PRC Williston 10-K 5 Mar 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Feb. 24, 2014
Document and Entity Information [Abstract]	'	'
Document Type	'10-K	'
Amendment Flag	'false	'
Document Period End Date	31-Dec-13	'
Entity Registrant Name	'PRC WILLISTON, LLC	'
Entity Central Index Key	'0001565640	'
Entity Filer Category	'Non-accelerated Filer	'
Current Fiscal Year End Date	'--12-31	'
Entity Well-known Seasoned Issuer	'No	'
Entity Voluntary Filers	'No	'
Entity Current Reporting Status	'Yes	'
Common Stock, Shares, Outstanding	'	0
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'FY	'
Entity Public Float	'	$0

BALANCE_SHEETS

BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
CURRENT ASSETS:	'	'
Restricted cash	$5,000	$0
Accounts receivable	1,013	703
Total current assets	6,013	703
PROPERTY AND EQUIPMENT:	'	'
Oil and natural gas properties, successful efforts method	0	33,800
Accumulated depletion and depreciation	0	-15,543
Total oil and natural gas properties, net	0	18,257
Total Assets	6,013	18,960
CURRENT LIABILITIES:	'	'
Accounts payable and accrued liabilities	2,035	1,402
Current portion of asset retirement obligation	0	889
Accounts payable due to Parent	45,661	58,966
Total current liabilities	47,696	61,257
NONCURRENT LIABILITIES	'	'
Asset retirement obligation	0	1,274
Total liabilities	47,696	62,531
MEMBER’S DEFICIT:	-41,683	-43,571
Total Liabilities and Member’s Deficit	$6,013	$18,960

STATEMENTS_OF_OPERATIONS

STATEMENTS OF OPERATIONS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement [Abstract]	'	'	'
GENERAL AND ADMINISTRATIVE EXPENSES	$1,655	$1,197	$2,650
OPERATING LOSS	-1,655	-1,197	-2,650
INTEREST EXPENSE	-1,928	-2,092	-2,065
LOSS FROM CONTINUING OPERATIONS	-3,583	-3,289	-4,715
GAIN (LOSS) FROM DISCONTINUED OPERATIONS	-1,674	-11,602	1,698
GAIN ON SALE OF DISCONTINUED OPERATIONS	7,145	0	0
NET INCOME (LOSS)	$1,888	($14,891)	($3,017)

STATEMENT_OF_CHANGES_IN_MEMBER

STATEMENT OF CHANGES IN MEMBER'S DEFICIT (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
In Thousands, unless otherwise specified
Changes in Member's Deficit	'	'	'	'
Balance, Period Start	($41,683)	($43,571)	($28,680)	($25,663)
Balance, Period End	($41,683)	($43,571)	($28,680)	($25,663)

STATEMENTS_OF_CASH_FLOWS

STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities	'	'	'
Net income (loss)	$1,888	($14,891)	($3,017)
Adjustments to reconcile net loss to net cash used in operating activities:	'	'	'
Exploration and abandonment	0	10,461	0
Depreciation, depletion, and accretion	1,761	1,868	1,868
Impairment of proved oil and gas properties	1,231	2,250	0
Gain on sale of assets	-7,145	0	0
Changes in operating assets and liabilities:	'	'	'
Accounts receivable	-310	1,485	-1,131
Accounts payable and accrued liabilities	643	83	542
Net cash (used in)/provided by operating activities	-1,932	1,256	-1,738
Cash flows from investing activities	'	'	'
Restricted cash	-5,000	0	0
Capital expenditures	-1,312	-49	-175
Proceeds from sales of assets	21,548	0	0
Net cash used in investing activities	15,236	-49	-175
Cash flows from financing activities	'	'	'
(Repayments to) advances from parent	-13,304	-1,207	1,913
Net cash (used in)/provided by financing activities	-13,304	-1,207	1,913
Net change in cash and cash equivalents	0	0	0
Cash and cash equivalents, beginning of year	0	0	0
Cash and cash equivalents, end of year	$0	$0	$0

ORGANIZATION_AND_NATURE_OF_OPE

ORGANIZATION AND NATURE OF OPERATIONS	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
ORGANIZATION AND NATURE OF OPERATIONS	'
	ORGANIZATION AND NATURE OF OPERATIONS
	PRC Williston, LLC (the “Company" or “PRC Williston”) is a 87.5% - owned subsidiary of Magnum Hunter Resources Corporation, a Delaware corporation, operating directly and indirectly through its subsidiaries (“Magnum Hunter”, or “Parent”), a Houston, Texas based independent exploration and production company engaged in the acquisition and development of producing properties and undeveloped acreage, the production of oil and natural gas, and certain midstream and oil field service activities in the United States ("U.S."). PRC Williston is engaged in secondary enhanced oil recovery projects in the U.S., and all of its properties are non-operated in the Williston Basin.
	The Company is a limited liability company (“LLC”).  As an LLC, the amount of loss at risk for each individual member is limited to the amount of capital contributed to the LLC, and unless otherwise noted, the individual member’s liability for indebtedness of an LLC is limited to the member’s actual capital contribution.  Magnum Hunter is the sole member of the Company; however, the Company has granted a 12.5% net profits interest.  The net profits interest is functionally equivalent to a nonvoting class of membership interest in that it allows participation in any future distributions in respect of the equity interests of the members of the Company.

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	Basis of Presentation
	Our financial statements are prepared in accordance with accounting principles generally accepted in the United States of America. The preparation of our financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses. These estimates are based on information that is currently available to us and on various other assumptions that we believe to be reasonable under the circumstances. Actual results could differ from those estimates under different assumptions and conditions.  Significant estimates are required for proved oil and gas reserves which, as described below under Estimates of Proved Oil and Gas Reserves, may have a material impact on the carrying value of oil and gas property.
	Divestitures and Discontinued Operations
	Certain balances in the financial statements and disclosures in the footnotes have been revised as a result of the sale of all of the oil and gas assets of PRC Williston, LLC on December 30, 2013. The operating results of PRC Williston, have been reclassified as discontinued operations in the consolidated statements of operations for the years ended December 31, 2013, 2012, and 2011. See "Note 3 - Divestitures and Discontinued Operations".
		Year Ended December 31,
		2013			2012				2011
		(in thousands)
	Revenues	$	7,194		$	7,614			$	8,687
	Expenses	8,868			19,216				6,989
	Loss from discontinued operations before tax	(1,674		)	(11,602		)		1,698
	Income tax benefit (expense)	—			—				—
	Loss from discontinued operations	(1,674		)	(11,602		)		1,698
	Gain on disposal of discontinued operations	7,145			—				—
	Income (loss) from discontinued operations	$	5,471		$	(11,602	)		$	1,698
	Financial Instruments
	The carrying amounts of financial instruments including accounts receivable, accounts payable and accrued liabilities, and accounts payable to Parent approximate fair value as of December 31, 2013 and 2012.
	Oil and Gas Properties
	Capitalized Costs
	Our oil and gas properties consisted of the following:
			December 31,
			2013 (1)			2012
			(in thousands)
	Unproved properties		$	—		$	—
	Proved properties		—			33,800
	Total costs		—			33,800
	Less accumulated depreciation and depletion		—			(15,543		)
	Net capitalized costs		$	—		$	18,257
	________________________________
	(1)    No capitalized costs exist at December 31, 2013 due to the sale of the oil and gas properties of PRC Williston, LLC.
	We follow the successful efforts method of accounting for our oil and gas producing activities. Costs to acquire mineral interests in oil and gas properties and to drill and equip development wells and related asset retirement costs are capitalized. Costs to drill exploratory wells are capitalized pending determination of whether the wells have proved reserves. If we determine that the wells do not have proved reserves, the costs are charged to expense. There were no costs capitalized for exploratory wells pending the determination of proved reserves at either December 31, 2013 or 2012.  Geological and geophysical costs, including seismic studies and costs of carrying and retaining unproved properties are charged to expense as incurred. We capitalize interest on expenditures for significant exploration and development projects that last more than six months while activities are in progress to bring the assets to their intended use.  No interest was capitalized during the periods presented.
	On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depreciation, depletion, and amortization are eliminated from the property accounts, and the resultant gain or loss is recognized. On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated depreciation, depletion, and amortization with a resulting gain or loss recognized in income.
	Capitalized amounts attributable to proved oil and gas properties are depleted by the unit-of-production method over proved reserves using the unit conversion ratio of six Mcf of gas to one Bbl of oil and the ratio of forty-two Gal of natural gas liquids to one Bbl of oil.  Well costs and related equipment are depleted over proved developed reserves, and leasehold costs are depleted over total proved reserves.  Depreciation and depletion expense from continuing operations for oil and gas producing property and related equipment was $0 million for the years ended December 31, 2013, 2012, and 2011.
	Capitalized costs related to proved oil and gas properties, including wells and related equipment and facilities, are evaluated for impairment based on an analysis of undiscounted future net cash flows. If undiscounted cash flows are insufficient to recover the net capitalized costs related to proved properties, then we recognize an impairment charge in income from operations equal to the difference between the net capitalized costs related to proved properties and their estimated fair values based on the present value of the related future net cash flows. We recorded $1.2 million of impairment charge to our proved properties during the year ended December 31, 2013, we recorded $2.3 million of impairments for the year ended December 31, 2012 in discontinued operations, and we incurred no impairment charge to our proved properties for the year ended December 31, 2011 based on our analysis.
	Unproved oil and gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment by providing an impairment allowance in the Company’s statement of operations.  We recorded no impairment to unproved properties during the year ended December 31, 2013, and $10.5 million during the year ended December 31, 2012 in discontinued operations. We did not record impairment during the year ended 2011.
	On the sale of an entire interest in an unproved property for cash or cash equivalent, gain or loss on the sale is recognized, taking into consideration the amount of any recorded impairment if the property had been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained.
	Estimates of Proved Oil and Gas Reserves
	Estimates of our proved reserves included in this report are prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) and SEC guidelines. The accuracy of a reserve estimate is a function of:
	·                  the quality and quantity of available data;
	·                  the interpretation of that data;
	·                  the accuracy of various mandated economic assumptions;
	·                  and the judgment of the persons preparing the estimate.
	Our proved reserve information included in this report was predominately based on evaluations prepared by independent petroleum engineers. Estimates prepared by other third parties may be higher or lower than those included herein. Because these estimates depend on many assumptions, all of which may substantially differ from future actual results, reserve estimates will be different from the quantities of oil and gas that are ultimately recovered. In addition, results of drilling, testing and production after the date of an estimate may justify material revisions to the estimate.
	In accordance with SEC requirements, we based the estimated discounted future net cash flows from proved reserves on the unweighted arithmetic average of the prior 12-month commodity prices as of the first day of each of the months constituting the period and costs on the date of the estimate. Future prices and costs may be materially higher or lower than these prices and costs which would impact the estimated value of our reserves.
	The estimates of proved reserves may materially impact depreciation, depletion, and amortization (“DD&A”) expense. If the estimates of proved reserves decline, the rate at which we record depreciation and depletion expense will increase, reducing net income. Such a decline may result from lower estimated market prices.
	Revenue Recognition
	Revenues associated with sales of crude oil, natural gas, natural gas liquids and petroleum products, and other items are recognized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery of goods occurs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry.
	Revenues from the production of natural gas and crude oil properties in which we have an interest with other producers are recognized based on the actual volumes we sold during the period. Any differences between volumes sold and entitlement volumes, based on our net working interest, which are deemed to be non-recoverable through remaining production, are recognized as accounts receivable or accounts payable, as appropriate. Cumulative differences between volumes sold and entitlement volumes are generally not significant.
	Restricted Cash
	On December 23, 2013, the Chancery Court entered a temporary restraining order prohibiting the Company from transferring, assigning, removing, distributing or otherwise displacing to its Parent, or its parent’s creditors, or any other person or entity $5,000,000 of the proceeds received in connection with the sale of the Company’s assets. See “Note 8 - Contingencies.”
	Accounts Receivable
	Accounts receivable consists of oil and gas sales, due under normal trade terms, generally requiring payment within 30 to 60 days of production.  Payments made on all accounts receivable are applied to the earliest unpaid items.  We review our accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible.  Based on our review, no allowance was warranted at either December 31, 2013 or 2012.
	Production Costs
	Production costs, including compressor rental and repair, pumpers’ salaries, saltwater disposal, ad valorem taxes, insurance, repairs and maintenance, expensed workovers and other operating expenses are expensed as incurred and included in lease operating expense on our consolidated statements of operations.
	Severance Tax and Marketing
	Severance taxes comprise production taxes charged by the state of North Dakota on oil and natural gas produced.  These taxes are computed on the basis of volumes and/or value of production or sales.  These taxes are usually levied at the time and place the minerals are severed from the producing reservoir.  Marketing costs are those directly associated with marketing our production and are based on volumes produced.
	Exploration and Abandonments
	Exploration expenses include dry hole costs, delay rentals, and geological and geophysical costs. Abandonment costs are charges to leasehold costs associated with properties that we chose not to develop and impair such costs.
	Dependence on Major Customers
	For the years ended December 31, 2013, 2012, and 2011, we sold 48%; 99%; and 98%, respectively, of our oil and gas produced to Plains Marketing, L.P. (“Plains”), a subsidiary of Plains All American Pipeline, L.P. Additionally, substantially all of our accounts receivable related to oil and gas sales were due from Plains at December 31, 2013 and 2012. For the year ended December 31, 2013, we sold 52% of our oil and gas produced to Trafigura Limited. We believe that there are potential alternative purchasers and that it may be necessary to establish relationships with new purchasers if our production grows. However, there can be no assurance that we can establish such relationships and that those relationships will result in increased purchasers. Although we are exposed to a concentration of credit risk, we believe that Plains and Trafigura are credit worthy.
	Dependence on Suppliers
	Our industry is cyclical, and from time to time there is a shortage of drilling rigs, fracture stimulation services, equipment, supplies and qualified personnel. During these periods, the costs and delivery times of rigs, equipment and supplies are substantially greater. If the unavailability or high cost of drilling rigs, equipment, supplies or qualified personnel were particularly severe in the areas where we operate, we could be materially and adversely affected. We believe that there are potential alternative providers of drilling services and that it may be necessary to establish relationships with new contractors as our activity level and capital program grows. However, there can be no assurance that we can establish such relationships and that those relationships will result in increased availability of drilling rigs.
	Accounts Payable to Parent
In accordance with revolving credit agreement between the Company and its Parent, the Parent has loaned funds to the Company to i) pay off third party debt, ii) fund operations, principally joint interest billings offset by revenue receipts, and iii) fund the development of oil and gas properties. As of December 31, 2013 and 2012, the Company has an outstanding liability owed to its Parent in the amount of $45.7 million and $59.0 million, respectively. See “Note 5- Related Party Transactions.”
Asset Retirement Obligation
Our asset retirement obligation represents the present value of the estimated amount we will incur to plug, abandon and remediate our producing properties at the end of their productive lives, in accordance with applicable federal, state and local laws. We determine our asset retirement obligation by calculating the present value of estimated cash flows related to the liability. The retirement obligation is recorded as a liability at its estimated present value as of the asset’s inception, with an offsetting increase to proved properties. Periodic accretion of discount of the estimated liability is recorded as accretion expense in the consolidated statements of operations.
Our liability is determined using significant assumptions, including current estimates of plugging and abandonment costs, annual inflation of these costs, the productive lives of wells and our risk-adjusted interest rate. Changes in any of these assumptions can result in significant revisions to the estimated asset retirement obligation. See “Note 4 — Asset Retirement Obligations” to our financial statements for more information.
Income Taxes
The Company is not subject to federal income taxes and does not have a tax sharing agreement or allocate taxes with its member.  Therefore, no provision has been made for federal or state income taxes on the Company’s books.  It is the responsibility of the member to report its share of taxable income or loss on its separate income tax return.  Accordingly, no recognition has been given to federal or state income taxes in the accompanying financial statements.
Based on management’s analysis, the Company did not have any uncertain tax positions as of December 31, 2013 or 2012.  The Company’s income tax returns for the periods subsequent to December 31, 2009 remain open for examination by taxing authorities.  Interest and penalties, and the associated tax expense related to uncertain tax positions, when applicable, will be recorded in income tax expense as the positions are recognized.  At December 31, 2013, and 2012, there were no material income tax interest or penalty items recorded in the statement of operations or as a liability on the balance sheet.

DIVESTITURES_AND_DISCONTINEUD_

DIVESTITURES AND DISCONTINEUD OPERATIONS (Notes)	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
DIVESTITURES AND DISCONTINUED OPERATIONS	'
	DIVESTITURES AND DISCONTINUED OPERATIONS
	Sale of Assets of PRC Williston, LLC and Williston Hunter ND, LLC
	On December 30, 2013, PRC Williston (together with its affiliate Williston Hunter) closed on the sale of all of their oil and gas assets to Enduro Operating, LLC for a total purchase price of approximately $44.1 million in cash, after initial purchase price adjustments, of which $21.9 million was attributed to the Company, such proceeds being allocated according to Magnum Hunter's working interest in the assets sold. The effective date of the sale was September 1, 2013. PRC Williston has recognized a preliminary gain on the sale of $7.1 million.

ASSET_RETIREMENT_OBLIGATION

ASSET RETIREMENT OBLIGATION	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
ASSET RETIREMENT OBLIGATION	'
	ASSET RETIREMENT OBLIGATIONS
	The Company accounts for asset retirement obligations based on the guidance of ASC 410 which addresses accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs.  ASC 410 requires that the fair value of a liability for an asset’s retirement obligation be recorded in the period in which it is incurred and the corresponding cost capitalized by increasing the carrying amount of the related long-lived asset.  The liability is accreted to its present value each period, and the capitalized cost is depreciated over the estimated useful life of the related asset.  Both the accretion of the liability and the depreciation of the asset are included in DD&A.  We have included estimated future costs of abandonment and dismantlement in our successful efforts oil and gas properties base and deplete these costs as a component of our DD&A expense in the accompanying financial statements.
	The following table summarizes the Company’s asset retirement obligation transactions during the years ended December 31:
		Year Ended December 31,
		(in thousands)
		2013			2012
	Asset retirement obligation at beginning of period	$	2,163		$	1,983
	Accretion expense	126			180
	Revisions in estimated liabilities	48			—
	Liabilities incurred	7			—
	Liabilities sold	(2,344		)	—
	Asset retirement obligation at end of period	—			2,163
	Less: current portion	—			(889		)
	Asset retirement obligation at end of period	$	—		$	1,274

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
RELATED PARTY TRANSACTIONS	'
	RELATED PARTY TRANSACTIONS
	The Company and its parent, Magnum Hunter, have an arrangement whereby Magnum Hunter provides funding to the Company for costs of developing oil and gas properties and Magnum Hunter allocates interest expense and general and administrative expenses to the Company.  The allocation of interest expense is computed based on the amount funded to the Company multiplied by the interest rate applicable to Magnum Hunter’s revolving credit facility.  The effective interest rate due by the Company to Magnum Hunter was approximately 3.42%, 3.56%, and 3.55% for the years ended December 31, 2013, 2012, and 2011, respectively.  The interest expense allocated to PRC Williston was $1.9 million, $2.1 million, and $2.1 million, for the years ended December 31, 2013, 2012, and 2011, respectively.  Accrued interest is included in accounts payable due to Parent.  General and administrative expenses are allocated to the Company from Magnum Hunter on a pro rata basis relating to the Company’s revenues in proportion to the consolidated oil and gas sales of Magnum Hunter and all its subsidiaries.  The general and administrative expense allocated to PRC Williston was $1.7 million, $1.2 million, and $2.7 million for the years ended December 31, 2013, 2012, and 2011, respectively.  The accumulated charges from the general and administrative expense allocation are included in accounts payable due to Parent.  At December 31, 2013, the balance due to Magnum Hunter was $45.7 million, and the balance was $59.0 million as of December 31, 2012.
	Accumulated interest and general and administrative expense allocated to PRC Williston are included in accounts payable due to Parent. At December 31, 2013, the balance due to Magnum Hunter was $45.7 million, and $59.0 million at December 31, 2012.

GUARANTEE

GUARANTEE	12 Months Ended
	Dec. 31, 2013
Guarantees [Abstract]	'
GUARANTEE	'
	GUARANTEE
	On May 16, 2012, the Company was named a guarantor subsidiary to the Senior Notes issued by the Parent, which are due November 2020.  The Senior Notes were issued by the Parent pursuant to an indenture entered into on May 16, 2012 as supplemented, among the Parent, the subsidiary guarantors party thereto, Wilmington Trust, National Association, as the trustee, and Citibank, N.A., as the paying agent, registrar and authenticating agent.  The terms of the Senior Notes are governed by the indenture, which contains affirmative and restrictive covenants that, among other things, limit the Parent’s and the guarantors’ ability to incur or guarantee additional indebtedness or issue certain preferred stock; pay dividends on capital stock or redeem, repurchase or retire capital stock or subordinated indebtedness or make certain other restricted payments; transfer or sell assets; make loans and other investments; create or permit to exist certain liens; enter into agreements that restrict dividends or other payments from restricted subsidiaries to the Company; consolidate, merge or transfer all or substantially all of their assets; engage in transactions with affiliates; and create unrestricted subsidiaries.
	The indenture also contains events of default.  Upon the occurrence of events of default arising from certain events of bankruptcy or insolvency, the Senior Notes shall become due and payable immediately without any declaration or other act of the trustee or the holders of the Senior Notes.  Upon the occurrence of certain other events of default, the trustee or the holders of at least 25% in aggregate principal amount of the then outstanding Senior Notes may declare all outstanding Senior Notes to be due and payable immediately.
	The Parent had $600.0 million in principal outstanding under the Senior Notes as of December 31, 2013.  The Company shares joint and several liability with other guaranteeing subsidiaries of the Parent, and the Company does not expect the default provisions to require recourse to the lenders.  As such, the Company cannot estimate any potential loss as a result of the guarantee of indebtedness of the Parent. In January 2014, the Company ceased to be a guarantor subsidiary. See “Note 9 - Subsequent Events.”

SUPPLEMENTAL_OIL_AND_GAS_DISCL

SUPPLEMENTAL OIL AND GAS DISCLOSURES (UNAUDITED) (Notes)	12 Months Ended
	Dec. 31, 2013
Extractive Industries [Abstract]	'
SUPPLMENTAL OIL AND GAS DISCLOSURES (UNAUDITED)	'
	SUPPLEMENTAL OIL AND GAS DISCLOSURES (UNAUDITED)
	The following table sets forth the costs incurred in oil and gas property acquisition, exploration, and development activities.
		2013				2012			2011
		(in thousands)
	Acquisition costs	$	2			$	—		$	—
	Exploration costs	—				—			—
	Development costs	1,355				49			—
		$	1,357			$	49		$	—
	Oil and Gas Reserve Information
	Proved oil and gas reserve quantities are based on estimates prepared by Magnum Hunter’s third party reservoir engineering firms. There are numerous uncertainties inherent in estimating quantities of proved reserves and projecting future rates of production and timing of development expenditures. The following reserve data only represent estimates and should not be construed as being exact.
	Total Proved Reserves
		Crude oil and Condensate			Natural Gas
		MBbl			MMcf
	Balances January 1, 2011	2,416			558
	Extensions, discoveries and other additions	(195	)		119
	Production	(103	)		(82	)
	Balances December 31, 2011	2,118			595
	Revisions of previous estimates	15			65
	Production	(98	)		(69	)
	Balances December 31, 2012	2,035			591
	Revisions of previous estimates	—			—
	Sale of assets	(1,945	)		(543	)
	Production	(90	)		(48	)
	Balances December 31, 2013	—			—
	Developed reserves, included above
	31-Dec-11	1,209			594
	31-Dec-12	1,170			591
	31-Dec-13	—			—
	Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves
	The standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves and the changes in standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves were prepared in accordance with current provisions of ASC 932.  Future cash inflows at December 31, 2013, 2012, and 2011 were computed by applying the unweighted, arithmetic average on the closing price on the first day of each month for the 12-month period prior to December 31, 2013, 2012, and 2011 to estimated future production.  Future production and development costs are computed by estimating the expenditures to be incurred in developing and producing the proved oil and natural gas reserves at year-end, based on year-end costs and assuming continuation of existing economic conditions.
	The standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves are as follows:
		as of December 31,
		2013				2012			2011
		(in thousands)
	Future cash inflows	$	—			$	159,290		$	185,867
	Future production costs	—				(60,207		)	(79,959		)
	Future development costs	—				(6,966		)	(7,192		)
	Future net cash flows	—				92,117			98,716
	10% annual discount for estimated timing of cash flows	—				(48,287		)	(47,401		)
	Standardized measure of discounted future net cash flows	$	—			$	43,830		$	51,315
	Changes in Standardized Measure of Discounted Future Net Cash Flows
	The changes in the standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves are as follows:
		Year Ended December 31,
		2013				2012			2011
		(in thousands)
	Balances, beginning of period	$	43,830			$	51,315		$	46,565
	Net change in sales and transfer prices and in production (lifting) costs related to future production	—				(1,454		)	9,324
	Changes in estimated future development costs	—				108			1,074
	Sales and transfers of oil and gas produced during the period	(1,337		)		(2,650		)	(3,566		)
	Net change due to revisions in quantity estimates	—				571			(5,846		)
	Previously estimated development costs incurred during the period	(1,357		)		—			—
	Accretion of discount	—				5,132			4,656
	Sales of minerals in place	(41,136		)		—			—
	Changes in timing and other	—				(9,192		)	(892		)
	Standardized measure of discounted future net cash flows	$	—			$	43,830		$	51,315
	The commodity prices inclusive of adjustments for quality and location used in determining future net revenues related to the standardized measure calculation are as follows.
		2013				2012			2011
	Oil (per Bbl)	$	—			$	77.9		$	86.86
	Gas (per Mcf)	$	—			$	1.24		$	3.11

CONTINGENCIES_Notes

CONTINGENCIES (Notes)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Contingencies	'
	NOTE 8 — CONTINGENCIES
	On December 16, 2013, Drawbridge Special Opportunities Fund LP (“Drawbridge”) and Fortress Value Recovery Fund I LLC f/k/a D.B. Zwirn Special Opportunities Fund, L.P. (“Fortress”) (collectively, “Plaintiffs”) filed suit against PRC Williston LLC in the Court of Chancery of the State of Delaware in a case captioned C.A. No. 9166-VCL, Drawbridge Special Opportunities Fund LP and Fortress Value Recovery Fund I LLC f/k/a D.B. Zwirn Special Opportunities Fund, L.P. v. PRC Williston LLC.  Plaintiffs allege that they are entitled to a 12.5% collective interest in any distributions in respect of the equity interests of the members of the Company.  Their claims are based on Participation Agreements entered into between PRC Williston and the Plaintiffs in February 2007 in connection with the Plaintiffs extending credit to PRC Williston pursuant to a credit agreement.  Plaintiffs claim that they are entitled to compensation for 12.5% of alleged past distributions on equity from PRC Williston to Magnum Hunter Resources Corporation (“Magnum Hunter”), as well as to receive 12.5% of any transfers of funds to Magnum Hunter from the proceeds of the December 30, 2013 sale of PRC Williston’s assets for approximately $21.9 million.  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 million of the proceeds received by PRC Williston in connection with the sale of PRC Williston’s assets to Enduro Operating LLC.  The Court also granted Plaintiffs’ motion for expedited proceedings, ordering expedited discovery and a hearing within 90 days on Plaintiffs’ motion for a preliminary injunction.  Plaintiffs’ motion for a preliminary injunction effectively seeks to extend the relief granted by the temporary restraining order until after a full trial on the merits.  A hearing on Plaintiffs’ motion for a preliminary injunction is scheduled to occur on March 18, 2014.  The Company believes the claim is without merit and intends to vigorously defend the lawsuit.

SUBSEQUENT_EVENTS_Notes

SUBSEQUENT EVENTS (Notes)	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	NOTE 9 — SUBSEQUENT EVENTS
	In January 2014, as permitted by the Magnum Hunter debt agreements referred to in clauses (i) and (ii),  the Company ceased to be a guarantor of (i) Magnum Hunter’s indebtedness under Magnum Hunter’s senior revolving credit facility and (ii) Magnum Hunter’s indebtedness under its indenture pursuant to which Magnum Hunter has issued certain senior unsecured notes.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	Our financial statements are prepared in accordance with accounting principles generally accepted in the United States of America. The preparation of our financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses. These estimates are based on information that is currently available to us and on various other assumptions that we believe to be reasonable under the circumstances. Actual results could differ from those estimates under different assumptions and conditions.  Significant estimates are required for proved oil and gas reserves which, as described below under Estimates of Proved Oil and Gas Reserves, may have a material impact on the carrying value of oil and gas property.
Divestitures and Discontinued Operations	'
	Divestitures and Discontinued Operations
	Certain balances in the financial statements and disclosures in the footnotes have been revised as a result of the sale of all of the oil and gas assets of PRC Williston, LLC on December 30, 2013. The operating results of PRC Williston, have been reclassified as discontinued operations in the consolidated statements of operations for the years ended December 31, 2013, 2012, and 2011. See "Note 3 - Divestitures and Discontinued Operations".
		Year Ended December 31,
		2013			2012				2011
		(in thousands)
	Revenues	$	7,194		$	7,614			$	8,687
	Expenses	8,868			19,216				6,989
	Loss from discontinued operations before tax	(1,674		)	(11,602		)		1,698
	Income tax benefit (expense)	—			—				—
	Loss from discontinued operations	(1,674		)	(11,602		)		1,698
	Gain on disposal of discontinued operations	7,145			—				—
	Income (loss) from discontinued operations	$	5,471		$	(11,602	)		$	1,698
	F
Oil and Gas Properties	'
	Oil and Gas Properties
	Capitalized Costs
	Our oil and gas properties consisted of the following:
			December 31,
			2013 (1)			2012
			(in thousands)
	Unproved properties		$	—		$	—
	Proved properties		—			33,800
	Total costs		—			33,800
	Less accumulated depreciation and depletion		—			(15,543		)
	Net capitalized costs		$	—		$	18,257
	________________________________
	(1)    No capitalized costs exist at December 31, 2013 due to the sale of the oil and gas properties of PRC Williston, LLC.
	We follow the successful efforts method of accounting for our oil and gas producing activities. Costs to acquire mineral interests in oil and gas properties and to drill and equip development wells and related asset retirement costs are capitalized. Costs to drill exploratory wells are capitalized pending determination of whether the wells have proved reserves. If we determine that the wells do not have proved reserves, the costs are charged to expense. There were no costs capitalized for exploratory wells pending the determination of proved reserves at either December 31, 2013 or 2012.  Geological and geophysical costs, including seismic studies and costs of carrying and retaining unproved properties are charged to expense as incurred. We capitalize interest on expenditures for significant exploration and development projects that last more than six months while activities are in progress to bring the assets to their intended use.  No interest was capitalized during the periods presented.
	On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depreciation, depletion, and amortization are eliminated from the property accounts, and the resultant gain or loss is recognized. On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated depreciation, depletion, and amortization with a resulting gain or loss recognized in income.
	Capitalized amounts attributable to proved oil and gas properties are depleted by the unit-of-production method over proved reserves using the unit conversion ratio of six Mcf of gas to one Bbl of oil and the ratio of forty-two Gal of natural gas liquids to one Bbl of oil.  Well costs and related equipment are depleted over proved developed reserves, and leasehold costs are depleted over total proved reserves.  Depreciation and depletion expense from continuing operations for oil and gas producing property and related equipment was $0 million for the years ended December 31, 2013, 2012, and 2011.
	Capitalized costs related to proved oil and gas properties, including wells and related equipment and facilities, are evaluated for impairment based on an analysis of undiscounted future net cash flows. If undiscounted cash flows are insufficient to recover the net capitalized costs related to proved properties, then we recognize an impairment charge in income from operations equal to the difference between the net capitalized costs related to proved properties and their estimated fair values based on the present value of the related future net cash flows. We recorded $1.2 million of impairment charge to our proved properties during the year ended December 31, 2013, we recorded $2.3 million of impairments for the year ended December 31, 2012 in discontinued operations, and we incurred no impairment charge to our proved properties for the year ended December 31, 2011 based on our analysis.
	Unproved oil and gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment by providing an impairment allowance in the Company’s statement of operations.  We recorded no impairment to unproved properties during the year ended December 31, 2013, and $10.5 million during the year ended December 31, 2012 in discontinued operations. We did not record impairment during the year ended 2011.
	On the sale of an entire interest in an unproved property for cash or cash equivalent, gain or loss on the sale is recognized, taking into consideration the amount of any recorded impairment if the property had been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained.
Estimates of Proved Oil and Gas Reserves	'
	Estimates of Proved Oil and Gas Reserves
	Estimates of our proved reserves included in this report are prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) and SEC guidelines. The accuracy of a reserve estimate is a function of:
	·                  the quality and quantity of available data;
	·                  the interpretation of that data;
	·                  the accuracy of various mandated economic assumptions;
	·                  and the judgment of the persons preparing the estimate.
	Our proved reserve information included in this report was predominately based on evaluations prepared by independent petroleum engineers. Estimates prepared by other third parties may be higher or lower than those included herein. Because these estimates depend on many assumptions, all of which may substantially differ from future actual results, reserve estimates will be different from the quantities of oil and gas that are ultimately recovered. In addition, results of drilling, testing and production after the date of an estimate may justify material revisions to the estimate.
	In accordance with SEC requirements, we based the estimated discounted future net cash flows from proved reserves on the unweighted arithmetic average of the prior 12-month commodity prices as of the first day of each of the months constituting the period and costs on the date of the estimate. Future prices and costs may be materially higher or lower than these prices and costs which would impact the estimated value of our reserves.
	The estimates of proved reserves may materially impact depreciation, depletion, and amortization (“DD&A”) expense. If the estimates of proved reserves decline, the rate at which we record depreciation and depletion expense will increase, reducing net income. Such a decline may result from lower estimated market prices.
Revenue Recognition	'
	Revenue Recognition
	Revenues associated with sales of crude oil, natural gas, natural gas liquids and petroleum products, and other items are recognized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery of goods occurs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry.
	Revenues from the production of natural gas and crude oil properties in which we have an interest with other producers are recognized based on the actual volumes we sold during the period. Any differences between volumes sold and entitlement volumes, based on our net working interest, which are deemed to be non-recoverable through remaining production, are recognized as accounts receivable or accounts payable, as appropriate. Cumulative differences between volumes sold and entitlement volumes are generally not significant.
Restricted Cash	'
	Restricted Cash
	On December 23, 2013, the Chancery Court entered a temporary restraining order prohibiting the Company from transferring, assigning, removing, distributing or otherwise displacing to its Parent, or its parent’s creditors, or any other person or entity $5,000,000 of the proceeds received in connection with the sale of the Company’s assets. See “Note 8 - Contingencies.”
Accounts Receivable	'
	Accounts Receivable
	Accounts receivable consists of oil and gas sales, due under normal trade terms, generally requiring payment within 30 to 60 days of production.  Payments made on all accounts receivable are applied to the earliest unpaid items.  We review our accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible.
Production Costs	'
	Production Costs
	Production costs, including compressor rental and repair, pumpers’ salaries, saltwater disposal, ad valorem taxes, insurance, repairs and maintenance, expensed workovers and other operating expenses are expensed as incurred and included in lease operating expense on our consolidated statements of operations.
Severance Taxes and Marketing	'
	Severance Tax and Marketing
	Severance taxes comprise production taxes charged by the state of North Dakota on oil and natural gas produced.  These taxes are computed on the basis of volumes and/or value of production or sales.  These taxes are usually levied at the time and place the minerals are severed from the producing reservoir.  Marketing costs are those directly associated with marketing our production and are based on volumes produced.
Exploration and Abandonments	'
	Exploration and Abandonments
	Exploration expenses include dry hole costs, delay rentals, and geological and geophysical costs. Abandonment costs are charges to leasehold costs associated with properties that we chose not to develop and impair such costs.
Dependence on Major Customers	'
	Dependence on Major Customers
	For the years ended December 31, 2013, 2012, and 2011, we sold 48%; 99%; and 98%, respectively, of our oil and gas produced to Plains Marketing, L.P. (“Plains”), a subsidiary of Plains All American Pipeline, L.P. Additionally, substantially all of our accounts receivable related to oil and gas sales were due from Plains at December 31, 2013 and 2012. For the year ended December 31, 2013, we sold 52% of our oil and gas produced to Trafigura Limited. We believe that there are potential alternative purchasers and that it may be necessary to establish relationships with new purchasers if our production grows. However, there can be no assurance that we can establish such relationships and that those relationships will result in increased purchasers. Although we are exposed to a concentration of credit risk, we believe that Plains and Trafigura are credit worthy.
Dependence on Suppliers	'
	Dependence on Suppliers
	Our industry is cyclical, and from time to time there is a shortage of drilling rigs, fracture stimulation services, equipment, supplies and qualified personnel. During these periods, the costs and delivery times of rigs, equipment and supplies are substantially greater. If the unavailability or high cost of drilling rigs, equipment, supplies or qualified personnel were particularly severe in the areas where we operate, we could be materially and adversely affected. We believe that there are potential alternative providers of drilling services and that it may be necessary to establish relationships with new contractors as our activity level and capital program grows. However, there can be no assurance that we can establish such relationships and that those relationships will result in increased availability of drilling rigs.
Asset Retirement Obligations	'
	Asset Retirement Obligation
	Our asset retirement obligation represents the present value of the estimated amount we will incur to plug, abandon and remediate our producing properties at the end of their productive lives, in accordance with applicable federal, state and local laws. We determine our asset retirement obligation by calculating the present value of estimated cash flows related to the liability. The retirement obligation is recorded as a liability at its estimated present value as of the asset’s inception, with an offsetting increase to proved properties. Periodic accretion of discount of the estimated liability is recorded as accretion expense in the consolidated statements of operations.
	Our liability is determined using significant assumptions, including current estimates of plugging and abandonment costs, annual inflation of these costs, the productive lives of wells and our risk-adjusted interest rate. Changes in any of these assumptions can result in significant revisions to the estimated asset retirement obligation. See “Note 4 — Asset Retirement Obligations” to our financial statements for more information.
Income Taxes	'
	Income Taxes
	The Company is not subject to federal income taxes and does not have a tax sharing agreement or allocate taxes with its member.  Therefore, no provision has been made for federal or state income taxes on the Company’s books.  It is the responsibility of the member to report its share of taxable income or loss on its separate income tax return.  Accordingly, no recognition has been given to federal or state income taxes in the accompanying financial statements.
	Based on management’s analysis, the Company did not have any uncertain tax positions as of December 31, 2013 or 2012.  The Company’s income tax returns for the periods subsequent to December 31, 2009 remain open for examination by taxing authorities.  Interest and penalties, and the associated tax expense related to uncertain tax positions, when applicable, will be recorded in income tax expense as the positions are recognized.

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Discontinued Operations	'
		Year Ended December 31,
		2013			2012				2011
		(in thousands)
	Revenues	$	7,194		$	7,614			$	8,687
	Expenses	8,868			19,216				6,989
	Loss from discontinued operations before tax	(1,674		)	(11,602		)		1,698
	Income tax benefit (expense)	—			—				—
	Loss from discontinued operations	(1,674		)	(11,602		)		1,698
	Gain on disposal of discontinued operations	7,145			—				—
	Income (loss) from discontinued operations	$	5,471		$	(11,602	)		$	1,698
Capitalized costs of oil and gas properties	'
	Our oil and gas properties consisted of the following:
			December 31,
			2013 (1)			2012
			(in thousands)
	Unproved properties		$	—		$	—
	Proved properties		—			33,800
	Total costs		—			33,800
	Less accumulated depreciation and depletion		—			(15,543		)
	Net capitalized costs		$	—		$	18,257
	________________________________
	(1)    No capitalized costs exist at December 31, 2013 due to the sale of the oil and gas properties of PRC Williston, LLC.

ASSET_RETIREMENT_OBLIGATION_Ta

ASSET RETIREMENT OBLIGATION (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Schedule of Change in Asset Retirement Obligation	'
	The following table summarizes the Company’s asset retirement obligation transactions during the years ended December 31:
		Year Ended December 31,
		(in thousands)
		2013			2012
	Asset retirement obligation at beginning of period	$	2,163		$	1,983
	Accretion expense	126			180
	Revisions in estimated liabilities	48			—
	Liabilities incurred	7			—
	Liabilities sold	(2,344		)	—
	Asset retirement obligation at end of period	—			2,163
	Less: current portion	—			(889		)
	Asset retirement obligation at end of period	$	—		$	1,274

SUPPLEMENTAL_OIL_AND_GAS_DISCL1

SUPPLEMENTAL OIL AND GAS DISCLOSURES (UNAUDITED) (Tables)	12 Months Ended
	Dec. 31, 2013
Extractive Industries [Abstract]	'
Costs incurred in oil and gas property acquisition, exploration, and development activities	'
	The following table sets forth the costs incurred in oil and gas property acquisition, exploration, and development activities.
		2013				2012			2011
		(in thousands)
	Acquisition costs	$	2			$	—		$	—
	Exploration costs	—				—			—
	Development costs	1,355				49			—
		$	1,357			$	49		$	—
Summary of estimating quantities of proved reserves data	'
	Total Proved Reserves
		Crude oil and Condensate			Natural Gas
		MBbl			MMcf
	Balances January 1, 2011	2,416			558
	Extensions, discoveries and other additions	(195	)		119
	Production	(103	)		(82	)
	Balances December 31, 2011	2,118			595
	Revisions of previous estimates	15			65
	Production	(98	)		(69	)
	Balances December 31, 2012	2,035			591
	Revisions of previous estimates	—			—
	Sale of assets	(1,945	)		(543	)
	Production	(90	)		(48	)
	Balances December 31, 2013	—			—
	Developed reserves, included above
	31-Dec-11	1,209			594
	31-Dec-12	1,170			591
	31-Dec-13	—			—
Details of standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves	'
	The standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves are as follows:
		as of December 31,
		2013				2012			2011
		(in thousands)
	Future cash inflows	$	—			$	159,290		$	185,867
	Future production costs	—				(60,207		)	(79,959		)
	Future development costs	—				(6,966		)	(7,192		)
	Future net cash flows	—				92,117			98,716
	10% annual discount for estimated timing of cash flows	—				(48,287		)	(47,401		)
	Standardized measure of discounted future net cash flows	$	—			$	43,830		$	51,315
Changes in standardized measure of discounted future net cash flow relating to proved oil and gas reserves	'
	The changes in the standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves are as follows:
		Year Ended December 31,
		2013				2012			2011
		(in thousands)
	Balances, beginning of period	$	43,830			$	51,315		$	46,565
	Net change in sales and transfer prices and in production (lifting) costs related to future production	—				(1,454		)	9,324
	Changes in estimated future development costs	—				108			1,074
	Sales and transfers of oil and gas produced during the period	(1,337		)		(2,650		)	(3,566		)
	Net change due to revisions in quantity estimates	—				571			(5,846		)
	Previously estimated development costs incurred during the period	(1,357		)		—			—
	Accretion of discount	—				5,132			4,656
	Sales of minerals in place	(41,136		)		—			—
	Changes in timing and other	—				(9,192		)	(892		)
	Standardized measure of discounted future net cash flows	$	—			$	43,830		$	51,315
Standardized measure to calculate future net revenues	'
	The commodity prices inclusive of adjustments for quality and location used in determining future net revenues related to the standardized measure calculation are as follows.
		2013				2012			2011
	Oil (per Bbl)	$	—			$	77.9		$	86.86
	Gas (per Mcf)	$	—			$	1.24		$	3.11

ORGANIZATION_AND_NATURE_OF_OPE1

ORGANIZATION AND NATURE OF OPERATIONS (Details)	Dec. 31, 2013
Entity Information [Line Items]	'
Net profit interest percentage granted	12.50%
Magnum Hunter Resources Corporation [Member]	'
Entity Information [Line Items]	'
Percentage owned by parent	87.50%

SUMMARY_OF_SIGNIFICANT_ACCOUNT3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	gal
	Mcf
Oil and Gas Properties	'	'	'
Depletion, unit conversion ratio (Mcf per Bbl)	6	'	'
Depletion, unit conversion ratio (Gal per Bbl)	42	'	'
Depreciation, Depletion and Amortization	$0	$0	$0
Impairment of proved oil and gas properties	1,231,000	2,250,000	0
Restricted cash	5,000,000	0	'
Proved Properties	'	'	'
Oil and Gas Properties	'	'	'
Impairment of proved oil and gas properties	1,200,000	'	0
Unproved Properties	'	'	'
Oil and Gas Properties	'	'	'
Impairment of proved oil and gas properties	0	'	0
Discontinued Operations [Member] | Proved Properties	'	'	'
Oil and Gas Properties	'	'	'
Impairment of proved oil and gas properties	'	2,300,000	'
Discontinued Operations [Member] | Unproved Properties	'	'	'
Oil and Gas Properties	'	'	'
Impairment of proved oil and gas properties	'	$10,500,000	'
Minimum	'	'	'
Oil and Gas Properties	'	'	'
Collection period of accounts receivable	'30 days	'	'
Maximum [Member]	'	'	'
Oil and Gas Properties	'	'	'
Collection period of accounts receivable	'60 days	'	'

SUMMARY_OF_SIGNIFICANT_ACCOUNT4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - DISCONTINUED OPERATIONS (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accounting Policies [Abstract]	'	'	'
Revenues	$7,194	$7,614	$8,687
Expenses	8,868	19,216	6,989
Loss from discontinued operations, before tax	-1,674	-11,602	1,698
Income tax benefit (expense)	0	0	0
Loss from discontinued operations	-1,674	-11,602	1,698
Gain on sale of discontinued operations	7,145	0	0
Income (loss) from discontinued operations	$5,471	($11,602)	$1,698

SUMMARY_OF_SIGNIFICANT_ACCOUNT5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - CAPITALIZED COSTS (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Accounting Policies [Abstract]	'		'
Unproved properties	$0	[1]	$0
Proved properties	0	[1]	33,800
Total costs	0	[1]	33,800
Less accumulated depreciation and depletion	0	[1]	-15,543
Net capitalized costs	$0	[1]	$18,257
[1]	No capitalized costs exist at December 31, 2013 due to the sale of the oil and gas properties of PRC Williston, LLC.

SUMMARY_OF_SIGNIFICANT_ACCOUNT6

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - MAJOR CUSTOMERS (Details) (Sales [Member], Customer Concentration Risk [Member])	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Plains Marketing, LP [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	48.00%	99.00%	98.00%
Trafigura [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	52.00%	'	'

SUMMARY_OF_SIGNIFICANT_ACCOUNT7

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - ACCOUNTS PAYABLE TO PARENT (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Related Party Transaction [Line Items]	'	'
Accounts payable due to Parent	$45,661	$58,966
Magnum Hunter	'	'
Related Party Transaction [Line Items]	'	'
Accounts payable due to Parent	$45,700	$59,000

DIVESTITURES_AND_DISCONTINEUD_1

DIVESTITURES AND DISCONTINEUD OPERATIONS (Details) (USD $)	0 Months Ended	12 Months Ended
	Dec. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Proceeds from Divestiture of Interest in Consolidated Subsidiaries	$21,900,000	'	'	'
Gain on sale of discontinued operations	'	7,145,000	0	0
PRC Wiliston LLC [Member] | Magnum Hunter Resources Corporation [Member]	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Proceeds from Divestiture of Interest in Consolidated Subsidiaries	$44,100,000	'	'	'

ASSET_RETIREMENT_OBLIGATION_De

ASSET RETIREMENT OBLIGATION (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligation, Roll Forward Analysis	'	'
Asset retirement obligation at beginning of period	$2,163	$1,983
Accretion expense	126	180
Revisions in estimated liabilities	48	0
Liabilities incurred	7	0
Liabilities sold	-2,344	0
Asset retirement obligation at end of period	0	2,163
Less: current portion	0	-889
Asset retirement obligation at end of period	$0	$1,274

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Related Party Transaction [Line Items]	'	'	'
Accounts payable due to Parent	$45,661,000	$58,966,000	'
Magnum Hunter	'	'	'
Related Party Transaction [Line Items]	'	'	'
Related party, effective interest rate	3.42%	3.56%	3.55%
Related party, interest expense	1,900,000	2,100,000	2,100,000
Related party, selling, general and administrative expense	1,700,000	1,200,000	2,700,000
Accounts payable due to Parent	$45,700,000	$59,000,000	'

RELATED_PARTY_TRANSACTIONS_EXP

RELATED PARTY TRANSACTIONS - EXPENSES (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Related Party Transaction [Line Items]	'	'	'
Interest Expense	($1,928)	($2,092)	($2,065)
General and Administrative Expense	$1,655	$1,197	$2,650

GUARANTEE_Details

GUARANTEE (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Minimum	'
Guarantor Obligations	'
Debt, trustee or holders percentage of principal able to decrease debt due or payable immediately	25.00%
Indirect Guarantee of Indebtedness | Magnum Hunter | Senior Notes	'
Guarantor Obligations	'
Debt principal amount	600

SUPPLEMENTAL_OIL_AND_GAS_DISCL2

SUPPLEMENTAL OIL AND GAS DISCLOSURES (UNAUDITED) - COSTS INCURRED (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Extractive Industries [Abstract]	'	'	'
Acquisition costs	$2	$0	$0
Exploration costs	0	0	0
Development costs	1,355	49	0
Total costs incurred	$1,357	$49	$0

SUPPLEMENTAL_OIL_AND_GAS_DISCL3

SUPPLEMENTAL OIL AND GAS DISCLOSURES (UNAUDITED) - TOTAL PROVED RESERVES (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MBbls	MBbls	MBbls
Crude Oil and NGL [Member]	'	'	'
Summary of estimating quantities of proved reserves data	'	'	'
Beginning balance	2,035,000	2,118,000	2,416,000
Extensions, discoveries, and other additions	'	'	-195,000
Revisions of previous estimates	0	15,000	'
Sale of assets	-1,945,000	'	'
Production	-90,000	-98,000	-103,000
Ending balance	0	2,035,000	2,118,000
Developed reserves	0	1,170,000	1,209,000
Natural Gas [Member]	'	'	'
Summary of estimating quantities of proved reserves data	'	'	'
Beginning balance	591,000	595,000	558,000
Extensions, discoveries, and other additions	'	'	119,000
Revisions of previous estimates	0	65,000	'
Sale of assets	-543,000	'	'
Production	-48,000	-69,000	-82,000
Ending balance	0	591,000	595,000
Developed reserves	0	591,000	594,000

SUPPLEMENTAL_OIL_AND_GAS_DISCL4

SUPPLEMENTAL OIL AND GAS DISCLOSURES (UNAUDITED) - DISCOUNTED CASH FLOWS (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Extractive Industries [Abstract]	'	'	'
Future cash inflows	$0	$159,290	$185,867
Future production costs	0	-60,207	-79,959
Future development costs	0	-6,966	-7,192
Future net cash flows	0	92,117	98,716
10% annual discount for estimated timing of cash flows	0	-48,287	-47,401
Standardized measure of discounted future net cash flows	$0	$43,830	$51,315

SUPPLEMENTAL_OIL_AND_GAS_DISCL5

SUPPLEMENTAL OIL AND GAS DISCLOSURES (UNAUDITED) - CHANGES IN STANDARDIZED MEASURE OF CASH FLOWS (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Changes in standardized measure of discounted future net cash flow relating to proved oil and gas reserves	'	'	'
Balances, beginning of period	$43,830	$51,315	$46,565
Net change in sales and transfer prices and in production (lifting) costs related to future production	0	-1,454	9,324
Changes in estimated future development costs	0	108	1,074
Sales and transfers of oil and gas produced during the period	-1,337	-2,650	-3,566
Net change due to revisions in quantity estimates	0	571	-5,846
Previously estimated development costs incurred during the period	-1,357	0	0
Accretion of discount	0	5,132	4,656
Sales of minerals in place	-41,136	0	0
Changes in timing and other	0	-9,192	-892
Standardized measure of discounted future net cash flows	$0	$43,830	$51,315

SUPPLEMENTAL_OIL_AND_GAS_DISCL6

SUPPLEMENTAL OIL AND GAS DISCLOSURES (UNAUDITED) - COMMODITY PRICES (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Oil (per Bbl) [Member]	'	'	'
Average Sales Price and Production Costs Per Unit of Production [Line Items]	'	'	'
Commodity prices inclusive of adjustments for quality and location	0	77,900	86,860
Gas (per Mcf) [Member]	'	'	'
Average Sales Price and Production Costs Per Unit of Production [Line Items]	'	'	'
Commodity prices inclusive of adjustments for quality and location	0	1,240	3,110

CONTINGENCIES_Details

CONTINGENCIES (Details) (USD $)	0 Months Ended			0 Months Ended
	Dec. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 30, 2013	Dec. 23, 2013	Dec. 16, 2013
				C.A. No. 9166-VCL [Member]	C.A. No. 9166-VCL [Member]	C.A. No. 9166-VCL [Member]
Loss Contingencies [Line Items]	'	'	'	'	'	'
Damages sought, percent of collective interest in any distributions on equity made by PRC	'	'	'	'	'	12.50%
Damages sought, percent of transfers of funds to Magnum Hunter from the proceeds of the sale of PRC's assets	'	'	'	'	'	12.50%
Proceeds from sale of assets	$21,900,000	'	'	$21,900,000	'	'
Restricted cash	'	$5,000,000	$0	'	$5,000,000	'
Period of hearing within Plaintiff's motion for a preliminary injunction	'	'	'	'	'90 days	'