning of period	47,895			(17,651		)	11,469			—			41,713
Cash at end of period	$	44,243		$	(4,459	)	$	2,883		$	—		$	42,667
	Nine Months Ended September 30, 2013
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Cash flow from operating activities	$	(264,051	)	$	236,112		$	107,136		$	—		$	79,197
Cash flow from investing activities	422,056			(245,179		)	(132,054		)	—			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

SUBSEQUENT_EVENTS

SUBSEQUENT EVENTS	9 Months Ended
	Sep. 30, 2014
Subsequent Events [Abstract]	'
SUBSEQUENT EVENTS	'
	NOTE 20 - SUBSEQUENT EVENTS
	Second Amended and Restated Eureka Hunter Holdings LLC Agreement
	On September 16, 2014, the Company entered into a Transaction Agreement with MSI relating to a separate purchase agreement between MSI and Ridgeline providing for the purchase by MSI of all the Eureka Hunter Holdings Series A Preferred Units and Class A Common Units owned by Ridgeline. The Transaction Agreement contemplates two closings comprised of (i) the purchase by MSI of Ridgeline's equity interests in Eureka Hunter Holdings and the execution of the New LLC Agreement; and (ii) the purchase by MSI of an additional equity interest in Eureka Hunter Holdings from MHR as described below. On October 3, 2014, the first closing contemplated in the Transaction Agreement was consummated between MSI and Ridgeline. The Company was not a party to the transaction between MSI and Ridgeline.
	Contemporaneously with the first closing, the New LLC Agreement for Eureka Hunter Holdings became effective. In accordance with the terms of the New LLC Agreement, all of the Eureka Hunter Holdings Series A Preferred Units and Class A Common Units of Eureka Hunter Holdings acquired by MSI from Ridgeline were converted into a new class of common equity interests of Eureka Hunter Holdings (the "Series A-2 Units"). Magnum Hunter's Class A Common Units held on the date of the first closing were also converted into a new class of common equity (the "Series A-1 Common Units"). The Series A-2 Units will have a liquidation preference to the Series A-1 Common Units if a Sale Transaction (as defined in the New LLC Agreement) or Initial Public Offering (as defined in the New LLC Agreement) occurs subsequent to January 1, 2017. The liquidation preference available to the Series A-2 Unit members provides a specified Internal Rate of Return (as defined in the New LLC Agreement), depending upon the proceeds available for distribution upon a Sale Transaction or an Initial Public Offering. Once the Internal Rate of Return (as defined in the New LLC Agreement) applicable to Series A-2 Unit members is achieved, Series A-2 Unit members and Series A-1 Unit members will participate in remaining distributions according to their Upside Sharing Percentages (as defined in the New LLC Agreement).
	As a result of the conversion of the Eureka Hunter Holdings Series A Preferred Units into Series A-2 Units, the features, terms, and cash flows associated with the Series A-2 Units are substantially different than those of the former Eureka Hunter Holdings Series A Preferred Units. Consequently, it is anticipated that the conversion will be treated as an extinguishment of a class of equity, and an issuance of a new class of equity that will be recorded initially at fair value. Additionally, the accrued and unpaid dividends outstanding on the Eureka Hunter Holdings Series A Preferred Units and the fair value associated with the embedded derivative attached to the Eureka Hunter Holdings Series A Preferred Units, which has been accounted for as a liability in these consolidated financial statements, will be included in determining the total carrying value of the equity to be extinguished.
	The Transaction Agreement further provides that Magnum Hunter will sell to MSI in a second closing, that is expected to occur in mid-January 2015, a portion of its Eureka Hunter Holdings Series A-1 Common Units, which, assuming completion of the full amount of additional capital contributions expected to be made by MSI, would constitute approximately 6.5% of the total common equity interests then outstanding in Eureka Hunter Holdings. Any Series A-1 Common Units purchased by MSI from the Company under a second closing will convert immediately into Series A-2 Units. The purchase price of such additional equity interests is expected to be approximately $65 million. Such closing, together with follow on capital contributions expected to be made by MSI in 2014, will result in Magnum Hunter and MSI owning approximately equal equity interests in Eureka Hunter Holdings which collectively will constitute an approximate 98% equity interest in Eureka Hunter Holdings. Upon consummation of the second closing, the Company will reassess its subsequent accounting for Eureka Hunter Holdings in accordance with the criteria for consolidation.
	Also, in accordance with the terms and conditions of the New LLC Agreement, Magnum Hunter will have the right, under certain circumstances, to not make its portion of certain required future capital contributions to Eureka Hunter, and, if Magnum Hunter validly exercises its right to do so, MSI will make the capital contributions which otherwise would be made by Magnum Hunter, with Magnum Hunter having the right to make capital contributions within 180 days that will bring Magnum Hunter's ownership interest back to the level prior to the capital call. This catch-up feature will be at no cost to Magnum Hunter but will be subject to a maximum of $40 million for each 180-day period.
	Sales of Certain North Dakota Assets
	On October 15, 2014, Bakken Hunter closed on the sale of certain non-operated working interests in oil and natural gas properties located in Divide County, North Dakota for cash consideration of $84.8 million, subject to customary purchase price adjustments. The effective date of the sale is August 1, 2014.
	Fourth Amended and Restated Credit Agreement and New Second Lien Term Loan
	Revolving Credit Facility
	On October 22, 2014, the Company entered into a New Credit Agreement, by and among the Company, as borrower, Bank of Montreal, as administrative agent, the lenders party thereto and the agents party thereto. The New Credit Agreement amended and restated the Credit Agreement, dated as of December 13, 2013, by and among those parties, as amended.
	The New Credit Agreement provides for an asset-based, senior secured revolving credit facility maturing October 22, 2018 (the "Revolving Facility") with an initial borrowing base of $50 million. The Revolving 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 increased up to a maximum commitment level of $250 million. As discussed below, however, provisions of the Second Lien Term Loan Agreement limit the amount of indebtedness that the Company may incur under the New Credit Agreement.
	The terms of the New Credit Agreement provide that the Revolving Facility may be used for loans and, subject to a $50 million sublimit, letters of credit. The New Credit Agreement provides for a commitment fee of 0.5% based on the unused portion of the borrowing base under the Revolving Facility.
	Borrowings under the Revolving Facility will, at the Company’s election, bear interest at either (i) an alternate base rate ("ABR") equal to the higher of (A) the prime rate (as determined by Bank of Montreal) (B) the overnight federal funds effective rate, plus 0.50% per annum, and (C) the adjusted one-month LIBOR plus 1.00% or (ii) the adjusted LIBO Rate (which is based on LIBOR), plus, in each of the cases described in clauses (i) and (ii), an applicable margin ranging from 1.00% to 2.00% for ABR loans and from 2.00% to 3.00% for adjusted LIBO Rate loans. Accrued interest on each ABR loan is payable in arrears on the last day of each March, June, September and December and accrued interest on each adjusted LIBO Rate loan is payable in arrears on the last day of the Interest Period (as defined in the New Credit Agreement) applicable to the borrowing of which such adjusted LIBO Rate loan is a part and, in the case of an adjusted LIBO Rate borrowing with an Interest Period of more than three months’ duration, each day prior to the last day of such Interest Period that occurs at intervals of three months’ duration after the first day of such Interest Period.
	The New Credit Agreement contains negative covenants that, among other things, restrict the ability of the Company and its restricted subsidiaries to, with certain exceptions, (i) incur indebtedness, (ii) grant liens, (iii) make certain payments, (iv) change the nature of its business, (v) dispose of all or substantially all of its assets or enter into mergers, consolidations or similar transactions, (vi) make investments, loans or advances, (vii) pay cash dividends, unless certain conditions are met, and with respect to the payment of dividends on preferred stock, subject to (A) no Event of Default (as defined in the New Credit Agreement) existing, (B) after giving effect to any such preferred stock dividend payment, the Company maintaining availability under the borrowing base in an amount greater than the greater of (x) 2.50% percent of the borrowing base then in effect or (y) $5,000,000 and (C) a "basket" of $45,000,000 per year, (viii) enter into transactions with affiliates, and (ix) enter into hedging transactions.
	In addition, the New Credit Agreement requires the Company to satisfy certain financial covenants, including maintaining:
	(i)	a current ratio of not less than 1.0 to 1.0, commencing with the fiscal quarter ending December 31, 2014;
	(ii)	a leverage ratio (secured net debt to EBITDAX (as defined in the New Credit Agreement) with, beginning with the fiscal quarter ending March 31, 2016, a limitation on netting of up to $100,000,000 of unencumbered cash) of not more than (A) 2.5 to 1.0 as of the last day of the fiscal quarter ending December 31, 2014, (B) 2.25 to 1.00 as of the last day of the fiscal quarter ending March 31, 2015 and (C) 2.0 to 1.0 as of the last day of the fiscal quarter ending June 30, 2015 and each fiscal quarter ending thereafter; and
	(iii)	the proved reserves based asset coverage ratios contained in the Second Lien Term Loan Agreement described below.
	The obligations of the Company under the New Credit Agreement may be accelerated upon the occurrence of an Event of Default. 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 and warranties, bankruptcy or related defaults, defaults relating to judgments and the occurrence of a Change of Control (as defined in the New Credit Agreement) and any "Event of Default" under the Second Lien Term Loan Agreement, subject to certain cure periods.
	Subject to certain exceptions, the Revolving Facility is secured by substantially all of the assets of the Company and its restricted subsidiaries, including, without limitation, no less than 90% of the present value (with a discount rate of 10%) of the proved oil and gas reserves of the Company and its restricted subsidiaries. Additionally, any collateral pledged as security for the Second Lien Term Loan (as defined below) is required to be pledged as security for the New Credit Agreement. In connection with the New Credit Agreement, the Company and its restricted subsidiaries also entered into customary ancillary agreements and arrangements, which among other things, provide that the Revolving Facility is unconditionally guaranteed by such restricted subsidiaries. The Company’s restricted subsidiaries under the New Credit Agreement and the Second Lien Term Loan do not include the Company’s majority-owned subsidiaries through which the Company conducts its midstream operations, including Eureka Hunter Holdings, Eureka Hunter Pipeline and TransTex Hunter.
	Second Lien Term Loan
	On October 22, 2014, the Company also entered into a Second Lien Credit Agreement (the "Second Lien Term Loan Agreement"), by and among the Company, as borrower, Credit Suisse AG, Cayman Islands Branch, as administrative agent and collateral agent, the lenders party thereto and the agents party thereto.
	The Second Lien Term Loan Agreement provides for a $340 million term loan facility (the "Second Lien Term Loan"), secured by, subject to certain exceptions, a second lien on substantially all of the assets of the Company and its restricted subsidiaries. The entire $340 million Second Lien Term Loan was drawn on October 22, 2014. The Company used the proceeds of the Second Lien Term Loan to repay amounts outstanding under its Credit Agreement, to pay transaction expenses related to the New Credit Agreement and the Second Lien Term Loan Agreement, and for working capital and general corporate purposes. Amounts borrowed under the Second Lien Term Loan that are repaid or prepaid may not be reborrowed. The Second Lien Term Loan has a maturity date of October 22, 2019 and will amortize (beginning December 31, 2014) in equal quarterly installments in an aggregate annual amount equal to 1.00% of the original principal amount of the Second Lien Term Loan.
	Borrowings under the Second Lien Term Loan will, at the Company’s election, bear interest at either (i) an alternate base rate (which is equal to the higher of (A) the prime rate (as determined by Credit Suisse), (B) the overnight federal funds effective rate, plus 0.50% per annum, and (C) the adjusted one-month LIBOR plus 1.00%) plus 6.50% or (ii) the adjusted LIBO Rate (which is based on LIBOR) plus 7.50%.
	The Second Lien Term Loan Agreement contains negative covenants substantially similar to those in the New Credit Agreement that, among other things, restrict the ability of the Company and its restricted subsidiaries to, with certain exceptions: (i) incur indebtedness; (ii) grant liens; (iii) dispose of all or substantially all of its assets or enter into mergers, consolidations, or similar transactions; (iv) change the nature of its business; (v) make investments, loans, or advances or guarantee obligations; (vi) pay cash dividends or make certain other payments; (vii) enter into transactions with affiliates; (viii) enter into sale and leaseback transactions; (ix) enter into hedging transactions; and (x) amend its organizational documents or the New Credit Agreement. The Second Lien Term Loan Agreement limits the amount of indebtedness that the Company may incur under the New Credit Agreement to the greater of (a) the sum of $50 million plus the aggregate amount of loans repaid or prepaid under the Second Lien Term Loan Agreement and (b) an amount equal to 25% of Adjusted Consolidated Net Tangible Assets (as defined in the Second Lien Term Loan Agreement) of the Company and its restricted subsidiaries; provided, in the case of clause (b), after giving effect to such incurrence of indebtedness and the application of proceeds therefrom, aggregate secured debt may not exceed 25% of the Adjusted Consolidated Net Tangible Assets of the Company and its restricted subsidiaries as of the date of such incurrence.
	The Second Lien Term Loan Agreement also requires the Company to satisfy certain financial covenants, including maintaining
	(i)	a ratio of proved reserves to secured debt of not less than 1.5 to 1.0 and a ratio of proved developed and producing reserves to secured debt of not less than 1.0 to 1.0, each as of the last day of any fiscal quarter commencing with the fiscal quarter ending December 31, 2014; and
	(ii)	commencing with the fiscal quarter ending March 31, 2016, a leverage ratio (secured net debt to EBITDAX (as defined in the Second Lien Term Loan Agreement) with a limitation on netting of up to $100,000,000 of unencumbered cash) of not more than 2.5 to 1.0 as of the last day of any fiscal quarter for the trailing four-quarter period then ended.
	The obligations of the Company under the Second Lien Term Loan may be accelerated upon the occurrence of an Event of Default (as defined in the Second Lien Term Loan Agreement). Events of Default are substantially similar to Events of Default under the Credit Agreement (except that a breach of a financial covenant under the New Credit Agreement will not constitute an Event of Default under the Second Lien Term Loan Agreement until acceleration) and include customary events for these types of financings.
	In connection with the Second Lien Term Loan Agreement, the Company and its restricted subsidiaries also entered into customary ancillary agreements and arrangements, which among other things, provide that the Second Lien Term Loan is unconditionally guaranteed by such restricted subsidiaries.
	Proceeds from the new term loan were used to repay 100% of the outstanding borrowings under the Company's prior revolving credit facility upon closing ($256 million as of September 30, 2014), and to pay fees and expenses associated with the transactions. Additional proceeds and borrowing capacity under the Revolving Facility will be available to fund operations in the Marcellus and Utica Shale plays of West Virginia and Ohio, and for general corporate purposes.
	TGT Credit Support Agreement
	On October 21, 2014 Triad Hunter executed a Credit Support Agreement with TGT, related to the TGT Transportation Services Agreement executed on August 18, 2014 (the "Precedent Agreement Date"). In accordance with the provisions of the Credit Support Agreement, Triad Hunter will provide TGT with letters of credit on the dates and in the amounts that follow (the "Credit Support Amount"):
	(i)	during the period beginning on the date that is fourteen months after the Precedent Agreement Date and ending on the day immediately prior to the date that is twenty-one months after the Precedent Agreement Date, an amount equal to $13 million
	(ii)	during the period beginning on the date that is twenty-one months after the Precedent Agreement Date and ending on the day immediately prior to the date that is twenty-eight months after the Precedent Agreement Date, an amount equal to $36 million; and
	(iii)	during the period beginning on the date that is twenty-eight months after the Precedent Agreement Date and ending on the date the Credit Support Agreement terminates, an amount equal to $65 million.
	Provided however, that the Credit Support Amount shall be subject to reduction (on a cumulative basis) at specified dates depending on Triad Hunter's Interest Coverage Ratio or if Triad Hunter meets the creditworthiness standards established in the Texas Gas FERC Gas Tariff as in effect on such date that Triad Hunter meets the said standard.
	REX Transportation Agreement
	On October 8, 2014, Triad Hunter executed a Precedent Agreement with Rockies Express Pipeline LLC ("REX"), (the "REX Transportation Services Agreement") for the delivery by Triad Hunter and the transportation by REX of natural gas produced by Triad Hunter. In executing the REX Transportation Services Agreement, Triad Hunter committed to purchase 100,000 MMBtu per day of firm transportation from REX. The term of the REX Transportation Services Agreement will commence with the date the pipeline project is available for service, currently anticipated to between mid-2016 and mid-2017, and will end 15 years thereafter. The execution of a Firm Transportation Agreement is contingent upon REX receiving appropriate approvals from FERC for their pipeline project. Upon executing a Firm Transportation Agreement, the Company will have minimum annual contractual obligations for reservation charges of approximately $16.4 million over the 15 year term of the agreement.
	In addition, the Company will be required to provide Credit Support to REX, in the form of a letter of credit, in the initial amount of twenty-seven months of Triad Hunter's reservation charges, or approximately $37 million, within 45 days of executing the REX Transportation Services Agreement.
	Amendment to Asset Purchase Agreement and Purchase of Utica Shale Acreage
	On October 28, 2014, Triad Hunter and MNW entered into the First Amendment to the Asset Purchase Agreement and Partial Release of Earn-Out Agreement (the "Amendment"). In connection with the asset purchase agreement with MNW dated August 12, 2013, Triad Hunter and MNW also entered into an earn-out agreement dated August 12, 2013 which provided for MNW to perform certain consulting services for Triad Hunter and to be paid for such services through the release by Triad Hunter of escrow funds being withheld from the purchase price at each closing under the asset purchase agreement. The Amendment terminates MNW's obligation to perform further consulting services under the earn-out agreement, provides for the disbursement of funds to MNW that have been withheld from closings to date, and amends the asset purchase agreement to end further withholdings of escrow funds from the purchase price at future closings.
	On October 30, 2014, Triad Hunter purchased approximately 5,160 net acres of undeveloped leasehold in the Utica Shale in Ohio for $20.6 million under its asset purchase agreement with MNW and also released $0.4 million in escrowed funds, for a total disbursement to MNW of approximately $21.0 million. Following this purchase, approximately 9,840 net acres remain to be purchased by the Company under the asset purchase agreement with MNW, contingent upon proposed leasehold acreage being cured of title defects.
	Sale of Certain West Virginia Assets
	On November 3, 2014, Triad Hunter closed on the sale of certain non-core working interests in oil and gas properties located primarily in Calhoun and Roane, Counties, West Virginia, for cash consideration of $1.2 million, subject to customary purchase price adjustments. The effective date of the sale is August 1, 2014.

GENERAL_Policies

GENERAL (Policies)	9 Months Ended
	Sep. 30, 2014
Accounting Policies [Abstract]	'
Principles of Consolidation and Presentation	'
	Presentation of Consolidated Financial Statements
	The accompanying unaudited interim consolidated financial statements of Magnum Hunter are presented in U.S. Dollars and have been prepared in accordance with accounting principles generally accepted in the United States ("GAAP"). The preparation of these consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during reporting periods. Actual results could differ materially from those estimates.
	In the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary for the 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 GAAP.
	Certain information and disclosures normally included in the consolidated financial statements prepared in accordance with GAAP that would substantially duplicate the disclosures contained in the audited consolidated financial statements as reported in the Company's Annual Report on Form 10-K have been condensed or omitted.
Non-controlling Interest in Consolidated Subsidiaries	'
	Non-Controlling Interest in Consolidated Subsidiaries
	The Company has consolidated Eureka Hunter Holdings, LLC ("Eureka Hunter Holdings") in which it owned 57.5% as of September 30, 2014 and 56.4% as of December 31, 2013. 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.
Reclassification of Prior-Year Balances	'
	Reclassification of Prior-Period Balances
	Certain prior period balances have been reclassified to correspond with current-year presentation.  As a result of the Company's decision in September 2014 to withdraw its plan to divest of its 100% equity interest in MHP and cease all marketing efforts, the results of operations of MHP, which had previously been reported as a component of discontinued operations, have been reclassified to continuing operations for all periods presented, and all assets and liabilities of MHP that were previously reported as assets and liabilities held for sale in our consolidated balance sheet have been reclassified to assets and liabilities held for use as of September 30, 2014.
Regulated Activities	'
	Regulated Activities
	Energy Hunter Securities, Inc. ("Energy Hunter Securities") is a 100%-owned subsidiary and is a registered broker-dealer and member of the Financial Industry Regulatory Authority ("FINRA"). Among other regulatory requirements, it is subject to the net capital provisions of Rule 15c3-1 under the Securities Exchange Act of 1934, as amended. Because it does not hold customer funds or securities or owe money or securities to customers, Energy Hunter Securities is required to maintain minimum net capital equal to the greater of $5,000 or 6.67% of its aggregate indebtedness.
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 March 2013, the FASB issued Accounting Standards Update ("ASU") 2013-05, Parent’s Accounting for the Cumulative Translation Adjustment upon Derecognition of Certain Subsidiaries or Groups of Assets within a Foreign Entity or of an Investment in a Foreign Entity, to provide guidance on whether to release cumulative translation adjustments ("CTA") upon certain derecognition events. ASU 2013-05 requires a parent company to apply the guidance in ASC Subtopic 830-30 when an entity ceases to have a controlling financial interest in a subsidiary or group of assets that is a business within a foreign entity. Consequently, the CTA related to a foreign entity is released into net income only if the transaction results in complete or substantially complete liquidation of the foreign entity in which the subsidiary or group of assets resided; otherwise, no portion of the CTA is released.  The Company adopted this pronouncement prospectively on January 1, 2014. The adoption of this updated standard did not have a material impact on the Company’s consolidated financial statements.
	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 ASC Topic 740, Income Taxes ("FASB ASC Topic 740"). This update clarified 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. The Company adopted this ASU prospectively on January 1, 2014. The adoption of this accounting standard update did not have a material impact on the Company's consolidated financial statements or its financial statement disclosures.
	In April 2014, the FASB issued ASU 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. ASU 2014-08 updates the requirements for reporting discontinued operations in ASC Subtopic 205-20, Presentation of Financial Statements - Discontinued Operations, by requiring classification as discontinued operations of a component of an entity or a group of components of an entity if the disposal represents a strategic shift that has (or will have) a major effect on an entity's operations and financial results when either 1) the component or group of components of an entity meet the criteria to be classified as held for sale, 2) are disposed of by sale, or 3) are disposed of other than by sale (e.g. abandonment or a distribution to owners in a spinoff). The amendments in this update expand the disclosure requirements related to discontinued operations and disposals of individually significant components that do not qualify for discontinued operations presentation in the financial statements. This ASU is effective prospectively for all disposals (or classification as held for sale) of components of an entity that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). ASU 2014-09 supersedes the revenue recognition requirements in ASC Topic 605, Revenue Recognition, and most industry-specific guidance throughout the Industry Topics of the ASC. The core principle of the revised standard is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. To achieve that core principle, an entity should apply the following steps: identify the contract(s) with a customer, identify the performance obligations in the contract, determine the transaction price, allocate the transaction price to the performance obligations in the contract, and recognize revenue when (or as) the entity satisfies a performance obligation. ASU 2014-09 requires entities to disclose both quantitative and qualitative information that enables users of financial statements to understand the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. This amendment is effective for annual reporting periods beginning after December 15, 2016, including interim periods within those reporting periods. The guidance allows for either a "full retrospective" adoption or a "modified retrospective" adoption, however early application is not permitted. The Company is currently evaluating the adoption methods and the impact of this ASU on its consolidated financial statements and financial statement disclosures.
	In June 2014, the FASB issued ASU 2014-12, Compensation - Stock Compensation: Accounting for Share Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period. ASU 2014-12 clarifies that a performance target that affects vesting and that could be achieved after the requisite service period should be treated as a performance condition. An entity should apply existing guidance in ASC Topic 718 as it relates to awards with performance conditions that affect vesting to account for such awards. As such, the performance target should not be reflected in estimating the grant-date fair value of the award. This amendment is effective for annual periods and interim periods within those annual periods beginning after December 15, 2015. Early adoption is permitted. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.

DIVESTITURES_AND_DISCONTINUED_1

DIVESTITURES AND DISCONTINUED OPERATIONS (Tables)	9 Months Ended
	Sep. 30, 2014
Discontinued Operations and Disposal Groups [Abstract]	'
Schedule of Assets and Liabilities Held for Sale	'
	The following shows the Company's assets and liabilities held for sale at September 30, 2014 and December 31, 2013:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Accounts receivable	$	—		$	4,362
	Other current assets	—			1,004
	Oil and natural gas properties, net	86,362			150,770
	Gas transportation, gathering, and processing equipment and other, net	—			11,721
	Other long-term assets	—			196
	Total assets held for sale	$	86,362		$	168,053
	Accounts payable	$	—		$	7,292
	Accrued liabilities and other liabilities	—			5,573
	Asset retirement obligations	1,619			8,678
	Other long-term liabilities	—			5,845
	Total liabilities held for sale	$	1,619		$	27,388
Schedule of discontinued operations	'
	The Company included the results of operations of WHI Canada through May 12, 2014 and Eagle Ford Hunter through April 24, 2013 in discontinued operations. The following presents our discontinued operations.
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in thousands)
	Revenues	$	—		$	7,943		$	8,533		$	62,429
	Expenses	—			(93,755		)	(3,976		)	(128,464		)
	Other income	—			59			4			81
	Income tax benefit	—			10,180			—			3,501
	Income (loss) from discontinued operations, net of tax	—			(75,573		)	4,561			(62,453		)
	Gain (loss) on disposal of discontinued operations, net of taxes	(258		)	(69,521		)	(13,983		)	102,931
	Income (loss) from discontinued operations, net of taxes	$	(258	)	$	(145,094	)	$	(9,422	)	$	40,478

OIL_NATURAL_GAS_SALES_Tables

OIL & NATURAL GAS SALES (Tables)	9 Months Ended
	Sep. 30, 2014
Other Income and Expenses [Abstract]	'
Schedule of Oil Natural Gas And NGL Revenue	'
	During the three and nine months ended September 30, 2014 and 2013, the Company recognized sales from oil, natural gas, and natural gas liquids ("NGL") as follows:
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
		(in thousands)
	Oil	$	34,495	$	40,471	$	111,354	$	103,545
	Natural gas	18,247		12,417		74,031		41,145
	NGL	9,768		6,173		36,862		12,082
	Total oil and natural gas sales	$	62,510	$	59,061	$	222,247	$	156,772

PROPERTY_PLANT_EQUIPMENT_Table

PROPERTY, PLANT, & EQUIPMENT (Tables)	9 Months Ended
	Sep. 30, 2014
Property, Plant and Equipment [Abstract]	'
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure	'
	The historical cost of gas transportation, gathering, and processing equipment and other property, presented on a gross basis with accumulated depreciation, as of September 30, 2014 and December 31, 2013 is summarized as follows:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Gas transportation, gathering and processing equipment and other	$	516,258		$	315,642
	Less accumulated depreciation	(47,350		)	(26,222		)
	Net capitalized costs	$	468,908		$	289,420
	The following sets forth the net capitalized costs under the successful efforts method for oil and natural gas properties as of:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Mineral interests in properties:
	Unproved mineral rights and leasehold costs	$	510,296		$	469,337
	Proved mineral rights and leasehold costs	282,150			336,357
	Wells and related equipment and facilities	735,947			536,023
	Advances to operators for wells in progress	2,508			13,571
	Total costs	1,530,901			1,355,288
	Less accumulated depletion, depreciation, and amortization	(208,495		)	(130,629		)
	Net capitalized costs	$	1,322,406		$	1,224,659
Schedule of the Company's geological and geophysical costs and leasehold abandonments expense	'
	During the three and nine months ended September 30, 2014 and 2013, the Company recognized exploration expense as follows:
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014		2013
		(in thousands)
	Leasehold impairments	$	26,922		$	41,624		$	51,305	$	74,249
	Geological and geophysical	362			354			1,089		1,008
	Total exploration expense	$	27,284		$	41,978		$	52,394	$	75,257

INTANGIBLE_ASSETS_Tables

INTANGIBLE ASSETS (Tables)	9 Months Ended
	Sep. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Finite-Lived Intangible Assets [Table Text Block]	'
	Intangible assets consist primarily of gas gathering and processing contracts and customer relationships. The following table summarizes the Company's net intangible assets as of September 30, 2014 and December 31, 2013:
		September 30,			December 31,
		2014			2013
		(in thousands)
	Customer relationships	$	5,434		$	5,434
	Trademark	859			859
	Existing contracts	4,199			4,199
	Total intangible assets	10,492			10,492
	Less: accumulated amortization	(5,467		)	(3,962		)
	Intangible assets, net of accumulated amortization	$	5,025		$	6,530

INVENTORY_Tables

INVENTORY (Tables)	9 Months Ended
	Sep. 30, 2014
Inventory Disclosure [Abstract]	'
Schedule of Inventory	'
	The following table shows the composition of the Company's inventory as of:
		September 30,		December 31,
		2014		2013
		(in thousands)
	Materials and supplies	$	2,228	$	6,790
	Commodities	811		368
	Inventory	$	3,039	$	7,158

ASSET_RETIREMENT_OBLIGATIONS_T

ASSET RETIREMENT OBLIGATIONS (Tables)	9 Months Ended
	Sep. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Summary of asset retirement obligation	'
	The following table summarizes the Company’s asset retirement obligation ("ARO") activities during the nine-month period ended September 30, 2014 and for the year ended December 31, 2013:
		30-Sep-14			31-Dec-13
		(in thousands)
	Asset retirement obligation at beginning of period	$	16,216		$	30,680
	Assumed in acquisitions	—			17
	Liabilities incurred	218			253
	Liabilities settled	(26		)	(98		)
	Liabilities sold	(596		)	(7,614		)
	Accretion expense	1,731			2,264
	Revisions in estimated liabilities (1)	2,625			1,935
	Reclassified as liabilities associated with assets held for sale	(1,619		)	(11,148		)
	Reclassified from liabilities associated with assets held for sale	8,109			—
	Effect of foreign currency translation	—			(73		)
	Asset retirement obligation at end of period	26,658			16,216
	Less: current portion (included in other liabilities)	(1,482		)	(53		)
	Asset retirement obligation at end of period	$	25,176		$	16,163
	________________________________
	(1) Revisions in estimated liabilities during 2014 relate to a change in assumptions used with respect to certain wells in the Appalachian Basin in Ohio and West Virginia. Approximately $1.5 million of the revisions in estimated liabilities during 2013 is related to a change in assumptions used with respect to certain wells in the Williston Basin in North Dakota.

FAIR_VALUE_OF_FINANCIAL_INSTRU1

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)	9 Months Ended
	Sep. 30, 2014
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-14
	Life	2.4
	Risk-free interest rate	1.03		%
	Estimated volatility	40		%
	Dividend	—
	GreenHunter stock price at end of period	$	1.52
	The fair value of the bifurcated conversion feature was valued using the "with and without" analysis in a simulation model based upon management's estimate of the expected life of the conversion feature. The key assumptions used in the model to determine fair value at September 30, 2014 were as follows:
		September 30, 2014
	Volatility	13.7		%
	Credit spread	24		%
	Expected term	1-2 years
	Total enterprise value (in millions)	$	929.7
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 (Level 3 inputs) for the nine-month period ended September 30, 2014:
		Preferred Stock Embedded				Convertible Security Embedded
		Derivative Liability				Derivative Asset
		(in thousands)
	Fair value as of December 31, 2013	$	(75,934	)		$	79
	Issuance of redeemable preferred stock	(5,479		)		—
	Increase in fair value recognized in gain (loss) on derivative contracts, net	(91,792		)		4
	Fair value as of September 30, 2014	$	(173,205	)		$	83
Fair value measurements on a recurring basis	'
	The following tables present the fair value hierarchy levels of the Company's financial assets and liabilities which are measured and carried at fair value on a recurring basis:
		Fair Value Measurements on a Recurring Basis
		30-Sep-14
		(in thousands)
	Assets	Level 1				Level 2			Level 3
	Available for sale securities	$	8,076			$	—		$	—
	Commodity derivative assets	—				2,127			—
	Convertible security derivative assets	—				—			83
	Total assets at fair value	$	8,076			$	2,127		$	83
	Liabilities
	Commodity derivative liabilities	$	—			$	114		$	—
	Convertible preferred stock derivative liabilities	—				—			173,205
	Total liabilities at fair value	$	—			$	114		$	173,205
		Fair Value Measurements on a Recurring Basis
		31-Dec-13
		(in thousands)
	Assets	Level 1				Level 2			Level 3
	Available for sale securities	$	1,819			$	—		$	—
	Commodity derivative assets	—				554			—
	Convertible security derivative assets	—				—			79
	Total assets at fair value	$	1,819			$	554		$	79
	Liabilities
	Commodity derivative liabilities	$	—			$	2,279		$	—
	Convertible preferred stock derivative liabilities	—				—			75,934
	Total liabilities at fair value	$	—			$	2,279		$	75,934
Carrying amounts and fair values of long-term debt	'
	The following table presents the carrying amounts and fair values categorized by fair value hierarchy level of the Company's financial instruments not carried at fair value:
					30-Sep-14						31-Dec-13
			Fair Value Hierarchy		Carrying Amount			Estimated Fair Value			Carrying Amount		Estimated Fair Value
					(in thousands)
	Senior Notes		Level 2		$	597,313		$	639,000		$	597,230	$	651,300
	MHR Senior Revolving Credit Facility		Level 3		$	256,000		$	256,000		$	218,000	$	218,000
	Eureka Hunter Pipeline second lien term loan		Level 3		$	—		$	—		$	50,000	$	58,921
	Eureka Hunter Pipeline Credit Agreement		Level 3		$	80,000		$	80,000		$	—	$	—
	Equipment Notes Payable		Level 3		$	25,149		$	25,170		$	18,615	$	17,676

FINANCIAL_INSTRUMENTS_AND_DERI1

FINANCIAL INSTRUMENTS AND DERIVATIVES (Tables)	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Summary of changes in investments	'
	Below is a summary of changes in investments for the nine months ended September 30, 2014:
		Available for Sale Securities				Equity Method Investments (1)
		(in thousands)
	Carrying value as of December 31, 2013	$	1,819			$	940
	Securities received as consideration for assets sold	9,447				—
	Equity in net loss recognized in other income (expense)	—				(504		)
	Change in fair value recognized in other comprehensive loss	(3,190		)		—
	Carrying value as of September 30, 2014	$	8,076			$	436
	(1) Equity method investments includes $282,000 classified as long-term other assets.
Schedule of investments by balance sheet grouping	'
	The Company's investments have been presented in the consolidated balance sheet as of September 30, 2014 as follows:
		Available for Sale Securities			Equity Method Investments			Total
	Investments - Current	$	8,076		$	154		$	8,230
	Other Assets - Long-Term	—			282			282
	Carrying value as of September 30, 2014	$	8,076		$	436		$	8,512
Summary of cost for equity securities and fair value	'
	The cost for equity securities and their respective fair values as of September 30, 2014 and December 31, 2013 are as follows:
			September 30, 2014
			(in thousands)
			Cost				Gross Unrealized Gains				Gross Unrealized Losses				Fair Value
	Securities available for sale, carried at fair value:
	Equity securities		$	9,875			$	—			$	(4,030	)		$	5,845
	Equity securities - related party (see "Note 15 - Related Party Transactions")		2,200				—				31				2,231
	Total Securities available for sale		$	12,075			$	—			$	(3,999	)		$	8,076
			December 31, 2013
			(in thousands)
			Cost				Gross Unrealized Gains				Gross Unrealized Losses				Fair Value
	Securities available for sale, carried at fair value:
	Equity securities		$	428			$	—			$	(281	)		$	147
	Equity securities - related party (see "Note 15 - Related Party Transactions")		2,200				—				(528		)		1,672
	Total Securities available for sale		$	2,628			$	—			$	(809	)		$	1,819
Estimated fair values of commodity derivatives	'
	As of September 30, 2014, the Company had the following commodity derivative instruments:
					Weighted Average
	Natural Gas	Period	MMBtu/day		Price per MMBtu
	Collars (1)	Oct 2014- Dec 2014	15,000		$4.27 - $5.23
	Swaps	Oct 2014 - Dec 2014	41,000		$4.18
		Jan 2015 - Dec 2015	30,000		$4.12
	Ceilings purchased (call)	Oct 2014 - Dec 2014	16,000		$5.91
	Ceilings sold (call)	Oct 2014 - Dec 2014	16,000		$5.91
					Weighted Average
	Crude Oil	Period	Bbl/day		Price per Bbl
	Collars (1)	Oct 2014 - Dec 2014	663		$85.00 - $91.25
		Jan 2015 - Dec 2015	259		$85.00 - $91.25
	Traditional three-way collars (2)	Oct 2014 - Dec 2014	4,000		$64.94 - $85.00 - $102.50
	Ceilings sold (call)	Jan 2015 - Dec 2015	1,570		$120.00
	Floors sold (put)	Oct 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.
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:
					Derivative Assets								Derivative Liabilities
	Derivatives not designated as hedging instruments		Balance Sheet Classification		September 30, 2014				December 31, 2013				September 30, 2014				December 31, 2013
					(in thousands)
	Commodity
			Derivative assets		$	1,871			$	529			$	—			$	—
			Derivative assets - long-term		255				25				—				—
			Derivative liabilities		—				—				(48		)		(1,903		)
			Derivative liabilities - long-term		—				—				(66		)		(376		)
	Total commodity				$	2,126			$	554			$	(114	)		$	(2,279	)
	Financial
			Derivative assets		$	83			$	79			$	—			$	—
			Derivative liabilities - long-term		—				—				(173,205		)		(75,934		)
	Total financial				$	83			$	79			$	(173,205	)		$	(75,934	)
	Total derivatives				$	2,209			$	633			$	(173,319	)		$	(78,213	)
Schedule of commodity derivatives and master netting arrangements	'
	The tables below summarize the Company's commodity derivatives and the effect of master netting arrangements on the presentation in the Company's consolidated balance sheets as of:
		September 30, 2014
		Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset on the Consolidated Balance Sheet		Net Amount
		(in thousands)
	Current assets:  Fair value of derivative contracts	$	2,399		(528	)	$	1,871
	Long-term assets:  Fair value of derivative contracts	377			(122	)	255
	Current liabilities:  Fair value of derivative contracts	(576		)	528		(48		)
	Long-term liabilities:  Fair value of derivative contracts	(188		)	122		(66		)
		$	2,012		—		$	2,012
		December 31, 2013
		Gross Amounts of Assets and Liabilities			Gross Amounts Offset on the Consolidated Balance Sheet		Net Amount
		(in thousands)
	Current assets:  Fair value of derivative contracts	$	4,034		(3,505	)	$	529
	Long-term assets:  Fair value of derivative contracts	516			(491	)	25
	Current liabilities:  Fair value of derivative contracts	(5,408		)	3,505		(1,903		)
	Long-term liabilities:  Fair value of derivative contracts	(867		)	491		(376		)
		$	(1,725	)	—		$	(1,725	)
Schedule of the realized and unrealized gain (loss) on derivatives	'
	The following table summarizes the net gain (loss) on all derivative contracts included in gain (loss) on derivative contracts, net on the consolidated statements of operations for the three and nine months ended September 30, 2014 and 2013:
		Three Months Ended September 30,								Nine Months Ended
										September 30,
		2014				2013				2014				2013
		(in thousands)
	Gain (loss) on settled transactions	$	477			$	(6,582	)		$	(4,074	)		$	(6,887	)
	Loss on open contracts	(50,113		)		(22,971		)		(88,051		)		(23,757		)
	Total loss	$	(49,636	)		$	(29,553	)		$	(92,125	)		$	(30,644	)

DEBT_Tables

DEBT (Tables)	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
Schedule of long-term debt	'
	Long-term debt at September 30, 2014 and December 31, 2013 consisted of the following:
		September 30, 2014			December 31, 2013
		(in thousands)
	Senior Notes payable due May 15, 2020, interest rate of 9.75%, net of unamortized net discount of $2.7 million at September 30, 2014 and December 31, 2013	$	597,313		$	597,230
	Various equipment and real estate notes payable with maturity dates January 2015 - April 2021, interest rates of 4.25% - 7.94%(1)	25,149			18,615
	Eureka Hunter Pipeline Credit Agreement due March 28, 2018, interest rate of 3.66%	80,000			—
	Eureka Hunter Pipeline second lien term loan due August 16, 2018, interest rate of 12.5%	—			50,000
	MHR Senior Revolving Credit Facility due April 13, 2016, interest rate of 3.06% at September 30, 2014 and 3.56% at December 31, 2013	256,000			218,000
		958,462			883,845
	Less: current portion	(8,670		)	(3,967		)
	Total long-term debt obligations, net of current portion	$	949,792		$	879,878
	_________________________________
	-1	Balance as of December 31, 2013 includes notes classified as liabilities associated with assets held for sale of which $0.2 million is current and $3.8 million is long-term.
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 $2.7 million:
		(in thousands)
	2014	$	2,565
	2015	7,717
	2016	264,727
	2017	2,548
	2018	80,559
	Thereafter	603,032
	Total	$	961,148
Schedule of Interest Expense	'
	The following table sets forth interest expense for the three and nine month periods ended September 30, 2014 and 2013, respectively:
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014		2013
		(in thousands)
	Interest expense incurred on debt, net of amounts capitalized	$	17,013		$	14,648		$	53,748	$	49,691
	Amortization and write-off of deferred financing costs	1,082			1,111			8,725		3,661
	Total interest expense	$	18,095		$	15,759		$	62,473	$	53,352

SHAREBASED_COMPENSATION_Tables

SHARE-BASED COMPENSATION (Tables)	9 Months Ended
	Sep. 30, 2014
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, 2014 and 2013 is presented below:
		Nine Months Ended September 30,
		2014		2013		2014		2013
		(in thousands of shares)				Weighted Average Exercise Price per Share
	Outstanding at beginning of period	16,891		14,847		$	5.69	$	6.01
	Granted	—		4,938		$	—	$	4.11
	Exercised	(2,355	)	(685	)	$	4.09	$	2.95
	Forfeited	(1,241	)	(742	)	$	6.28	$	6
	Outstanding at end of period	13,295		18,358		$	5.91	$	5.61
	Exercisable at end of period	9,179		10,512		$	6.22	$	5.86
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, 2014 and 2013 is presented below:
		Nine Months Ended September 30,
		2014		2013
		(in thousands of shares)
	Non-vested at beginning of period	6,908		6,163
	Granted	—		4,938
	Vested	(1,916	)	(2,867	)
	Forfeited	(876	)	(389	)
	Non-vested at end of period	4,116		7,845

SHAREHOLDERS_EQUITY_Tables

SHAREHOLDERS' EQUITY (Tables)	9 Months Ended
	Sep. 30, 2014
Equity [Abstract]	'
Schedule of dividends paid	'
	A summary of the Company's preferred dividends for the three and nine months ended September 30, 2014 and 2013 is presented below:
		Three Months Ended September 30,					Nine Months Ended September 30,
		2014			2013		2014		2013
		(in thousands)					(in thousands)
	Dividend on Eureka Hunter Holdings Series A Preferred Units	$	4,338		$	3,771	$	12,619	$	10,441
	Accretion of the carrying value of the Eureka Hunter Holdings Series A Preferred Units	2,306			1,826		6,583		4,990
	Dividend on Series C Preferred Stock	2,562			2,562		7,686		7,686
	Dividend on Series D Preferred Stock	4,424			4,424		13,273		13,231
	Dividend on Series E Preferred Stock	1,862			1,834		5,557		5,686
	Total dividends on Preferred Stock	$	15,492		$	14,417	$	45,718	$	42,034
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share	'
	The following table summarizes the types of potentially dilutive securities outstanding as of September 30, 2014 and 2013:
		September 30,
		2014		2013
		(in thousands of shares)
	Series E Preferred Stock	10,946		11,185
	Warrants	19,214		30,407
	Unvested restricted shares	1,445		—
	Common stock options and stock appreciation rights	13,295		18,358
	Total	44,900		59,950

TAXES_Tables

TAXES (Tables)	9 Months Ended
	Sep. 30, 2014
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, 2014 and 2013 was:
		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
		(in thousands)
	Deferred	$	—	$	582	$	—	$	47,227
	Income tax benefit	$	—	$	582	$	—	$	47,227

RELATED_PARTY_TRANSACTIONS_Tab

RELATED PARTY TRANSACTIONS (Tables)	9 Months Ended
	Sep. 30, 2014
Related Party Transactions [Abstract]	'
Schedule of Related Party Balances	'
	The following table sets forth the related party balances as of September 30, 2014 and December 31, 2013:
		September 30, 2014				December 31, 2013
		(in thousands)
	Green Hunter (1)
	Accounts payable - net	$	355			$	23
	Derivative assets (2)	$	83			$	79
	Investments (2)	$	2,385			$	2,262
	Notes receivable (2)	$	1,360			$	1,768
	Prepaid expenses	$	—			$	9
Schedule of Related Party Transactions	'
	The following table sets forth the related party transaction activities for the three and nine months ended September 30, 2014 and 2013, respectively:
			Three Months Ended							Nine Months Ended
			September 30,							September 30,
			2014				2013			2014		2013
			(in thousands)
	GreenHunter
		Salt water disposal (1)	$	820			$	623		$	1,754	$	2,069
		Equipment rental (1)	74				95			215		167
		Gas gathering-trucking (1)	132				—			532		—
		MAG tank panels (1)	—				—			800		—
		Office space rental	—				—			36		—
		Interest income from note receivable (2)	38				51			121		159
		Dividends earned from Series C shares	55				73			165		165
		Unrealized gain/(loss) on investments (2)	(38		)		(24		)	123		653
	Pilatus Hunter, LLC
		Airplane rental expenses (3)	49				26			207		94
	_________________________________
	-1	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman, a major shareholder and interim CEO. Eagle Ford Hunter received, and Triad Hunter and Viking International Resources Co., Inc., 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.
	-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.  See "Note 8 - 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.

SUPPLEMENTAL_CASH_FLOW_INFORMA1

SUPPLEMENTAL CASH FLOW INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2014
Supplemental Cash Flow Elements [Abstract]	'
Schedule of Cash Flow, Supplemental Disclosures	'
	The following table summarizes cash paid (received) for interest and income taxes, as well as non-cash investing transactions:
		Nine Months Ended September 30,
		2014		2013
		(in thousands)
	Cash paid for interest	$	38,565	$	38,225
	Non-cash transactions
	Common stock issued for 401k matching contributions	$	1,593	$	1,192
	Non-cash consideration received from sale of assets	$	9,447	$	—
	Change in accrued capital expenditures	$	129,778	$	(5,742	)
	Non-cash additions to asset retirement obligation	$	2,439	$	2,089
	Eureka Hunter Holdings Series A Preferred Unit dividends paid in kind	$	1,950	$	6,367

SEGMENT_REPORTING_Tables

SEGMENT REPORTING (Tables)	9 Months Ended
	Sep. 30, 2014
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, 2014 and 2013, respectively.
		As of and for the Three Months Ended September 30, 2014
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	63,438		$	—		$	11,845		$	8,176		$	—		$	(3,789	)	$	79,670
	Depletion, depreciation, amortization and accretion	31,217			—			4,224			929			—			—			36,370
	Gain on sale of assets, net	(7,988		)	—			(12		)	—			—			—			(8,000		)
	Other operating expenses	87,035			—			7,350			6,569			11,711			(3,789		)	108,876
	Other income (expense)	1,907			—			(58,078		)	(205		)	(9,237		)	—			(65,613		)
	Income (loss) from continuing operations before income tax	(44,919		)	—			(57,795		)	473			(20,948		)	—			(123,189		)
	Total income (loss) from discontinued operations, net of tax 1	(259		)	—			—			—			1			—			(258		)
	Net income (loss)	$	(45,178	)	$	—		$	(57,795	)	$	473		$	(20,947	)	$	—		$	(123,447	)
	Total assets	$	1,475,305		$	—		$	443,008		$	45,661		$	74,614		$	(5,023	)	$	2,033,565
	Total capital expenditures	$	104,265		$	—		$	88,525		$	3,628		$	21		$	—		$	196,439
	_________________________________
	-1	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.
		As of and for the Three Months Ended September 30, 2013
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	59,325		$	—		$	14,618		$	6,448		$	—		$	(2,100	)	$	78,291
	Depletion, depreciation, amortization and accretion	25,233			—			3,174			720			—			—			29,127
	Loss on sale of assets, net	40,952			—			—			—			—			—			40,952
	Other operating expenses	100,484			—			11,140			4,931			11,457			74			128,086
	Other income (expense)	2,038			—			(16,572		)	(141		)	(20,814		)	2,268			(33,221		)
	Income (loss) from continuing operations before income tax	(105,306		)	—			(16,268		)	656			(32,271		)	94			(153,095		)
	Income tax benefit (expense)	17,794			926			—			—			(18,138		)	—			582
	Total income (loss) from discontinued operations, net of tax	(13,881		)	(132,861		)	—			—			1,742			(94		)	(145,094		)
	Net income (loss)	$	(101,393	)	$	(131,935	)	$	(16,268	)	$	656		$	(48,667	)	$	—		$	(297,607	)
	Total assets	$	1,406,515		$	106,438		$	269,692		$	42,648		$	62,182		$	(1,659	)	$	1,885,816
	Total capital expenditures	$	149,577		$	181		$	19,918		$	5,850		$	504		$	—		$	176,030
		As of and for the Nine Months Ended September 30, 2014
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	223,788		$	—		$	98,697		$	23,882		$	—		$	(14,752	)	$	331,615
	Depletion, depreciation, amortization and accretion	87,345			—			11,831			2,557			—			—			101,733
	Gain on sale of assets, net	(4,231		)	—			(12		)	(369		)	—			—			(4,612		)
	Other operating expenses	197,013			—			86,120			19,643			35,253			(14,752		)	323,277
	Other income (expense)	1,739			—			(98,505		)	(625		)	(54,979		)	—			(152,370		)
	Income (loss) from continuing operations before income tax	(54,600		)	—			(97,747		)	1,426			(90,232		)	—			(241,153		)
	Total income (loss) from discontinued operations, net of tax 1	(7,283		)	10,636			—			—			(12,775		)	—			(9,422		)
	Net income (loss)	$	(61,883	)	$	10,636		$	(97,747	)	$	1,426		$	(103,007	)	$	—		$	(250,575	)
	Total assets	$	1,475,305		$	—		$	443,008		$	45,661		$	74,614		$	(5,023	)	$	2,033,565
	Total capital expenditures	$	320,719		$	305		$	171,152		$	6,575		$	127		$	—		$	498,878
	_________________________________
	-1	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.
		As of and for the Nine Months Ended September 30, 2013
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	158,217		$	—		$	48,071		$	13,873		$	—		$	(5,802	)	$	214,359
	Depletion, depreciation, amortization and accretion	69,420			—			9,142			1,579			—			—			80,141
	Loss on sale of assets, net	42,110			—			—			4			—			—			42,114
	Other operating expenses	198,363			—			41,276			12,884			38,932			(3,628		)	287,827
	Other income (expense)	440			—			(24,261		)	(372		)	(47,330		)	2,288			(69,235		)
	Income (loss) from continuing operations before income tax	(151,236		)	—			(26,608		)	(966		)	(86,262		)	114			(264,958		)
	Income tax benefit	23,560			—			—			—			23,667			—			47,227
	Total income (loss) from discontinued operations, net of tax	181,233			(134,070		)	—			—			(6,571		)	(114		)	40,478
	Net income (loss)	$	53,557		$	(134,070	)	$	(26,608	)	$	(966	)	$	(69,166	)	$	—		$	(177,253	)
	Total assets	$	1,406,515		$	106,438		$	269,692		$	42,648		$	62,182		$	(1,659	)	$	1,885,816
	Total capital expenditures	$	322,768		$	14,317		$	55,003		$	19,971		$	927		$	—		$	412,986

CONDENSED_CONSOLIDATING_GUARAN1

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Tables)	9 Months Ended
	Sep. 30, 2014
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, 2014
		Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Net income (loss)	$	(127,328	)	$	(44,101	)	$	(58,873	)	$	106,855		$	(123,447	)
	Foreign currency translation gain	—			—			—			—			—
	Unrealized loss on available for sale securities	—			(2,583		)	—			—			(2,583		)
	Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	—			—			—			—			—
	Comprehensive income (loss)	(127,328		)	(46,684		)	(58,873		)	106,855			(126,030		)
	Comprehensive income attributable to non-controlling interest	—			—			—			2,764			2,764
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(127,328	)	$	(46,684	)	$	(58,873	)	$	109,619		$	(123,266	)
		Three Months Ended September 30, 2013
		Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Net income (loss)	$	(302,363	)	$	(81,981	)	$	(178,410	)	$	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)	(307,063		)	(81,808		)	(174,554		)	265,147			(298,278		)
	Comprehensive income attributable to non-controlling interest	—			—			—			725			725
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(307,063	)	$	(81,808	)	$	(174,554	)	$	265,872		$	(297,553	)
		Nine Months Ended September 30, 2014
		Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Net income (loss)	$	(266,125	)	$	(51,611	)	$	(88,330	)	$	155,491		$	(250,575	)
	Foreign currency translation loss	—			—			(1,218		)	—			(1,218		)
	Unrealized loss on available for sale securities	—			(3,188		)	—			—			(3,188		)
	Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	20,741			—			—			—			20,741
	Comprehensive income (loss)	(245,384		)	(54,799		)	(89,548		)	155,491			(234,240		)
	Comprehensive income attributable to non-controlling interest	—			—			—			3,653			3,653
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(245,384	)	$	(54,799	)	$	(89,548	)	$	159,144		$	(230,587	)
		Nine Months Ended September 30, 2013
		Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Net income (loss)	$	(190,954	)	$	(97,486	)	$	(202,152	)	$	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		)	(97,564		)	(210,095		)	313,339			(185,274		)
	Comprehensive income attributable to non-controlling interest	—			—			—			1,614			1,614
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(190,954	)	$	(97,564	)	$	(210,095	)	$	314,953		$	(183,660	)
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, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	ASSETS
	Current assets	$	52,405		$	43,367		$	10,301		$	(5,022	)	$	101,051
	Intercompany accounts receivable	1,084,519			—			—			(1,084,519		)	—
	Property and equipment (using successful efforts method of accounting)	5,614			1,390,673			395,027			—			1,791,314
	Investment in subsidiaries	193,337			100,392			—			(293,729		)	—
	Assets held for sale and other	16,594			87,291			37,315			—			141,200
	Total Assets	$	1,352,469		$	1,621,723		$	442,643		$	(1,383,270	)	$	2,033,565
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	40,822		$	124,895		$	94,550		$	(5,025	)	$	255,242
	Intercompany accounts payable	—			1,044,555			42,201			(1,086,756		)	—
	Long-term liabilities	856,161			45,822			253,257			—			1,155,240
	Redeemable preferred stock	100,000			—			151,685			—			251,685
	Shareholders' equity (deficit)	355,486			406,451			(99,050		)	(291,489		)	371,398
	Total Liabilities and Shareholders' Equity	$	1,352,469		$	1,621,723		$	442,643		$	(1,383,270	)	$	2,033,565
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
		As of December 31, 2013
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	ASSETS
	Current assets	$	53,161		$	43,841		$	27,096		$	(3,372	)	$	120,726
	Intercompany accounts receivable	965,138			—			—			(965,138		)	—
	Property and equipment (using successful efforts method of accounting)	7,214			1,272,027			234,838			—			1,514,079
	Investment in subsidiaries	372,236			102,314			—			(474,550		)	—
	Other assets	17,308			100,894			103,644			—			221,846
	Total Assets	$	1,415,057		$	1,519,076		$	365,578		$	(1,443,060	)	$	1,856,651
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	54,826		$	97,520		$	34,929		$	(3,410	)	$	183,865
	Intercompany accounts payable	—			921,237			43,866			(965,103		)	—
	Long-term liabilities	818,651			39,067			127,663			—			985,381
	Redeemable preferred stock	100,000			—			136,675			—			236,675
	Shareholders' equity (deficit)	441,580			461,252			22,445			(474,547		)	450,730
	Total Liabilities and Shareholders' Equity	$	1,415,057		$	1,519,076		$	365,578		$	(1,443,060	)	$	1,856,651
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, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Revenues	$	10		$	72,809		$	11,141		$	(4,290	)	$	79,670
	Expenses	21,317			115,817			70,015			(4,290		)	202,859
	Income (loss) from continuing operations before equity in net income of subsidiaries	(21,307		)	(43,008		)	(58,874		)	—			(123,189		)
	Equity in net income of subsidiaries	(105,762		)	(1,093		)	—			106,855			—
	Income (loss) from continuing operations before income tax	(127,069		)	(44,101		)	(58,874		)	106,855			(123,189		)
	Income tax benefit (expense)	—			—			—			—			—
	Income (loss) from continuing operations	(127,069		)	(44,101		)	(58,874		)	106,855			(123,189		)
	Income from discontinued operations, net of tax	—			—			—			—			—
	Gain on sale of discontinued operations, net of tax	(259		)	—			1			—			(258		)
	Net income (loss)	(127,328		)	(44,101		)	(58,873		)	106,855			(123,447		)
	Net income attributable to non-controlling interest	—			—			—			2,764			2,764
	Net income (loss) attributable to Magnum Hunter Resources Corporation	(127,328		)	(44,101		)	(58,873		)	109,619			(120,683		)
	Dividends on preferred stock	(8,848		)	—			(6,644		)	—			(15,492		)
	Net income (loss) attributable to common shareholders	$	(136,176	)	$	(44,101	)	$	(65,517	)	$	109,619		$	(136,175	)
		Three Months Ended September 30, 2013
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Revenues	$	29		$	71,246		$	9,112		$	(2,096	)	$	78,291
	Expenses	35,350			171,183			27,045			(2,192		)	231,386
	Income (loss) from continuing operations before equity in net income of subsidiaries	(35,321		)	(99,937		)	(17,933		)	96			(153,095		)
	Equity in net income of subsidiaries	(236,767		)	163			(28,543		)	265,147			—
	Income (loss) from continuing operations before income tax	(272,088		)	(99,774		)	(46,476		)	265,243			(153,095		)
	Income tax benefit (expense)	(18,138		)	17,793			927			—			582
	Income (loss) from continuing operations	(290,226		)	(81,981		)	(45,549		)	265,243			(152,513		)
	Income (loss) from discontinued operations, net of tax	1,743			—			(77,220		)	(96		)	(75,573		)
	Gain on sale of discontinued operations, net of tax	(13,880		)	—			(55,641		)	—			(69,521		)
	Net income (loss)	(302,363		)	(81,981		)	(178,410		)	265,147			(297,607		)
	Net income attributable to non-controlling interest	—			—			—			725			725
	Net income (loss) attributable to Magnum Hunter Resources Corporation	(302,363		)	(81,981		)	(178,410		)	265,872			(296,882		)
	Dividends on preferred stock	(8,820		)	—			(5,597		)	—			(14,417		)
	Net income (loss) attributable to common shareholders	$	(311,183	)	$	(81,981	)	$	(184,007	)	$	265,872		$	(311,299	)
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
		Nine Months Ended September 30, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Revenues	$	124		$	313,898		$	32,846		$	(15,253	)	$	331,615
	Expenses	92,622			363,587			131,812			(15,253		)	572,768
	Income (loss) from continuing operations before equity in net income of subsidiaries	(92,498		)	(49,689		)	(98,966		)	—			(241,153		)
	Equity in net income of subsidiaries	(153,569		)	(1,922		)	—			155,491			—
	Income (loss) from continuing operations before income tax	(246,067		)	(51,611		)	(98,966		)	155,491			(241,153		)
	Income tax benefit (expense)	—			—			—			—			—
	Income (loss) from continuing operations	(246,067		)	(51,611		)	(98,966		)	155,491			(241,153		)
	Income from discontinued operations, net of tax	—			—			4,561			—			4,561
	Gain (loss) on sale of discontinued operations, net of tax	(20,058		)	—			6,075			—			(13,983		)
	Net income (loss)	(266,125		)	(51,611		)	(88,330		)	155,491			(250,575		)
	Net income attributable to non-controlling interest	—			—			—			3,653			3,653
	Net income (loss) attributable to Magnum Hunter Resources Corporation	(266,125		)	(51,611		)	(88,330		)	159,144			(246,922		)
	Dividends on preferred stock	(26,516		)	—			(19,202		)	—			(45,718		)
	Net income (loss) attributable to common shareholders	$	(292,641	)	$	(51,611	)	$	(107,532	)	$	159,144		$	(292,640	)
	Nine Months Ended September 30, 2013
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Revenues	$	(134	)	$	194,599		$	25,693		$	(5,799	)	$	214,359
Expenses	91,559			337,827			55,845			(5,914		)	479,317
Income (loss) from continuing operations before equity in net income of subsidiaries	(91,693		)	(143,228		)	(30,152		)	115			(264,958		)
Equity in net income of subsidiaries	(274,930		)	(479		)	(37,930		)	313,339			—
Income (loss) from continuing operations before income tax	(366,623		)	(143,707		)	(68,082		)	313,454			(264,958		)
Income tax benefit (expense)	23,667			23,560			—			—			47,227
Income (loss) from continuing operations	(342,956		)	(120,147		)	(68,082		)	313,454			(217,731		)
Income (loss) from discontinued operations, net of tax	(6,570		)	22,661			(78,429		)	(115		)	(62,453		)
Gain on sale of discontinued operations, net of tax	158,572			—			(55,641		)	—			102,931
Net income (loss)	(190,954		)	(97,486		)	(202,152		)	313,339			(177,253		)
Net income attributable to non-controlling interest	—			—			—			1,614			1,614
Net income (loss) attributable to Magnum Hunter Resources Corporation	(190,954		)	(97,486		)	(202,152		)	314,953			(175,639		)
Dividends on preferred stock	(26,603		)	—			(15,431		)	—			(42,034		)
Net income (loss) attributable to common shareholders	$	(217,557	)	$	(97,486	)	$	(217,583	)	$	314,953		$	(217,673	)
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, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Cash flow from operating activities	$	(261,039	)	$	222,520		$	52,074		$	—		$	13,555
	Cash flow from investing activities	63,502			(211,560		)	(99,246		)	—			(247,304		)
	Cash flow from financing activities	193,885			2,232			38,542			—			234,659
	Effect of exchange rate changes on cash	—			—			44			—			44
	Net increase (decrease) in cash	(3,652		)	13,192			(8,586		)	—			954
	Cash at beginning of period	47,895			(17,651		)	11,469			—			41,713
	Cash at end of period	$	44,243		$	(4,459	)	$	2,883		$	—		$	42,667
		Nine Months Ended September 30, 2013
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Cash flow from operating activities	$	(264,051	)	$	236,112		$	107,136		$	—		$	79,197
	Cash flow from investing activities	422,056			(245,179		)	(132,054		)	—			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

GENERAL_Details

GENERAL (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

PRC Williston, LLC (PRC)

PRC Williston, LLC (PRC)

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Energy Hunter Securities, Inc. (EHS)

Energy Hunter Securities, Inc. (EHS)

Eureka Hunter Pipeline, LLC

Trans Tex Hunter LLC

Eureka Hunter Land, LLC

Sentra Corporation

Sentra Corporation

Sentra Corporation

Sentra Corporation

Summary of Significant Accounting Policies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated controlling interest (as a percent)

100.00%

87.50%

57.50%

56.40%

'

'

'

'

'

'

'

'

'

Consolidated entities ownership percentage in entity (as a percent)

'

'

'

'

'

'

100.00%

100.00%

100.00%

'

'

'

'

Minimum Net Capital Required for Broker-Dealer Subsidiary

'

'

'

'

$5,000

'

'

'

'

'

'

'

'

Ratio of Indebtedness to Net Capital

'

'

'

'

0.0667

'

'

'

'

'

'

'

'

Net capital

'

'

'

'

83,204

77,953

'

'

'

'

'

'

'

Aggregate indebtedness

'

'

'

'

8,494

16,657

'

'

'

'

'

'

'

Regulated operating revenue, gas

'

'

'

'

'

'

'

'

'

$27,656

$215,618

$473,555

$215,618

DIVESTITURES_AND_DISCONTINUED_2

DIVESTITURES AND DISCONTINUED OPERATIONS (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Mar. 31, 2014

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production, Inc.

Eagle Ford Hunter, Inc.

Results reclassified to discontinued operations

'

'

'

'

'

'

'

'

'

'

Revenues

$0

$7,943,000

$8,533,000

$62,429,000

'

'

'

'

'

'

Expenses

0

-93,755,000

-3,976,000

-128,464,000

'

'

'

'

'

'

Other income

0

59,000

4,000

81,000

'

'

'

'

'

'

Income tax benefit

0

10,180,000

0

3,501,000

'

'

'

'

'

'

Income (loss) from discontinued operations, net of tax

0

-75,573,000

4,561,000

-62,453,000

'

'

'

'

'

'

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

-258,000

-69,521,000

-13,983,000

102,931,000

'

-12,800,000

'

'

-84,500,000

172,500,000

Income (loss) from discontinued operations, net of taxes

-258,000

[1]

-145,094,000

-9,422,000

[1]

40,478,000

'

'

'

'

'

'

Impairment expense from discontinued operations

'

'

'

'

18,600,000

'

67,600,000

18,500,000

'

'

Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.

$0

$0

$20,741,000

$0

'

($20,700,000)

'

'

'

'

[1]

Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.

DIVESTITURES_AND_DISCONTINUED_3

DIVESTITURES AND DISCONTINUED OPERATIONS (Sale of Eagle Ford Hunter) (Details) (USD $)	1 Months Ended	3 Months Ended		9 Months Ended
	Apr. 24, 2013	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Jun. 30, 2014
Discontinued operations	'	'	'	'	'	'
Gain (loss) on disposal of discontinued operations, net of tax	'	($258,000)	($69,521,000)	($13,983,000)	$102,931,000	'
Eagle Ford Hunter, Inc.	'	'	'	'	'	'
Discontinued operations	'	'	'	'	'	'
Total consideration received	422,100,000	'	'	'	'	'
Cash consideration received	379,800,000	'	'	'	'	'
Gain (loss) on disposal of discontinued operations, net of tax	'	'	'	172,500,000	'	'
Liabilities of disposal group	'	'	'	'	'	33,700,000
Accrued liabilities of disposal group	'	'	'	'	'	1,300,000
Amount of adjustment to prior period gain (loss) on disposal	'	-300,000	-13,900,000	-7,300,000	0	'
Penn Virginia [Member] | Eagle Ford Hunter, Inc.	'	'	'	'	'	'
Discontinued operations	'	'	'	'	'	'
Consideration received, number of shares of common stock received	10,000,000	'	'	'	'	'
Consideration received, value of common stock received	$42,300,000	'	'	'	'	'
Price per share	$4.23	'	'	'	'	'

DIVESTITURES_AND_DISCONTINUED_4

DIVESTITURES AND DISCONTINUED OPERATIONS (Assets and Liabilities Held for Sale) (Details)

3 Months Ended

9 Months Ended

0 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Apr. 10, 2014

Apr. 10, 2014

12-May-14

12-May-14

Sep. 30, 2014

Mar. 31, 2014

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Mar. 01, 2014

Sep. 30, 2014

Dec. 31, 2013

Apr. 24, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 17, 2014

Sep. 23, 2014

Sep. 30, 2014

Sep. 30, 2014

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Williston Hunter Canada Assets

Williston Hunter Canada Assets

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

MHP and WHI Canada

MHP and WHI Canada

Eagle Ford Hunter, Inc.

Eagle Ford Hunter, Inc.

Eagle Ford Hunter, Inc.

Eagle Ford Hunter, Inc.

Eagle Ford Hunter, Inc.

Divide County, North Dakota

Divide County, North Dakota

Roane Counties, West Virginia

Unproved Oil And Natural Gas Properties [Member]

Proved Oil and Natural Gas Properties [Member]

USD ($)

CAD

USD ($)

CAD

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

CAD

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Non-Operated Working Interests In Oil And Gas Properties [Member]

Non-Operated Working Interests In Oil And Gas Properties [Member]

Non-Core Working Interests In Oil And Gas Properties [Member]

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Assets and Liabilities Held for Sale [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounts receivable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

$4,362,000

'

'

'

'

'

'

'

'

'

'

Other current assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

1,004,000

'

'

'

'

'

'

'

'

'

'

Oil and natural gas properties, net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

86,362,000

150,770,000

'

'

'

'

'

'

'

'

'

'

Gas transportation, gathering, and processing equipment and other, net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

11,721,000

'

'

'

'

'

'

'

'

'

'

Other long-term assets

86,362,000

'

86,362,000

'

162,687,000

'

'

'

'

'

'

'

'

'

'

0

196,000

'

'

'

'

'

'

'

'

'

'

Total assets held for sale

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

86,362,000

168,053,000

'

'

'

'

'

'

'

'

'

'

Accounts payable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

7,292,000

'

'

'

'

'

'

'

'

'

'

Accrued liabilities and other liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

5,573,000

'

'

'

'

'

'

'

'

'

'

Asset retirement obligations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,619,000

8,678,000

'

'

'

'

'

'

'

'

'

'

Other long-term liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

5,845,000

'

'

'

'

'

'

'

'

'

'

Total liabilities held for sale

0

'

0

'

12,865,000

'

'

'

'

'

'

'

'

'

'

1,619,000

27,388,000

'

'

'

'

'

'

'

'

'

'

Impairment expense from discontinued operations

'

'

'

'

'

'

'

'

'

'

18,600,000

'

67,600,000

18,500,000

'

'

'

'

'

'

'

'

'

'

'

1,900,000

17,000,000

Depreciation

'

'

'

'

'

'

'

'

'

1,700,000

'

1,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash consideration on sale of certain oil and gas properties and assets

'

'

'

'

'

8,700,000

9,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

-258,000

-69,521,000

-13,983,000

102,931,000

'

6,100,000

'

'

'

'

'

-12,800,000

'

'

'

'

'

'

'

'

172,500,000

'

8,200,000

'

'

'

'

Cash consideration received

'

'

'

'

'

'

'

68,800,000

75,000,000

'

'

'

'

'

'

'

'

379,800,000

'

'

'

'

23,500,000

84,800,000

1,200,000

'

'

Cash In escrow

'

'

'

'

'

'

'

'

'

'

'

'

'

'

18,400,000

'

'

'

'

'

'

'

'

'

'

'

'

Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.

0

0

-20,741,000

0

'

'

'

'

'

'

'

20,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

($300,000)

($13,900,000)

($7,300,000)

$0

'

'

'

'

'

DIVESTITURES_AND_DISCONTINUED_5

DIVESTITURES AND DISCONTINUED OPERATIONS (Sale of Certain Eagle Ford Shale Assets) (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Jan. 28, 2014	Jan. 28, 2014	Jan. 28, 2014	Jan. 28, 2014	Sep. 30, 2014
			Eagle Ford Shale Assets [Member]	Leasehold Acreage, Atascosa County, Texas [Member]	New Standard Energy Texas LLC [Member]	MHR Senior Revolving Credit Facility	Investments [Member]
				Eagle Ford Shale Assets [Member]	Eagle Ford Shale Assets [Member]	Eagle Ford Shale Assets [Member]	New Standard Energy Texas LLC [Member]
				Well			Eagle Ford Shale Assets [Member]
Discontinued operations	'	'	'	'	'	'	'
Number of horizontal oil and gas wells	'	'	'	5	'	'	'
Number of horizontal oil and gas wells operated by Magnum Hunter Resources	'	'	'	4	'	'	'
Cash consideration received	'	'	$15,500,000	'	'	'	'
Consideration received, number of shares of common stock received	'	'	'	'	65,650,000	'	'
Consideration received, value of common stock received	'	'	'	'	9,400,000	'	'
Price per share	'	'	'	'	$0.14	'	'
Investment holding of total shares outstanding as a percent	'	'	'	'	17.00%	'	'
Available for sale securities	8,076,000	1,819,000	'	'	'	'	5,700,000
Loss on the sale of assets	'	'	4,500,000	'	'	'	'
Reduction in borrowing base	'	'	'	'	'	$10,000,000	'

OIL_NATURAL_GAS_SALES_Details

OIL & NATURAL GAS SALES (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Oil and Gas In Process Activities [Line Items]	'	'	'	'
Oil and Gas Sales Revenue	$62,510	$59,061	$222,247	$156,772
Oil	'	'	'	'
Oil and Gas In Process Activities [Line Items]	'	'	'	'
Oil and Gas Sales Revenue	34,495	40,471	111,354	103,545
Natural Gas	'	'	'	'
Oil and Gas In Process Activities [Line Items]	'	'	'	'
Oil and Gas Sales Revenue	18,247	12,417	74,031	41,145
NGL	'	'	'	'
Oil and Gas In Process Activities [Line Items]	'	'	'	'
Oil and Gas Sales Revenue	$9,768	$6,173	$36,862	$12,082

PROPERTY_PLANT_EQUIPMENT_Ormet

PROPERTY, PLANT, & EQUIPMENT Ormet Asset Purchase Agreement (Details) (Ormet Asset Purchase Agreement, USD $)	0 Months Ended				0 Months Ended
In Millions, unless otherwise specified	Jul. 24, 2014	Jun. 18, 2014	Jun. 18, 2014	Jun. 18, 2014	Jun. 17, 2014
		acre	Monroe County, Ohio	Wetzerl County, West Virginia	Marcellus Zone
			acre	acre
Business Acquisition [Line Items]	'	'	'	'	'
Acreage in which mineral interests are acquired	'	2,000	1,375	325	'
Leasehold rights royalty carried on production, percentage	'	'	'	'	12.50%
Purchase price to acquire mineral rights	$22.70	'	'	'	'

PROPERTY_PLANT_EQUIPMENT_Detai

PROPERTY, PLANT, & EQUIPMENT (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Mineral interests in properties:	'	'	'	'	'
Unproved mineral rights and leasehold costs	$510,296,000	'	$510,296,000	'	$469,337,000
Proved mineral rights and leasehold costs	282,150,000	'	282,150,000	'	336,357,000
Wells and related equipment and facilities	735,947,000	'	735,947,000	'	536,023,000
Advances to operators for wells in progress	2,508,000	'	2,508,000	'	13,571,000
Total costs	1,530,901,000	'	1,530,901,000	'	1,355,288,000
Less accumulated depreciation	-208,495,000	'	-208,495,000	'	-130,629,000
Net capitalized costs	1,322,406,000	'	1,322,406,000	'	1,224,659,000
Impairment of proved oil and gas properties	'	'	39,798,000	88,504,000	'
Proved Oil and Natural Gas Properties [Member]	'	'	'	'	'
Mineral interests in properties:	'	'	'	'	'
Depreciation, depletion and amortization	28,000,000	23,600,000	81,900,000	58,000,000	'
Impairment of proved oil and gas properties	22,900,000	23,500,000	39,800,000	39,500,000	'
Fair value disclosure, oil and gas properties write-down	17,100,000	16,400,000	33,800,000	16,400,000	'
Gas transportation, gathering and processing equipment and other	'	'	'	'	'
Mineral interests in properties:	'	'	'	'	'
Total costs	516,258,000	'	516,258,000	'	315,642,000
Less accumulated depreciation	-47,350,000	'	-47,350,000	'	-26,222,000
Net capitalized costs	468,908,000	'	468,908,000	'	289,420,000
Depreciation, depletion and amortization	$6,500,000	$4,300,000	$16,100,000	$11,100,000	'

PROPERTY_PLANT_EQUIPMENT_Explo

PROPERTY, PLANT, & EQUIPMENT (Exploration) (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Property, Plant and Equipment [Line Items]	'	'	'	'
Leasehold impairments	$26,922	$41,624	$51,305	$74,249
Geological and geophysical	362	354	1,089	1,008
Total exploration expense	27,284	41,978	52,394	75,257
Williston Basin [Member]	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'
Leasehold impairments	17,800	38,800	37,800	71,500
Appalachian Basin [Member]	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'
Leasehold impairments	'	'	13,500	'
Magnum Hunter Production, Inc.	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'
Leasehold impairments	$1,900	$1,900	$3,800	$1,900

PROPERTY_PLANT_EQUIPMENT_Capit

PROPERTY, PLANT, & EQUIPMENT (Capitalized costs of oil and gas properties) (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Capitalized costs, gross	$1,530,901,000	'	$1,530,901,000	'	$1,355,288,000
Less accumulated depreciation	-208,495,000	'	-208,495,000	'	-130,629,000
Net capitalized costs	1,322,406,000	'	1,322,406,000	'	1,224,659,000
Gas transportation, gathering and processing equipment and other	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Capitalized costs, gross	516,258,000	'	516,258,000	'	315,642,000
Less accumulated depreciation	-47,350,000	'	-47,350,000	'	-26,222,000
Net capitalized costs	468,908,000	'	468,908,000	'	289,420,000
Depreciation, depletion and amortization	6,500,000	4,300,000	16,100,000	11,100,000	'
Assets Held under Capital Leases [Member]	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
PP&E Useful life (in years)	'	'	'3 years	'	'
Capital Leases, Net Investment in Direct Financing and Sales Type Leases	12,800,000	'	12,800,000	'	'
Capital Leases, Future Minimum Payments Due, Next Twelve Months	2,900,000	'	2,900,000	'	'
Capital Leases Future Minimum Payments Due After Next Twelve Months	500,000	'	500,000	'	'
Farley Pad And Farley 1305 H	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Costs incurred	'	'	1,100,000	'	'
Farley 1305 H	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Costs incurred	'	'	13,800,000	'	'
Magnum Hunter Production and Williston Hunter Canada	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Depreciation	$1,700,000	'	$1,700,000	'	'

INTANGIBLE_ASSETS_Details

INTANGIBLE ASSETS (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]	'	'	'	'	'
Intangible assets	$10,492	'	$10,492	'	$10,492
Less: accumulated amortization	-5,467	'	-5,467	'	-3,962
Intangible assets, net of accumulated amortization	5,025	'	5,025	'	6,530
Amortization of intangible assets	502	569	1,500	1,900	'
Customer relationships	'	'	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'	'	'
Intangible assets	5,434	'	5,434	'	5,434
Trademark	'	'	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'	'	'
Intangible assets	859	'	859	'	859
Existing contracts	'	'	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'	'	'
Intangible assets	$4,199	'	$4,199	'	$4,199

INVENTORY_Details

INVENTORY (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Materials and supplies	$2,228	$6,790
Commodities	811	368
Inventory	$3,039	$7,158

ASSET_RETIREMENT_OBLIGATIONS_D

ASSET RETIREMENT OBLIGATIONS (Details) (USD $)	9 Months Ended		12 Months Ended
	Sep. 30, 2014		Dec. 31, 2013
Summary of asset retirement obligation	'		'
Asset retirement obligation at beginning of period	$16,216,000		$30,680,000
Assumed in acquisitions	0		17,000
Liabilities incurred	218,000		253,000
Liabilities settled	-26,000		-98,000
Liabilities sold	-596,000		-7,614,000
Accretion expense	1,731,000		2,264,000
Revisions in estimated liabilities	2,625,000	[1]	1,935,000	[1]
Reclassified as liabilities associated with assets held for sale	-1,619,000		-11,148,000
Reclassified from liabilities associated with assets held for sale	8,109,000		0
Effect of foreign currency translation	0		-73,000
Asset retirement obligation at end of period	26,658,000		16,216,000
Less: current portion (included in other liabilities)	-1,482,000		-53,000
Asset retirement obligation at end of period	25,176,000		16,163,000
Revision of estimate due to change in assumptions	$1,500,000		'
[1]	Revisions in estimated liabilities during 2014 relate to a change in assumptions used with respect to certain wells in the Appalachian Basin in Ohio and West Virginia. Approximately $1.5 million of the revisions in estimated liabilities during 2013 is related to a change in assumptions used with respect to certain wells in the Williston Basin in North Dakota.

FAIR_VALUE_OF_FINANCIAL_INSTRU2

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

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Maximum

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

Recurring

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)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

24.00%

Total enterprise value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$929,700,000

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years 4 months 24 days

'

'

'

'2 years

Risk-free interest rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.03%

'

'

'

'

Estimated volatility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40.00%

'

'

'

13.70%

Dividend

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.00%

'

'

'

'

GreenHunter stock price at end of period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1.52

'

'

'

'

Fair value measurements on a Recurring Basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available for sale securities

8,076,000

1,819,000

8,076,000

1,819,000

'

'

'

'

'

'

0

0

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

Derivative assets

'

'

'

'

0

0

0

0

'

'

'

'

2,127,000

554,000

0

0

'

'

'

'

0

0

83,000

79,000

'

'

'

Total assets at fair value

'

'

8,076,000

1,819,000

'

'

'

'

'

'

2,127,000

554,000

'

'

'

'

'

'

83,000

79,000

'

'

'

'

'

'

'

Derivative liabilities

'

'

'

'

0

0

'

'

0

0

'

'

114,000

2,279,000

'

'

0

0

'

'

0

0

'

'

173,205,000

75,934,000

'

Total liabilities at fair value

'

'

$0

$0

'

'

'

'

'

'

$114,000

$2,279,000

'

'

'

'

'

'

$173,205,000

$75,934,000

'

'

'

'

'

'

'

FAIR_VALUE_OF_FINANCIAL_INSTRU3

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 2) (Level 3, USD $)	9 Months Ended			9 Months Ended	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014
	Preferred Stock Embedded Derivative Liability	Embedded Derivatives, Assets	Recurring	Recurring	Minimum	Maximum	Eureka Hunter Holdings, LLC	Eureka Hunter Holdings, LLC
	Embedded Derivatives, Liabilities	Convertible Security Embedded Derivative Financial Instruments [Member]	Preferred Stock Embedded Derivative Liability	Convertible Security Embedded Derivative Financial Instruments [Member]	Recurring	Recurring	Minimum	Maximum
					Preferred Stock Embedded Derivative Liability	Preferred Stock Embedded Derivative Liability	Recurring	Recurring
							Preferred Stock Embedded Derivative Liability	Preferred Stock Embedded Derivative Liability
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'	'	'	'	'	'	'
Expected term	'	'	'	'2 years 4 months 24 days	'1 year	'2 years	'0 years	'6 years
Estimated volatility	'	'	'	40.00%	'	13.70%	'	'
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'	'	'	'	'	'	'	'
31-Dec-13	($75,934,000)	'	'	'	'	'	'	'
Issuance of derivative liability	-5,479,000	'	'	'	'	'	'	'
Decrease in fair value recognized in other income (expense)	-91,792,000	'	'	'	'	'	'	'
30-Sep-14	-173,205,000	'	'	'	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'	'	'	'	'	'	'	'
Fair value at December 31, 2013 Convertible Security Embedded Derivative Asset	'	79,000	'	'	'	'	'	'
Issuance of derivative liability Convertible Security Embedded Derivative Asset	'	0	'	'	'	'	'	'
Decrease in fair value recognized in other (expense) Convertible Security Embedded Derivative Asset	'	4,000	'	'	'	'	'	'
Fair value as of June 30, 2014 Convertible Security Embedded Derivative Asset	'	83,000	'	'	'	'	'	'
Fair Value Assumptions Credit Spread Rate	'	'	'	'	'	24.00%	'	'
Business Acquisition, Cost of Acquired Entity, Total Enterprise Value	'	'	$929,700,000	'	'	'	'	$1,000,000,000

FAIR_VALUE_OF_FINANCIAL_INSTRU4

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 4) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Level 2 | Carrying Amount | Senior Notes	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	$597,313	$597,230
Level 2 | Estimated Fair Value | Senior Notes	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	639,000	651,300
Level 3 | Carrying Amount | MHR Senior Revolving Credit Facility	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	256,000	218,000
Level 3 | Carrying Amount | Eureka Hunter Pipeline second lien term loan	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	0	50,000
Level 3 | Carrying Amount | Eureka Hunter Pipeline Credit Agreement	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	80,000	0
Level 3 | Carrying Amount | Equipment Notes Payable	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	25,149	18,615
Level 3 | Estimated Fair Value | MHR Senior Revolving Credit Facility	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	256,000	218,000
Level 3 | Estimated Fair Value | Eureka Hunter Pipeline second lien term loan	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	0	58,921
Level 3 | Estimated Fair Value | Eureka Hunter Pipeline Credit Agreement	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	80,000	0
Level 3 | Estimated Fair Value | Equipment Notes Payable	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	$25,170	$17,676

FINANCIAL_INSTRUMENTS_AND_DERI2

FINANCIAL INSTRUMENTS AND DERIVATIVES INVESTMENTS BY TYPE (Details) (USD $)	9 Months Ended
	Sep. 30, 2014
Schedule of Available-for-sale Securities [Line Items]	'
Available-for-sale Securities, beginning of period	$1,819,000
Securities received as consideration for assets sold	9,447,000
Change in fair value recognized in other comprehensive loss	-3,190,000
Available-for-sale Securities, end of period	8,076,000
Current available-for-sale securities	8,076,000
Equity Method Investments, end of period	940,000	[1]
Equity in net loss recognized in other income (expense)	-504,000	[1]
Equity Method Investments, end of period	436,000	[1]
Equity Method Investments, Noncurrent	282,000
Long Term Assets [Member]	'
Schedule of Available-for-sale Securities [Line Items]	'
Equity Method Investments, Noncurrent	$282,000
[1]	Equity method investments includes $282,000 classified as long-term other assets.

FINANCIAL_INSTRUMENTS_AND_DERI3

FINANCIAL INSTRUMENTS AND DERIVATIVES INVESTMENTS BY BALANCE SHEET LOCATION (Details) (USD $)	Sep. 30, 2014		Dec. 31, 2013
Schedule of Available-for-sale Securities [Line Items]	'		'
Available-for-sale Securities, Current	$8,076,000		'
Equity Method Investments, Current	154,000		'
Investments, Available-for-sale and Equity Method, Current	8,230,000		'
Available-for-sale Securities, Noncurrent	0		'
Equity Method Investments, Noncurrent	282,000		'
Investments, Available-for-sale and Equity Method, Noncurrent	282,000		'
Available-for-sale Securities	8,076,000		1,819,000
Equity Method Investments	436,000	[1]	940,000	[1]
Investments, Available-for-sale and Equity Method, Current and Noncurrent	8,512,000		'
Long Term Assets [Member]	'		'
Schedule of Available-for-sale Securities [Line Items]	'		'
Equity Method Investments, Noncurrent	$282,000		'
[1]	Equity method investments includes $282,000 classified as long-term other assets.

FINANCIAL_INSTRUMENTS_AND_DERI4

FINANCIAL INSTRUMENTS AND DERIVATIVES INVESTMENTS, FAIR VALUE (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Investments, Debt and Equity Securities [Abstract]	'	'
Equity Securities, Amortized Cost	$9,875	$428
Equity Securities, Gross Unrealized Gain	0	0
Equity Securities, Gross Unrealized Loss	-4,030	-281
Equity Securities	5,845	147
Equity Securities, Related Party, Amortized Cost Basis	2,200	2,200
Equity Securities, Related Party, Gross Unrealized Gain	0	0
Equity Securities, Related Party, Gross Unrealized Loss	31	-528
Equity Securities, Related Party	2,231	1,672
Equity Securities, Including Related Party, Amortized Cost Basis	12,075	2,628
Equity Securities, Including Related Party, Gross Unrealized Gain	0	0
Equity Securities, Including Related Party, Gross Unrealized Loss	-3,999	-809
Equity Securities, Including Related Party	$8,076	$1,819

FINANCIAL_INSTRUMENT_AND_DERIV

FINANCIAL INSTRUMENT AND DERIVATIVES (Commodity Derivatives) (Details)	9 Months Ended
	Sep. 30, 2014
	MMBTU
Natural Gas | Oct 2014- Dec 2014 | Collars [Member]	'
Derivative [Line Items]	'
MMBtu/day	15,000	[1]
Natural Gas | Oct 2014- Dec 2014 | Swap [Member]	'
Derivative [Line Items]	'
MMBtu/day	41,000
Weighted Average Price	4.18
Natural Gas | Oct 2014- Dec 2014 | Call Option [Member]	'
Derivative [Line Items]	'
MMBtu/day	16,000
Weighted Average Price	5.91
Natural Gas | Jan 2015 - Dec 2015 | Swap [Member]	'
Derivative [Line Items]	'
MMBtu/day	30,000
Weighted Average Price	4.12
Crude Oil [Member] | Oct 2014- Dec 2014 | Collars [Member]	'
Derivative [Line Items]	'
Bbl/day	663	[1]
Crude Oil [Member] | Oct 2014- Dec 2014 | Three Way Collars [Member]	'
Derivative [Line Items]	'
Bbl/day	4,000	[2]
Weighted Average Price	85	[2]
Crude Oil [Member] | Oct 2014- Dec 2014 | Put Option [Member]	'
Derivative [Line Items]	'
Bbl/day	663
Weighted Average Price	65
Crude Oil [Member] | Jan 2015 - Dec 2015 | Collars [Member]	'
Derivative [Line Items]	'
Bbl/day	259
Crude Oil [Member] | Jan 2015 - Dec 2015 | Call Option [Member]	'
Derivative [Line Items]	'
Bbl/day	1,570
Weighted Average Price	120
Crude Oil [Member] | Jan 2015 - Dec 2015 | Put Option [Member]	'
Derivative [Line Items]	'
Bbl/day	259
Weighted Average Price	70
Maximum | Natural Gas | Oct 2014- Dec 2014 | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	5.23	[1]
Maximum | Crude Oil [Member] | Oct 2014- Dec 2014 | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	91.25	[1]
Maximum | Crude Oil [Member] | Oct 2014- Dec 2014 | Three Way Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	102.5	[2]
Maximum | Crude Oil [Member] | Jan 2015 - Dec 2015 | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	91.25	[1]
Minimum | Natural Gas | Oct 2014- Dec 2014 | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	4.27	[1]
Minimum | Crude Oil [Member] | Oct 2014- Dec 2014 | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	85	[1]
Minimum | Crude Oil [Member] | Oct 2014- Dec 2014 | Three Way Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	64.94	[2]
Minimum | Crude Oil [Member] | Jan 2015 - Dec 2015 | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	85	[1]
[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.

FINANCIAL_INSTRUMENTS_AND_DERI5

FINANCIAL INSTRUMENTS AND DERIVATIVES (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value	'	'
Derivative Assets	$2,209	$633
Derivative Liabilities	-173,319	-78,213
Commodity	'	'
Derivatives, Fair Value	'	'
Derivative Assets	2,126	554
Derivative Liabilities	-114	-2,279
Financial	'	'
Derivatives, Fair Value	'	'
Derivative Assets	83	79
Derivative Liabilities	-173,205	-75,934
Derivative assets | Commodity	'	'
Derivatives, Fair Value	'	'
Derivative Assets	1,871	529
Derivative assets | Financial	'	'
Derivatives, Fair Value	'	'
Derivative Assets	83	79
Derivative assets - long-term | Commodity	'	'
Derivatives, Fair Value	'	'
Derivative Assets	255	25
Derivative liabilities | Commodity	'	'
Derivatives, Fair Value	'	'
Derivative Liabilities	-48	-1,903
Derivative liabilities - long-term | Commodity	'	'
Derivatives, Fair Value	'	'
Derivative Liabilities	-66	-376
Derivative liabilities - long-term | Financial	'	'
Derivatives, Fair Value	'	'
Derivative Liabilities	($173,205)	($75,934)

FINANCIAL_INSTRUMENTS_AND_DERI6

FINANCIAL INSTRUMENTS AND DERIVATIVES (Effect of Master Netting) (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative [Line Items]	'	'
Derivative Assets	$2,209	$633
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	2,012	-1,725
Derivative, Fair Value, Amount Offset Against Collateral, Net	0	0
Derivative, Fair Value, Net	2,012	-1,725
Current Assets [Member]	'	'
Derivative [Line Items]	'	'
Derivative Assets	2,399	4,034
Derivative Asset, Fair Value, Amount Offset Against Collateral	-528	-3,505
Derivative assets	1,871	529
Long Term Assets [Member]	'	'
Derivative [Line Items]	'	'
Derivative Assets	377	516
Derivative Asset, Fair Value, Amount Offset Against Collateral	-122	-491
Derivative assets	255	25
Current Liabilities [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-576	-5,408
Derivative Liability, Fair Value, Amount Offset Against Collateral	528	3,505
Derivative Liability	-48	-1,903
Long-term Liabilities [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-188	-867
Derivative Liability, Fair Value, Amount Offset Against Collateral	122	491
Derivative Liability	($66)	($376)

FINANCIAL_INSTRUMENTS_AND_DERI7

FINANCIAL INSTRUMENTS AND DERIVATIVES (Details 3) (Commodity derivative assets, Other Income (Expense) [Member], USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Summary of net gain (loss) on derivative contracts	'	'	'	'
Gain (loss) on derivative contracts	($49,636)	($29,553)	($92,125)	($30,644)
Settled Transaction [Member]	'	'	'	'
Summary of net gain (loss) on derivative contracts	'	'	'	'
Gain (loss) on derivative contracts	477	-6,582	-4,074	-6,887
Open Transaction [Member]	'	'	'	'
Summary of net gain (loss) on derivative contracts	'	'	'	'
Gain (loss) on derivative contracts	($50,113)	($22,971)	($88,051)	($23,757)

DEBT_Details

DEBT (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2012

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Mar. 28, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Senior Notes

Senior Notes

Notes Payable, Other Payables [Member]

Notes Payable, Other Payables [Member]

Notes Payable, Other Payables [Member]

Notes Payable, Other Payables [Member]

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Term Loan

Term Loan

Term Loan

Term Loan

Term Loan

9.75 Percent Senior Notes Due May 15, 2020 [Member]

9.75 Percent Senior Notes Due May 15, 2020 [Member]

Notes Payable Due January 2015 - April 2021 [Member]

Notes Payable Due January 2015 - April 2021 [Member]

Notes Payable Due January 2015 - April 2021 [Member]

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

2.96 and 3.56 Percent Revolving Credit Facility due April 2016 and December 2013 [Member]

2.96 and 3.56 Percent Revolving Credit Facility due April 2016 and December 2013 [Member]

Eureka Hunter Pipeline, LLC

Eureka Hunter Pipeline, LLC

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt, outstanding

$958,462,000

$883,845,000

$597,313,000

$597,230,000

'

$25,149,000

[1]

'

$18,615,000

[1]

$80,000,000

$0

$256,000,000

$218,000,000

$0

$50,000,000

$50,000,000

'

'

Less: current portion

-8,670,000

-3,967,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt obligations, net of current portion

949,792,000

879,878,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liabilities associated with assets held for sale

'

'

'

'

200,000

'

'

'

'

'

'

'

'

'

'

'

'

Long-term liabilities associated with assets held for sale

1,619,000

14,523,000

'

'

3,800,000

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt, stated interest rate

'

'

9.75%

9.75%

'

'

'

'

3.66%

3.66%

3.57%

3.56%

'

'

'

12.50%

12.50%

Long-term debt, unamortized discount

'

'

$2,700,000

$2,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt, stated interest rate, minimum

'

'

'

'

'

4.25%

4.25%

'

'

'

'

'

'

'

'

'

'

Long-term debt, stated interest rate, maximum

'

'

'

'

'

7.94%

7.94%

'

'

'

'

'

'

'

'

'

'

[1]

Balance as of December 31, 2013 includes notes classified as liabilities associated with assets held for sale of which $0.2 million is current and $3.8 million is long-term.

DEBT_Expected_Annual_Maturitie

DEBT (Expected Annual Maturities of Debt) (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
Summary of approximate annual maturities of debt	'	'
2014	$2,565,000	'
2015	7,717,000	'
2016	264,727,000	'
2017	2,548,000	'
2018	80,559,000	'
Thereafter	603,032,000	'
Total long-term debt, outstanding	961,148,000	'
Senior Notes | 9.75 Percent Senior Notes Due May 15, 2020 [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term debt, unamortized discount	$2,700,000	$2,700,000

DEBT_MHR_Senior_Revolving_Cred

DEBT (MHR Senior Revolving Credit Facility) (Details) (USD $)

0 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

6-May-14

Dec. 31, 2013

31-May-14

Sep. 30, 2014

Dec. 31, 2013

6-May-14

Dec. 31, 2013

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

31-May-14

Sep. 30, 2014

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Letter of Credit

Letter of Credit

Period On or Before July 1, 2014 [Member]

Period July 1, 2014 [Member]

Line of Credit

Fiscal Quarters Ending June 30, 2014 and September 30, 2014 [Member]

Line of Credit

Fiscal Quarter Ending December 31, 2014

Fiscal Quarter Ending March 31, 2015 and Each Quarter Thereafter [Member]

Alternate Base Rate

Eurodollar [Member]

Minimum

Minimum

Minimum

Minimum

Maximum

Maximum

Maximum

Maximum

Wilson Hunter Canada, Inc. [Member]

Certain North Dakota Oil and Gas Properties [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

MHR Senior Revolving Credit Facility

MHR Senior Revolving Credit Facility

MHR Senior Revolving Credit Facility

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Line of Credit

Line of Credit

Amendment to Third Amended and Restated Credit Agreement [Member]

Line of Credit

Amendment to Third Amended and Restated Credit Agreement [Member]

Line of Credit

Line of Credit

Period May 6, 2014 Through July 1, 2014 [Member]

Period May 6, 2014 Through July 1, 2014 [Member]

Alternate Base Rate

Alternate Base Rate

Eurodollar [Member]

Eurodollar [Member]

Alternate Base Rate

Alternate Base Rate

Eurodollar [Member]

Eurodollar [Member]

Line of Credit

Line of Credit

MHR Senior Revolving Credit Facility [Member]

MHR Senior Revolving Credit Facility [Member]

MHR Senior Revolving Credit Facility [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Line of Credit

Line of Credit

Period From July 1, 2014 Through Date of Delivery of Compliance Certificate for Quarter Ending June 30, 2014 [Member]

Period From Delivery of Compliance Certificate and After [Member]

Period From July 1, 2014 Through Date of Delivery of Compliance Certificate for Quarter Ending June 30, 2014 [Member]

Period From Delivery of Compliance Certificate and After [Member]

Period From July 1, 2014 Through Date of Delivery of Compliance Certificate for Quarter Ending June 30, 2014 [Member]

Period From Delivery of Compliance Certificate and After [Member]

Period From July 1, 2014 Through Date of Delivery of Compliance Certificate for Quarter Ending June 30, 2014 [Member]

Period From Delivery of Compliance Certificate and After [Member]

MHR Senior Revolving Credit Facility

MHR Senior Revolving Credit Facility

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

MHR Senior Revolving Credit Facility [Member]

MHR Senior Revolving Credit Facility [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base

$325,000,000

$232,500,000

'

'

'

$50,000,000

$10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liens percentage used in reserve reports for borrowing base determinations

90.00%

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred finance costs, gross

'

3,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base

'

'

'

265,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility amount outstanding

'

'

'

256,000,000

218,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reduction in the borrowing base

'

'

25,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

27,500,000

7,500,000

Borrowing capacity limit increase

750,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reduction of borrowing base

'

'

'

'

'

'

'

25,000,000

25,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reduction of borrowing base for each dollar of additional senior notes

'

'

'

'

'

'

'

'

$0.25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reduction of borrowing base, percent of net proceeds from issuance of common equity

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, basis spread on variable rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.75%

3.75%

1.50%

1.00%

2.50%

2.00%

2.25%

1.75%

3.25%

2.75%

'

'

Required minimum consolidated Current Ratio

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

EBITDAX to interest expense

'

'

'

'

'

'

'

'

'

200.00%

225.00%

250.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Required maximum ratio of Total Debt to EBITDAX

'

'

'

'

'

'

'

'

'

'

4.75

'

4.5

4.25

'

'

'

'

'

'

'

'

'

'

'

'

DEBT_Eureka_Hunter_Pipeline_Cr

DEBT (Eureka Hunter Pipeline Credit Agreement) (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Mar. 28, 2014

Dec. 31, 2013

Jan. 21, 2014

Sep. 30, 2014

Mar. 28, 2014

Sep. 30, 2014

Dec. 31, 2013

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Term Loan

Term Loan

Term Loan

Notes Payable, Other Payables [Member]

Notes Payable, Other Payables [Member]

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Minimum

Minimum

Maximum

Maximum

Revolving Credit Facility

Fiscal Quarter Ending March 31, 2014 Through September 30, 2014 [Member]

Commitment Fee Percent When Consolidated Leverage Ratio is Less Than 3 to 1 [Member]

Commitment Fee Percent When Consolidated Leverage Ratio is Greater or Equal to 3 to 1 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

7.94 Percent Equipment Note Payable [Member]

4.875% Building Note Payable [Member]

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Line of Credit

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

Line of Credit

Line of Credit

Line of Credit

Line of Credit

5.75 Percent Credit Agreement due March 28, 2018 [Member]

Line of Credit

Line of Credit

Line of Credit

Eurodollar [Member]

Federal Funds Rate

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

Eurodollar [Member]

Base Rate [Member]

Eurodollar [Member]

Base Rate [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base

'

'

'

'

'

'

'

$117,000,000

$90,200,000

'

'

'

'

'

'

'

'

'

'

'

Borrowing capacity limit increase

'

'

'

'

'

'

'

150,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Deferred finance costs

'

'

'

'

'

'

'

1,200,000

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt

958,462,000

883,845,000

0

50,000,000

50,000,000

'

'

'

80,000,000

0

'

'

'

'

'

'

'

'

'

'

Line of credit facility, commitment fee percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.38%

0.50%

Consolidated leverage ratio

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, basis spread on variable rate

'

'

'

'

'

'

'

'

'

'

1.00%

0.50%

2.00%

1.00%

3.50%

2.50%

'

'

'

'

Interest rate increase under default

'

'

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

Maximum leverage ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4.5

4.75

'

'

Minimum interest coverage ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.5

2.75

'

'

Credit facility amount outstanding

'

'

'

'

'

'

'

'

-80,000,000

'

'

'

'

'

'

'

'

'

'

'

Prepayment penalty

'

'

2,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued interest

'

'

'

1,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Face amount

'

'

'

'

'

$5,600,000

$3,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt, stated interest rate

'

'

'

'

'

7.94%

4.88%

'

3.66%

3.66%

'

'

'

'

'

'

'

'

'

'

Term of note payable

'

'

'

'

'

'48 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

DEBT_Interest_Expense_Details

DEBT (Interest Expense) (Details) (USD $)	3 Months Ended		9 Months Ended				3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014	Mar. 31, 2013	Sep. 30, 2014	Sep. 30, 2013
					Amendment to Third Amended and Restated Credit Agreement [Member]	Term Loan	Oil and Gas Properties [Member]	Oil and Gas Properties [Member]	Oil and Gas Properties [Member]	Oil and Gas Properties [Member]
						12.5 Percent Term Loan due August 16, 2018 [Member]
Debt Instrument [Line Items]	'	'	'	'	'	'	'	'	'	'
Interest costs capitalized	'	'	'	'	'	'	$723,000	$582,000	$1,600,000	$2,000,000
Prepayment penalty	'	'	'	'	'	2,200,000	'	'	'	'
Write off of unamortized deferred financing costs	'	'	2,700,000	'	1,700,000	'	'	'	'	'
Interest expense incurred on debt, net of amounts capitalized	17,013,000	14,648,000	53,748,000	49,691,000	'	'	'	'	'	'
Amortization and write-off of deferred financing costs	1,082,000	1,111,000	8,725,000	3,661,000	'	'	'	'	'	'
Total interest expense	$18,095,000	$15,759,000	$62,473,000	$53,352,000	'	'	'	'	'	'

SHAREBASED_COMPENSATION_Detail

SHARE-BASED COMPENSATION (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

0 Months Ended

In Thousands, except Share data, unless otherwise specified

Sep. 30, 2013

Jun. 30, 2012

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2011

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

12-May-14

12-May-14

12-May-14

12-May-14

Stock options and stock appreciation rights

Stock options and stock appreciation rights

Stock options and stock appreciation rights

Restricted stock

Restricted stock

Restricted stock

Restricted stock

Restricted stock

Restricted stock

Restricted stock

Amended And Restated Stock Incentive Plan

Amended And Restated Stock Incentive Plan

Eureka Hunter Holdings Plan

Eureka Hunter Holdings Plan

Eureka Hunter Holdings Plan

Eureka Hunter Holdings Plan

Officers executives and employees

Officers executives and employees

Board of directors

Board of directors

Common Stock

Class B Common Units

Class B Common Units

Incentive Plan Units

Incentive Plan Units

Share Based Compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares authorized under the plan

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

27,500,000

'

2,336,905

'

2,336,905

Number of shares issued under the plan

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,274,248

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,398,898,000

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13,294,506

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Options, Nonvested, Number of Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,115,833

'

'

'

'

'

Stock options, granted

'

'

'

'

'

'

'

'

'

'

1,486,373

'

123,798

'

'

'

'

'

'

'

Award vesting period

'

'

'

'

'

'

'

'

'

'1 year

'3 years

'

'

'

'

'

'5 years

'

'

'

Estimated future forfeiture rate

'

'

'

'

'

'

'

'

'

'

'

'

'

3.40%

'

'

'

'

'

'

Vesting rights percentage

'

'

'

'

'

'

'

'

'

'

33.00%

'

100.00%

'

'

'

'

'

'

'

Vesting Period for One Third of Shares

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

'

'

Share based compensation

$2,300

$3,100

$5,674

$11,800

'

'

'

'

'

'

'

'

'

$10,800

'

'

'

'

'

'

Grants under the plan

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

894,102

'

894,102

'

Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at beginning of period (in shares)

'

'

'

'

16,891,000

'

14,847,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Granted (in shares)

'

'

'

'

0

4,938,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exercised (in shares)

'

'

'

'

-2,355,000

-685,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cancelled (in shares)

'

'

'

'

-1,241,000

-742,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at end of period (in shares)

'

'

'

'

13,295,000

18,358,000

14,847,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Exercisable at end of period (in shares)

'

'

'

'

9,179,000

10,512,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted Average Exercise Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at beginning of period (in dollars per share)

'

'

'

'

$5.69

'

$6.01

'

'

'

'

'

'

'

'

'

'

'

'

'

Granted (in dollars per share)

'

'

'

'

$0

$4.11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exercised (in dollars per share)

'

'

'

'

$4.09

$2.95

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cancelled (in dollars per share)

'

'

'

'

$6.28

$6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at end of period (in dollars per share)

'

'

'

'

$5.91

$5.61

$6.01

'

'

'

'

'

'

'

'

'

'

'

'

'

Exercisable at end of period (in dollars per share)

'

'

'

'

$6.22

$5.86

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-vested Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-vested at beginning of period (in shares)

'

'

'

'

6,908,000

'

6,163,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Granted (in shares)

'

'

'

'

0

4,938,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Vested (in shares)

'

'

'

'

-1,916,000

-2,867,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cancelled (in shares)

'

'

'

'

-876,000

-389,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-vested at end of period (in shares)

'

'

'

'

4,116,000

7,845,000

6,163,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Additional disclosures

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecognized compensation cost

'

'

'

'

$4,700

$12,900

'

$7,100

$66

'

'

'

'

'

'

'

'

'

'

'

Weighted average period for recognition of compensation cost

'

'

'

'

'1 year 1 month 6 days

'

'

'2 years 1 month 6 days

'

'

'

'

'

'

'

'

'

'

'

'

Remaining contractual term

'

'

'

'

'5 years 7 months 6 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

SHAREHOLDERS_EQUITY_Details

SHAREHOLDERS’ EQUITY (Details) (USD $)

3 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

In Thousands, except Share data, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

31-May-14

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

31-May-14

Sep. 30, 2014

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 E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Common Stock

Dilutive [Member]

Dilutive [Member]

Series E Preferred Stock

Series E Preferred Stock

Warrant [Member]

Warrant [Member]

Unvested restricted shares

Unvested restricted shares

Common stock options and stock appreciation rights

Common stock options and stock appreciation rights

Common Stock Warrant [Member]

401K Plan [Member]

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Common Stock

Class of Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

44,900,000

59,950,000

10,946,000

11,185,000

19,214,000

30,407,000

1,445,000

0

13,295,000

18,358,000

'

'

Shares issued in connection with share-based compensation

'

'

70,575

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares of common stock issued upon exercise of common stock options

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,355,000

'

'

'

'

'

'

'

'

'

'

'

'

Dividends, ratio of warrants received per common stock

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stocks issued (in Shares)

'

'

'

'

21,428,580

'

'

'

'

610,000

'

'

'

'

'

'

'

'

'

'

'

'

'

25,729,000

'

'

'

'

'

'

'

'

'

'

'

249,531

Proceeds from stock issuance

'

'

'

$10,181

'

'

$28,900

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest in share of Series E Preferred Stock per Depository Share

'

'

'

'

'

'

0.001

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued in connection with acquisition (in shares)

'

'

'

'

'

'

4,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share price

'

'

'

'

$7

'

$7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock dividends

15,492

14,417

45,718

42,034

'

'

'

4,338

3,771

12,619

10,441

2,562

2,562

7,686

7,686

4,424

4,424

13,273

13,231

1,862

1,834

5,557

5,686

'

'

'

'

'

'

'

'

'

'

'

'

'

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

2,306

1,826

6,583

4,990

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued, value

'

'

$178,432

'

$149,700

'

'

'

'

$12,000

'

'

'

'

'

'

'

'

'

'

'

'

'

$257

'

'

'

'

'

'

'

'

'

'

'

'

Warrants Exercised Number

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,142,858

'

Exercise price of warrant

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.5

'

Redemption price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.001

'

Redemption period notice

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'30 days

'

REDEEMABLE_PREFERRED_STOCK_Det

REDEEMABLE PREFERRED STOCK (Details) (USD $)	3 Months Ended		9 Months Ended						9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2014	Sep. 30, 2014	Apr. 14, 2014
					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]	'	'	'	'	'	'	'	'	'	'	'
Maximum purchase commitment amount	'	'	'	'	'	'	'	'	'	'	$200,000,000
Proceeds from sale of Eureka Hunter Holdings Series A Preferred Units	'	'	11,956,000	27,440,000	'	'	'	'	'	200,000,000	'
Stocks issued (in Shares)	'	'	'	'	'	'	'	'	610,000	'	'
Stock Issued, value	'	'	178,432,000	'	'	'	'	'	12,000,000	'	'
Preferred stock, shares issued	'	'	'	'	'	'	10,592,540	9,885,048	'	'	'
Ownership percentage	'	'	'	'	'	'	'	'	40.90%	'	'
Preferred stock issued as in-kind payment (in shares)	'	'	'	'	'	'	'	'	97,492	'	'
Preferred stock, dividends paid-in-kind	'	'	1,950,000	6,367,000	'	'	'	'	1,900,000	'	'
Embedded derivative, fair value	'	'	'	'	173,205,000	75,934,000	'	'	'	'	'
Accretion of the difference between the carrying value and the redemption value of preferred stock included in dividends	$2,306,000	$1,826,000	$6,583,000	$4,990,000	'	'	'	'	'	'	'

TAXES_Details

TAXES (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Income Tax Expense (Benefit), Continuing Operations [Abstract]	'	'	'	'
Deferred	$0	$582	$0	$47,227
Income tax benefit	$0	$582	$0	$47,227

RELATED_PARTY_TRANSACTIONS_Bal

RELATED PARTY TRANSACTIONS (Balances) (Details) (GreenHunter Resources, Inc., USD $)	Sep. 30, 2014		Dec. 31, 2013
Related Party Transaction	'		'
Accounts payable - net	$355,000	[1]	$23,000	[1]
Derivative assets	83,000	[1],[2]	79,000	[1],[2]
Investments	2,385,000	[1],[2]	2,262,000	[1],[2]
Notes receivable	1,360,000	[1],[2]	1,768,000	[1],[2]
Prepaid Expense	0	[1]	9,000	[1]
Common Stock	'		'
Related Party Transaction	'		'
Investment in related parties, shares	1,846,722		'
Investment in related parties, carrying value	154,252		'
Series C Preferred Stock	'		'
Related Party Transaction	'		'
Investment in related parties, shares	88,000		'
Investment in related parties, carrying value	$2,200,000		'
[1]	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman, a major shareholder and interim CEO. Eagle Ford Hunter received, and Triad Hunter and Viking International Resources Co., Inc., 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.
[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. See "Note 8 - 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.

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (USD $)	3 Months Ended				9 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
GreenHunter Resources, Inc.	'		'		'		'
Related Party Transaction	'		'		'		'
Loss related to investment	($38)	[1]	($24)	[1]	$123	[1]	$653	[1]
Rental agreement term	'		'		'5 years		'
GreenHunter Resources, Inc. | Water disposal costs	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	820	[2]	623	[2]	1,754	[2]	2,069	[2]
GreenHunter Resources, Inc. | Equipment Rental Expense	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	74	[2]	95	[2]	215	[2]	167	[2]
GreenHunter Resources, Inc. | Gas gathering-trucking	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	132	[2]	0	[2]	532	[2]	0	[2]
GreenHunter Resources, Inc. | MAG tank panels	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	0	[2]	0	[2]	800	[2]	0	[2]
GreenHunter Resources, Inc. | Office space rental	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	0		0		36		0
GreenHunter Resources, Inc. | Interest Income from Note Receivable	'		'		'		'
Related Party Transaction	'		'		'		'
Drilling revenues	38	[1]	51	[1]	121	[1]	159	[1]
Pilatus Hunter	'		'		'		'
Related Party Transaction	'		'		'		'
Percentage of owned in subsidiary	'		'		100.00%		'
Pilatus Hunter | Airplane Rental Expenses	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	49	[3]	26	[3]	207	[3]	94	[3]
Series C Cumulative Perpetual Preferred Stock | GreenHunter Resources, Inc.	'		'		'		'
Related Party Transaction	'		'		'		'
Proceeds from Dividends Received	$55		$73		$165		$165
Chief Executive Officer | GreenHunter Resources, Inc.	'		'		'		'
Related Party Transaction	'		'		'		'
Shares purchased by related party from agreement for acquisition of assets	'		'		27,641		'
[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. See "Note 8 - 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 interim CEO. Eagle Ford Hunter received, and Triad Hunter and Viking International Resources Co., Inc., 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.
[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.

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Aug. 12, 2013

Aug. 18, 2014

Aug. 18, 2014

Jun. 05, 2014

Sep. 30, 2014

Jun. 05, 2014

Jul. 24, 2014

Jun. 18, 2014

Sep. 05, 2014

Jun. 20, 2014

Jun. 30, 2014

Jul. 01, 2014

28-May-14

Jul. 24, 2014

Dec. 30, 2013

Dec. 30, 2013

Jul. 24, 2014

Jun. 18, 2014

Jun. 18, 2014

Jun. 17, 2014

Sep. 30, 2014

Sep. 30, 2014

31-May-14

Oct. 31, 2014

Jul. 25, 2014

Jun. 30, 2014

Triad Hunter

Texas Gas Transportation Services Agreement, MMBtu Per Day Of Transportation Capacity [Member]

Texas Gas Transportation Services Agreement, MMBtu Per Day Of Transportation Capacity [Member]

Leasehold Acreage From MNW Energy, LLC

Leasehold Acreage From MNW Energy, LLC

Leasehold Acreage From MNW Energy, LLC

Ormet Asset Purchase Agreement

Ormet Asset Purchase Agreement

Ambassador Oil And Gas Limited, Off-market Takeover

Ambassador Oil And Gas Limited, Off-market Takeover

Drilling Rig Purchase

Drilling Rig Purchase

The Company, Triad Hunter, MNW vs. Dux Petroleum, LLC

PRC Williston vs. Drawbridge Special Opportunities Fund LP And Fortress Value Recovery Fund I LLC D.B. Zwirn Special Opportunities Fund, L.P.

PRC Williston vs. Drawbridge Special Opportunities Fund LP And Fortress Value Recovery Fund I LLC D.B. Zwirn Special Opportunities Fund, L.P.

PRC Williston vs. Drawbridge Special Opportunities Fund LP And Fortress Value Recovery Fund I LLC D.B. Zwirn Special Opportunities Fund, L.P.

The Company, PRC Williston vs. Drawbridge Special Opportunities Fund LP [Member]

Monroe County, Ohio

Wetzerl County, West Virginia

Marcellus Zone

Southern Appalachia

Muhlenberg County, Kentucky

Common Stock

Common Stock

Eagle Ford Hunter, Inc.

Eagle Ford Hunter, Inc.

acre

MMBTU

acre

acre

acre

Outback Shale Hunter Pty Ltd

Outback Shale Hunter Pty Ltd

Alpha Hunter Drilling LLC

Alpha Hunter Drilling LLC

Triad Hunter

PRC Williston Inc

Ormet Asset Purchase Agreement

Ormet Asset Purchase Agreement

Ormet Asset Purchase Agreement

Seminole Energy Services, Settlement Agreement [Member]

Seminole Energy Services, Settlement Agreement [Member]

Ambassador Oil And Gas Limited, Off-market Takeover

acre

acre

Well

Natural gas gathering trunk line and treatment facility

Outback Shale Hunter Pty Ltd

Subsequent Event

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

MMBtu/day

'

'

'

'

100,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pipeline project term of agreement

'

'

'

'15 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contractual obligation

'

'

'

'

$12,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of mineral acres agreed to acquire

'

'

32,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Litigation settlement, amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000

2,900,000

'

'

'

'

'

'

450,000

'

'

'

'

'

Net leasehold acres purchased

'

'

'

'

'

'

17,000

11,128

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payment to acquire leasehold acres

'

'

'

'

'

45,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of total leasehold acres acquired under the asset purchase agreement

'

'

'

'

'

'

53.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acreage in which mineral interests are acquired

'

'

'

'

'

'

'

'

'

2,000

'

'

'

'

'

'

'

'

'

1,375

325

'

'

'

'

'

'

'

Leasehold rights royalty carried on production, percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12.50%

'

'

'

'

'

'

Purchase price to acquire mineral rights

'

'

'

'

'

'

'

'

22,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock, par value (in dollars per share)

$0.01

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares offered for one share in off-market takeover

'

'

'

'

'

'

'

'

'

'

'

23.6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock, Shares, Outstanding

199,898,027

171,494,071

'

'

'

'

'

'

'

'

23,116

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment holding of total shares outstanding as a percent

'

'

'

'

'

'

'

'

'

'

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stocks issued (in Shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21,428,580

980

'

'

Share price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$7

'

'

'

Number of wells not drilled

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

Number of wells required to be drilled per agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

'

'

Interest acquired (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

Purchase price of a new drilling rig

'

'

'

'

'

'

'

'

'

'

'

'

6,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deposit on equipment purchase

'

'

'

'

'

'

'

'

'

'

'

'

'

1,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Collective interest in any distributions in respect of the equity interests

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12.50%

'

'

'

'

'

'

'

'

'

'

'

Proceeds from sale of assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,000,000

'

'

'

'

'

'

'

'

'

'

Liabilities of Disposal Group, Including Discontinued Operation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

33,700,000

Disposal Group, Including Discontinued Operation, Accrued Liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,300,000

Disposal Group, Working Capital Adjustments, Basis For Liability Claims

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$7,800,000

'

Loss Contingency, Settlement Agreement, Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

[1]

A collar is a sold call and a purchased put. Some collars are "costless" collars with the premiums netting to approximately zero.

SUPPLEMENTAL_CASH_FLOW_INFORMA2

SUPPLEMENTAL CASH FLOW INFORMATION (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Supplemental Cash Flow Elements [Abstract]	'	'
Cash paid for interest	$38,565	$38,225
Non-cash transactions	'	'
Non-cash consideration received from sale of assets	9,447	'
Change in accrued capital expenditures	129,778	-5,742
Non-cash additions to asset retirement obligation	2,439	2,089
Eureka Hunter Holdings Series A Preferred Unit dividends paid in kind	$1,950	$6,367

SEGMENT_REPORTING_Details

SEGMENT REPORTING (Details) (USD $)	3 Months Ended			9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013	Sep. 30, 2014		Sep. 30, 2013	Dec. 31, 2013
Details of operating activities by segment	'		'	'		'	'
Total revenue	$79,670		$78,291	$331,615		$214,359	'
Depletion, depreciation, amortization and accretion	36,370		29,127	101,733		80,141	'
Loss (gain) on sale of assets, net	-8,000		40,952	-4,612		42,114	'
Other operating expenses	108,876		128,086	323,277		287,827	'
Other income (expense)	-65,613		-33,221	-152,370		-69,235	'
Income (loss) from continuing operations before income tax	-123,189		-153,095	-241,153		-264,958	'
Income tax benefit	0		582	0		47,227	'
Total income (loss) from discontinued operations, net of tax	-258	[1]	-145,094	-9,422	[1]	40,478	'
Net income (loss)	-123,447		-297,607	-250,575		-177,253	'
Total assets	2,033,565		1,885,816	2,033,565		1,885,816	1,856,651
Total capital expenditures	196,439		176,030	498,878		412,986	'
U.S. Upstream	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	63,438		59,325	223,788		158,217	'
Depletion, depreciation, amortization and accretion	31,217		25,233	87,345		69,420	'
Loss (gain) on sale of assets, net	-7,988		40,952	-4,231		42,110	'
Other operating expenses	87,035		100,484	197,013		198,363	'
Other income (expense)	1,907		2,038	1,739		440	'
Income (loss) from continuing operations before income tax	-44,919		-105,306	-54,600		-151,236	'
Income tax benefit	'		17,794	'		23,560	'
Total income (loss) from discontinued operations, net of tax	-259	[1]	-13,881	-7,283	[1]	181,233	'
Net income (loss)	-45,178		-101,393	-61,883		53,557	'
Total assets	1,475,305		1,406,515	1,475,305		1,406,515	'
Total capital expenditures	104,265		149,577	320,719		322,768	'
Canadian Upstream	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	0		0	0		0	'
Depletion, depreciation, amortization and accretion	0		0	0		0	'
Loss (gain) on sale of assets, net	0		0	0		0	'
Other operating expenses	0		0	0		0	'
Other income (expense)	0		0	0		0	'
Income (loss) from continuing operations before income tax	0		0	0		0	'
Income tax benefit	'		926	'		0	'
Total income (loss) from discontinued operations, net of tax	0	[1]	-132,861	10,636	[1]	-134,070	'
Net income (loss)	0		-131,935	10,636		-134,070	'
Total assets	0		106,438	0		106,438	'
Total capital expenditures	0		181	305		14,317	'
Midstream and Marketing	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	11,845		14,618	98,697		48,071	'
Depletion, depreciation, amortization and accretion	4,224		3,174	11,831		9,142	'
Loss (gain) on sale of assets, net	-12		0	-12		0	'
Other operating expenses	7,350		11,140	86,120		41,276	'
Other income (expense)	-58,078		-16,572	-98,505		-24,261	'
Income (loss) from continuing operations before income tax	-57,795		-16,268	-97,747		-26,608	'
Income tax benefit	'		0	'		0	'
Total income (loss) from discontinued operations, net of tax	0	[1]	0	0	[1]	0	'
Net income (loss)	-57,795		-16,268	-97,747		-26,608	'
Total assets	443,008		269,692	443,008		269,692	'
Total capital expenditures	88,525		19,918	171,152		55,003	'
Oilfield Services	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	8,176		6,448	23,882		13,873	'
Depletion, depreciation, amortization and accretion	929		720	2,557		1,579	'
Loss (gain) on sale of assets, net	0		0	-369		4	'
Other operating expenses	6,569		4,931	19,643		12,884	'
Other income (expense)	-205		-141	-625		-372	'
Income (loss) from continuing operations before income tax	473		656	1,426		-966	'
Income tax benefit	'		0	'		0	'
Total income (loss) from discontinued operations, net of tax	0	[1]	0	0	[1]	0	'
Net income (loss)	473		656	1,426		-966	'
Total assets	45,661		42,648	45,661		42,648	'
Total capital expenditures	3,628		5,850	6,575		19,971	'
Corporate Unallocated	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	0		0	0		0	'
Depletion, depreciation, amortization and accretion	0		0	0		0	'
Loss (gain) on sale of assets, net	0		0	0		0	'
Other operating expenses	11,711		11,457	35,253		38,932	'
Other income (expense)	-9,237		-20,814	-54,979		-47,330	'
Income (loss) from continuing operations before income tax	-20,948		-32,271	-90,232		-86,262	'
Income tax benefit	'		-18,138	'		23,667	'
Total income (loss) from discontinued operations, net of tax	1	[1]	1,742	-12,775	[1]	-6,571	'
Net income (loss)	-20,947		-48,667	-103,007		-69,166	'
Total assets	74,614		62,182	74,614		62,182	'
Total capital expenditures	21		504	127		927	'
Inter-segment Eliminations	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	-3,789		-2,100	-14,752		-5,802	'
Depletion, depreciation, amortization and accretion	0		0	0		0	'
Loss (gain) on sale of assets, net	0		0	0		0	'
Other operating expenses	-3,789		74	-14,752		-3,628	'
Other income (expense)	0		2,268	0		2,288	'
Income (loss) from continuing operations before income tax	0		94	0		114	'
Income tax benefit	'		0	'		0	'
Total income (loss) from discontinued operations, net of tax	0	[1]	-94	0	[1]	-114	'
Net income (loss)	0		0	0		0	'
Total assets	-5,023		-1,659	-5,023		-1,659	'
Total capital expenditures	$0		$0	$0		$0	'
[1]	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.

CONDENSED_CONSOLIDATING_GUARAN2

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	($123,447)	($297,607)	($250,575)	($177,253)	'
ASSETS	'	'	'	'	'
Current assets	101,051	'	101,051	'	120,726
Property and equipment (using successful efforts method of accounting)	1,791,314	'	1,791,314	'	1,514,079
Total assets	2,033,565	1,885,816	2,033,565	1,885,816	1,856,651
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	255,242	'	255,242	'	183,865
Redeemable preferred stock	251,685	'	251,685	'	236,675
Shareholders’ equity	371,398	'	371,398	'	450,730
Total liabilities and shareholders’ equity	2,033,565	'	2,033,565	'	1,856,651
Magnum Hunter Resources Corporation	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-127,328	-302,363	-266,125	-190,954	'
100% Owned Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-44,101	-81,981	-51,611	-97,486	'
Non Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-58,873	-178,410	-88,330	-202,152	'
Eliminations	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	106,855	265,147	155,491	313,339	'
Magnum Hunter Resources Corporation Consolidated	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-123,447	-297,607	-250,575	-177,253	'
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-127,328	-302,363	-266,125	-190,954	'
ASSETS	'	'	'	'	'
Current assets	52,405	'	52,405	'	53,161
Intercompany accounts receivable	1,084,519	'	1,084,519	'	965,138
Property and equipment (using successful efforts method of accounting)	5,614	'	5,614	'	7,214
Investment in subsidiaries	193,337	'	193,337	'	372,236
Other assets	16,594	'	16,594	'	17,308
Total assets	1,352,469	'	1,352,469	'	1,415,057
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	40,822	'	40,822	'	54,826
Intercompany accounts payable	0	'	0	'	0
Long-term liabilities	856,161	'	856,161	'	818,651
Redeemable preferred stock	100,000	'	100,000	'	100,000
Shareholders’ equity	355,486	'	355,486	'	441,580
Total liabilities and shareholders’ equity	1,352,469	'	1,352,469	'	1,415,057
Debt Securities Under Universal Shelf Registration Statement Form S-4 | 100% Owned Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-44,101	-81,981	-51,611	-97,486	'
ASSETS	'	'	'	'	'
Current assets	43,367	'	43,367	'	43,841
Intercompany accounts receivable	'	'	'	'	'
Property and equipment (using successful efforts method of accounting)	1,390,673	'	1,390,673	'	1,272,027
Investment in subsidiaries	100,392	'	100,392	'	102,314
Other assets	87,291	'	87,291	'	100,894
Total assets	1,621,723	'	1,621,723	'	1,519,076
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	124,895	'	124,895	'	97,520
Intercompany accounts payable	1,044,555	'	1,044,555	'	921,237
Long-term liabilities	45,822	'	45,822	'	39,067
Redeemable preferred stock	0	'	0	'	0
Shareholders’ equity	406,451	'	406,451	'	461,252
Total liabilities and shareholders’ equity	1,621,723	'	1,621,723	'	1,519,076
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Non Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-58,873	-178,410	-88,330	-202,152	'
ASSETS	'	'	'	'	'
Current assets	10,301	'	10,301	'	27,096
Intercompany accounts receivable	'	'	'	'	'
Property and equipment (using successful efforts method of accounting)	395,027	'	395,027	'	234,838
Investment in subsidiaries	'	'	'	'	'
Other assets	37,315	'	37,315	'	103,644
Total assets	442,643	'	442,643	'	365,578
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	94,550	'	94,550	'	34,929
Intercompany accounts payable	42,201	'	42,201	'	43,866
Long-term liabilities	253,257	'	253,257	'	127,663
Redeemable preferred stock	151,685	'	151,685	'	136,675
Shareholders’ equity	-99,050	'	-99,050	'	22,445
Total liabilities and shareholders’ equity	442,643	'	442,643	'	365,578
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Eliminations	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	106,855	265,147	155,491	313,339	'
ASSETS	'	'	'	'	'
Current assets	-5,022	'	-5,022	'	-3,372
Intercompany accounts receivable	-1,084,519	'	-1,084,519	'	-965,138
Property and equipment (using successful efforts method of accounting)	'	'	'	'	'
Investment in subsidiaries	-293,729	'	-293,729	'	-474,550
Other assets	'	'	'	'	'
Total assets	-1,383,270	'	-1,383,270	'	-1,443,060
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	-5,025	'	-5,025	'	-3,410
Intercompany accounts payable	-1,086,756	'	-1,086,756	'	-965,103
Long-term liabilities	0	'	0	'	0
Redeemable preferred stock	0	'	0	'	0
Shareholders’ equity	-291,489	'	-291,489	'	-474,547
Total liabilities and shareholders’ equity	-1,383,270	'	-1,383,270	'	-1,443,060
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation Consolidated	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-123,447	-297,607	-250,575	-177,253	'
ASSETS	'	'	'	'	'
Current assets	101,051	'	101,051	'	120,726
Intercompany accounts receivable	0	'	0	'	0
Property and equipment (using successful efforts method of accounting)	1,791,314	'	1,791,314	'	1,514,079
Investment in subsidiaries	0	'	0	'	0
Other assets	141,200	'	141,200	'	221,846
Total assets	2,033,565	'	2,033,565	'	1,856,651
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	255,242	'	255,242	'	183,865
Intercompany accounts payable	0	'	0	'	0
Long-term liabilities	1,155,240	'	1,155,240	'	985,381
Redeemable preferred stock	251,685	'	251,685	'	236,675
Shareholders’ equity	371,398	'	371,398	'	450,730
Total liabilities and shareholders’ equity	$2,033,565	'	$2,033,565	'	$1,856,651

CONDENSED_CONSOLIDATING_GUARAN3

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 2) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Condensed consolidating statements of operations	'	'	'	'
Revenues	$79,670	$78,291	$331,615	$214,359
Income (loss) from continuing operations before income taxes	-123,189	-153,095	-241,153	-264,958
Income tax benefit	0	582	0	47,227
Income (loss) from continuing operations	-123,189	-152,513	-241,153	-217,731
Income (loss) from discontinued operations, net of tax	0	-75,573	4,561	-62,453
Gain (loss) on disposal of discontinued operations, net of tax	-258	-69,521	-13,983	102,931
Net income (loss)	-123,447	-297,607	-250,575	-177,253
Net loss attributed to non-controlling interests	2,764	725	3,653	1,614
Net income (loss) attributable to Magnum Hunter Resources Corporation	-120,683	-296,882	-246,922	-175,639
Dividends on preferred stock	-15,492	-14,417	-45,718	-42,034
Net income (loss) attributable to common shareholders	-136,175	-311,299	-292,640	-217,673
Magnum Hunter Resources Corporation	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Net income (loss)	-127,328	-302,363	-266,125	-190,954
100% Owned Guarantor Subsidiaries	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Net income (loss)	-44,101	-81,981	-51,611	-97,486
Non Guarantor Subsidiaries	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Net income (loss)	-58,873	-178,410	-88,330	-202,152
Eliminations	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Net income (loss)	106,855	265,147	155,491	313,339
Magnum Hunter Resources Corporation Consolidated	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Net income (loss)	-123,447	-297,607	-250,575	-177,253
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Revenues	10	29	124	-134
Expenses	21,317	35,350	92,622	91,559
Loss from continuing operations before equity in net income of subsidiary	-21,307	-35,321	-92,498	-91,693
Equity in net income of subsidiary	-105,762	-236,767	-153,569	-274,930
Income (loss) from continuing operations before income taxes	-127,069	-272,088	-246,067	-366,623
Income tax benefit	'	-18,138	0	23,667
Income (loss) from continuing operations	-127,069	-290,226	-246,067	-342,956
Income (loss) from discontinued operations, net of tax	0	1,743	0	-6,570
Gain (loss) on disposal of discontinued operations, net of tax	-259	-13,880	-20,058	158,572
Net income (loss)	-127,328	-302,363	-266,125	-190,954
Net loss attributed to non-controlling interests	0	'	0	0
Net income (loss) attributable to Magnum Hunter Resources Corporation	-127,328	-302,363	-266,125	-190,954
Dividends on preferred stock	-8,848	-8,820	-26,516	-26,603
Net income (loss) attributable to common shareholders	-136,176	-311,183	-292,641	-217,557
Debt Securities Under Universal Shelf Registration Statement Form S-4 | 100% Owned Guarantor Subsidiaries	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Revenues	72,809	71,246	313,898	194,599
Expenses	115,817	171,183	363,587	337,827
Loss from continuing operations before equity in net income of subsidiary	-43,008	-99,937	-49,689	-143,228
Equity in net income of subsidiary	-1,093	163	-1,922	-479
Income (loss) from continuing operations before income taxes	-44,101	-99,774	-51,611	-143,707
Income tax benefit	'	17,793	0	23,560
Income (loss) from continuing operations	-44,101	-81,981	-51,611	-120,147
Income (loss) from discontinued operations, net of tax	0	0	0	22,661
Gain (loss) on disposal of discontinued operations, net of tax	0	0	0	0
Net income (loss)	-44,101	-81,981	-51,611	-97,486
Net loss attributed to non-controlling interests	0	'	0	0
Net income (loss) attributable to Magnum Hunter Resources Corporation	-44,101	-81,981	-51,611	-97,486
Dividends on preferred stock	0	0	0	0
Net income (loss) attributable to common shareholders	-44,101	-81,981	-51,611	-97,486
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Non Guarantor Subsidiaries	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Revenues	11,141	9,112	32,846	25,693
Expenses	70,015	27,045	131,812	55,845
Loss from continuing operations before equity in net income of subsidiary	-58,874	-17,933	-98,966	-30,152
Equity in net income of subsidiary	0	-28,543	0	-37,930
Income (loss) from continuing operations before income taxes	-58,874	-46,476	-98,966	-68,082
Income tax benefit	'	927	0	0
Income (loss) from continuing operations	-58,874	-45,549	-98,966	-68,082
Income (loss) from discontinued operations, net of tax	0	-77,220	4,561	-78,429
Gain (loss) on disposal of discontinued operations, net of tax	1	-55,641	6,075	-55,641
Net income (loss)	-58,873	-178,410	-88,330	-202,152
Net loss attributed to non-controlling interests	0	'	0	0
Net income (loss) attributable to Magnum Hunter Resources Corporation	-58,873	-178,410	-88,330	-202,152
Dividends on preferred stock	-6,644	-5,597	-19,202	-15,431
Net income (loss) attributable to common shareholders	-65,517	-184,007	-107,532	-217,583
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Eliminations	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Revenues	-4,290	-2,096	-15,253	-5,799
Expenses	-4,290	-2,192	-15,253	-5,914
Loss from continuing operations before equity in net income of subsidiary	0	96	0	115
Equity in net income of subsidiary	106,855	265,147	155,491	313,339
Income (loss) from continuing operations before income taxes	106,855	265,243	155,491	313,454
Income tax benefit	'	'	0	0
Income (loss) from continuing operations	106,855	265,243	155,491	313,454
Income (loss) from discontinued operations, net of tax	0	-96	0	-115
Gain (loss) on disposal of discontinued operations, net of tax	0	0	0	0
Net income (loss)	106,855	265,147	155,491	313,339
Net loss attributed to non-controlling interests	2,764	725	3,653	1,614
Net income (loss) attributable to Magnum Hunter Resources Corporation	109,619	265,872	159,144	314,953
Dividends on preferred stock	0	0	0	0
Net income (loss) attributable to common shareholders	109,619	265,872	159,144	314,953
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation Consolidated	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Revenues	79,670	78,291	331,615	214,359
Expenses	202,859	231,386	572,768	479,317
Loss from continuing operations before equity in net income of subsidiary	-123,189	-153,095	-241,153	-264,958
Equity in net income of subsidiary	0	0	0	0
Income (loss) from continuing operations before income taxes	-123,189	-153,095	-241,153	-264,958
Income tax benefit	'	582	0	47,227
Income (loss) from continuing operations	-123,189	-152,513	-241,153	-217,731
Income (loss) from discontinued operations, net of tax	0	-75,573	4,561	-62,453
Gain (loss) on disposal of discontinued operations, net of tax	-258	-69,521	-13,983	102,931
Net income (loss)	-123,447	-297,607	-250,575	-177,253
Net loss attributed to non-controlling interests	2,764	725	3,653	1,614
Net income (loss) attributable to Magnum Hunter Resources Corporation	-120,683	-296,882	-246,922	-175,639
Dividends on preferred stock	-15,492	-14,417	-45,718	-42,034
Net income (loss) attributable to common shareholders	($136,175)	($311,299)	($292,640)	($217,673)

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, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	($123,447)	($297,607)	($250,575)	($177,253)
Foreign currency translation gain	0	3,856	-1,218	-7,943
Unrealized loss on available for sale securities	-2,583	3,735	-3,188	8,184
Amounts reclassified from accumulated other comprehensive income	0	-8,262	0	-8,262
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	0	20,741	0
COMPREHENSIVE LOSS	-126,030	-298,278	-234,240	-185,274
Comprehensive loss attributable to non-controlling interests	2,764	725	3,653	1,614
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-123,266	-297,553	-230,587	-183,660
Magnum Hunter Resources Corporation	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-127,328	-302,363	-266,125	-190,954
Foreign currency translation gain	0	0	0	0
Unrealized loss on available for sale securities	0	3,562	0	8,262
Amounts reclassified from accumulated other comprehensive income	'	-8,262	'	-8,262
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	'	20,741	'
COMPREHENSIVE LOSS	-127,328	-307,063	-245,384	-190,954
Comprehensive loss attributable to non-controlling interests	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-127,328	-307,063	-245,384	-190,954
100% Owned Guarantor Subsidiaries	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-44,101	-81,981	-51,611	-97,486
Foreign currency translation gain	0	0	0	0
Unrealized loss on available for sale securities	-2,583	173	-3,188	-78
Amounts reclassified from accumulated other comprehensive income	'	0	'	0
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	'	0	'
COMPREHENSIVE LOSS	-46,684	-81,808	-54,799	-97,564
Comprehensive loss attributable to non-controlling interests	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-46,684	-81,808	-54,799	-97,564
Non-Guarantor Subsidiaries [Member]	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-58,873	-178,410	-88,330	-202,152
Foreign currency translation gain	0	3,856	-1,218	-7,943
Unrealized loss on available for sale securities	0	0	0	0
Amounts reclassified from accumulated other comprehensive income	'	0	'	0
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	'	0	'
COMPREHENSIVE LOSS	-58,873	-174,554	-89,548	-210,095
Comprehensive loss attributable to non-controlling interests	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-58,873	-174,554	-89,548	-210,095
Eliminations	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	106,855	265,147	155,491	313,339
Foreign currency translation gain	0	0	0	0
Unrealized loss on available for sale securities	0	0	0	0
Amounts reclassified from accumulated other comprehensive income	'	0	'	0
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	'	0	'
COMPREHENSIVE LOSS	106,855	265,147	155,491	313,339
Comprehensive loss attributable to non-controlling interests	2,764	725	3,653	1,614
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	109,619	265,872	159,144	314,953
Magnum Hunter Resources Corporation Consolidated	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-123,447	-297,607	-250,575	-177,253
Foreign currency translation gain	0	3,856	-1,218	-7,943
Unrealized loss on available for sale securities	-2,583	3,735	-3,188	8,184
Amounts reclassified from accumulated other comprehensive income	'	-8,262	'	-8,262
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	'	20,741	'
COMPREHENSIVE LOSS	-126,030	-298,278	-234,240	-185,274
Comprehensive loss attributable to non-controlling interests	2,764	725	3,653	1,614
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	($123,266)	($297,553)	($230,587)	($183,660)

CONDENSED_CONSOLIDATING_GUARAN5

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 4) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	$13,555	$79,197
Cash flow from operating activities	-247,304	44,823
Cash flow from investing activities	234,659	-126,267
Effect of changes in exchange rate on cash	44	-93
Net increase (decrease) in cash	954	-2,340
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	41,713	57,623
CASH AND CASH EQUIVALENTS, END OF PERIOD	42,667	55,283
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	-261,039	-264,051
Cash flow from operating activities	63,502	422,056
Cash flow from investing activities	193,885	-152,265
Effect of changes in exchange rate on cash	'	'
Net increase (decrease) in cash	-3,652	5,740
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	47,895	26,872
CASH AND CASH EQUIVALENTS, END OF PERIOD	44,243	32,612
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	222,520	236,112
Cash flow from operating activities	-211,560	-245,179
Cash flow from investing activities	2,232	2,105
Effect of changes in exchange rate on cash	'	'
Net increase (decrease) in cash	13,192	-6,962
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	-17,651	-4,187
CASH AND CASH EQUIVALENTS, END OF PERIOD	-4,459	-11,149
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	52,074	107,136
Cash flow from operating activities	-99,246	-132,054
Cash flow from investing activities	38,542	23,893
Effect of changes in exchange rate on cash	44	-93
Net increase (decrease) in cash	-8,586	-1,118
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	11,469	34,938
CASH AND CASH EQUIVALENTS, END OF PERIOD	2,883	33,820
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	13,555	79,197
Cash flow from operating activities	-247,304	44,823
Cash flow from investing activities	234,659	-126,267
Effect of changes in exchange rate on cash	44	-93
Net increase (decrease) in cash	954	-2,340
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	41,713	57,623
CASH AND CASH EQUIVALENTS, END OF PERIOD	$42,667	$55,283

SUBSEQUENT_EVENTS_Details

SUBSEQUENT EVENTS (Details) (USD $)

0 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

1 Months Ended

Sep. 30, 2014

Sep. 17, 2014

Sep. 23, 2014

Sep. 30, 2014

Oct. 08, 2014

Oct. 08, 2014

Oct. 15, 2014

Oct. 30, 2014

Oct. 30, 2014

Nov. 03, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 08, 2014

Oct. 21, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 22, 2014

Oct. 21, 2014

Oct. 21, 2014

Oct. 21, 2014

Jan. 31, 2015

Jan. 31, 2015

Divide County, North Dakota

Divide County, North Dakota

Roane Counties, West Virginia

Prior Revolving Credit Facility

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Scenario, Forecast

Scenario, Forecast

Non-Operated Working Interests In Oil And Gas Properties [Member]

Non-Operated Working Interests In Oil And Gas Properties [Member]

Non-Core Working Interests In Oil And Gas Properties [Member]

Line of Credit

REX Services Agreement, MMBtu Per Day Of Firm Transportation

REX Services Agreement, MMBtu Per Day Of Firm Transportation

Divide County, North Dakota

Utica Shale, Ohio

Utica Shale, Ohio

Roane Counties, West Virginia

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Second Lien Term Loan Agreement

Second Lien Term Loan Agreement

Second Lien Term Loan Agreement

Second Lien Term Loan Agreement

Second Lien Term Loan Agreement

Second Lien Term Loan Agreement

Prior Revolving Credit Facility

Credit Support Agreement With REX

Credit Support Agreement With REX

Fiscal Quarter Ending December 31, 2014

Fiscal Quarter Ending December 31, 2014

Fiscal Quarter Ending March 31, 2016

Fiscal Quarter Ending March 31, 2015

Fiscal Quarter Ending June 30, 2015 And Each Fiscal Quarter Thereafter

Second Lien Term Loan Agreement

Second Lien Term Loan Agreement

Period Between Fourteen Months After and Twenty One Months From August 18, 2014

Period Between Twenty One Months After and Twenty Eight Months From August 18, 2014

Period Beginning Twenty Eight Months After August 18, 2014

Morgan Stanley Infrastructure (MSI) [Member]

Morgan Stanley Infrastructure (MSI) [Member]

Revolving Credit Facility

Triad Hunter

Triad Hunter

Non-Operated Working Interests In Oil And Gas Properties [Member]

Asset purchase agreement with MNW

Asset purchase agreement with MNW

Non-Core Working Interests In Oil And Gas Properties [Member]

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Second Lien Term Loan Agreement

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018

Line of Credit

Line of Credit

Credit Support Agreement With TGT

Credit Support Agreement With TGT

Credit Support Agreement With TGT

Eureka Hunter Holdings, LLC

Maximum

MMBTU

Triad Hunter

Triad Hunter

Triad Hunter

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Letter of Credit

Letter of Credit

Term Loan

Term Loan

Term Loan

Term Loan

Term Loan

Term Loan

Revolving Credit Facility

Letter of Credit

Letter of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Line of Credit

Term Loan

Term Loan

Line of Credit

Line of Credit

Line of Credit

Eureka Hunter Holdings, LLC

acre

Federal Funds Rate

London Interbank Offered Rate (LIBOR)

Minimum

Minimum

Maximum

Maximum

Federal Funds Rate

Adjusted one-month LIBOR

London Interbank Offered Rate (LIBOR)

Alternate Base Rate

Triad Hunter

Triad Hunter

Revolving Credit Facility

Term Loan

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Letter of Credit

Letter of Credit

Letter of Credit

London Interbank Offered Rate (LIBOR)

Alternate Base Rate

London Interbank Offered Rate (LIBOR)

Alternate Base Rate

Triad Hunter

Triad Hunter

Triad Hunter

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment holding of total shares outstanding as a percent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6.50%

'

Payments to acquire equity method investments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$65,000,000

'

Ownership percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

98.00%

'

Future capital contributions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40,000,000

Future capital contributions, catch up feature, period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'180 days

'

Cash consideration received

23,500,000

84,800,000

1,200,000

'

'

'

84,800,000

'

'

1,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base

'

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

'

'

'

'

50,000,000

'

340,000,000

'

'

'

'

'

'

37,000,000

'

'

'

'

'

'

'

13,000,000

36,000,000

65,000,000

'

'

Borrowing capacity limit increase

'

'

'

'

'

'

'

'

'

'

'

250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit facility, commitment fee percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, basis spread on variable rate

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

1.00%

2.00%

1.00%

3.00%

2.00%

'

'

'

'

0.50%

1.00%

7.50%

6.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest period interval

'

'

'

'

'

'

'

'

'

'

'3 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum borrowing capacity availability as percent of borrowing base

'

'

'

'

'

'

'

'

'

'

'

2.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum borrowing capacity availability, covenant

'

'

'

'

'

'

'

'

'

'

'

5,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum borrowing capacity availability, basket per year

'

'

'

'

'

'

'

'

'

'

'

45,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

Leverage ratio limitation on netting of unencumbered cash

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

'

'

'

100,000,000

'

'

'

'

'

Required maximum secured Net Debt to EBITDAX ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.5

'

'

2.25

2

2.5

'

'

'

'

'

'

Present value of proved oil and gas reserves lien, percent

'

'

'

'

'

'

'

'

'

'

'

90.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Present value of proved oil and gas reserves lien, discount rate, percent

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit outstanding

'

'

'

256,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

340,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Original principal amount amortization installment (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount outstanding in addition to loans repaid or prepaid, threshold

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Indebtedness threshold, percent of Adjusted Consolidated Net Tangible Assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proved Reserves to secured debt ratio (not less than 1.5 to 1.0)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.5

'

'

'

'

'

'

'

'

'

'

Proved developed and producing reserves to secured debt ratio (not less than 1.0 to 1.0)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

Repayments percent of outstanding borrowings

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

MMBtu/day

'

'

'

'

'

100,000

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pipeline project term of agreement

'

'

'

'

'15 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contractual obligation

'

'

'

'

'

16,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Required period for credit support (letter of credit)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'45 days

'

'

'

'

'

'

'

'

'

'

'

'

'

Net acreage of undeveloped leasehold acquired

'

'

'

'

'

'

'

'

5,160

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payment to acquire leasehold acres

'

'

'

'

'

'

'

20,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Escrow funds released

'

'

'

'

'

'

'

400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total consideration

'

'

'

'

'

'

'

$21,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net acreage of undeveloped leasehold available for purchase

'

'

'

'

'

'

'

'

9,840

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

A collar is a sold call and a purchased put. Some collars are "costless" collars with the premiums netting to approximately zero.