Eagle Rock Energy Partners L P (EROC) 10-Q 1 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document	3 Months Ended
	Mar. 31, 2015	Apr. 28, 2015
Entity Information [Line Items]
Entity Registrant Name	EAGLE ROCK ENERGY PARTNERS L P
Entity Central Index Key	1364541
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Amendment Flag	FALSE
Entity Common Stock, Shares Outstanding		152,990,305

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Thousands, unless otherwise specified
CURRENT ASSETS:
Cash and cash equivalents	$37		$1,343
Short-term investments	72,924		153,448
Accounts receivable (a)	32,931	[1]	39,596	[1]
Risk management assets	47,392		44,805
Prepayments and other current assets	11,764		9,911
Total current assets	165,048		249,103
PROPERTY, PLANT AND EQUIPMENT — Net	432,291		487,988
INTANGIBLE ASSETS — Net	3,023		3,072
DEFERRED TAX ASSET	1,805		2,315
RISK MANAGEMENT ASSETS	50,007		46,490
OTHER ASSETS	5,063		5,307
TOTAL	657,237		794,275
CURRENT LIABILITIES:
Accounts payable	38,145		49,226
Accrued liabilities	7,575		8,053
Taxes payable	2,212		2,246
Total current liabilities	47,932		59,525
LONG-TERM DEBT	212,762		263,343
ASSET RETIREMENT OBLIGATIONS	47,575		47,907
DEFERRED TAX LIABILITY	28,921		30,321
OTHER LONG TERM LIABILITIES	5,270		4,709
COMMITMENTS AND CONTINGENCIES (Note 12)
MEMBERS' EQUITY (b)	314,777	[2]	388,470	[2]
TOTAL	$657,237		$794,275
[1]	Net of allowance for bad debt of $1,263 as of March 31, 2015 and $1,023 as of December 31, 2014.
[2]	149,027,423 and 150,154,909 common units were issued and outstanding as of March 31, 2015 and December 31, 2014, respectively. These amounts do not include unvested restricted common units granted under the Partnership's long-term incentive plan of 2,121,963 and 2,419,750 as of March 31, 2015 and December 31, 2014, respectively.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets Parenthetical (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, except Share data, unless otherwise specified
Allowance for doubtful accounts	$1,263	$1,023
Common stock, units issued	149,027,423	150,154,909
Common stock, units outstanding	149,027,423	150,154,909
Unvested Restricted Units granted	2,121,963	2,419,750

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
REVENUE:
Natural gas, natural gas liquids, oil, condensate and sulfur	$29,513	$55,084
Commodity risk management gains (losses), net	22,600	-10,033
Other revenue	9	152
Total revenue	52,122	45,203
COSTS AND EXPENSES:
Operations and maintenance	10,082	11,498
Taxes other than income	1,388	3,791
General and administrative	10,989	13,290
Impairment	68,344	0
Depreciation, depletion and amortization	14,645	20,406
Total costs and expenses	105,448	48,985
OPERATING LOSS	-53,326	-3,782
OTHER (EXPENSE) INCOME:
Interest expense, net	-2,318	-4,754
Interest rate risk management losses, net	-3,066	-290
Loss on short-term investments	-2,004	0
Other income, net	2,135	1
Total other (expense) income	-5,253	-5,043
LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	-58,579	-8,825
INCOME TAX BENEFIT	-826	-865
LOSS FROM CONTINUING OPERATIONS	-57,753	-7,960
DISCONTINUED OPERATIONS, NET OF TAX	-966	-10,603
NET LOSS	($58,719)	($18,563)
NET LOSS PER COMMON UNIT—BASIC AND DILUTED:
Income (loss) from continuing operations per common unit - Basic	($0.39)	($0.05)
Income (loss) from continuing operations per common unit - Diluted	($0.39)	($0.05)
Discontinued operations per common unit - Basic	($0.01)	($0.07)
Discontinued operations per common unit - Diluted	($0.01)	($0.07)
Net income (loss) per common unit - Basic	($0.40)	($0.12)
Net income (loss) per common unit - Diluted	($0.40)	($0.12)
Weighted Average Number of Shares Outstanding Basic and Diluted
Weighted average common units outstanding - Basic	149,143	156,644
Weighted average common units outstanding - Diluted	149,143	156,644

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income Statement (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Net loss	($58,719)	($18,563)
Loss on short-term investments	-3,603	0
COMPREHENSIVE LOSS	($62,322)	($18,563)

Consolidated_Statement_of_Memb

Consolidated Statement of Member's Equity (USD $)	Total	Number of Common Units [Member]	Common Units [Member]	Accumulated Other Comprehensive Income (Loss) [Member]
In Thousands, except Share data, unless otherwise specified	USD ($)		USD ($)	USD ($)
Members' Equity - Beginning Balance at Dec. 31, 2014	$388,470		$388,470	$0
Beginning Balance - Units Outstanding at Dec. 31, 2014	150,154,909	150,154,909
Increase (Decrease) in Members' Equity [Roll Forward]
Net loss	-58,719		-58,719
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	-3,603
Distributions	-10,565		-10,565
Vesting of restricted units		60,700
Stock Repurchased During Period, Shares		1,188,186
Stock Repurchased During Period, Value	2,662		2,662
Share Based Compensation, Aggregate Amount	1,856		1,856
Members' Equity - Ending Balance at Mar. 31, 2015	$314,777		$318,380	($3,603)
Ending Balance - Units Outstanding at Mar. 31, 2015	149,027,423	149,027,423

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	($58,719)	($18,563)
Adjustments to reconcile net loss to net cash provided by operating activities:
Discontinued operations	966	10,603
Depreciation, depletion and amortization	14,645	20,406
Impairment	68,344	0
Amortization of debt issuance costs	264	659
(Gain) loss from risk management activities, net	-19,534	10,323
Derivative settlements	14,370	-3,138
Equity-based compensation	1,856	2,583
Loss on short-term investments	2,004	0
Other	-887	151
Changes in assets and liabilities—net of acquisitions:
Accounts receivable	4,039	-11,636
Prepayments and other current assets	-1,853	-6,068
Accounts payable	-9,555	2,795
Accrued liabilities	-435	16,636
Other assets	-3	-117
Other current liabilities	-775	-831
Net cash provided by operating activities	14,727	23,803
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to property, plant and equipment	-28,055	-42,282
Proceeds from Sale of Short-term Investments	77,755	0
Net cash provided by (used in) investing activities	49,700	-42,282
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term debt	45,300	144,250
Repayment of long-term debt	-95,900	-127,050
Payment of debt issuance costs	0	205
Proceeds from derivative contracts	-940	-1,708
Repurchase of common units	-2,662	0
Distributions to members and affiliates	-10,565	-23,801
Net cash used in financing activities	-64,767	-8,514
CASH FLOWS FROM DISCONTINUED OPERATIONS:
Operating activities	-966	44,750
Investing activities	0	-12,210
Net cash (used in) provided by discontinued operations	-966	32,540
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS	-1,306	5,547
CASH AND CASH EQUIVALENTS—Beginning of period	1,343	76
CASH AND CASH EQUIVALENTS—End of period	37	5,623
NONCASH INVESTING AND FINANCING ACTIVITIES:
Investments in property, plant and equipment, not paid	10,627	6,241
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:
Interest paid—net of amounts capitalized	999	5,558
Cash paid for taxes	$98	$0

Organization_and_Description_o

Organization and Description of Business	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Description of Business	ORGANIZATION AND DESCRIPTION OF BUSINESS
	Description of Business—Eagle Rock Energy Partners, L.P. ("Eagle Rock Energy" or the "Partnership") is a growth-oriented master limited partnership engaged in (a) the exploitation, development and production of oil and natural gas properties and (b) ancillary gathering, compressing, treating, processing and marketing services with respect to its production of natural gas, natural gas liquids ("NGLs"), condensate and crude oil. The Partnership's assets, located primarily in Alabama (where it also operates the associated gathering and processing assets), Texas, Oklahoma, Mississippi and Arkansas, are characterized by long-lived, high-working interest properties with extensive production histories and development opportunities.
	On July 1, 2014, the Partnership contributed its business of gathering, compressing, treating, processing, transporting, marketing and trading natural gas, fractionating, transporting and marketing NGLs and crude oil and condensate logistics and marketing (collectively, the “Midstream Business”) to Regency Energy Partners LP ("Regency") (such contribution, the "Midstream Business Contribution"). Accordingly, prior periods have been retrospectively adjusted to reflect the Midstream Business's operations as discontinued (see Note 16) in the financial statements included in this report. As a result of this transaction, the Partnership only reports as one segment.
	The general partner of Eagle Rock Energy is Eagle Rock Energy GP, L.P., and the general partner of Eagle Rock Energy GP, L.P. is Eagle Rock Energy G&P, LLC (our "general partner"), both of which are wholly owned subsidiaries of the Partnership.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	Basis of Presentation and Principles of Consolidation—The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements presented in the Partnership's Annual Report on Form 10-K for the year ended December 31, 2014 (the "2014 10-K"). In the opinion of management, the accompanying unaudited condensed consolidated financial statements contain all appropriate adjustments, all of which are normally recurring adjustments unless otherwise noted, considered necessary to present fairly the financial position of the Partnership and its consolidated subsidiaries and the results of operations and cash flows for the respective periods. Operating results for the three months ended March 31, 2015 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2015.
	All intercompany accounts and transactions are eliminated in the unaudited condensed consolidated financial statements.
	The Partnership has provided a discussion of significant accounting policies in its 2014 annual report on Form 10-K. Certain items from that discussion are repeated or updated below as necessary to assist in the understanding of these financial statements.
	Use of Estimates—The preparation of financial statements in conformity 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 revenues and expenses during the reported period. Significant estimates are required for proved oil and natural gas reserves, which can affect the carrying value of oil and natural gas properties. The Partnership evaluates its estimates and assumptions on a regular basis. The Partnership bases its estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results could differ from those estimates and such differences could be material.
	Short-term Investments— A portion of the consideration received for the Midstream Business Contribution included Regency common units. These common units have a readily determinable fair value, are being classified as available-for-sale equity securities and are recorded as short-term investments on the unaudited condensed consolidated balance sheets. Unrealized gains and losses associated with increases and decreases in the fair value of these securities are included in other comprehensive income until such time that the gains and losses become realized and then will be included in the unaudited condensed consolidated statements of operations. Losses from declines in fair value determined to be other than temporary are recorded in the unaudited condensed consolidated statements of operations as a loss on short-term investments. Distributions received from Regency as a result of holding these common units are recorded as other income on the unaudited condensed consolidated statements of operations.
	For the three months ended March 31, 2015, the Partnership received and recorded distributions from Regency of $2.1 million, recorded a $2.0 million loss as a result of the sale of Regency common units and recorded a $3.6 million unrealized loss resulting from the decrease in the fair value, which the Partnership deemed to be temporary, of the remaining Regency common units. As of March 31, 2015, the Partnership held 3,188,624 Regency common units, which did not include sales of 150,000 Regency common units that had not settled as of March 31, 2015 and for which a receivable of $3.4 million was recorded as part of accounts receivable in the unaudited condensed consolidated balance sheets.
	Impairment of Long-Lived Assets—Management evaluates whether the carrying value of non-oil and natural gas long-lived assets has been impaired when circumstances indicate the carrying value of those assets may not be recoverable. This evaluation is based on undiscounted cash flow projections. The carrying amount is not recoverable if it exceeds the undiscounted sum of cash flows expected to result from the use and eventual disposition of the assets. Management considers various factors when determining if these assets should be evaluated for impairment, including, but not limited to:
	•	significant adverse changes in legal factors or in the business climate;
	•	a current-period operating or cash flow loss combined with a history of operating or cash flow losses or a projection or forecast which demonstrates continuing losses associated with the use of a long-lived asset;
	•	an accumulation of costs significantly in excess of the amount originally expected for the acquisition or construction of a long-lived asset;
	•	significant adverse changes in the extent or manner in which an asset is used or in its physical condition;
	•	a significant change in the market value of an asset; or
	•	a current expectation that, more likely than not, an asset will be sold or otherwise disposed of before the end of its estimated useful life.
	For its oil and natural gas long-lived assets, the Partnership reviews its proved properties at the field level when management determines that events or circumstances indicate that the recorded carrying value of the properties may not be recoverable. Such events include a negative revision or unfavorable projection of future oil and natural gas reserves that will be produced from a field and/or forward prices resulting from this future production, the timing of this future production, future costs to produce the oil and natural gas, and future inflation levels.
	If the carrying value is not recoverable on an undiscounted basis, the impairment loss is measured as the excess of the asset's carrying value over its fair value. Management assesses the fair value of long-lived assets using commonly accepted techniques, and may use more than one method, including, but not limited to, recent third party comparable sales, internally developed discounted cash flow analysis and analysis from outside advisors. Significant changes in market conditions resulting from events such as the condition of an asset or a change in management's intent to utilize the asset would generally require management to reassess the cash flows related to the long-lived assets.
	See Note 4 for further discussion on impairment charges.
	Revenue Recognition—Revenues associated with sales of natural gas, NGLs, crude oil, condensate and sulfur are recognized when title passes to the customer, which is when the risk of ownership passes to the customer and physical delivery occurs.
	Revenues from the Partnership's Midstream Business included the sale of natural gas, NGLs, crude oil, condensate, sulfur and helium and from the compression, gathering, processing, treating and transportation of natural gas. Revenues associated with transportation and processing fees were recognized in the period when the services were provided. These revenues have been classified as discontinued operations within the unaudited condensed consolidated statements of operations.
	Natural gas revenues produced from the Partnership's natural gas interests are based on the amount of natural gas sold to purchasers. The volumes of natural gas sold may differ from the volumes to which the Partnership is entitled based on its interests in the properties. Differences between volumes sold and volumes based on entitlements create natural gas imbalances. Imbalances are reflected as adjustments to reported natural gas reserves and future cash flows.  The Partnership had long-term imbalance payables totaling $0.4 million and $0.3 million as of March 31, 2015 and December 31, 2014, respectfully.
	Derivatives—Authoritative guidance establishes accounting and reporting standards for derivative instruments, including certain derivative instruments embedded in other contracts, and for hedging activities. It requires an entity to recognize all derivatives as either assets or liabilities in the statement of financial position and measure those instruments at fair value. The guidance provides that normal purchase and sale contracts, when appropriately designated, are not subject to the guidance. Normal purchase and sales are contracts which provide for the purchase or sale of something, other than a financial instrument or derivative instrument, which will be delivered in quantities expected to be used or sold by the reporting entity over a reasonable period in the normal course of business. The Partnership's forward natural gas and crude oil purchase and sales contracts are designated as normal purchases and normal sales. The Partnership uses financial instruments such as swaps, collars and other derivatives to mitigate the risks to cash flows resulting from changes in commodity prices and interest rates. The Partnership recognizes these financial instruments on its unaudited condensed consolidated balance sheet at the instrument's fair value with changes in fair value reflected in the unaudited condensed consolidated statement of operations, as the Partnership has not designated any of these derivative instruments as hedges. The cash flows from derivatives are reported as cash flows from operating activities unless the derivative contract is deemed to contain a financing element. Derivatives deemed to contain a financing element are reported as a financing activity in the unaudited condensed consolidated statement of cash flows. See Note 10 for a description of the Partnership's risk management activities.
	Other Reclassifications—Certain prior period financial statement balances have been reclassified to conform to current year presentation. These reclassifications had no effect on the recorded net income.

New_Accounting_Pronouncements

New Accounting Pronouncements	3 Months Ended
	Mar. 31, 2015
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Pronouncements	NEW ACCOUNTING PRONOUNCEMENTS
	Discontinued Operations - On April 10, 2014, the Financial Accounting Standards Board ("FASB") issued new guidance which amends the definition of a discontinued operation and requires entities to provide additional disclosures about disposal transactions that do not meet the discontinued operations criteria. Under the new guidance, a discontinued operation is defined as a disposal of a component or group of components that is disposed of or is classified as held for sale and represents a strategic shift that has or will have a major effect on an entity's operations and financial results. The new guidance is effective prospectively for all disposals (except disposals classified as held for sale before the adoption date) or components initially classified as held for sale in periods beginning on or after December 15, 2014, with early adoption permitted. The Partnership decided to early adopt this guidance in relation to the Midstream Business Contribution (see Notes 1 and 16).
	Revenue Recognition - On May 28, 2014, the FASB issued new guidance related to revenue from contracts with customers. This new guidance outlines a single comprehensive model for entities to use and supersedes most current revenue recognition guidance, including industry-specific guidance. This guidance is effective for annual reporting periods (including interim reporting periods within those periods) beginning after December 15, 2016. Early adoption of the guidance is not permitted. The Partnership is currently evaluating the potential impact, if any, of the adoption of this new guidance on its financial statements.
	Going Concern - On August 27, 2014, the FASB issued new guidance on determining how to perform going concern assessments and when to disclose going concern uncertainties in the financial statements. The new guidance requires management to perform interim and annual assessments of an entity's ability to continue as a going concern within one year after the date the financial statements are issued. An entity must provide certain disclosures if conditions or events raise substantial doubt about the entity's ability to continue as a going concern. This guidance is effective for annual periods ending after December 15, 2016, with early adoption permitted. The Partnership is currently evaluating the potential impact, if any, of the adoption of this new guidance on its financial statements.
	Consolidation - On February 18, 2015, the FASB issued new guidance which amends the consolidation requirements. The new guidance changes the way entities evaluate consolidation of limited partnerships and other variable interest entities ("VIEs"), fees paid to a decision maker or service provider and variable interests in a VIE held by related parties. The new consolidation guidance is effective for annual periods, and interim periods within those annual periods, beginning after December 15, 2015. Early adoption is permitted using either a full retrospective or a modified retrospective adoption approach. The Partnership is currently evaluating the potential impact, if any, of the adoption of this new guidance on its financial statements.
	Debt Issuance Costs- On April 7, 2015, the FASB issued new guidance which changes the presentation of debt issuance costs in the financial statements. Under the new guidance, debt issuance costs are presented on the balance sheet as a direct deduction from the related debt liability rather than as an asset. Amortization of the costs is reported as interest expense. The new guidance is effective for annual periods, and interim periods within those annual periods, beginning after December 15, 2015. Early adoption is permitted for financial statements that have not been previously issued. The new guidance will be retrospectively applied to all prior periods. The Partnership is currently evaluating the potential impact of the adoption of this new guidance on its financial statements.

Property_Plant_and_Equipment

Property, Plant and Equipment	3 Months Ended
	Mar. 31, 2015
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment Disclosure	PROPERTY, PLANT AND EQUIPMENT
	Property, plant and equipment consisted of the following:
		March 31,			December 31,
		2015			2014
		($ in thousands)
	Equipment and machinery	$	101		$	101
	Vehicles and transportation equipment	212			212
	Office equipment, furniture and fixtures	3,020			3,020
	Computer equipment	13,583			13,234
	Proved properties	863,565			905,622
	Unproved properties	7,066			7,512
	Work in progress	1,201			1,195
		888,748			930,896
	Less: accumulated depreciation, depletion and amortization	(456,457		)	(442,908		)
	Net property, plant and equipment	$	432,291		$	487,988
	The following table sets forth the total depreciation, depletion and impairment expense by type of asset within the Partnership's unaudited condensed consolidated statements of operations:
			Three Months Ended March 31,
			2015			2014
		($ in thousands)
	Depreciation		$	559		$	707
	Depletion		$	13,719		$	19,672
	Impairment expense:
	Proved properties (a)		$	68,344		$	—
	________________________________
	(a)During the three months ended March 31, 2015, the Partnership incurred impairment charges related to certain proved properties in Mid-Continent, East Texas and Permian regions primarily due to lower commodity prices.
	The table above does not include amounts related to the Partnership's Midstream Business, as these amounts have been classified as part of discontinued operations within the unaudited condensed consolidated statement of operations (see Note 16).

Asset_Retirement_Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS
	The Partnership recognizes asset retirement obligations associated with the retirement of tangible long-lived assets that result from the acquisition, construction and development of the assets. The Partnership records the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. The Partnership makes estimates of property abandonment costs that, in some cases, will not be incurred until a substantial number of years in the future. Such cost estimates could be subject to significant revisions in subsequent years due to increases in current abandonment costs, changes in regulatory requirements, technological advances and other factors that may be difficult to predict. Although uncertainty about the timing and/or method of settlement may exist and may be conditional upon a future event, the obligation to perform the asset retirement activity is unconditional. Accordingly, the Partnership is required to recognize a liability for the fair value of a conditional asset retirement obligation upon initial recognition if the fair value of the liability can be reasonably estimated. The fair value of additions to the asset retirement obligation is estimated using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation include estimates of (i) remediation costs, (ii) remaining lives, (iii) future inflation factors and (iv) a credit-adjusted risk free interest rate.
	A reconciliation of the Partnership's liability for asset retirement obligations is as follows:
		2015			2014
		($ in thousands)
	Asset retirement obligations—January 1 (a)	$	50,873		$	48,564
	Additional liabilities	9			16
	Liabilities settled	(1,302		)	(682		)
	Revision to liabilities	124			(105		)
	Accretion expense	793			812
	Asset retirement obligations—March 31 (a)	$	50,497		$	48,605
	_____________________________________
	(a)	As of March 31, 2015 and December 31, 2014, $2.9 million and $3.0 million, respectively, were included within accrued liabilities in the unaudited condensed consolidated balance sheets.
	The table above does not include the activity related to asset retirement obligations associated with the Partnership's Midstream Business, as these amounts have been classified as discontinued operations within the unaudited condensed consolidated statement of operations (see Note 16).
	During the three months ended March 31, 2015 and 2014, the Partnership made increase revisions of $0.1 million and decrease revisions of $0.1 million, respectively, to certain asset retirement obligations due to changes in the estimated costs to remediate.

Intangible_Assets

Intangible Assets	3 Months Ended
	Mar. 31, 2015
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Intangible Assets	INTANGIBLE ASSETS
	Intangible assets consist of rights-of-way and easements, which the Partnership amortizes over the estimated useful life of 20 years.
	Intangible assets consisted of the following:
		March 31,			December 31,
		2015			2014
		($ in thousands)
	Rights-of-way and easements—at cost	$	3,920		$	3,920
	Less: accumulated amortization	(897		)	(848		)
	Net intangible assets	$	3,023		$	3,072
	The following table sets forth amortization expense by type of intangible asset within the Partnership's unaudited condensed consolidated statements of operations:
			Three Months Ended
			March 31,
			2015			2014
		($ in thousands)
	Amortization		$	49		$	49
	The table above does not include amounts related to the Partnership's Midstream Business, as these amounts have been classified as part of discontinued operations within the unaudited condensed consolidated statement of operations (see Note 16).
	Estimated future amortization expense related to the intangible assets at March 31, 2015 is as follows (in thousands):
	Year ending December 31,
	2015	$	147
	2016	$	196
	2017	$	196
	2018	$	196
	2019	$	196
	Thereafter	$	2,092

Long_Term_Debt

Long Term Debt	3 Months Ended
	Mar. 31, 2015
Long-term Debt, by Current and Noncurrent [Abstract]
Long-term Debt [Text Block]	LONG-TERM DEBT
	Long-term debt consisted of the following:
		March 31,			December 31,
		2015			2014
		($ in thousands)
	Revolving credit facility:	$	162,000		$	212,600
	Senior Notes:
	8.375% Senior Notes due 2019	51,120			51,120
	Unamortized bond discount	(358		)	(377		)
	Total Senior Notes	50,762			50,743
	Total long-term debt	$	212,762		$	263,343
	Revolving Credit Facility
	On October 10, 2014, the Partnership entered into the Fifth Amendment (the "Fifth Amendment") to its Amended and Restated Credit Agreement (as amended, the "Credit Agreement"). The Fifth Amendment, among other items, provided for current commitments totaling $320 million, with the ability to increase commitments up to a total aggregate amount of $1.2 billion. The Fifth Amendment coincided with the semi-annual borrowing base redetermination by the Partnership's commercial lenders. The amendment extended the maturity to October 2019. In addition, as a result of the completion of the Midstream Business Contribution, the Partnership's borrowing base under the Credit Agreement is now strictly based on the value of its oil and natural gas properties and its commodity derivative contracts, which was formerly referred to as the upstream component of the borrowing base.
	As of March 31, 2015, the Partnership had approximately $158.0 million of availability under the credit facility, based on its borrowing base on that date. The Partnership currently pays a 0.50% commitment fee (based on the Partnership's borrowing base utilization percentage) per year on the difference between total commitments and the amount drawn under the credit facility. The Credit Agreement includes a sub-limit for the issuance of standby letters of credit for a total of $50.0 million. As of March 31, 2015, the Partnership had no outstanding letters of credit.
	The following table presents the debt covenant levels specified in the Partnership's revolving credit facility and the actual covenant ratios as of March 31, 2015:
		Debt Covenant		Actual Covenant Ratio as of March 31, 2015
	Maximum total leverage ratio	4		1.8
	Minimum current ratio	1		5.8
	As of March 31, 2015, the Partnership was in compliance with the financial covenants under the Credit Agreement.
	On April 1, 2015, the borrowing base under the Partnership's credit facility decreased from $320 million to $270 million as part of its regularly scheduled semi-annual redetermination by the Partnership's commercial lenders. The Partnership's next borrowing base redetermination is scheduled for October 1, 2015.
	8.375 % Senior Notes due 2019 (the "Senior Notes")
	Following the Midstream Business Contribution, $51.1 million of the Senior Notes remain outstanding under an amended indenture with substantially all of the restrictive covenants and certain events of default eliminated.

Members_Equity

Members' Equity	3 Months Ended
	Mar. 31, 2015
Partners' Capital [Abstract]
Members' Equity	MEMBERS’ EQUITY
	At March 31, 2015 and December 31, 2014, there were 149,027,423 and 150,154,909 unrestricted common units outstanding, respectively. In addition, there were 2,121,963 and 2,419,750 unvested restricted common units outstanding at March 31, 2015 and December 31, 2014, respectively.
	On May 31, 2012, the Partnership announced a program through which it may issue common units, from time to time, with an aggregate market value of up to $100 million. The Partnership is under no obligation to issue equity under the program and the Partnership has not issued common units under this program since 2013.
	On October 27, 2014, the Partnership announced a common unit repurchase program of up to $100.0 million through which repurchases may be made from time to time at prevailing prices on the open market or in privately negotiated transactions. The program commenced following the filing of the Partnership's Quarterly Report on Form 10-Q for the quarter ending September 30, 2014 and will conclude by March 31, 2016. The repurchase program does not obligate the Partnership to acquire any, or any specific number of, units and may be discontinued at any time. The Partnership intends to cancel any units it repurchases under the repurchase program. During the three months ended March 31, 2015, 1,171,584 units were repurchased under this program for approximately $2.6 million.
	The table below summarizes the distributions paid or payable and declared for the quarters listed below:
	Quarter Ended		Distribution		Record Date*	Payment Date
			per Common Unit
	December 31, 2014+		$	0.07	February 6, 2015	February 13, 2015
	March 31, 2015+		$	0.07	May 8, 2015	May 15, 2015
	_____________________________
	+	The distribution excludes certain restricted units under the LTIP (as defined in Note 14 below).
	*	Means the close of business on each of the listed Record Dates.

Related_Party_Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS
	The following table summarizes transactions between the Partnership and certain affiliated entities:
		Three Months Ended March 31,
		2015		2014
	Affiliates of Natural Gas Partners:	($ in thousands)
	Natural gas purchases from affiliates	$	—	$	1,142
	The transactions above were all related to the Partnership's Midstream Business and have been classified as part of discontinued operations within the unaudited condensed consolidated statement of operations (see Note 16).

Risk_Management_Activities

Risk Management Activities	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Risk Management Activities	RISK MANAGEMENT ACTIVITIES
	Interest Rate Swap Derivative Instruments
	To mitigate its interest rate risk, the Partnership enters into various interest rate swaps. These swaps convert the variable-rate term loan into a fixed-rate obligation. The purpose of entering into these swaps is to eliminate interest rate variability by converting LIBOR-based variable-rate payments to fixed-rate payments. Amounts received or paid under these swaps were recorded as reductions or increases in interest expense.
	For accounting purposes, the Partnership has not designated any of its interest rate derivative instruments as hedges; instead it marks these derivative contracts to fair value (see Note 11).  Changes in fair values of the interest rate derivative instruments are recorded as an adjustment to the mark-to-market gains (losses) on risk management transactions within other income (expense).
	The following table sets forth certain information regarding the Partnership's interest rate swaps as of March 31, 2015:
	Effective Date		Expiration		Notional			Fixed
			Date		Amount			Rate
	12/31/14		12/31/19		$	175,000,000		2.3195	%
	Commodity Derivative Instruments
	The prices of crude oil, natural gas and NGLs are subject to fluctuations in response to changes in supply, demand, market uncertainty and a variety of additional factors which are beyond the Partnership's control.  These risks can cause significant changes in the Partnership's cash flows and affect its ability to achieve its distribution objectives and comply with the covenants of its Credit Agreement.  In order to manage the risks associated with changes in the future prices of crude oil, natural gas and NGLs on its forecasted equity production, the Partnership engages in risk management activities that take the form of commodity derivative instruments.  The Partnership has determined that it is necessary to hedge a substantial portion of its expected production in order to meaningfully reduce its future cash flow volatility.  The Partnership generally limits its hedging levels to less than its total expected future production. While hedging at this level of production does not eliminate all of the volatility in the Partnership's cash flows, it allows the Partnership to mitigate the risk of situations where a modest loss of production would not put it in an over-hedged position.  At times, the Partnership may enter into or assume (in connection with acquisitions) hedges with strike prices above current future prices or resetting existing hedges to higher price levels in order to meet its cash flow objectives.   In addition, the Partnership may also terminate or unwind hedges or portions of hedges when the expected future volumes do not support the level of hedges.  Expected future production is derived from the proved reserves, adjusted for certain price-dependent expenses and revenue deductions. The Partnership applies the appropriate contract terms to these projections to determine its expected future equity share of the commodities.
	The Partnership uses fixed-price swaps, costless collars and put options to achieve its hedging objectives. Historically, the Partnership has hedged its expected future commodity volumes either with derivatives of the same commodity ("direct hedges") or with derivatives of another commodity which the Partnership expects will correlate well with the underlying commodity ("proxy hedges").  For example, the Partnership has often hedged the changes in future NGL prices using crude oil hedges because NGL prices have been highly correlated to crude oil prices and hedging NGLs directly is usually less attractive due to the relative illiquidity in the NGL forward market.  The Partnership may use natural gas hedges to hedge a portion of its expected future ethane production because forward prices for ethane are often heavily discounted from its current prices. Also, natural gas prices provide support for ethane prices because in many processing plants ethane can be recombined with the residue gas stream and sold as natural gas.  When the Partnership uses proxy hedges, it converts the expected volumes of the underlying commodity to equivalent volumes of the hedged commodity.
	For accounting purposes, the Partnership has not designated any of its commodity derivative instruments as hedges; instead it marks these derivative contracts to fair value (see Note 11).  Changes in fair values of the commodity derivative instruments are recorded as an adjustment to the mark-to-market gains (losses) on risk management transactions within revenue.
	By using derivative instruments to economically hedge exposure to changes in commodity prices, the Partnership exposes itself to counterparty credit risk. Historically, the Partnership's counterparties have all been participants or affiliates of participants within its Credit Agreement (see Note 7), which is secured by substantially all of the assets of the Partnership. Therefore, the Partnership is not currently required to post any collateral, nor does it require collateral from its counterparties. The Partnership minimizes the credit risk in derivative instruments by limiting exposure to any single counterparty and monitoring the creditworthiness of its counterparties on an ongoing basis. In addition, the Partnership's derivative contracts for certain counterparties are subject to counterparty netting agreements governing such derivatives, and when possible, the Partnership nets the open positions of each counterparty. See Note 11 for the impact to the Partnership's unaudited condensed consolidated balance sheets of the netting of these derivative contracts.
	The following tables set forth certain information regarding the Partnership's commodity derivatives. Within the table, some trades of the same commodities with the same tenors have been aggregated and shown as weighted averages.
	Commodity derivatives, as of March 31, 2015, that will mature during the years ended December 31, 2015 through 2019:
	Underlying		Type		Notional		Floor				Cap
					Volumes		Strike				Strike
					(units) (a)		Price				Price
							($/unit)(b)				($/unit)(b)
	Portion of Contracts Maturing in 2015
	Natural Gas		Swap (Pay Floating/Receive Fixed)		8,100,000		$	4.07
	Crude Oil		Costless Collar		360,000		$	90			$	97.55
	Crude Oil		Swap (Pay Floating/Receive Fixed)		472,500		$	89.78
	IsoButane		Swap (Pay Floating/Receive Fixed)		1,591,800		$	0.66
	Natural Gasoline		Swap (Pay Floating/Receive Fixed)		1,251,600		$	1.13
	Normal Butane		Swap (Pay Floating/Receive Fixed)		1,234,800		$	0.66
	Propane		Swap (Pay Floating/Receive Fixed)		3,952,200		$	0.54
	Contracts Maturing in 2016
	Natural Gas		Swap (Pay Floating/Receive Fixed)		9,480,000		$	4.25
	Crude Oil		Swap (Pay Floating/Receive Fixed)		936,000		$	84.66
	Contracts Maturing in 2017
	Crude Oil		Swap (Pay Floating/Receive Fixed)		444,000		$	89.24
	Contracts Maturing in 2018
	Crude Oil		Swap (Pay Floating/Receive Fixed)		396,000		$	88.78
	Contracts Maturing in 2019
	Crude Oil		Swap (Pay Floating/Receive Fixed)		348,000		$	88.39
	_______________________
	(a)	Volumes of natural gas are measured in MMbtu, volumes of crude oil are measured in barrels and volumes of NGLs are measured in gallons.
	(b)	Amounts represent the weighted average price. The weighted average prices are in $/MMbtu for natural gas, $/barrel for crude oil and $/gallon for NGLs.
	Fair Value of Interest Rate and Commodity Derivatives
	The following tables set forth the fair values of interest rate and commodity derivative instruments not designated as hedging instruments and their location within the unaudited condensed consolidated balance sheet as of March 31, 2015 and December 31, 2014:
		As of March 31, 2015
		Derivative Assets					Derivative Liabilities
		Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
		($ in thousands)
	Interest rate derivatives - liabilities	Current assets		$	(3,220	)	Current liabilities		$	—
	Interest rate derivatives - liabilities	Long-term assets		(4,712		)	Long-term liabilities		—
	Commodity derivatives - assets	Current assets		50,624			Current liabilities		—
	Commodity derivatives - assets	Long-term assets		54,718			Long-term liabilities		—
	Commodity derivatives - liabilities	Current assets		(11		)	Current liabilities		—
	Total derivatives			$	97,399				$	—
		As of December 31, 2014
		Derivative Assets					Derivative Liabilities
		Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
		($ in thousands)
	Interest rate derivatives - liabilities	Current assets		$	(3,165	)	Current liabilities		$	—
	Interest rate derivatives - liabilities	Long-term assets		(2,641		)	Long-term liabilities		—
	Commodity derivatives - assets	Current assets		47,971			Current liabilities		—
	Commodity derivatives - assets	Long-term assets		49,130			Long-term liabilities		—
	Total derivatives			$	91,295				$	—
	The following table sets forth the location of gains and losses for derivatives not designated as hedging instruments within the Partnership's unaudited condensed consolidated statement of operations:
	Amount of Gain (Loss) Recognized in Income on Derivatives			Three Months Ended March 31,
				2015			2014
				($ in thousands)
Interest rate derivatives	Interest rate risk management losses, net		$	(3,066	)	$	(290	)
Commodity derivatives	Commodity risk management gains (losses), net		22,600			(10,033		)
Commodity derivatives	Discontinued operations		—			(4,911		)
Commodity derivatives - trading	Discontinued operations		—			(987		)
	Total		$	19,534		$	(16,221	)

Fair_Value_of_Financial_Instru

Fair Value of Financial Instruments	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	FAIR VALUE OF FINANCIAL INSTRUMENTS
	Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). The Partnership utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk inherent in the inputs to the valuation technique. The authoritative guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements).
	The three levels of the fair value hierarchy are as follows:
	Level 1 – Quoted prices are available in active markets for identical assets and liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide information on an ongoing basis.
	Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the market place throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace.
	Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management's best estimate of fair value.
	As of March 31, 2015, the Partnership has recorded its interest rate swaps and commodity derivative instruments (see Note 10), which includes crude oil, natural gas and NGLs, at fair value. The Partnership reviews the classification of the inputs at the end of each period and, following such review for the period ended March 31, 2015, classified the inputs to measure the fair value of its interest rate swaps, crude oil derivatives, NGL derivatives and natural gas derivatives as Level 2.  In addition, the Partnership recorded its investments in equity securities at fair value, and classified the inputs as Level 1.
	The following tables disclose the fair value of the Partnership's derivative instruments and equity investments as of March 31, 2015 and December 31, 2014:
		As of March 31, 2015
		Level 1		Level 2			Level 3		Netting (a)			Total
		($ in thousands)
	Assets:
	Crude oil derivatives	$	—	$	84,171		$	—	$	—		$	84,171
	Natural gas derivatives	—		21,049			—		—			21,049
	NGL derivatives	—		122			—		(11		)	111
	Interest rate swaps	—		—			—		(7,932		)	(7,932		)
	Equity investments	72,924		—			—		—			72,924
	Total	$	72,924	$	105,342		$	—	$	(7,943	)	$	170,323
	Liabilities:
	NGL derivatives	—		(11		)	—		11			—
	Interest rate swaps	—		(7,932		)	—		7,932			—
	Total	$	—	$	(7,943	)	$	—	$	7,943		$	—
	____________________________
	(a)	Represents counterparty netting under the agreement governing such derivative contracts.
		As of December 31, 2014
		Level 1		Level 2			Level 3		Netting (a)			Total
		($ in thousands)
	Assets:
	Crude oil derivatives	$	—	$	78,516		$	—	$	—		$	78,516
	Natural gas derivatives	—		18,585			—		—			18,585
	Interest rate swaps	—		—			—		(5,806		)	(5,806		)
	Equity investments	153,448		—			—		—			153,448
	Total	$	153,448	$	97,101		$	—	$	(5,806	)	$	244,743
	Liabilities:
	Interest rate swaps	—		(5,806		)	—		5,806			—
	Total	$	—	$	(5,806	)	$	—	$	5,806		$	—
	____________________________
	(a)	Represents counterparty netting under the agreement governing such derivative contracts.
	Gains and losses from continuing operations related to the interest rate derivatives are recorded as part of interest rate risk management gains and losses in the unaudited condensed consolidated statements of operations.  Gains and losses from continuing operations related to the Partnership's commodity derivatives are recorded as a component of revenue in the unaudited condensed consolidated statements of operations.
	Fair Value of Assets and Liabilities Measured on a Non-recurring Basis
	For periods in which impairment charges have been incurred, the Partnership is required to write down the value of the impaired asset to its fair value. See Note 4 for a further discussion of the impairment charges recorded during the three months ended March 31, 2015. The following table discloses the fair value of the Partnership's assets measured at fair value on a nonrecurring basis during the three months ended March 31, 2015:
		Three Months Ended March 31,
		2015		Level 1			Level 2		Level 3			Total Losses
		($ in thousands)
	Proved properties	$	44,658	$	—		$	—	$	44,658		$	68,344
	The Partnership calculated the fair value of the impaired assets using a discounted cash flow analysis to determine the excess of the asset's carrying value over its fair value. Significant inputs to the valuation of fair value of the proved properties, plant, pipeline and intangible assets includes estimates of (i) future cash flows, including revenue, expenses and capital expenditures, (ii) timing of cash flows, (iii) forward commodity prices, adjusted for estimate location differentials and (iv) a discount rate reflective of our cost of capital.
	The carrying amounts of cash equivalents, accounts receivable and accounts payable are believed to approximate their fair values because of the short-term nature of these instruments.
	As of March 31, 2015, the outstanding debt associated with the Credit Agreement bore interest at a floating rate; as such, the Partnership believes that the carrying value of this debt approximates its fair value. The outstanding debt associated with the Senior Notes bore interest at a fixed rate; based on the market price of the Senior Notes as of March 31, 2015 and December 31, 2014, the Partnership estimates that the fair value of the Senior Notes was $49.1 million and $47.0 million, respectively. Fair value of the Senior Notes was estimated based on prices quoted from third-party financial institutions, which are characteristic of Level 2 fair value measurement inputs.

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES
	Litigation—The Partnership and its operating subsidiaries are subject to lawsuits which arise from time to time in the ordinary course of business. The Partnership had no accruals as of March 31, 2015 or December 31, 2014 related to legal matters and current lawsuits are not expected to have a material adverse effect on the Partnership's financial position, results of operations or cash flows.
	Insurance—The Partnership covers its operations and assets with insurance which management believes is consistent with that in force for other companies engaged in similar commercial operations with similar type properties.  This insurance includes: (1) commercial general liability insurance covering liabilities to third parties for bodily injury, property damage and pollution arising out of the Partnership's operations; (2) workers’ compensation liability coverage for employees to required statutory limits; (3) automobile liability insurance covering liability to third parties for bodily injury and property damage arising out of the operation of all owned, hired and non-owned vehicles by its employees on company business; (4) property insurance covering the replacement cost of all owned real and personal property, including coverage for losses due to boiler and machinery breakdown, earthquake, flood and consequent business interruption/extra expense; (5) control of well/operator's extra expense insurance for operated and non-operated wells; and (6) corporate liability insurance, including coverage for directors and officers and employment practices liabilities.  In addition, the Partnership maintains excess liability insurance providing limits in excess of the established primary limits for commercial general liability and automobile liability insurance.
	All coverages are subject to industry accepted policy terms, conditions, limits and deductibles comparable to that obtained by other energy companies with similar operations. The cost of insurance for the energy industry continued to fluctuate over the past year, reflecting the changing conditions in the insurance markets.
	Environmental—The Partnership's business involves acquiring, developing and producing oil and natural gas working interests, and certain associated gathering and processing activities for our interests in Alabama. The Partnership's operations and those of the Partnership's lease operators are subject to stringent and complex federal, state and local laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection or safety. The Partnership must comply with United States laws and regulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal and other environmental matters. The cost of developing and producing our oil and natural gas working interests as well as planning, designing and operating our associated processing facility in Alabama, must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures, including citizen suits, which can include the assessment of monetary penalties, the imposition of remedial requirements and the issuance of injunctions or restrictions on operation. Management believes that, based on currently known information, compliance with these laws and regulations will not have a material adverse effect on the Partnership's combined results of operations, financial position or cash flows. At March 31, 2015 and December 31, 2014, the Partnership had accrued approximately $2.7 million and $2.8 million, respectively, for environmental matters.
	Retained Revenue Interest—Certain of the Partnership's assets are subject to retained revenue interests.  These interests were established under purchase and sale agreements that were executed by the Partnership's predecessors in title.  The terms of these agreements entitle the owners of the retained revenue interests to a portion of the revenues received from the sale of the hydrocarbons above specified base oil and natural gas prices.  These retained revenue interests do not represent a real property interest in the hydrocarbons.  The Partnership's reported revenues are reduced to account for the retained revenue interests on a monthly basis.
	The retained revenue interests affect the Partnership's interest in the Big Escambia Creek, Flomaton and Fanny Church fields in Escambia County, Alabama. With respect to the Partnership's Flomaton and Fanny Church fields, these retained revenue interests are in effect for any calendar year in which the Partnership surpasses certain average net production rates. The Partnership did not surpass such rates in 2014 and does not anticipate exceeding these rates in future years. With respect to the Partnership's Big Escambia Creek field, the retained revenue interest commenced in 2010 and continues through the end of 2019.
	Other Commitments—The Partnership utilizes assets under operating leases for its corporate office, certain rights-of-way and facilities locations, vehicles and in several areas of its operations. Rental expense from continuing operations, including leases with no continuing commitment, amounted to approximately $0.5 million and $0.8 million for the three months ended March 31, 2015 and 2014, respectively. Rental expense for leases with escalation clauses is recognized on a straight-line basis over the initial lease term.

Income_Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES
	Provision for Income Taxes -The Partnership is a limited partnership for federal and state income tax purposes, in which income tax liabilities and/or benefits of the Partnership are passed through to its unitholders. In the State of Texas, limited partnerships are directly subject to the Texas margin tax, which liability is not passed through to the Partnership's unitholders. In addition, certain of the Partnership's subsidiaries are Subchapter C-corporations subject to federal and state income taxes. During the three months ended March 31, 2015 and March 31, 2014, the Partnership recognized an income tax benefit of $0.8 million and $0.9 million, respectively. The change in the Partnership's tax benefit from period to period is primarily due to changes in income generated by the Partnership's taxable entities.

Equity_Based_Compensation

Equity Based Compensation	3 Months Ended
	Mar. 31, 2015
Share-based Compensation [Abstract]
Equity-based Compensation	EQUITY-BASED COMPENSATION
	Long-Term Incentive Plan
	Eagle Rock Energy G&P, LLC has a long-term incentive plan (as amended, the "LTIP"), for its employees, directors and consultants who provide services to the Partnership and its subsidiaries and affiliates. The LTIP provides for the issuance of an aggregate of up to 14,500,000 common units to be granted either as options, restricted units or phantom units, of which, as of March 31, 2015, a total of 6,975,671 common units remained available for issuance (which calculation reserves the maximum common units (i.e., 200%) that may potentially be earned and vested in respect of the outstanding performance units). Grants under the LTIP are made at the discretion of the board and to date have been made in the form of restricted units and performance units (i.e., phantom units subject to performance conditions). Distributions declared and paid on outstanding restricted units, where such restricted units are eligible to receive distributions, are paid directly to the holders of the restricted units. With respect to the performance units (as described below), distributions declared and paid will be grossed-up by an additional number of performance units as determined in the performance unit agreement. No options have been issued to date.
	Restricted Units
	Grants of restricted units eligible to receive distributions are valued at the market price as of the date issued, while grants of restricted units not eligible to receive distributions are valued at the market price as of the date issued less the present value of the expected distribution stream over the vesting period using the risk-free interest rate. The awards generally vest over three years on the basis of one-third of the award vesting each year.
	The Partnership recognizes compensation expense on a straight-line basis over the requisite service period for the restricted unit grants. During the restriction period, distributions associated with the grants of restricted units eligible to receive distributions are distributed to the awardees.
	A summary of the changes in outstanding restricted common units for the three months ended March 31, 2015 is provided below:
		Number of		Weighted
		Restricted		Average
		Units		Fair Value
	Outstanding at December 31, 2014	2,419,750		$	6.06
	Granted	23,000		$	2.37
	Vested	(60,700	)	$	4.46
	Forfeited	(260,087	)	$	6.69
	Outstanding at March 31, 2015	2,121,963		$	5.99
	Performance Units
	Performance units are described in the LTIP as phantom units subject to restrictions that lapse based on the performance of the Partnership, as measured by total unitholder return in comparison to a peer group of upstream master limited partnerships and a continued service requirement that spans a three-year period.
	The performance units represent hypothetical common units of the Partnership and therefore do not carry any of the rights and privileges (including voting privileges) associated with actual common units. Performance units settle in common units rather than cash. The fair value of the performance units is estimated using a Monte Carlo simulation at the grant date. The Partnership recognizes compensation expense for the performance unit grants over the three-year vesting period.
	The amount of performance units subject to an award that vests will be determined on each vesting date based on a two-step approach. The right to receive actual common units in settlement of the performance units depends first on the relative level of total unitholder return attained by the Partnership over the applicable performance period (for grants made prior to April 21, 2015, generally July 1, 2014 through June 30, 2016, and for grants made on or after April 21, 2015, generally a specified three-year period), as measured against the Partnership's peer group. The number of units that may be earned will either be 0% of the target performance units subject to the award for performance at anything less than the 50th percentile of the peer group, or in the range of 70% to 200% of the target performance units subject to the award for performance from the 50th percentile to the 100th percentile of the peer group over the performance period. Second, the right to receive actual common units with respect to the earned performance units depends on the satisfaction of a continued service requirement, which, for grants made prior to April 21, 2015, is generally continued service through June 30, 2016 for two-thirds of the performance units and through June 30, 2017 for the remaining one-third of the performance units, and for grants made on or after April 21, 2015, is generally aligned with the applicable performance period.
	In the event the Partnership pays any distributions in respect of its outstanding units, the target performance units and any earned performance units will be grossed-up to reflect such distribution by an additional number of target performance units or earned performance units, as applicable. Any target performance units that do not become earned performance units or any earned performance units for which the continued service requirement is not satisfied shall terminate, expire and otherwise be forfeited by the awardee on the last day of the applicable performance period. Any earned performance units that vest (based on fulfillment of the continued service requirement) shall be settled in actual common units.
	A summary of the changes in outstanding performance units for the three months ended March 31, 2015 is provided below:
		Number of		Weighted
		Performance		Average
		Units		Fair Value
	Outstanding at December 31, 2014	647,788		$	3.63
	Forfeited	(123,175	)	$	3.59
	Outstanding at March 31, 2015	524,613		$	3.64
	Equity-Based Compensation
	For the three months ended March 31, 2015 and March 31, 2014, the Partnership recorded non-cash compensation expense of approximately $1.9 million and $2.6 million, respectively, related to the granted restricted units and performance units as general and administrative expense on the unaudited condensed consolidated statements of operations.
	As of March 31, 2015, unrecognized compensation costs related to the outstanding restricted units and performance units under the LTIP totaled approximately $8.6 million. The remaining expense is to be recognized over a weighted average of 1.91 years.
	In connection with the vesting of certain restricted units during the three months ended March 31, 2015, the Partnership cancelled 16,602 of the newly-vested common units in satisfaction of less than $0.1 million of minimum employee tax liability paid by the Partnership. Pursuant to the terms of the LTIP, these cancelled units are available for future grants under the LTIP.

Earnings_Per_Unit

Earnings Per Unit	3 Months Ended
	Mar. 31, 2015
Earnings Per Unit [Abstract]
Earnings Per Unit	EARNINGS PER UNIT
	Basic earnings per unit is computed by dividing the net income (loss) by the weighted average number of units outstanding during a period. To determine net income (loss) allocated to each class of ownership (common and restricted common units), the Partnership first allocates net income (loss) in accordance with the amount of distributions made for the quarter by each class, if any. The remaining net income is allocated to each class in proportion to the class weighted average number of units outstanding for a period as compared to the weighted average number of units for all classes for the period, with the exception of net losses. Net losses are allocated to just the common units.
	As of March 31, 2015 and 2014, the Partnership had unvested restricted common units outstanding, which are considered dilutive securities. These units are considered in the diluted weighted average common units outstanding number in periods of net income. In periods of net losses, these units are excluded from the diluted weighted average common units outstanding number.
	The majority of the restricted units granted under the LTIP, as discussed in Note 14, contain non-forfeitable rights to the distributions declared by the Partnership and therefore meet the definition of participating securities. Participating securities are required to be included in the computation of earnings per unit pursuant to the two-class method. Restricted units granted in 2013 to certain senior executives and members of the board of directors are not eligible to receive the distributions declared by the Partnership and therefore do not meet the definition of participating securities.
	The following table presents the Partnership's calculation of basic and diluted units outstanding for the periods indicated:
			Three Months Ended March 31,
			2015			2014
		(in thousands)
	Weighted average units outstanding during period:
	Common units - Basic		149,143			156,644
	Common units - Diluted		149,143			156,644
	The following table presents the Partnership's basic and diluted loss per unit for the three months ended March 31, 2015:
			Total				Common Units			Restricted Common Units*
			($ in thousands, except for per unit amounts)
	Loss from continuing operations		$	(57,753	)
	Distributions		10,561				$	10,432		$	129
	Assumed loss from continuing operations after distribution to be allocated		(68,314		)		(68,314		)	—
	Assumed allocation of loss from continuing operations		(57,753		)		(57,882		)	129
	Discontinued operations, net of tax		(966		)		(966		)	—
	Assumed net loss to be allocated		$	(58,719	)		$	(58,848	)	$	129
	Basic loss from continuing operations per unit						$	(0.39	)
	Basic discontinued operations per unit						$	(0.01	)
	Basic loss per unit						$	(0.40	)
	Diluted loss from continuing operations per unit						$	(0.39	)
	Diluted discontinued operations per unit						$	(0.01	)
	Diluted loss per unit						$	(0.40	)
	_____________________________
	*	Restricted common units granted under the LTIP that contain non-forfeitable rights to the distributions declared by the Partnership.
	The following table presents the Partnership's basic and diluted loss per unit for the three months ended March 31, 2014:
			Total				Common Units			Restricted Common Units*
			($ in thousands, except for per unit amounts)
	Loss from continuing operations		$	(7,960	)
	Distributions**		—				$	—		$	—
	Assumed loss from continuing operations after distribution to be allocated		(7,960		)		(7,960		)	—
	Assumed allocation of loss from continuing operations		(7,960		)		(7,960		)	—
	Discontinued operations, net of tax		(10,603		)		(10,603		)	—
	Assumed net loss to be allocated		$	(18,563	)		$	(18,563	)	$	—
	Basic income from continuing operations per unit						$	(0.05	)
	Basic discontinued operations per unit						$	(0.07	)
	Basic loss per unit						$	(0.12	)
	Diluted income from continuing operations per unit						$	(0.05	)
	Diluted discontinued operations per unit						$	(0.07	)
	Diluted income per unit						$	(0.12	)

Divestiture_Related_Activities

Divestiture Related Activities Divestiture Related Activites (Notes)	3 Months Ended
	Mar. 31, 2015
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	DIVESTITURE RELATED ACTIVITIES
	As discussed in Note 1, on July 1, 2014, the Partnership completed the Midstream Business Contribution. As a result of this transaction, the operations of the Midstream Business have been classified as discontinued.
	The following table is the reconciliation of major classes of line items classified as discontinued operations for the Midstream Business for the three months ended March 31, 2015 and 2014:
			Three Months Ended March 31,
			2015				2014
			($ in thousands)
	Class of statement of operations line item of discontinued operations:
	Revenue		$	—			$	302,871
	Cost of natural gas, NGLs, condensate and helium		—				244,973
	Operations, maintenance and taxes other than income		—				25,049
	General and administrative		966				8,101
	Depreciation, amortization and impairment		—				22,199
	Interest expense		—				(13,232		)
	Other expense		—				(8		)
	Operating loss from discontinued operations before taxes		(966		)		(10,691		)
	Income tax benefit		—				(88		)
	Discontinued operations, net of tax		$	(966	)		$	(10,603	)
	Allocation of Interest Expense
	Per accounting guidance provided by the FASB related to discontinued operations, interest on debt that is to be assumed by the buyer and interest on debt that is required to be repaid as a result of a disposal transaction should be allocated to discontinued operations. Per the Partnership's Credit Agreement, as a result of the Midstream Business Contribution, the Partnership is required to pay down outstanding debt to the amount of the upstream portion of the borrowing base. Thus, interest expense in the table above includes the interest expense related to the portion of the Partnership's unsecured Senior Notes exchanged for Regency unsecured senior notes on July 1, 2014 and interest related to the difference between the total amount outstanding under the Credit Agreement and the upstream portion of the borrowing base for periods prior to July 1, 2014.
	Restructuring activities
	In connection with the Midstream Business Contribution, the Partnership incurred one-time employee termination benefits and lease payments of the partial abandonment of an operating lease of $4.0 million and $0.6 million, respectively, during the year ended December 31, 2014. The accruals are recorded as part of accrued liabilities within the unaudited condensed consolidated balance sheets, while the expenses are recorded as part of discontinued operations within the unaudited condensed consolidated statement of operations. During the three months ended March 31, 2015, the Partnership adjusted its accrual related to the lease payments of the partial abandonment of an operating lease to account for the softening of the sublease market. The following table summarizes activity related to liabilities associated with the Partnership's restructuring activities during the three months ended March 31, 2015.
		Employee Related Costs				Facility and Other Costs				Total
		($ in thousands)
	Balance at December 31, 2014	$	835			$	490			$	1,325
	Payments and other adjustments	(183		)		1,026				843
	Balance at March 31, 2015	$	652			$	1,516			$	2,168

Subsidiary_Guarantors

Subsidiary Guarantors	3 Months Ended
	Mar. 31, 2015
SUBSIDIARY GUARANTORS [Abstract]
Subsidiary Guarantors	SUBSIDIARY GUARANTORS
	The Partnership has issued registered debt securities guaranteed by its subsidiaries.  As of March 31, 2015, all guarantors were wholly-owned or available to be pledged and such guarantees were joint and several and full and unconditional.  Although the guarantees of the Partnership's subsidiary guarantors are considered full and unconditional, the guarantees are subject to certain customary release provisions. Such guarantees may be released in the following customary circumstances:
	•	in connection with any sale or other disposition of all or substantially all of the properties or assets of that guarantor (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) an issuer or a restricted subsidiary of the Partnership;
	•	in connection with any sale or other disposition of capital stock of that guarantor to a person that is not (either before or after giving effect to such transaction) an issuer or a restricted subsidiary of us, such that, the guarantor ceases to be a restricted subsidiary of us as a result of the sale or other disposition;
	•	if the Partnership designates any restricted subsidiary that is a guarantor to be an unrestricted subsidiary in accordance with the applicable provisions of the indenture;
	•	upon legal defeasance or satisfaction and discharge of the indenture;
	•	upon the liquidation or dissolution of such guarantor provided no default or event of default has occurred that is continuing;
	•	at such time as such guarantor ceases to guarantee any other indebtedness of either of the issuers or any guarantor; or
	•	upon such guarantor consolidating with, merging into or transferring all of its properties or assets to us or another guarantor, and as a result of, or in connection with, such transaction such guarantor dissolving or otherwise ceasing to exist.
	In accordance with Rule 3-10 of the Securities and Exchange Commission Regulation S-X, the Partnership has prepared unaudited condensed consolidating financial statements as supplemental information.  The following unaudited condensed consolidated balance sheets at March 31, 2015 and December 31, 2014, and unaudited condensed consolidated statements of operations for the three months ended March 31, 2015 and 2014, and unaudited condensed consolidated statements of cash flows for the three months ended March 31, 2015 and 2014, present financial information for Eagle Rock Energy as the parent on a stand-alone basis (carrying any investments in subsidiaries under the equity method), financial information for the co-issuer and the subsidiary guarantors, which are all 100% owned by the Partnership, on a stand-alone basis, and the consolidation and elimination entries necessary to arrive at the information for the Partnership on a consolidated basis.  The subsidiary guarantors are not restricted from making distributions to the Partnership.
	Unaudited Condensed Consolidating Balance Sheet
	March 31, 2015
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Consolidating			Total
										Entries
		($ in thousands)
	ASSETS:
	Accounts receivable – related parties	$	865,930		$	—	$	—		$	(865,930	)	$	—
	Other current assets	129,008			1		36,039			—			165,048
	Total property, plant and equipment, net	1,531			—		430,760			—			432,291
	Investment in subsidiaries	(486,135		)	—		—			486,135			—
	Total other long-term assets	55,072			—		4,826			—			59,898
	Total assets	$	565,406		$	1	$	471,625		$	(379,795	)	$	657,237
	LIABILITIES AND EQUITY:
	Accounts payable – related parties	$	—		$	—	$	865,930		$	(865,930	)	$	—
	Other current liabilities	37,497			—		10,435			—			47,932
	Other long-term liabilities	370			—		81,396			—			81,766
	Long-term debt	212,762			—		—			—			212,762
	Equity	314,777			1		(486,136		)	486,135			314,777
	Total liabilities and equity	$	565,406		$	1	$	471,625		$	(379,795	)	$	657,237
	Unaudited Condensed Consolidating Balance Sheet
	December 31, 2014
		Parent Issuer			Co-Issuer		Subsidiary			Consolidating Entries			Total
							Guarantors
		($ in thousands)
	ASSETS:
	Accounts receivable – related parties	$	838,656		$	—	$	—		$	(838,656	)	$	—
	Other current assets	211,213			1		37,889			—			249,103
	Total property, plant and equipment, net	1,334			—		486,654			—			487,988
	Investment in subsidiaries	(413,023		)	—		—			413,023			—
	Total other long-term assets	52,272			—		4,912			—			57,184
	Total assets	$	690,452		$	1	$	529,455		$	(425,633	)	$	794,275
	LIABILITIES AND EQUITY:
	Accounts payable – related parties	$	—		$	—	$	838,656		$	(838,656	)	$	—
	Other current liabilities	37,850			—		21,675			—			59,525
	Other long-term liabilities	789			—		82,148			—			82,937
	Long-term debt	263,343			—		—			—			263,343
	Equity	388,470			1		(413,024		)	413,023			388,470
	Total liabilities and equity	$	690,452		$	1	$	529,455		$	(425,633	)	$	794,275
	Unaudited Condensed Consolidating Statement of Operations
	For the Three Months Ended March 31, 2015
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Consolidating			Total
										Entries
		($ in thousands)
	Total revenues	$	21,227		$	—	$	30,895		$	—		$	52,122
	Operations and maintenance	—			—		10,082			—			10,082
	Taxes other than income	—			—		1,388			—			1,388
	General and administrative	2,082			—		8,907			—			10,989
	Depreciation, depletion and amortization	136			—		14,509			—			14,645
	Impairment	—			—		68,344			—			68,344
	Income (loss) from operations	19,009			—		(72,335		)	—			(53,326		)
	Interest expense, net	(2,318		)	—		—			—			(2,318		)
	Other non-operating income	4,257			—		2,264			(4,386		)	2,135
	Other non-operating expense	(6,459		)	—		(2,997		)	4,386			(5,070		)
	Income (loss) before income taxes	14,489			—		(73,068		)	—			(58,579		)
Income tax expense (benefit)	96			—		(922		)	—			(826		)
Equity in earnings of subsidiaries	(73,110		)	—		—			73,110			—
Loss from continuing operations	(58,717		)	—		(72,146		)	73,110			(57,753		)
Discontinued operations, net of tax	(2		)	—		(964		)	—			(966		)
Net loss	$	(58,719	)	$	—	$	(73,110	)	$	73,110		$	(58,719	)
Unaudited Condensed Consolidating Statement of Operations
For the Three Months Ended March 31, 2014
	Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
	($ in thousands)
Total revenues	$	(10,033	)	$	—	$	55,236		$	—		$	—		$	45,203
Operations and maintenance	—			—		11,498			—			—			11,498
Taxes other than income	—			—		3,791			—			—			3,791
General and administrative	2,897			—		10,393			—			—			13,290
Depreciation, depletion and amortization	53			—		20,353			—			—			20,406
Loss from operations	(12,983		)	—		9,201			—			—			(3,782		)
Interest expense, net	(4,754		)	—		—			—			—			(4,754		)
Other non-operating income	2,221			—		2,301			—			(4,522		)	—
Other non-operating expense	(1,716		)	—		(3,095		)	—			4,522			(289		)
Loss before income taxes	(17,232		)	—		8,407			—			—			(8,825		)
Income tax benefit	(267		)	—		(598		)	—			—			(865		)
Equity in earnings of subsidiaries	18,634			—		—			—			(18,634		)	—
Loss from continuing operations	1,669			—		9,005			—			(18,634		)	(7,960		)
Discontinued operations, net of tax	(20,232		)	—		9,636			(7		)	—			(10,603		)
Net loss	$	(18,563	)	$	—	$	18,641		$	(7	)	$	(18,634	)	$	(18,563	)
Unaudited Condensed Consolidating Statement of Cash Flows
For the Three Months Ended March 31, 2015
	Parent Issuer			Co-Issuer		Subsidiary Guarantors			Consolidating Entries			Total
	($ in thousands)
Net cash flows provided by operating activities	$	(14,013	)	$	—	$	28,740		$	—		$	14,727
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to property, plant and equipment	(334		)	—		(27,721		)	—			(28,055		)
Proceeds from sale of short-term investments	77,755			—		—			—			77,755
Net cash flows provided by investing activities	77,421			—		(27,721		)	—			49,700
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term debt	45,300			—		—			—			45,300
Repayment of long-term debt	(95,900		)	—		—			—			(95,900		)
Payments for derivative contracts	(940		)	—		—			—			(940		)
Repurchase of common units	(2,662		)	—		—			—			(2,662		)
Distributions to members and affiliates	(10,565		)	—		—			—			(10,565		)
Net cash flows used in financing activities	(64,767		)	—		—			—			(64,767		)
Net cash flows used in discontinued operations	(2		)	—		(964		)	—			(966		)
Net decrease in cash and cash equivalents	(1,361		)	—		55			—			(1,306		)
Cash and cash equivalents at beginning of period	2,686			1		(1,344		)	—			1,343
Cash and cash equivalents at end of period	$	1,325		$	1	$	(1,289	)	$	—		$	37
Unaudited Condensed Consolidating Statement of Cash Flows
For the Three Months Ended March 31, 2014
	Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
	($ in thousands)
Net cash flows provided by operating activities	$	30,293		$	—	$	(6,490	)	$	—		$	—		$	23,803
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to property, plant and equipment	(336		)	—		(41,946		)	—			—			(42,282		)
Net cash flows used in investing activities	(336		)	—		(41,946		)	—			—			(42,282		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term debt	144,250			—		—			—			—			144,250
Repayment of long-term debt	(127,050		)	—		—			—			—			(127,050		)
Payment of debt issuance cost	(205		)	—		—			—			—			(205		)
Payments for derivative contracts	(1,708		)	—		—			—			—			(1,708		)
Distributions to members and affiliates	(23,801		)	—		—			—			—			(23,801		)
Net cash flows used in financing activities	(8,514		)	—		—			—			—			(8,514		)
Net cash flows provided by discontinued operations	(17,154		)	—		49,678			16			—			32,540
Net increase in cash and cash equivalents	4,289			—		1,242			16			—			5,547
Cash and cash equivalents at beginning of period	1,237			1		(1,389		)	227			—			76
Cash and cash equivalents at end of period	$	5,526		$	1	$	(147	)	$	243		$	—		$	5,623

Summary_of_Significant_Account1

Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Basis of Presentation and Principles of Consolidation [Text Block]	Basis of Presentation and Principles of Consolidation—The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements presented in the Partnership's Annual Report on Form 10-K for the year ended December 31, 2014 (the "2014 10-K"). In the opinion of management, the accompanying unaudited condensed consolidated financial statements contain all appropriate adjustments, all of which are normally recurring adjustments unless otherwise noted, considered necessary to present fairly the financial position of the Partnership and its consolidated subsidiaries and the results of operations and cash flows for the respective periods. Operating results for the three months ended March 31, 2015 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2015.
	All intercompany accounts and transactions are eliminated in the unaudited condensed consolidated financial statements.
	The Partnership has provided a discussion of significant accounting policies in its 2014 annual report on Form 10-K. Certain items from that discussion are repeated or updated below as necessary to assist in the understanding of these financial statements.
Use of Estimates, Policy [Policy Text Block]	Use of Estimates—The preparation of financial statements in conformity 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 revenues and expenses during the reported period. Significant estimates are required for proved oil and natural gas reserves, which can affect the carrying value of oil and natural gas properties. The Partnership evaluates its estimates and assumptions on a regular basis. The Partnership bases its estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results could differ from those estimates and such differences could be material.
Short-term Investments [Policy Text Block]	Short-term Investments— A portion of the consideration received for the Midstream Business Contribution included Regency common units. These common units have a readily determinable fair value, are being classified as available-for-sale equity securities and are recorded as short-term investments on the unaudited condensed consolidated balance sheets. Unrealized gains and losses associated with increases and decreases in the fair value of these securities are included in other comprehensive income until such time that the gains and losses become realized and then will be included in the unaudited condensed consolidated statements of operations. Losses from declines in fair value determined to be other than temporary are recorded in the unaudited condensed consolidated statements of operations as a loss on short-term investments. Distributions received from Regency as a result of holding these common units are recorded as other income on the unaudited condensed consolidated statements of operations.
	For the three months ended March 31, 2015, the Partnership received and recorded distributions from Regency of $2.1 million, recorded a $2.0 million loss as a result of the sale of Regency common units and recorded a $3.6 million unrealized loss resulting from the decrease in the fair value, which the Partnership deemed to be temporary, of the remaining Regency common units. As of March 31, 2015, the Partnership held 3,188,624 Regency common units, which did not include sales of 150,000 Regency common units that had not settled as of March 31, 2015 and for which a receivable of $3.4 million was recorded as part of accounts receivable in the unaudited condensed consolidated balance sheets.
Impairment of Long-Lived Assets, Policy [Policy Text Block]	Impairment of Long-Lived Assets—Management evaluates whether the carrying value of non-oil and natural gas long-lived assets has been impaired when circumstances indicate the carrying value of those assets may not be recoverable. This evaluation is based on undiscounted cash flow projections. The carrying amount is not recoverable if it exceeds the undiscounted sum of cash flows expected to result from the use and eventual disposition of the assets. Management considers various factors when determining if these assets should be evaluated for impairment, including, but not limited to:
	•	significant adverse changes in legal factors or in the business climate;
	•	a current-period operating or cash flow loss combined with a history of operating or cash flow losses or a projection or forecast which demonstrates continuing losses associated with the use of a long-lived asset;
	•	an accumulation of costs significantly in excess of the amount originally expected for the acquisition or construction of a long-lived asset;
	•	significant adverse changes in the extent or manner in which an asset is used or in its physical condition;
	•	a significant change in the market value of an asset; or
	•	a current expectation that, more likely than not, an asset will be sold or otherwise disposed of before the end of its estimated useful life.
	For its oil and natural gas long-lived assets, the Partnership reviews its proved properties at the field level when management determines that events or circumstances indicate that the recorded carrying value of the properties may not be recoverable. Such events include a negative revision or unfavorable projection of future oil and natural gas reserves that will be produced from a field and/or forward prices resulting from this future production, the timing of this future production, future costs to produce the oil and natural gas, and future inflation levels.
	If the carrying value is not recoverable on an undiscounted basis, the impairment loss is measured as the excess of the asset's carrying value over its fair value. Management assesses the fair value of long-lived assets using commonly accepted techniques, and may use more than one method, including, but not limited to, recent third party comparable sales, internally developed discounted cash flow analysis and analysis from outside advisors. Significant changes in market conditions resulting from events such as the condition of an asset or a change in management's intent to utilize the asset would generally require management to reassess the cash flows related to the long-lived assets.
	See Note 4 for further discussion on impairment charges.
Revenue Recognition, Policy [Policy Text Block]	Revenue Recognition—Revenues associated with sales of natural gas, NGLs, crude oil, condensate and sulfur are recognized when title passes to the customer, which is when the risk of ownership passes to the customer and physical delivery occurs.
	Revenues from the Partnership's Midstream Business included the sale of natural gas, NGLs, crude oil, condensate, sulfur and helium and from the compression, gathering, processing, treating and transportation of natural gas. Revenues associated with transportation and processing fees were recognized in the period when the services were provided. These revenues have been classified as discontinued operations within the unaudited condensed consolidated statements of operations.
Sales Method or Entitlements Method, Policy [Policy Text Block]	Natural gas revenues produced from the Partnership's natural gas interests are based on the amount of natural gas sold to purchasers. The volumes of natural gas sold may differ from the volumes to which the Partnership is entitled based on its interests in the properties. Differences between volumes sold and volumes based on entitlements create natural gas imbalances. Imbalances are reflected as adjustments to reported natural gas reserves and future cash flows.  The Partnership had long-term imbalance payables totaling $0.4 million and $0.3 million as of March 31, 2015 and December 31, 2014, respectfully.
Derivatives, Policy [Policy Text Block]	Derivatives—Authoritative guidance establishes accounting and reporting standards for derivative instruments, including certain derivative instruments embedded in other contracts, and for hedging activities. It requires an entity to recognize all derivatives as either assets or liabilities in the statement of financial position and measure those instruments at fair value. The guidance provides that normal purchase and sale contracts, when appropriately designated, are not subject to the guidance. Normal purchase and sales are contracts which provide for the purchase or sale of something, other than a financial instrument or derivative instrument, which will be delivered in quantities expected to be used or sold by the reporting entity over a reasonable period in the normal course of business. The Partnership's forward natural gas and crude oil purchase and sales contracts are designated as normal purchases and normal sales. The Partnership uses financial instruments such as swaps, collars and other derivatives to mitigate the risks to cash flows resulting from changes in commodity prices and interest rates. The Partnership recognizes these financial instruments on its unaudited condensed consolidated balance sheet at the instrument's fair value with changes in fair value reflected in the unaudited condensed consolidated statement of operations, as the Partnership has not designated any of these derivative instruments as hedges. The cash flows from derivatives are reported as cash flows from operating activities unless the derivative contract is deemed to contain a financing element. Derivatives deemed to contain a financing element are reported as a financing activity in the unaudited condensed consolidated statement of cash flows. See Note 10 for a description of the Partnership's risk management activities.
Other Reclassifications, Policy [Policy Text Block]	Other Reclassifications—Certain prior period financial statement balances have been reclassified to conform to current year presentation. These reclassifications had no effect on the recorded net income.
Asset Retirement Obligations, Policy [Policy Text Block]	The Partnership recognizes asset retirement obligations associated with the retirement of tangible long-lived assets that result from the acquisition, construction and development of the assets. The Partnership records the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. The Partnership makes estimates of property abandonment costs that, in some cases, will not be incurred until a substantial number of years in the future. Such cost estimates could be subject to significant revisions in subsequent years due to increases in current abandonment costs, changes in regulatory requirements, technological advances and other factors that may be difficult to predict. Although uncertainty about the timing and/or method of settlement may exist and may be conditional upon a future event, the obligation to perform the asset retirement activity is unconditional. Accordingly, the Partnership is required to recognize a liability for the fair value of a conditional asset retirement obligation upon initial recognition if the fair value of the liability can be reasonably estimated. The fair value of additions to the asset retirement obligation is estimated using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation include estimates of (i) remediation costs, (ii) remaining lives, (iii) future inflation factors and (iv) a credit-adjusted risk free interest rate.
Intangible Assets, Finite-Lived, Policy [Policy Text Block]	Intangible assets consist of rights-of-way and easements, which the Partnership amortizes over the estimated useful life of 20 years.
Earnings Per Share, Policy [Policy Text Block]	Basic earnings per unit is computed by dividing the net income (loss) by the weighted average number of units outstanding during a period. To determine net income (loss) allocated to each class of ownership (common and restricted common units), the Partnership first allocates net income (loss) in accordance with the amount of distributions made for the quarter by each class, if any. The remaining net income is allocated to each class in proportion to the class weighted average number of units outstanding for a period as compared to the weighted average number of units for all classes for the period, with the exception of net losses. Net losses are allocated to just the common units.
	As of March 31, 2015 and 2014, the Partnership had unvested restricted common units outstanding, which are considered dilutive securities. These units are considered in the diluted weighted average common units outstanding number in periods of net income. In periods of net losses, these units are excluded from the diluted weighted average common units outstanding number.
	The majority of the restricted units granted under the LTIP, as discussed in Note 14, contain non-forfeitable rights to the distributions declared by the Partnership and therefore meet the definition of participating securities. Participating securities are required to be included in the computation of earnings per unit pursuant to the two-class method. Restricted units granted in 2013 to certain senior executives and members of the board of directors are not eligible to receive the distributions declared by the Partnership and therefore do not meet the definition of participating securities.

Property_Plant_and_Equipment_P

Property, Plant and Equipment Property, Plant and Equipment (Tables)	3 Months Ended
	Mar. 31, 2015
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment [Table Text Block]	Property, plant and equipment consisted of the following:
		March 31,			December 31,
		2015			2014
		($ in thousands)
	Equipment and machinery	$	101		$	101
	Vehicles and transportation equipment	212			212
	Office equipment, furniture and fixtures	3,020			3,020
	Computer equipment	13,583			13,234
	Proved properties	863,565			905,622
	Unproved properties	7,066			7,512
	Work in progress	1,201			1,195
		888,748			930,896
	Less: accumulated depreciation, depletion and amortization	(456,457		)	(442,908		)
	Net property, plant and equipment	$	432,291		$	487,988
	The following table sets forth the total depreciation, depletion and impairment expense by type of asset within the Partnership's unaudited condensed consolidated statements of operations:
			Three Months Ended March 31,
			2015			2014
		($ in thousands)
	Depreciation		$	559		$	707
	Depletion		$	13,719		$	19,672
	Impairment expense:
	Proved properties (a)		$	68,344		$	—
	________________________________
	(a)During the three months ended March 31, 2015, the Partnership incurred impairment charges related to certain proved properties in Mid-Continent, East Texas and Permian regions primarily due to lower commodity prices.
	The table above does not include amounts related to the Partnership's Midstream Business, as these amounts have been classified as part of discontinued operations within the unaudited condensed consolidated statement of operations (see Note 16).

Asset_Retirement_Obligations_A

Asset Retirement Obligations Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation [Table Text Block]	A reconciliation of the Partnership's liability for asset retirement obligations is as follows:
		2015			2014
		($ in thousands)
	Asset retirement obligations—January 1 (a)	$	50,873		$	48,564
	Additional liabilities	9			16
	Liabilities settled	(1,302		)	(682		)
	Revision to liabilities	124			(105		)
	Accretion expense	793			812
	Asset retirement obligations—March 31 (a)	$	50,497		$	48,605
	_____________________________________
	(a)	As of March 31, 2015 and December 31, 2014, $2.9 million and $3.0 million, respectively, were included within accrued liabilities in the unaudited condensed consolidated balance sheets.
	The table above does not include the activity related to asset retirement obligations associated with the Partnership's Midstream Business, as these amounts have been classified as discontinued operations within the unaudited condensed consolidated statement of operations (see Note 16).
	During the three months ended March 31, 2015 and 2014, the Partnership made increase revisions of $0.1 million and decrease revisions of $0.1 million, respectively, to certain asset retirement obligations due to changes in the estimated costs to remediate.

Intangible_Assets_Intangible_A

Intangible Assets Intangible Assets (Tables)	3 Months Ended
	Mar. 31, 2015
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Finite-Lived Intangible Assets [Table Text Block]	Intangible assets consisted of the following:
		March 31,			December 31,
		2015			2014
		($ in thousands)
	Rights-of-way and easements—at cost	$	3,920		$	3,920
	Less: accumulated amortization	(897		)	(848		)
	Net intangible assets	$	3,023		$	3,072
Schedule of Impaired Intangible Assets [Table Text Block]	The following table sets forth amortization expense by type of intangible asset within the Partnership's unaudited condensed consolidated statements of operations:
			Three Months Ended
			March 31,
			2015			2014
		($ in thousands)
	Amortization		$	49		$	49
	The table above does not include amounts related to the Partnership's Midstream Business, as these amounts have been classified as part of discontinued operations within the unaudited condensed consolidated statement of operations (see Note 16).
Schedule of Finite-Lived Intangible Assets, Future Amortization Expense [Table Text Block]	Estimated future amortization expense related to the intangible assets at March 31, 2015 is as follows (in thousands):
	Year ending December 31,
	2015	$	147
	2016	$	196
	2017	$	196
	2018	$	196
	2019	$	196
	Thereafter	$	2,092

Long_Term_Debt_LongTerm_Debt_T

Long Term Debt Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2015
Long-term Debt, by Current and Noncurrent [Abstract]
Schedule of Long-term Debt Instruments [Table Text Block]	Long-term debt consisted of the following:
		March 31,			December 31,
		2015			2014
		($ in thousands)
	Revolving credit facility:	$	162,000		$	212,600
	Senior Notes:
	8.375% Senior Notes due 2019	51,120			51,120
	Unamortized bond discount	(358		)	(377		)
	Total Senior Notes	50,762			50,743
	Total long-term debt	$	212,762		$	263,343
Schedule of Debt Covenants [Table Text Block]	The following table presents the debt covenant levels specified in the Partnership's revolving credit facility and the actual covenant ratios as of March 31, 2015:
		Debt Covenant		Actual Covenant Ratio as of March 31, 2015
	Maximum total leverage ratio	4		1.8
	Minimum current ratio	1		5.8

Members_Equity_Members_Equity_

Members' Equity Members' Equity (Tables)	3 Months Ended
	Mar. 31, 2015
Distributions Made to Members or Limited Partners [Abstract]
Distributions Made to Limited Partners, by Distribution [Table Text Block]	The table below summarizes the distributions paid or payable and declared for the quarters listed below:
	Quarter Ended		Distribution		Record Date*	Payment Date
			per Common Unit
	December 31, 2014+		$	0.07	February 6, 2015	February 13, 2015
	March 31, 2015+		$	0.07	May 8, 2015	May 15, 2015
	_____________________________
	+	The distribution excludes certain restricted units under the LTIP (as defined in Note 14 below).
	*	Means the close of business on each of the listed Record Dates.

Related_Party_Transactions_Rel

Related Party Transactions Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2015
Related Party Transactions [Abstract]
Schedule of Related Party Transactions [Table Text Block]	The following table summarizes transactions between the Partnership and certain affiliated entities:
		Three Months Ended March 31,
		2015		2014
	Affiliates of Natural Gas Partners:	($ in thousands)
	Natural gas purchases from affiliates	$	—	$	1,142
	The transactions above were all related to the Partnership's Midstream Business and have been classified as part of discontinued operations within the unaudited condensed consolidated statement of operations (see Note 16).

Risk_Management_Activities_Ris

Risk Management Activities Risk Management Activities (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Interest Rate Derivatives [Table Text Block]	The following table sets forth certain information regarding the Partnership's interest rate swaps as of March 31, 2015:
	Effective Date		Expiration		Notional			Fixed
			Date		Amount			Rate
	12/31/14		12/31/19		$	175,000,000		2.3195	%
Schedule of Price Risk Derivatives [Table Text Block]	Commodity derivatives, as of March 31, 2015, that will mature during the years ended December 31, 2015 through 2019:
	Underlying		Type		Notional		Floor				Cap
					Volumes		Strike				Strike
					(units) (a)		Price				Price
							($/unit)(b)				($/unit)(b)
	Portion of Contracts Maturing in 2015
	Natural Gas		Swap (Pay Floating/Receive Fixed)		8,100,000		$	4.07
	Crude Oil		Costless Collar		360,000		$	90			$	97.55
	Crude Oil		Swap (Pay Floating/Receive Fixed)		472,500		$	89.78
	IsoButane		Swap (Pay Floating/Receive Fixed)		1,591,800		$	0.66
	Natural Gasoline		Swap (Pay Floating/Receive Fixed)		1,251,600		$	1.13
	Normal Butane		Swap (Pay Floating/Receive Fixed)		1,234,800		$	0.66
	Propane		Swap (Pay Floating/Receive Fixed)		3,952,200		$	0.54
	Contracts Maturing in 2016
	Natural Gas		Swap (Pay Floating/Receive Fixed)		9,480,000		$	4.25
	Crude Oil		Swap (Pay Floating/Receive Fixed)		936,000		$	84.66
	Contracts Maturing in 2017
	Crude Oil		Swap (Pay Floating/Receive Fixed)		444,000		$	89.24
	Contracts Maturing in 2018
	Crude Oil		Swap (Pay Floating/Receive Fixed)		396,000		$	88.78
	Contracts Maturing in 2019
	Crude Oil		Swap (Pay Floating/Receive Fixed)		348,000		$	88.39
	_______________________
	(a)	Volumes of natural gas are measured in MMbtu, volumes of crude oil are measured in barrels and volumes of NGLs are measured in gallons.
	(b)	Amounts represent the weighted average price. The weighted average prices are in $/MMbtu for natural gas, $/barrel for crude oil and $/gallon for NGLs.
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	The following tables set forth the fair values of interest rate and commodity derivative instruments not designated as hedging instruments and their location within the unaudited condensed consolidated balance sheet as of March 31, 2015 and December 31, 2014:
		As of March 31, 2015
		Derivative Assets					Derivative Liabilities
		Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
		($ in thousands)
	Interest rate derivatives - liabilities	Current assets		$	(3,220	)	Current liabilities		$	—
	Interest rate derivatives - liabilities	Long-term assets		(4,712		)	Long-term liabilities		—
	Commodity derivatives - assets	Current assets		50,624			Current liabilities		—
	Commodity derivatives - assets	Long-term assets		54,718			Long-term liabilities		—
	Commodity derivatives - liabilities	Current assets		(11		)	Current liabilities		—
	Total derivatives			$	97,399				$	—
		As of December 31, 2014
		Derivative Assets					Derivative Liabilities
		Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
		($ in thousands)
	Interest rate derivatives - liabilities	Current assets		$	(3,165	)	Current liabilities		$	—
	Interest rate derivatives - liabilities	Long-term assets		(2,641		)	Long-term liabilities		—
	Commodity derivatives - assets	Current assets		47,971			Current liabilities		—
	Commodity derivatives - assets	Long-term assets		49,130			Long-term liabilities		—
	Total derivatives			$	91,295				$	—
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table Text Block]	The following table sets forth the location of gains and losses for derivatives not designated as hedging instruments within the Partnership's unaudited condensed consolidated statement of operations:
	Amount of Gain (Loss) Recognized in Income on Derivatives			Three Months Ended March 31,
				2015			2014
				($ in thousands)
	Interest rate derivatives	Interest rate risk management losses, net		$	(3,066	)	$	(290	)
	Commodity derivatives	Commodity risk management gains (losses), net		22,600			(10,033		)
	Commodity derivatives	Discontinued operations		—			(4,911		)
	Commodity derivatives - trading	Discontinued operations		—			(987		)
		Total		$	19,534		$	(16,221	)

Fair_Value_of_Financial_Instru1

Fair Value of Financial Instruments Fair Value of Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following tables disclose the fair value of the Partnership's derivative instruments and equity investments as of March 31, 2015 and December 31, 2014:
		As of March 31, 2015
		Level 1		Level 2			Level 3		Netting (a)			Total
		($ in thousands)
	Assets:
	Crude oil derivatives	$	—	$	84,171		$	—	$	—		$	84,171
	Natural gas derivatives	—		21,049			—		—			21,049
	NGL derivatives	—		122			—		(11		)	111
	Interest rate swaps	—		—			—		(7,932		)	(7,932		)
	Equity investments	72,924		—			—		—			72,924
	Total	$	72,924	$	105,342		$	—	$	(7,943	)	$	170,323
	Liabilities:
	NGL derivatives	—		(11		)	—		11			—
	Interest rate swaps	—		(7,932		)	—		7,932			—
	Total	$	—	$	(7,943	)	$	—	$	7,943		$	—
	____________________________
	(a)	Represents counterparty netting under the agreement governing such derivative contracts.
		As of December 31, 2014
		Level 1		Level 2			Level 3		Netting (a)			Total
		($ in thousands)
	Assets:
	Crude oil derivatives	$	—	$	78,516		$	—	$	—		$	78,516
	Natural gas derivatives	—		18,585			—		—			18,585
	Interest rate swaps	—		—			—		(5,806		)	(5,806		)
	Equity investments	153,448		—			—		—			153,448
	Total	$	153,448	$	97,101		$	—	$	(5,806	)	$	244,743
	Liabilities:
	Interest rate swaps	—		(5,806		)	—		5,806			—
	Total	$	—	$	(5,806	)	$	—	$	5,806		$	—
	____________________________
	(a)	Represents counterparty netting under the agreement governing such derivative contracts.
Fair Value Measurements, Nonrecurring [Table Text Block]	The following table discloses the fair value of the Partnership's assets measured at fair value on a nonrecurring basis during the three months ended March 31, 2015:
		Three Months Ended March 31,
		2015		Level 1			Level 2		Level 3			Total Losses
		($ in thousands)
	Proved properties	$	44,658	$	—		$	—	$	44,658		$	68,344

Equity_Based_Compensation_Equi

Equity Based Compensation Equity Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2015
Share-based Compensation [Abstract]
Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]	A summary of the changes in outstanding restricted common units for the three months ended March 31, 2015 is provided below:
		Number of		Weighted
		Restricted		Average
		Units		Fair Value
	Outstanding at December 31, 2014	2,419,750		$	6.06
	Granted	23,000		$	2.37
	Vested	(60,700	)	$	4.46
	Forfeited	(260,087	)	$	6.69
	Outstanding at March 31, 2015	2,121,963		$	5.99
	A summary of the changes in outstanding performance units for the three months ended March 31, 2015 is provided below:
		Number of		Weighted
		Performance		Average
		Units		Fair Value
	Outstanding at December 31, 2014	647,788		$	3.63
	Forfeited	(123,175	)	$	3.59
	Outstanding at March 31, 2015	524,613		$	3.64

Earnings_Per_Unit_Earnings_Per

Earnings Per Unit Earnings Per Unit (Tables)	3 Months Ended
	Mar. 31, 2015
Earnings Per Unit [Abstract]
Schedule of Weighted Average Number of Shares [Table Text Block]	The following table presents the Partnership's calculation of basic and diluted units outstanding for the periods indicated:
			Three Months Ended March 31,
			2015			2014
		(in thousands)
	Weighted average units outstanding during period:
	Common units - Basic		149,143			156,644
	Common units - Diluted		149,143			156,644
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]
	The following table presents the Partnership's basic and diluted loss per unit for the three months ended March 31, 2015:
			Total				Common Units			Restricted Common Units*
			($ in thousands, except for per unit amounts)
	Loss from continuing operations		$	(57,753	)
	Distributions		10,561				$	10,432		$	129
	Assumed loss from continuing operations after distribution to be allocated		(68,314		)		(68,314		)	—
	Assumed allocation of loss from continuing operations		(57,753		)		(57,882		)	129
	Discontinued operations, net of tax		(966		)		(966		)	—
	Assumed net loss to be allocated		$	(58,719	)		$	(58,848	)	$	129
	Basic loss from continuing operations per unit						$	(0.39	)
	Basic discontinued operations per unit						$	(0.01	)
	Basic loss per unit						$	(0.40	)
	Diluted loss from continuing operations per unit						$	(0.39	)
	Diluted discontinued operations per unit						$	(0.01	)
	Diluted loss per unit						$	(0.40	)
	_____________________________
	*	Restricted common units granted under the LTIP that contain non-forfeitable rights to the distributions declared by the Partnership.
	The following table presents the Partnership's basic and diluted loss per unit for the three months ended March 31, 2014:
			Total				Common Units			Restricted Common Units*
			($ in thousands, except for per unit amounts)
	Loss from continuing operations		$	(7,960	)
	Distributions**		—				$	—		$	—
	Assumed loss from continuing operations after distribution to be allocated		(7,960		)		(7,960		)	—
	Assumed allocation of loss from continuing operations		(7,960		)		(7,960		)	—
	Discontinued operations, net of tax		(10,603		)		(10,603		)	—
	Assumed net loss to be allocated		$	(18,563	)		$	(18,563	)	$	—
	Basic income from continuing operations per unit						$	(0.05	)
	Basic discontinued operations per unit						$	(0.07	)
	Basic loss per unit						$	(0.12	)
	Diluted income from continuing operations per unit						$	(0.05	)
	Diluted discontinued operations per unit						$	(0.07	)
	Diluted income per unit						$	(0.12	)

Divestiture_Related_Activities1

Divestiture Related Activities Divestiture Related Activites(Tables)	3 Months Ended
	Mar. 31, 2015
Discontinued Operations and Disposal Groups [Abstract]
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	The following table is the reconciliation of major classes of line items classified as discontinued operations for the Midstream Business for the three months ended March 31, 2015 and 2014:
			Three Months Ended March 31,
			2015				2014
			($ in thousands)
	Class of statement of operations line item of discontinued operations:
	Revenue		$	—			$	302,871
	Cost of natural gas, NGLs, condensate and helium		—				244,973
	Operations, maintenance and taxes other than income		—				25,049
	General and administrative		966				8,101
	Depreciation, amortization and impairment		—				22,199
	Interest expense		—				(13,232		)
	Other expense		—				(8		)
	Operating loss from discontinued operations before taxes		(966		)		(10,691		)
	Income tax benefit		—				(88		)
	Discontinued operations, net of tax		$	(966	)		$	(10,603	)
Restructuring and Related Costs [Table Text Block]	The following table summarizes activity related to liabilities associated with the Partnership's restructuring activities during the three months ended March 31, 2015.
		Employee Related Costs				Facility and Other Costs				Total
		($ in thousands)
	Balance at December 31, 2014	$	835			$	490			$	1,325
	Payments and other adjustments	(183		)		1,026				843
	Balance at March 31, 2015	$	652			$	1,516			$	2,168

Subsidiary_Guarantors_Subsidia

Subsidiary Guarantors Subsidiary Guarantors (Tables)	3 Months Ended
	Mar. 31, 2015
SUBSIDIARY GUARANTORS [Abstract]
Subsidiary Guarantor Consolidating Balance Sheet [Table Text Block]	Condensed Consolidating Balance Sheet
	March 31, 2015
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Consolidating			Total
										Entries
		($ in thousands)
	ASSETS:
	Accounts receivable – related parties	$	865,930		$	—	$	—		$	(865,930	)	$	—
	Other current assets	129,008			1		36,039			—			165,048
	Total property, plant and equipment, net	1,531			—		430,760			—			432,291
	Investment in subsidiaries	(486,135		)	—		—			486,135			—
	Total other long-term assets	55,072			—		4,826			—			59,898
	Total assets	$	565,406		$	1	$	471,625		$	(379,795	)	$	657,237
	LIABILITIES AND EQUITY:
	Accounts payable – related parties	$	—		$	—	$	865,930		$	(865,930	)	$	—
	Other current liabilities	37,497			—		10,435			—			47,932
	Other long-term liabilities	370			—		81,396			—			81,766
	Long-term debt	212,762			—		—			—			212,762
	Equity	314,777			1		(486,136		)	486,135			314,777
	Total liabilities and equity	$	565,406		$	1	$	471,625		$	(379,795	)	$	657,237
	Unaudited Condensed Consolidating Balance Sheet
	December 31, 2014
		Parent Issuer			Co-Issuer		Subsidiary			Consolidating Entries			Total
							Guarantors
		($ in thousands)
	ASSETS:
	Accounts receivable – related parties	$	838,656		$	—	$	—		$	(838,656	)	$	—
	Other current assets	211,213			1		37,889			—			249,103
	Total property, plant and equipment, net	1,334			—		486,654			—			487,988
	Investment in subsidiaries	(413,023		)	—		—			413,023			—
	Total other long-term assets	52,272			—		4,912			—			57,184
	Total assets	$	690,452		$	1	$	529,455		$	(425,633	)	$	794,275
	LIABILITIES AND EQUITY:
	Accounts payable – related parties	$	—		$	—	$	838,656		$	(838,656	)	$	—
	Other current liabilities	37,850			—		21,675			—			59,525
	Other long-term liabilities	789			—		82,148			—			82,937
	Long-term debt	263,343			—		—			—			263,343
	Equity	388,470			1		(413,024		)	413,023			388,470
	Total liabilities and equity	$	690,452		$	1	$	529,455		$	(425,633	)	$	794,275
Subsidiary Guarantors Consolidating Statements of Operations [Table Text Block]
	Unaudited Condensed Consolidating Statement of Operations
	For the Three Months Ended March 31, 2015
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Consolidating			Total
										Entries
		($ in thousands)
	Total revenues	$	21,227		$	—	$	30,895		$	—		$	52,122
	Operations and maintenance	—			—		10,082			—			10,082
	Taxes other than income	—			—		1,388			—			1,388
	General and administrative	2,082			—		8,907			—			10,989
	Depreciation, depletion and amortization	136			—		14,509			—			14,645
	Impairment	—			—		68,344			—			68,344
	Income (loss) from operations	19,009			—		(72,335		)	—			(53,326		)
	Interest expense, net	(2,318		)	—		—			—			(2,318		)
	Other non-operating income	4,257			—		2,264			(4,386		)	2,135
	Other non-operating expense	(6,459		)	—		(2,997		)	4,386			(5,070		)
	Income (loss) before income taxes	14,489			—		(73,068		)	—			(58,579		)
	Income tax expense (benefit)	96			—		(922		)	—			(826		)
	Equity in earnings of subsidiaries	(73,110		)	—		—			73,110			—
	Loss from continuing operations	(58,717		)	—		(72,146		)	73,110			(57,753		)
	Discontinued operations, net of tax	(2		)	—		(964		)	—			(966		)
	Net loss	$	(58,719	)	$	—	$	(73,110	)	$	73,110		$	(58,719	)
	Unaudited Condensed Consolidating Statement of Operations
	For the Three Months Ended March 31, 2014
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
		($ in thousands)
	Total revenues	$	(10,033	)	$	—	$	55,236		$	—		$	—		$	45,203
	Operations and maintenance	—			—		11,498			—			—			11,498
	Taxes other than income	—			—		3,791			—			—			3,791
	General and administrative	2,897			—		10,393			—			—			13,290
	Depreciation, depletion and amortization	53			—		20,353			—			—			20,406
	Loss from operations	(12,983		)	—		9,201			—			—			(3,782		)
	Interest expense, net	(4,754		)	—		—			—			—			(4,754		)
	Other non-operating income	2,221			—		2,301			—			(4,522		)	—
	Other non-operating expense	(1,716		)	—		(3,095		)	—			4,522			(289		)
	Loss before income taxes	(17,232		)	—		8,407			—			—			(8,825		)
	Income tax benefit	(267		)	—		(598		)	—			—			(865		)
	Equity in earnings of subsidiaries	18,634			—		—			—			(18,634		)	—
	Loss from continuing operations	1,669			—		9,005			—			(18,634		)	(7,960		)
	Discontinued operations, net of tax	(20,232		)	—		9,636			(7		)	—			(10,603		)
	Net loss	$	(18,563	)	$	—	$	18,641		$	(7	)	$	(18,634	)	$	(18,563	)
Subsidiary Guarantor Consolidating Statements of Cash Flows [Table Text Block]	Unaudited Condensed Consolidating Statement of Cash Flows
	For the Three Months Ended March 31, 2015
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Consolidating Entries			Total
		($ in thousands)
	Net cash flows provided by operating activities	$	(14,013	)	$	—	$	28,740		$	—		$	14,727
	CASH FLOWS FROM INVESTING ACTIVITIES:
	Additions to property, plant and equipment	(334		)	—		(27,721		)	—			(28,055		)
	Proceeds from sale of short-term investments	77,755			—		—			—			77,755
	Net cash flows provided by investing activities	77,421			—		(27,721		)	—			49,700
	CASH FLOWS FROM FINANCING ACTIVITIES:
	Proceeds from long-term debt	45,300			—		—			—			45,300
	Repayment of long-term debt	(95,900		)	—		—			—			(95,900		)
	Payments for derivative contracts	(940		)	—		—			—			(940		)
	Repurchase of common units	(2,662		)	—		—			—			(2,662		)
	Distributions to members and affiliates	(10,565		)	—		—			—			(10,565		)
	Net cash flows used in financing activities	(64,767		)	—		—			—			(64,767		)
	Net cash flows used in discontinued operations	(2		)	—		(964		)	—			(966		)
	Net decrease in cash and cash equivalents	(1,361		)	—		55			—			(1,306		)
	Cash and cash equivalents at beginning of period	2,686			1		(1,344		)	—			1,343
	Cash and cash equivalents at end of period	$	1,325		$	1	$	(1,289	)	$	—		$	37
	Unaudited Condensed Consolidating Statement of Cash Flows
	For the Three Months Ended March 31, 2014
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
		($ in thousands)
	Net cash flows provided by operating activities	$	30,293		$	—	$	(6,490	)	$	—		$	—		$	23,803
	CASH FLOWS FROM INVESTING ACTIVITIES:
	Additions to property, plant and equipment	(336		)	—		(41,946		)	—			—			(42,282		)
	Net cash flows used in investing activities	(336		)	—		(41,946		)	—			—			(42,282		)
	CASH FLOWS FROM FINANCING ACTIVITIES:
	Proceeds from long-term debt	144,250			—		—			—			—			144,250
	Repayment of long-term debt	(127,050		)	—		—			—			—			(127,050		)
	Payment of debt issuance cost	(205		)	—		—			—			—			(205		)
	Payments for derivative contracts	(1,708		)	—		—			—			—			(1,708		)
	Distributions to members and affiliates	(23,801		)	—		—			—			—			(23,801		)
	Net cash flows used in financing activities	(8,514		)	—		—			—			—			(8,514		)
	Net cash flows provided by discontinued operations	(17,154		)	—		49,678			16			—			32,540
	Net increase in cash and cash equivalents	4,289			—		1,242			16			—			5,547
	Cash and cash equivalents at beginning of period	1,237			1		(1,389		)	227			—			76
	Cash and cash equivalents at end of period	$	5,526		$	1	$	(147	)	$	243		$	—		$	5,623

Summary_of_Significant_Account2

Summary of Significant Accounting Policies Narrative (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Loss on short-term investments	($2,004,000)	$0
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	-3,603,000	0
Distributions received from short term investments	2,134,000
Investment Owned, Balance, Shares	3,188,624
Regency units not settled at period end	150,000
Receivable from sale of short-term investments	3,449,000
Gas Balancing Payable	$400,000		$300,000

Property_Plant_and_Equipment_P1

Property, Plant and Equipment Property, Plant and Equipment (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment - Gross	$888,748	$930,896
Accumulated depreciation, depletion and amortization	-456,457	-442,908
Property, Plant and Equipment — Net	432,291	487,988
Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment - Gross	101	101
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment - Gross	212	212
Office Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment - Gross	3,020	3,020
Computer Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment - Gross	13,583	13,234
Proved Oil and Gas Properties [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment - Gross	863,565	905,622
Unproved Oil and Gas Properties [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment - Gross	7,066	7,512
Asset under Construction [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment - Gross	$1,201	$1,195

Property_Plant_and_Equipment_D

Property, Plant and Equipment Depreciation, Depletion, Amortization and Impairment (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Depreciation	$559	$707
Depletion	13,719	19,672
Oil and Gas Properties [Member]
Impairment of Long-Lived Assets Held-for-use	$68,344	$0

Asset_Retirement_Obligations_S

Asset Retirement Obligations Schedule of Change in Asset Retirement Obligation (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation - Beginning of Period	$50,873	[1]	$48,564
Additional liabilities	9		16
Liabilities settled	-1,302		-682
Revision to liabilities	124		-105
Accretion expense	793		812
Asset Retirement Obligation - End of Period	50,497		48,605
Asset Retirement Obligation, Current	$2,923			$2,966
[1]	As of March 31, 2015 and December 31, 2014, $2.9 million and $3.0 million, respectively, were included within accrued liabilities in the unaudited condensed consolidated balance sheets.

Intangible_Assets_Intangible_A1

Intangible Assets Intangible Assets (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible Assets — Net	$3,023	$3,072
Use Rights [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Rights-of-way and easements—at cost	3,920	3,920
Less: accumulated amortization	($897)	($848)

Intangible_Assets_Amortization

Intangible Assets Amortization and Impairment (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Amortization	$49	$49

Intangible_Assets_Future_Amort

Intangible Assets Future Amortization Expense (Details) (USD $)	Mar. 31, 2015
In Thousands, unless otherwise specified
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Amortization Expense, Remainder of Fiscal Year	$147
Finite-Lived Intangible Assets, Amortization Expense, Year Two	196
Finite-Lived Intangible Assets, Amortization Expense, Year Three	196
Finite-Lived Intangible Assets, Amortization Expense, Year Four	196
Finite-Lived Intangible Assets, Amortization Expense, Year Five	196
Finite-Lived Intangible Assets, Amortization Expense, after Year Five	$2,092

Intangible_Assets_Narrative_De

Intangible Assets Narrative (Details) (Use Rights [Member])	3 Months Ended
	Mar. 31, 2015
Use Rights [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Asset, Useful Life	20 years

Long_Term_Debt_LongTerm_Debt_D

Long Term Debt Long-Term Debt (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Debt Instrument [Line Items]
Revolving credit facility:	$162,000	$212,600
8 3/8% senior notes due 2019	51,120	51,120
Unamortized bond discount senior notes due 2019	-358	-377
Senior Notes	50,762	50,743
LONG-TERM DEBT	$212,762	$263,343

Long_Term_Debt_Debt_Covenants_

Long Term Debt Debt Covenants (Details)	Mar. 31, 2015
Total Leverage Ratio [Member]
Schedule of Debt Covenants [Line Items]
Line of Credit Facility, Covenant Ratio	1.8
Current Ratio [Member]
Schedule of Debt Covenants [Line Items]
Line of Credit Facility, Covenant Ratio	5.8
Maximum [Member] | Total Leverage Ratio [Member]
Schedule of Debt Covenants [Line Items]
Line of Credit Facility, Covenant Ratio	4
Minimum [Member] | Current Ratio [Member]
Schedule of Debt Covenants [Line Items]
Line of Credit Facility, Covenant Ratio	1

Long_Term_Debt_Narrative_Detai

Long Term Debt Narrative (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2014	Oct. 10, 2014	Apr. 01, 2015
	Rate
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount	$0
Revolving credit facility:	162,000,000	212,600,000
Line of Credit Facility, Commitment Fee Percentage	0.50%
Letters of Credit Sub-limit	50,000,000
Line of Credit Facility, Remaining Borrowing Capacity	158,000,000
Line of Credit Facility, Current Borrowing Capacity			320,000,000
Debt Instrument, Covenant Compliance	As of March 31, 2015, the Partnership was in compliance with the financial covenants under the Credit Agreement.
Line of Credit Facility, Maximum Borrowing Capacity			1,200,000,000
8 3/8% senior notes due 2019	51,120,000	51,120,000
Subsequent Event [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity				$270,000,000

Members_Equity_Narrative_Detai

Members' Equity Narrative (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Capital Unit [Line Items]
Limited Partners' Capital Account, Units Outstanding	149,027,423	150,154,909
Unvested Restricted Units granted	2,121,963	2,419,750
Equity Issuance, Market Value	$100,000,000
Equity Units, Issued	0
Stock Repurchase Program, Authorized Amount	100,000,000
Stock Repurchased and Retired During Period, Shares	1,171,584
Repurchase of common units	$2,622,000

Members_Equity_Distributions_D

Members' Equity Distributions (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Dividends Payable [Line Items]
Common Stock, Dividends, Per Share, Cash Paid	$0.07	$0.07
Distribution Made to Limited Partner, Date of Record	8-May-15	6-Feb-15
Distribution Made to Limited Partner, Distribution Date	15-May-15	13-Feb-15

Related_Party_Transactions_Sch

Related Party Transactions Schedule of Related Party Transactions (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Related Party Transaction [Line Items]
Natural gas purchases from affiliates	$0	$1,142

Risk_Management_Activities_Int

Risk Management Activities Interest Rate Derivatives (Details) (Effective Date, 12/31/2014 [Member], Interest Rate Swap [Member], USD $)	3 Months Ended
	Mar. 31, 2015
Derivative [Line Items]
Derivative, Maturity Date	31-Dec-19
Interest Rate Swap [Member]
Derivative [Line Items]
Derivative, Notional Amount	175,000,000
Derivative, Average Fixed Interest Rate	2.32%

Risk_Management_Activities_Com

Risk Management Activities Commodity Derivatives (Details)	Mar. 31, 2015
	MMbtu
Natural Gas Contract [Member] | Swap [Member] | Portion of contracts settling in 2015 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	8,100,000	[1]
Derivative, Average Floor Price	4.07	[2]
Natural Gas Contract [Member] | Swap [Member] | Portion of contracts settling in 2016 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	9,480,000	[1]
Derivative, Average Floor Price	4.25	[2]
Crude Oil Contract [Member] | Costless Collar [Member] | Portion of contracts settling in 2015 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	360,000	[1]
Derivative, Average Floor Price	90	[2]
Derivative, Average Cap Price	97.55	[2]
Crude Oil Contract [Member] | Swap [Member] | Portion of contracts settling in 2015 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	472,500	[1]
Derivative, Average Floor Price	89.78	[2]
Crude Oil Contract [Member] | Swap [Member] | Portion of contracts settling in 2016 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	936,000	[1]
Derivative, Average Floor Price	84.66	[2]
Crude Oil Contract [Member] | Swap [Member] | Portion of contracts settling in 2017 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	444,000	[1]
Derivative, Average Floor Price	89.24	[2]
Crude Oil Contract [Member] | Swap [Member] | Portion of contracts settling in 2018 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	396,000	[1]
Derivative, Average Floor Price	88.78	[2]
Crude Oil Contract [Member] | Swap [Member] | Portion of contracts settling in 2019 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	348,000	[1]
Derivative, Average Floor Price	88.39	[2]
Propane Contract [Member] | Swap [Member] | Portion of contracts settling in 2015 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	3,952,200	[1]
Derivative, Average Floor Price	0.54	[2]
IsoButane Contract [Member] | Swap [Member] | Portion of contracts settling in 2015 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	1,591,800	[1]
Derivative, Average Floor Price	0.66	[2]
Natural Gasoline Contract [Member] | Swap [Member] | Portion of contracts settling in 2015 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	1,251,600	[1]
Derivative, Average Floor Price	1.13	[2]
Normal Butane Contract [Member] | Swap [Member] | Portion of contracts settling in 2015 [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	1,234,800	[1]
Derivative, Average Floor Price	0.66	[2]
[1]	Volumes of natural gas are measured in MMbtu, volumes of crude oil are measured in barrels and volumes of NGLs are measured in gallons.
[2]	Amounts represent the weighted average price. The weighted average prices are in $/MMbtu for natural gas, $/barrel for crude oil and $/gallon for NGLs.

Risk_Management_Activities_Sch

Risk Management Activities Schedule of Derivative Instruments in the Statement of Financial Position (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]
Derivative assets, Current	$47,392	$44,805
Derivative assets, Noncurrent	50,007	46,490
Derivative Assets	97,399	91,295
Derivative Liabilities	0	0
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Liabilities, Current	-3,220	-3,165
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Long-term Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Liabilities, Noncurrent	-4,712	-2,641
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liabilities, Current	0	0
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Long-term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liabilities, Noncurrent	0	0
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Liabilities, Current	-11
Derivative assets, Current	50,624	47,971
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Long-term Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets, Noncurrent	54,718	49,130
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liabilities, Current	0
Derivative assets, Current	0	0
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Long-term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative assets, Noncurrent	$0	$0

Risk_Management_Activities_Sch1

Risk Management Activities Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate risk management losses, net	($3,066)	($290)
Commodity risk management (losses) gains	22,600	-10,033
Derivative Instruments, Gain (Loss) Recognized in Income, Net	19,534	-16,221
Interest Rate Contract [Member] | Other Expense [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate risk management losses, net	-3,066	-290
Commodity Contract [Member] | Commodity Risk Management Gains (Losses) [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Commodity risk management (losses) gains	22,600	-10,033
Commodity Contract [Member] | Discontinued Operations [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Commodity risk management (losses) gains	0	-4,911
Commodity Contract [Member] | Forward Contracts [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Commodity risk management (losses) gains	$0	($987)

Fair_Value_of_Financial_Instru2

Fair Value of Financial Instruments Fair Value, Assets and Liabilities Measured on a Recurring Basis (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Thousands, unless otherwise specified
Assets:
Derivative Assets	$97,399		$91,295
Short-term investments	72,924		153,448
Liabilities:
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring [Member]
Assets:
Derivative Assets	170,323		244,743
Derivative Asset, Fair Value, Gross Liability	-7,943	[1]	-5,806	[1]
Liabilities:
Derivative Liabilities	0		0
Derivative Liability, Fair Value, Gross Asset	7,943	[1]	5,806	[1]
Fair Value, Measurements, Recurring [Member] | Crude Oil Contract [Member]
Assets:
Derivative Assets	84,171		78,516
Derivative Asset, Fair Value, Gross Liability	0	[1]	0	[1]
Fair Value, Measurements, Recurring [Member] | Natural Gas Contract [Member]
Assets:
Derivative Assets	21,049		18,585
Derivative Asset, Fair Value, Gross Liability	0	[1]	0	[1]
Fair Value, Measurements, Recurring [Member] | Natural Gas Liquids Contract [Member]
Assets:
Derivative Assets	111
Derivative Asset, Fair Value, Gross Liability	-11	[1]
Liabilities:
Derivative Liabilities	0
Derivative Liability, Fair Value, Gross Asset	11	[1]
Fair Value, Measurements, Recurring [Member] | Interest Rate Contract [Member]
Assets:
Derivative Assets	7,932		5,806
Derivative Asset, Fair Value, Gross Liability	-7,932	[1]	-5,806	[1]
Liabilities:
Derivative Liabilities	0		0
Derivative Liability, Fair Value, Gross Asset	7,932	[1]	5,806	[1]
Fair Value, Measurements, Recurring [Member] | Short-term Investments [Member]
Assets:
Short-term investments	72,924		153,448
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	72,924		153,448
Assets:
Derivative Asset, Fair Value, Gross Liability	0
Liabilities:
Derivative Liability, Fair Value, Gross Liability			0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Crude Oil Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural Gas Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural Gas Liquids Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0
Assets:
Derivative Asset, Fair Value, Gross Liability	0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Interest Rate Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Assets:
Derivative Asset, Fair Value, Gross Liability	0
Liabilities:
Derivative Liability, Fair Value, Gross Liability			0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Short-term Investments [Member]
Assets:
Short-term investments	72,924		153,448
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	105,342		97,101
Assets:
Derivative Asset, Fair Value, Gross Liability	-7,943
Liabilities:
Derivative Liability, Fair Value, Gross Liability			5,806
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Crude Oil Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	84,171		78,516
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural Gas Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	21,049		18,585
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural Gas Liquids Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	122
Assets:
Derivative Asset, Fair Value, Gross Liability	-11
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Interest Rate Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Assets:
Derivative Asset, Fair Value, Gross Liability	-7,932
Liabilities:
Derivative Liability, Fair Value, Gross Liability			5,806
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Short-term Investments [Member]
Assets:
Short-term investments	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Assets:
Derivative Asset, Fair Value, Gross Liability	0
Liabilities:
Derivative Liability, Fair Value, Gross Liability			0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Crude Oil Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Liquids Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0
Assets:
Derivative Asset, Fair Value, Gross Liability	0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Interest Rate Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0		0
Assets:
Derivative Asset, Fair Value, Gross Liability	0
Liabilities:
Derivative Liability, Fair Value, Gross Liability			0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Short-term Investments [Member]
Assets:
Short-term investments	$0		$0
[1]	Represents counterparty netting under the agreement governing such derivative contracts.

Fair_Value_of_Financial_Instru3

Fair Value of Financial Instruments Fair Value, Assets and Liabilities Measured on a Nonrecurring Basis (Details) (Oil and Gas Properties [Member], USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Property, Plant, and Equipment, Fair Value Disclosure	$44,658
Impairment of Long-Lived Assets Held-for-use	68,344	0
Fair Value, Measurements, Nonrecurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Property, Plant, and Equipment, Fair Value Disclosure	0
Fair Value, Measurements, Nonrecurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Property, Plant, and Equipment, Fair Value Disclosure	0
Fair Value, Measurements, Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Property, Plant, and Equipment, Fair Value Disclosure	$44,658

Fair_Value_of_Financial_Instru4

Fair Value of Financial Instruments Narrative (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Fair Value Disclosures [Abstract]
Notes Payable, Fair Value Disclosure	$49.10	$47

Commitments_and_Contingencies_

Commitments and Contingencies Loss Contingencies (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies	$2.70	$2.80

Commitments_and_Contingencies_1

Commitments and Contingencies Operating Leases (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Operating leases [Line Items]
Operating Leases, Rent Expense	$0.50	$0.80

Income_Taxes_Schedule_of_Incom

Income Taxes Schedule of Income Tax Expense (Benefit) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
INCOME TAX BENEFIT	($826)	($865)

Equity_Based_Compensation_Shar

Equity Based Compensation Share-based Compensation Rollforward (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Unvested Restricted Units Outstanding - Beginning Balance		2,419,750
Unvested Restricted Units Outstanding - Ending Balance	2,121,963	2,419,750
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Unvested Restricted Units Outstanding - Beginning Balance	2,419,750
Grants in Period	23,000
Vesting of restricted units	60,700
Forfeited in Period	-260,087
Unvested Restricted Units Outstanding - Ending Balance	2,121,963
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward]
Weighted Average Grant Date Fair Value	$6.06
Grants in Period, Weighted Average Grant Date Fair Value	$2.37
Vested in Period, Weighted Average Grant Date Fair Value	$4.46
Forfeitures in Period, Weighted Average Grant Price	$6.69
Weighted Average Grant Date Fair Value - Ending	$5.99
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Unvested Restricted Units Outstanding - Beginning Balance	647,788
Forfeited in Period	-123,175
Unvested Restricted Units Outstanding - Ending Balance	524,613
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward]
Weighted Average Grant Date Fair Value	$3.63
Forfeitures in Period, Weighted Average Grant Price	$3.59
Weighted Average Grant Date Fair Value - Ending	$3.64

Equity_Based_Compensation_Narr

Equity Based Compensation Narrative (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Percentage of performance units earned	0.00%
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	14,500,000
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant	6,975,671
Equity-based compensation	$1,856,000	$2,583,000
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	8,600,000
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition	1 year 10 months 27 days
Common Units [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Shares cancelled during period, value	40,000
Number of Common Units [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Shares cancelled during period	16,602
Continuing Operations [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Equity-based compensation	$1,856,000	$2,583,000
Maximum [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Percentage of performance units earned	200.00%
Minimum [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Percentage of performance units earned	70.00%

Earnings_Per_Unit_Schedule_of_

Earnings Per Unit Schedule of Weighted Average Number of Units(Details)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Weighted average common units outstanding - Basic	149,143	156,644
Weighted average common units outstanding - Diluted	149,143	156,644

Earnings_Per_Unit_Calculation_

Earnings Per Unit Calculation of basic and diluted earnings per unit (Details) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Income (Loss) from Continuing Operations Attributable to Parent	($57,753)		($7,960)
Distributions	10,561		0	[1]
Assumed income (loss) from continuing operations after distribution to be allocated	-68,314		-7,960
DISCONTINUED OPERATIONS, NET OF TAX	-966		-10,603
Net loss	-58,719		-18,563
Income (loss) from continuing operations per common unit - Basic	($0.39)		($0.05)
Discontinued operations per common unit - Basic	($0.01)		($0.07)
Net income (loss) per common unit - Basic	($0.40)		($0.12)
Net income (loss) per common unit - Diluted	($0.40)		($0.12)
Common Units [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Income (Loss) from Continuing Operations Attributable to Parent	-57,882		-7,960
Distributions	10,432		0	[1]
Assumed income (loss) from continuing operations after distribution to be allocated	-68,314		-7,960
DISCONTINUED OPERATIONS, NET OF TAX	-966		-10,603
Net loss	-58,848		-18,563
Income (loss) from continuing operations per common unit - Basic	($0.39)		($0.05)
Discontinued operations per common unit - Basic	($0.01)		($0.07)
Net income (loss) per common unit - Basic	($0.40)		($0.12)
Income (loss) from continuing operations per common unit - Diluted	($0.39)		($0.05)
Discontinued operations per common unit - Diluted	($0.01)		($0.07)
Net income (loss) per common unit - Diluted	($0.40)		($0.12)
Restricted Stock Units (RSUs) [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Income (Loss) from Continuing Operations Attributable to Parent	129	[2]	0	[2]
Distributions	129	[2]	0	[1],[2]
Assumed income (loss) from continuing operations after distribution to be allocated	0	[2]	0	[2]
DISCONTINUED OPERATIONS, NET OF TAX	0	[2]	0	[2]
Net loss	$129	[2]	$0	[2]
[1]	**No distribution was declared or paid for this period as the distribution was suspended for this period.
[2]	*Restricted common units granted under the LTIP that contain non-forfeitable rights to the distributions declared by the Partnership.

Divestiture_Related_Activities2

Divestiture Related Activities Divestiture Related Activities - Asset & Liabilities Held for Sale and Discontinued Operations (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Class of statement of operations line item of discontinued operations:
Revenue	$0	$302,871
Cost of natural gas, natural gas liquids, condensate and helium	0	244,973
Operations and maintenance	0	25,049
General and administrative	966	8,101
Depreciation, amortization and impairment	0	22,199
Interest expense	0	-13,232
Other expense	0	-8
Operating income (loss) from discontinued operations before taxes	-966	-10,691
Income tax expense (benefit)	0	-88
Discontinued operations	($966)	($10,603)

Divestiture_Related_Activities3

Divestiture Related Activities Divestiture Related Activities - Restructuring Charges (Details) (USD $)	3 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Restructuring Cost and Reserve [Line Items]
Restructuring and Related Cost, Incurred Cost	$843
Restructuring Reserve, Current	2,168	1,325
One-time Termination Benefits [Member]
Restructuring Cost and Reserve [Line Items]
Increase (Decrease) in Restructuring Reserve		3,975
Restructuring and Related Cost, Incurred Cost	-183
Restructuring Reserve, Current	652	835
Facility Closing [Member]
Restructuring Cost and Reserve [Line Items]
Increase (Decrease) in Restructuring Reserve		563
Restructuring and Related Cost, Incurred Cost	1,026
Restructuring Reserve, Current	$1,516	$490

Subsidiary_Guarantors_Subsidia1

Subsidiary Guarantors Subsidiary Guarantors Condensed Consolidating Balance Sheets (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Thousands, unless otherwise specified
Subsidiary Guarantors [Line Items]
Accounts receivable – related parties	$0		$0
Other current assets	165,048		249,103
PROPERTY, PLANT AND EQUIPMENT — Net	432,291		487,988
Investment in subsidiaries	0		0
Total other long-term assets	59,898		57,184
TOTAL	657,237		794,275
Accounts payable – related parties	0		0
Other current liabilities	47,932		59,525
Other long-term liabilities	81,766		82,937
LONG-TERM DEBT	212,762		263,343
MEMBERS' EQUITY (b)	314,777	[1]	388,470	[1]
TOTAL	657,237		794,275
Parent Company [Member]
Subsidiary Guarantors [Line Items]
Accounts receivable – related parties	865,930		838,656
Other current assets	129,008		211,213
PROPERTY, PLANT AND EQUIPMENT — Net	1,531		1,334
Investment in subsidiaries	-486,135		-413,023
Total other long-term assets	55,072		52,272
TOTAL	565,406		690,452
Accounts payable – related parties	0		0
Other current liabilities	37,497		37,850
Other long-term liabilities	370		789
LONG-TERM DEBT	212,762		263,343
MEMBERS' EQUITY (b)	314,777		388,470
TOTAL	565,406		690,452
Co-issuer [Member]
Subsidiary Guarantors [Line Items]
Accounts receivable – related parties	0		0
Other current assets	1		1
PROPERTY, PLANT AND EQUIPMENT — Net	0		0
Investment in subsidiaries	0		0
Total other long-term assets	0		0
TOTAL	1		1
Accounts payable – related parties	0		0
Other current liabilities	0		0
Other long-term liabilities	0		0
LONG-TERM DEBT	0		0
MEMBERS' EQUITY (b)	1		1
TOTAL	1		1
Guarantor Subsidiaries [Member]
Subsidiary Guarantors [Line Items]
Accounts receivable – related parties	0		0
Other current assets	36,039		37,889
PROPERTY, PLANT AND EQUIPMENT — Net	430,760		486,654
Investment in subsidiaries	0		0
Total other long-term assets	4,826		4,912
TOTAL	471,625		529,455
Accounts payable – related parties	865,930		838,656
Other current liabilities	10,435		21,675
Other long-term liabilities	81,396		82,148
LONG-TERM DEBT	0		0
MEMBERS' EQUITY (b)	-486,136		-413,024
TOTAL	471,625		529,455
Consolidation, Eliminations [Member]
Subsidiary Guarantors [Line Items]
Accounts receivable – related parties	-865,930		-838,656
Other current assets	0		0
PROPERTY, PLANT AND EQUIPMENT — Net	0		0
Investment in subsidiaries	486,135		413,023
Total other long-term assets	0		0
TOTAL	-379,795		-425,633
Accounts payable – related parties	-865,930		-838,656
Other current liabilities	0		0
Other long-term liabilities	0		0
LONG-TERM DEBT	0		0
MEMBERS' EQUITY (b)	486,135		413,023
TOTAL	($379,795)		($425,633)
[1]	149,027,423 and 150,154,909 common units were issued and outstanding as of March 31, 2015 and December 31, 2014, respectively. These amounts do not include unvested restricted common units granted under the Partnership's long-term incentive plan of 2,121,963 and 2,419,750 as of March 31, 2015 and December 31, 2014, respectively.

Subsidiary_Guarantors_Subsidia2

Subsidiary Guarantors Subsidiary Guarantors Condensed Consolidating Income Statement (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Subsidiary Guarantors [Line Items]
Total revenues	$52,122	$45,203
Operations and maintenance	10,082	11,498
Taxes other than income	1,388	3,791
General and administrative	10,989	13,290
Depreciation, depletion and amortization	14,645	20,406
Impairment	68,344	0
OPERATING LOSS	-53,326	-3,782
Interest expense, net	-2,318	-4,754
Other non-operating income	2,135	0
Other (expense) income	-5,070	-289
Income (loss) before income taxes	-58,579	-8,825
INCOME TAX BENEFIT	-826	-865
Equity in earnings of subsidiaires	0	0
LOSS FROM CONTINUING OPERATIONS	-57,753	-7,960
Discontinued operations	-966	-10,603
Net income (loss)	-58,719	-18,563
Parent Company [Member]
Subsidiary Guarantors [Line Items]
Total revenues	21,227	-10,033
Operations and maintenance	0	0
Taxes other than income	0	0
General and administrative	2,082	2,897
Depreciation, depletion and amortization	136	53
Impairment	0
OPERATING LOSS	19,009	-12,983
Interest expense, net	-2,318	-4,754
Other non-operating income	4,257	2,221
Other (expense) income	-6,459	-1,716
Income (loss) before income taxes	14,489	-17,232
INCOME TAX BENEFIT	96	-267
Equity in earnings of subsidiaires	-73,110	18,634
LOSS FROM CONTINUING OPERATIONS	-58,717	1,669
Discontinued operations	-2	-20,232
Net income (loss)	-58,719	-18,563
Co-issuer [Member]
Subsidiary Guarantors [Line Items]
Total revenues	0	0
Operations and maintenance	0	0
Taxes other than income	0	0
General and administrative	0	0
Depreciation, depletion and amortization	0	0
Impairment	0
OPERATING LOSS	0	0
Interest expense, net	0	0
Other non-operating income	0	0
Other (expense) income	0	0
Income (loss) before income taxes	0	0
INCOME TAX BENEFIT	0	0
Equity in earnings of subsidiaires	0	0
LOSS FROM CONTINUING OPERATIONS	0	0
Discontinued operations	0	0
Net income (loss)	0	0
Guarantor Subsidiaries [Member]
Subsidiary Guarantors [Line Items]
Total revenues	30,895	55,236
Operations and maintenance	10,082	11,498
Taxes other than income	1,388	3,791
General and administrative	8,907	10,393
Depreciation, depletion and amortization	14,509	20,353
Impairment	68,344
OPERATING LOSS	-72,335	9,201
Interest expense, net	0	0
Other non-operating income	2,264	2,301
Other (expense) income	-2,997	-3,095
Income (loss) before income taxes	-73,068	8,407
INCOME TAX BENEFIT	-922	-598
Equity in earnings of subsidiaires	0	0
LOSS FROM CONTINUING OPERATIONS	-72,146	9,005
Discontinued operations	-964	9,636
Net income (loss)	-73,110	18,641
Non-Guarantor Subsidiaries [Member]
Subsidiary Guarantors [Line Items]
Total revenues		0
Operations and maintenance		0
Taxes other than income		0
General and administrative		0
Depreciation, depletion and amortization		0
OPERATING LOSS		0
Interest expense, net		0
Other non-operating income		0
Other (expense) income		0
Income (loss) before income taxes		0
INCOME TAX BENEFIT		0
Equity in earnings of subsidiaires		0
LOSS FROM CONTINUING OPERATIONS		0
Discontinued operations		-7
Net income (loss)		-7
Consolidation, Eliminations [Member]
Subsidiary Guarantors [Line Items]
Total revenues	0	0
Operations and maintenance	0	0
Taxes other than income	0	0
General and administrative	0	0
Depreciation, depletion and amortization	0	0
Impairment	0
OPERATING LOSS	0	0
Interest expense, net	0	0
Other non-operating income	-4,386	-4,522
Other (expense) income	4,386	4,522
Income (loss) before income taxes	0	0
INCOME TAX BENEFIT	0	0
Equity in earnings of subsidiaires	73,110	-18,634
LOSS FROM CONTINUING OPERATIONS	73,110	-18,634
Discontinued operations	0	0
Net income (loss)	$73,110	($18,634)

Subsidiary_Guarantors_Subsidia3

Subsidiary Guarantors Subsidiary Guarantor Condensed Consolidating Statements of Cash Flows (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Subsidiary Guarantors [Line Items]
Net cash flows provided by operating activities	$14,727	$23,803
Additions to property, plant and equipment	-28,055	-42,282
Proceeds from Sale of Short-term Investments	77,755	0
Net cash provided by (used in) investing activities	49,700	-42,282
Proceeds from long-term debt	45,300	144,250
Repayment of long-term debt	-95,900	-127,050
Payment of debt issuance costs	0	205
Proceeds from derivative contracts	-940	-1,708
Repurchase of common units	-2,662	0
Distributions to members and affiliates	-10,565	-23,801
Net cash used in financing activities	-64,767	-8,514
Net Cash Provided by (Used in) Discontinued Operations	-966	32,540
Net increase in cash and cash equivalents	-1,306	5,547
CASH AND CASH EQUIVALENTS—Beginning of period	1,343	76
CASH AND CASH EQUIVALENTS—End of period	37	5,623
Parent Company [Member]
Subsidiary Guarantors [Line Items]
Net cash flows provided by operating activities	-14,013	30,293
Additions to property, plant and equipment	-334	-336
Proceeds from Sale of Short-term Investments	77,755
Net cash provided by (used in) investing activities	77,421	-336
Proceeds from long-term debt	45,300	144,250
Repayment of long-term debt	-95,900	-127,050
Payment of debt issuance costs		205
Proceeds from derivative contracts	-940	-1,708
Repurchase of common units	-2,662
Distributions to members and affiliates	-10,565	-23,801
Net cash used in financing activities	-64,767	-8,514
Net Cash Provided by (Used in) Discontinued Operations	-2	-17,154
Net increase in cash and cash equivalents	-1,361	4,289
CASH AND CASH EQUIVALENTS—Beginning of period	2,686	1,237
CASH AND CASH EQUIVALENTS—End of period	1,325	5,526
Co-issuer [Member]
Subsidiary Guarantors [Line Items]
Net cash flows provided by operating activities	0	0
Additions to property, plant and equipment	0	0
Proceeds from Sale of Short-term Investments	0
Net cash provided by (used in) investing activities	0	0
Proceeds from long-term debt	0	0
Repayment of long-term debt	0	0
Payment of debt issuance costs		0
Proceeds from derivative contracts	0	0
Repurchase of common units	0
Distributions to members and affiliates	0	0
Net cash used in financing activities	0	0
Net Cash Provided by (Used in) Discontinued Operations	0	0
Net increase in cash and cash equivalents	0	0
CASH AND CASH EQUIVALENTS—Beginning of period	1	1
CASH AND CASH EQUIVALENTS—End of period	1	1
Guarantor Subsidiaries [Member]
Subsidiary Guarantors [Line Items]
Net cash flows provided by operating activities	28,740	-6,490
Additions to property, plant and equipment	-27,721	-41,946
Proceeds from Sale of Short-term Investments	0
Net cash provided by (used in) investing activities	-27,721	-41,946
Proceeds from long-term debt	0	0
Repayment of long-term debt	0	0
Payment of debt issuance costs		0
Proceeds from derivative contracts	0	0
Repurchase of common units	0
Distributions to members and affiliates	0	0
Net cash used in financing activities	0	0
Net Cash Provided by (Used in) Discontinued Operations	-964	49,678
Net increase in cash and cash equivalents	55	1,242
CASH AND CASH EQUIVALENTS—Beginning of period	-1,344	-1,389
CASH AND CASH EQUIVALENTS—End of period	-1,289	-147
Non-Guarantor Subsidiaries [Member]
Subsidiary Guarantors [Line Items]
Net cash flows provided by operating activities		0
Additions to property, plant and equipment		0
Net cash provided by (used in) investing activities		0
Proceeds from long-term debt		0
Repayment of long-term debt		0
Payment of debt issuance costs		0
Proceeds from derivative contracts		0
Distributions to members and affiliates		0
Net cash used in financing activities		0
Net Cash Provided by (Used in) Discontinued Operations		16
Net increase in cash and cash equivalents		16
CASH AND CASH EQUIVALENTS—Beginning of period		227
CASH AND CASH EQUIVALENTS—End of period		243
Consolidation, Eliminations [Member]
Subsidiary Guarantors [Line Items]
Net cash flows provided by operating activities	0	0
Additions to property, plant and equipment	0	0
Proceeds from Sale of Short-term Investments	0
Net cash provided by (used in) investing activities	0	0
Proceeds from long-term debt	0	0
Repayment of long-term debt	0	0
Payment of debt issuance costs		0
Proceeds from derivative contracts	0	0
Repurchase of common units	0
Distributions to members and affiliates	0	0
Net cash used in financing activities	0	0
Net Cash Provided by (Used in) Discontinued Operations	0	0
Net increase in cash and cash equivalents	0	0
CASH AND CASH EQUIVALENTS—Beginning of period	0	0
CASH AND CASH EQUIVALENTS—End of period	$0	$0