Eagle Rock Energy Partners L P (EROC) 10-Q 4 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document	6 Months Ended
	Jun. 30, 2014	Jul. 28, 2014
Entity Information [Line Items]	'	'
Entity Registrant Name	'EAGLE ROCK ENERGY PARTNERS L P	'
Entity Central Index Key	'0001364541	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Document Type	'10-Q	'
Document Period End Date	30-Jun-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'
Amendment Flag	'false	'
Entity Common Stock, Shares Outstanding	'	159,865,760

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Jun. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
CURRENT ASSETS:	'		'
Cash and cash equivalents	$741		$76
Accounts receivable	34,785	[1]	17,250	[1]
Risk management assets, current	18		5,559
Prepayments and other current assets	13,316		6,123
Assets held for sale	1,211,230		1,259,382
Total current assets	1,260,090		1,288,390
Property, Plant and Equipment — Net	859,895		824,451
Intangible Assets — Net	3,170		3,268
Deferred Tax Asset	2,224		1,438
Risk Management Assets	66		3,871
Other Assets	5,320		6,132
Total assets	2,130,765		2,127,550
CURRENT LIABILITIES:	'		'
Accounts payable	72,460		50,158
Accrued liabilities	11,075		23,162
Taxes payable	0		149
Risk management liabilities	14,467		8,360
Current portion of long-term debt	439,000		0
Liabilities held for sale	626,732		637,738
Total current liabilities	1,163,734		719,567
Long-term debt	380,712		757,480
Asset Retirement Obligations	47,241		37,306
Deferred Tax Liability	33,566		34,097
Risk Management Liabilities	8,011		2,826
Other long-term liabilities	4,499		2,395
Commitments and Contingencies (Note 12)	'		'
Members' Equity	493,002	[2]	573,879	[2]
Total liabilities and equity	$2,130,765		$2,127,550
[1]	Net of allowance for bad debt of $902 as of June 30, 2014 and $931 as of December 31, 2013.
[2]	157,354,239 and 156,644,153 common units were issued and outstanding as of June 30, 2014 and December 31, 2013, respectively. These amounts do not include unvested restricted common units granted under the Partnership's long-term incentive plan of 2,510,221 and 2,743,807 as of June 30, 2014 and December 31, 2013, respectively.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets Parenthetical (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified
Allowance for Doubtful Accounts Receivable, Current	$902	$931
Limited Partners' Capital Account, Units Issued	157,354,239	156,644,153
Limited Partners' Capital Account, Units Outstanding	157,354,239	156,644,153
Unvested Restricted Units Outstanding	2,510,221	2,743,807

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues:	'	'	'	'
Natural gas, natural gas liquids, oil, condensate and sulfur sales	$51,967	$49,252	$107,051	$96,057
Commodity risk management gains (losses)	-18,081	17,338	-28,114	10,502
Other revenue	158	76	310	573
Total revenue	34,044	66,666	79,247	107,132
COSTS AND EXPENSES:	'	'	'	'
Operations and maintenance	10,907	9,579	22,405	21,279
Taxes other than income	3,596	3,583	7,387	5,999
General and administrative	12,005	13,341	25,295	26,651
Impairment	0	1,839	0	1,839
Depreciation, Depletion and Amortization	20,299	22,060	40,705	43,356
Total costs and expenses	46,807	50,402	95,792	99,124
Operating income (loss)	-12,763	16,264	-16,545	8,008
OTHER INCOME (EXPENSE):	'	'	'	'
Interest expense	-4,948	-4,499	-9,702	-9,564
Interest rate risk management losses	-571	-151	-861	-307
Other (expense) income	2	-27	3	-35
Total other (expense) income	-5,517	-4,677	-10,560	-9,906
Income (loss) from continuing operations before income taxes	-18,280	11,587	-27,105	-1,898
Income Tax Expense (Benefit)	-885	-544	-1,750	-2,105
Income (loss) from continuing operations	-17,395	12,131	-25,355	207
Discontinued operations	-25,646	3,901	-36,249	-17,689
Net income (loss)	($43,041)	$16,032	($61,604)	($17,482)
NET INCOME PER COMMON UNIT—BASIC AND DILUTED:	'	'	'	'
Income (loss) from continuing operations per common unit - Basic	($0.11)	$0.07	($0.16)	($0.01)
Income (loss) from continuing operations per common units - Diluted	($0.11)	$0.07	($0.16)	($0.01)
Discontinued operations per common unit - Basic	($0.16)	$0.03	($0.23)	($0.12)
Discontinued operations per common unit - Diluted	($0.16)	$0.03	($0.23)	($0.12)
Net income (loss) per common unit - basic	($0.27)	$0.10	($0.39)	($0.13)
Net income (loss) per common unit - Diluted	($0.27)	$0.10	($0.39)	($0.13)
Weighted Average Number of Shares Outstanding Basic and Diluted	'	'	'	'
Weighted average common units outstanding - basic	156,955	155,269	156,802	150,860
Weighted average common units outstanding - Diluted	156,955	156,710	156,802	150,860

Consolidated_Statement_of_Memb

Consolidated Statement of Member's Equity (USD $)	Total	Number of Common Units [Member]	Common Units [Member]
In Thousands, except Share data, unless otherwise specified	USD ($)		USD ($)
Members' Equity - Beginning Balance at Dec. 31, 2013	$573,879	'	$573,879
Beginning Balance - Units Outstanding at Dec. 31, 2013	156,644,153	156,644,153	'
Increase (Decrease) in Members' Equity [Roll Forward]	'	'	'
Net income (loss)	-61,604	'	-61,604
Distributions	-23,801	'	-23,801
Vested in Period	'	963,392	'
Stock Repurchased During Period, Shares	'	253,306	'
Stock Repurchased During Period, Value	1,084	'	1,084
Share Based Compensation, Aggregate Amount	5,612	'	5,612
Members' Equity - Ending Balance at Jun. 30, 2014	$493,002	'	$493,002
Ending Balance - Units Outstanding at Jun. 30, 2014	157,354,239	157,354,239	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
CASH FLOWS FROM OPERATING ACTIVITIES:	'	'
Net income (loss)	($61,604)	($17,482)
Adjustments to reconcile net (loss) income to net cash provided by operating activities:	'	'
Discontinued operations	36,249	17,689
Depreciation, Depletion and Amortization	40,705	43,356
Impairment	0	1,839
Amortization of debt issuance costs	1,269	966
Loss (gain) from risk management activities, net	28,975	-10,195
Derivative settlements	-5,314	5,024
Equity-based compensation	4,042	4,705
Other	-139	818
Changes in assets and liabilities—net of acquisitions:	'	'
Accounts receivable	-17,535	8,671
Prepayments and other current assets	-7,193	-2,460
Accounts payable	7,704	2,817
Accrued liabilities	-496	1,005
Other assets	-15	1,110
Other current liabilities	-974	-779
Net cash flows provided by operating activities	25,674	57,084
CASH FLOWS FROM INVESTING ACTIVITIES:	'	'
Additions to property, plant and equipment	-63,789	-83,395
Net cash provided by (used in) investing activities	-63,789	-83,395
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'
Proceeds from long-term debt	315,150	316,700
Repayment of long-term debt	-252,950	-312,200
Payment of debt issuance costs	410	0
Proceeds from derivative contracts	-3,425	877
Common unit issuance	0	102,388
Payments of Unit Issuance Costs	0	-4,181
Payments for repurchase of common units	1,084	1,000
Distributions to members and affiliates	-23,801	-67,117
Net cash provided by (used in) financing activities	33,480	35,467
CASH FLOWS FROM DISCONTINUED OPERATIONS:	'	'
Operating activities	29,580	47,990
Investing activities	-24,280	-57,076
Net cash provided by (used in) discontinued operations	5,300	-9,086
Net increase in cash and cash equivalents	665	70
CASH AND CASH EQUIVALENTS—Beginning of period	76	25
CASH AND CASH EQUIVALENTS—End of period	741	95
NONCASH INVESTING AND FINANCING ACTIVITIES:	'	'
Investments in property, plant and equipment, not paid	22,304	14,869
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:	'	'
Interest paid—net of amounts capitalized	35,020	29,633
Cash paid for taxes	$0	$59

Organization_and_Description_o

Organization and Description of Business	6 Months Ended
	Jun. 30, 2014
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, as of July 1, 2014, 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, condensate and crude oil (collectively, the "Upstream Business"). The Partnership's upstream assets, located primarily in South 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 natural gas liquids ("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"). The consideration received by the Partnership for the Midstream Business Contribution included: (i) $576.2 million of cash; (ii)8,245,859 Regency common units (valued at approximately$265 million based on the closing price of Regency common units on June 30, 2014) and (iii) the exchange of $498.9 million face amount of the Partnership's outstanding unsecured senior notes ("Senior Notes") for an equivalent amount of Regency unsecured senior notes. $51.1 million of the Partnership's Senior Notes did not exchange and remain outstanding. However, the Partnership, having secured a sufficient number of consents as part of the exchange offer, amended the indenture governing its Senior Notes to eliminate substantially all of the restrictive covenants and certain events of default pertaining to its Senior Notes.
	Accordingly, upon satisfaction of the significant closing conditions of the Midstream Business Contribution, the assets, liabilities and operation of the Midstream Business were classified as held-for-sale and discontinued in the condensed consolidated financial statements. Prior periods have been retrospectively adjusted to reflect assets and liabilities held-for-sale and operations as discontinued (see Note 16) in the financial statements included in this report. As a result of this transaction, the Partnership now will only report 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, both of which are wholly-owned subsidiaries of the Partnership.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2014
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, 2013. 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 and six months ended June 30, 2014 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2014.
	As of June 30, 2014, the Partnership owned non-operating undivided interests in certain gas processing plants and gas gathering systems. The Partnership owned these interests as tenants-in-common with the majority owner-operator of the facilities. Accordingly, the Partnership includes its pro-rata share of assets, liabilities, revenues and expenses related to these assets in its financial statements. The assets and liabilities related to these undivided interests have been classified as assets and liabilities held-for-sale within the unaudited condensed consolidated balance sheet, while the operations related to these interests have been classified as discontinued within the unaudited condensed consolidated statement of operations (see Note 16).
	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 Annual Report on Form 10-K for the year ended December 31, 2013. 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.
	Inventory—Inventory is stated at the lower of cost or market, with cost being determined using the average cost method. At June 30, 2014 and December 31, 2013, the Partnership had $0.3 million and $1.0 million, respectively, of crude oil finished goods inventory, which is recorded as part of assets held for sale within the unaudited condensed consolidated balance sheet.
	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, accounted for utilizing the successful efforts method, the Partnership reviews its proved properties at the depletion unit 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 to the proved reserves estimates, unfavorable projections of future prices, the timing of future production and estimates of future costs to produce the oil and natural gas. Unproved properties (both individually significant and insignificant) are assessed periodically within specific geographic areas and, if necessary, impairments are charged to expense.
	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 Notes 4 and 6 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 for the Partnership's Midstream Business include 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 are recognized in the period when the services are 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. Material imbalances are reflected as adjustments to reported natural gas reserves and future cash flows.  The Partnership had long-term imbalance payables totaling $0.3 million and $0.3 million as of June 30, 2014 and December 31, 2013, respectively.
	Transportation and Exchange Imbalances—In the course of transporting natural gas and NGLs for others, the Partnership may receive for redelivery different quantities of natural gas or NGLs than the quantities actually delivered. These transactions result in transportation and exchange imbalance receivables or payables which are recovered or repaid through the receipt or delivery of natural gas or NGLs in future periods, if not subject to cash out provisions. Imbalance receivables are included in accounts receivable and imbalance payables are included in accounts payable on the unaudited condensed consolidated balance sheets and marked-to-market using current market prices in effect for the reporting period of the outstanding imbalances. As of June 30, 2014, the Partnership had imbalance receivables totaling $2.3 million and imbalance payables totaling $1.9 million. As of December 31, 2013, the Partnership had imbalance receivables totaling $0.7 million and imbalance payables totaling $1.6 million. Imbalance receivables and imbalance payables have been classified as assets and liabilities held for sale, respectively, within the unaudited condensed consolidated balance sheet. Changes in market value and the settlement of any such imbalance at a price greater than or less than the recorded imbalance results in either an upward or downward adjustment, as appropriate, to the cost of natural gas sold, and have been classified as discontinued operations within the unaudited condensed consolidated statements of operations.
	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 purchases and sales are contracts which provide for the purchase or sale of something, other than a financial instrument or derivative instrument, that 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, with the exception of certain contracts with it's natural gas trading and marketing business. 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—The prior period within the unaudited condensed consolidated statements of cash flows has been reclassified to conform to current period presentation. Amounts have been reclassified to new rows titled “Loss from risk management activities, net” that combines settled and mark-to-market gains/losses on derivative instruments and “Derivative settlements” that includes cash attributable to derivative instruments that settled during the periods. The revisions to the cash flow presentation had no impact on “Net cash provided by operating activities.”

New_Accounting_Pronouncements

New Accounting Pronouncements	6 Months Ended
	Jun. 30, 2014
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]	'
New Accounting Pronouncements	'
	NEW ACCOUNTING PRONOUNCEMENTS
	In February 2013, the Financial Accounting Standards Board ("FASB") issued new guidance related to obligations resulting from joint and several liability arrangements. The new guidance provides for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. The amendments in this update are effective for fiscal years, and interim periods within those years, beginning after December 15, 2013 and did not have a material impact on the Partnership’s unaudited condensed consolidated financial statements.
	On April 10, 2014, the 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 its transaction to contribute its Midstream Business to Regency (see Notes 1 and 16).
	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 application 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.

Property_Plant_and_Equipment

Property, Plant and Equipment	6 Months Ended
	Jun. 30, 2014
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment Disclosure	'
	PROPERTY, PLANT AND EQUIPMENT
	Fixed assets consisted of the following:
		June 30,			December 31,
		2014			2013
		($ in thousands)
	Equipment and machinery	$	101		$	101
	Vehicles and transportation equipment	212			212
	Office equipment, furniture, and fixtures	3,019			1,391
	Computer equipment	13,538			12,247
	Proved properties	1,233,079			1,156,895
	Unproved properties	9,209			10,022
	Construction in progress	2,174			6,636
		1,261,332			1,187,504
	Less: accumulated depreciation, depletion and amortization	(401,437		)	(363,053		)
	Net property, plant and equipment	$	859,895		$	824,451
	Amounts in the table above do not include the property, plant and equipment related to the Partnership's Midstream Business, as these amounts have been classified as assets held for sale within the unaudited condensed consolidated balance sheet (see Note 16).
	The following table sets forth the total depreciation, depletion, capitalized interest costs and impairment expense by type of asset within the Partnership's unaudited condensed consolidated statements of operations:
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014		2013
		($ in thousands)
	Depreciation	$	889		$	612		$	1,586	$	1,003
	Depletion	$	19,334		$	21,399		$	39,006	$	42,270
	Impairment expense:
	Proved properties (a)	$	—		$	1,839		$	—	$	1,839
	________________________________
	(a)	During the three and six months ended June 30, 2013, the Partnership incurred impairment charges in its Upstream Business related to certain proved property primarily in the Permian region due to lower commodity prices and continued high operating costs.
	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	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligations	'
	A reconciliation of the Partnership's liability for asset retirement obligations is as follows:
		2014			2013
		($ in thousands)
	Asset retirement obligations—January 1 (a)	$	48,564		$	38,991
	Additional liabilities	21			919
	Liabilities settled	(826		)	(730		)
	Revision to liabilities	(105		)	6,624
	Accretion expense	1,620			1,401
	Asset retirement obligations—June 30 (a)	$	49,274		$	47,205
	_____________________________________
	(a)	As of June 30, 2014 and December 31, 2013, $2.0 million and $11.3 million, respectively, were included within accrued liabilities in the unaudited condensed consolidated balance sheets.
	Amounts in the table above do not include the balances or the activity related to asset retirement obligations related to the Partnership's Midstream Business as these amount have been classified as liabilities held for sale within the unaudited condensed consolidated balance sheet and discontinued operations within the unaudited condensed consolidated statement of operations (see Note 16).
	During the six months ended June 30, 2014 and 2013, the Partnership made decrease revisions of $0.1 million and increase of $6.6 million, respectively, to certain asset retirement obligations due to changes in the estimated costs to remediate.

Intangible_Assets

Intangible Assets	6 Months Ended
	Jun. 30, 2014
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:
		June 30,			December 31,
		2014			2013
		($ in thousands)
	Rights-of-way and easements—at cost	$	3,920		$	3,920
	Less: accumulated amortization	(750		)	(652		)
	Net intangible assets	$	3,170		$	3,268
	Amounts in the table above do not include the intangible assets related to the Partnership's Midstream Business, as these amounts have been classified as assets held for sale within the unaudited condensed consolidated balance sheet (see Note 16).
	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						Six Months Ended
		June 30,						June 30,
		2014			2013			2014		2013
		($ in thousands)
	Amortization	$	49		$	49		$	98	$	98
	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 June 30, 2014, is as follows (in thousands):
	Year ending December 31,
	2014	$	98
	2015	$	196
	2016	$	196
	2017	$	196
	2018	$	196
	Thereafter	$	2,288

Long_Term_Debt

Long Term Debt	6 Months Ended
	Jun. 30, 2014
Long-term Debt, by Current and Noncurrent [Abstract]	'
Long-term Debt [Text Block]	'
	LONG-TERM DEBT
	Long-term debt consisted of the following:
		June 30,			December 31,
		2014			2013
		($ in thousands)
	Revolving credit facility:	$	769,000		$	706,800
	Senior notes:
	8.375% Senior Notes due 2019	51,120			51,120
	Unamortized bond discount	(408		)	(440		)
	Total Senior Notes	50,712			50,680
	Total debt	819,712			757,480
	Less: current maturities (1)	439,000			—
	Total long-term debt	$	380,712		$	757,480
	_____________________________
	1)	Per the Credit Agreement (as defined below), as a result of the contribution of the Midstream Business, the Partnership is required to pay down outstanding debt to the amount of the upstream portion of the borrowing base. As of June 30, 2014 and December 31, 2013, the Partnership has classified as current the difference between the amount outstanding under its credit facility and the upstream portion of the borrowing base.
	Amounts in the table above do not include the portion of the unsecured senior notes that were exchanged for Regency unsecured senior notes upon the completion of the Midstream Business Contribution on July 1, 2014 (see Note 1). These notes have been classified as part of liabilities held for sale within the unaudited condensed consolidated balance sheet.
	The Partnership currently pays an annual fee of 0.50% on the unused commitment under the Credit Agreement. As of June 30, 2014, the Partnership had approximately $4.4 million of outstanding letters of credit and approximately $45.8 million of availability under the Credit Agreement, based on its commitments of $819 million and before considering covenant limitations, prior to the paydown on July 1, 2014, as described above. The Credit Agreement matures on June 22, 2016.
	On July 1, 2014, the Partnership used the cash received from Regency for the Midstream Business Contribution (see Note 1) to paydown $570.4 million outstanding under our revolving credit facility (the "Credit Agreement"). Thus, as of July 1, 2014, the amount outstanding under the Credit Agreement was $198.6 million.
	On February 26, 2014, the Partnership and its lender group amended the Credit Agreement to allow for greater liquidity under the Credit Agreement and for greater covenant flexibility for the first quarter of 2014. Specifically, the amendment provided for: (i) an increase in the Total Leverage Ratio and Senior Secured Leverage Ratio (as defined in the Credit Agreement) for the quarter ended March 31, 2014; (ii) the exclusion of fees and expenses associated with the strategic review and disposition of the Partnership’s Midstream Business from the calculation of Consolidated EBITDA (as defined in the Credit Agreement); (iii) deferring the redetermination of the Upstream Borrowing Base (as defined in the Credit Agreement) until June 1, 2014; and (iv) the option for the Partnership, at its election, to expand the multiplier for the Midstream Borrowing Base (as defined in the Credit Agreement) from 3.75x to 4.00x. The Partnership exercised this option to expand the multiplier for the Midstream Borrowing Base on March 31, 2014.
	On May 28, 2014 the Partnership and its lender group further amended the Credit Agreement to allow for greater liquidity and certain covenant relief through the second quarter of 2014. The amendment, among other items, provided for an increase in the midstream component of the Credit Agreement's total borrowing base and provided for an increase in the Total Leverage Ratio and Senior Secured Leverage Ratio (as defined in the Credit Agreement) for the quarter ended June 30, 2014. The amendment also provided that (i) effective June 1, 2014, the upstream component of the borrowing base of the Credit Agreement will decrease from $380 million to $330 million as part of the Partnership's regular semi-annual redetermination by its commercial lenders, (ii) the next borrowing base redetermination will be September 1, 2014, and (iii) that such reduction would automatically reduce aggregate commitments of the lenders under the Credit Agreement, with further automatic reductions in such aggregate commitments in amounts equal to, and upon, any future reductions in the borrowing base.
	The following table presents the debt covenant levels specified in the Credit Agreement as of June 30, 2014:
	Quarter Ended	Total Leverage Ratio (a)		Senior Secured Leverage Ratio (a)	Interest Coverage Ratio (b)		Current Ratio (b)
	30-Jun-14	5.85		3.4	2.5		1
	30-Sep-14	4.75		2.95	2.5		1
	Thereafter	4.5		N/A	2.5		1
	_____________________
	(a)	Amount represents the maximum ratio for the period presented.
	(b)	Amount represents the minimum ratio for the period presented.
	The following table presents the Partnership's actual covenant ratios as of June 30, 2014:
	Interest coverage ratio	2.9
	Total leverage ratio	5.77
	Senior secured leverage ratio	3.37
	Current ratio	1
	The calculation of the ratios above includes the amounts classified in the unaudited condensed consolidated financial statements as held for sale and as discontinued operations.
	As of June 30, 2014, the Partnership was in compliance with the financial covenants under the revolving credit facility.
	In part due to the completion of the Midstream Business Contribution on July 1, 2014 (see Note 1), the Partnership expects to remain in compliance with its financial covenants under the Credit Agreement throughout June 2015.

Members_Equity

Members' Equity	6 Months Ended
	Jun. 30, 2014
Partners' Capital [Abstract]	'
Members' Equity	'
	MEMBERS’ EQUITY
	At June 30, 2014 and December 31, 2013, there were 157,354,239 and 156,644,153 unrestricted common units outstanding, respectively. In addition, there were 2,510,221 and 2,743,807 unvested restricted common units outstanding at June 30, 2014 and December 31, 2013, 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. During the six months ended June 30, 2014, no units were issued under this program.
	The table below summarizes the distributions paid or payable and declared for the six months ended June 30, 2014.
	Quarter Ended		Distribution		Record Date*	Payment Date
			per Common Unit
	December 31, 2013+*		$	0.15	February 7, 2014	February 14, 2014
	March 31, 2014**		$	—	N/A	N/A
	June 30, 2014**		$	—	N/A	N/A
	_____________________________
	+	The distribution excludes certain restricted unit grants.
	*	The "Record Date" set forth in the table above means the close of business on each of the listed Record Dates.
	**	No distribution was declared or paid for this period.

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
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				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
	Affiliates of Natural Gas Partners:	($ in thousands)
	Natural gas purchases from affiliates	$	949	$	419	$	2,091	$	542
		June 30, 2014		December 31, 2013
	Affiliates of Natural Gas Partners:	($ in thousands)
	Payable (related to natural gas purchases)	$	51	$	18
	The transactions above are 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 and liabilities held for sale within the unaudited condensed consolidated balance sheet (see Note 16).

Risk_Management_Activities

Risk Management Activities	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Risk Management Activities	'
	RISK MANAGEMENT ACTIVITIES
	Interest Rate Swap Derivative Instruments
	To reduce interest expense variability, the Partnership has entered into interest rate swaps that effectively convert 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 June 30, 2014:
	Effective Date		Expiration		Notional			Fixed
			Date		Amount			Rate
	6/22/11		6/22/15		$	250,000,000		2.95	%
	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.  Historically, the Partnership has hedged a substantial portion of its expected production in an attempt 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 attempt to 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's strategy may involve entering into hedges with strike prices above current future prices or resetting existing hedges to higher price levels in order to meet its cash flow objectives or to stay in compliance with the covenants under its Credit Agreement.  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 for its Upstream Business is derived from the proved reserves estimates, adjusted for certain expenses and revenue deductions that are a function of volume and price. 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 historically had been highly correlated to crude oil prices and hedging NGLs directly was less attractive due to the relative illiquidity in the NGL forward market.  Likewise, the Partnership has used natural gas hedges to hedge a portion of its expected future ethane production because forward prices for ethane are more often heavily discounted from its current prices than natural gas, ethane prices have been correlated to natural gas prices in the past, and 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.  In the case of NGLs hedged with crude oil derivatives, these conversions are based on the historical relationship of the prices of the two commodities and management's judgment regarding future price relationships of the commodities.  In the case where ethane is hedged with natural gas derivatives, the conversion is based on the thermal content of ethane. In recent quarters, the correlation of price changes in crude oil and NGLs has weakened relative to longer-term averages as NGL prices have fallen while crude index prices have risen which has reduced the effectiveness of some of our hedges in reducing the impact of price fluctuations. At this time, our practice is to no add new proxy hedges to our portfolio and to seek opportunities to convert our existing ones to direct product hedges.
	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, 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 each table, some trades of the same commodities with the same tenors have been aggregated and shown as weighted averages.
	Commodity derivatives, as of June 30, 2014, that will mature during the years ended December 31, 2014, 2015 and 2016:
	Underlying		Type		Notional		Floor				Cap
					Volumes		Strike				Strike
					(units) (a)		Price				Price
							($/unit)(b)				($/unit)(b)
	Portion of Contracts Maturing in 2014
	Natural Gas		Swap (Pay Floating/Receive Fixed)		5,880,000		$	4.51
	Crude Oil		Swap (Pay Floating/Receive Fixed)		624,000		$	96.14
	Crude Oil		Swap (Pay Fixed/Receive Floating)		99,570		$	92.53
	Propane		Swap (Pay Floating/Receive Fixed)		4,788,000		$	1.06
	IsoButane		Swap (Pay Floating/Receive Fixed)		1,134,000		$	1.31
	Normal Butane		Swap (Pay Floating/Receive Fixed)		2,066,400		$	1.3
	Contracts Maturing in 2015
	Natural Gas		Swap (Pay Floating/Receive Fixed)		10,800,000		$	4.07
	Crude Oil		Costless Collar		480,000		$	90			$	97.55
	Crude Oil		Swap (Pay Floating/Receive Fixed)		630,000		$	89.78
	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
	_______________________
	(a)	Volumes of natural gas are measured in MMbtu, volumes of crude oil are measured in barrels, and volumes of natural gas liquids are measured in gallons.
	(b)	Amounts represent the weighted average price in $/MMbtu for natural gas, $/barrel for crude oil and $/gallon for natural gas liquids.
	The table above does not include derivative contracts that have been classified as assets or liabilities held for sale within the unaudited condensed consolidated balance sheet (see Note 16).
	Commodity Derivative Instruments - Marketing & Trading
	Prior to the consummation of the Midstream Business Contribution, the Partnership's Midstream Business conducted natural gas marketing and trading activities intended to capitalize on favorable price differentials between various receipt and delivery locations. This business was contributed to Regency as part of the Midstream Business Contribution completed on July 1, 2014.
	Fair Value of Interest Rate and Commodity Derivatives
	The following tables set forth the fair values of interest rate and commodity derivative instruments not designated as hedging instruments and their location within the unaudited condensed consolidated balance sheet as of June 30, 2014 and December 31, 2013:
		As of June 30, 2014
		Derivative Assets					Derivative Liabilities
		Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
		($ in thousands)
	Interest rate derivatives - liabilities	Current assets		$	—		Current liabilities		$	(6,531	)
	Commodity derivatives - assets	Current assets		18			Current liabilities		3,238
	Commodity derivatives - assets	Long-term assets		66			Long-term liabilities		323
	Commodity derivatives - assets	Assets held-for-sale		745			Liabilities held-for-sale		572
	Commodity derivatives - liabilities	Current assets		—			Current liabilities		(11,173		)
	Commodity derivatives - liabilities	Long-term assets		—			Long-term liabilities		(8,334		)
	Commodity derivatives - liabilities	Assets held-for-sale		—			Liabilities held-for-sale		(12,796		)
	Total derivatives			$	829				$	(34,701	)
		As of December 31, 2013
		Derivative Assets					Derivative Liabilities
		Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
		($ in thousands)
	Interest rate derivatives - liabilities	Current assets		$	—		Current liabilities		$	(6,210	)
	Interest rate derivatives - liabilities	Long-term assets		—			Long-term liabilities		(2,885		)
	Commodity derivatives - assets	Current assets		6,841			Current liabilities		1,043
	Commodity derivatives - assets	Long-term assets		4,669			Long-term liabilities		202
	Commodity derivatives - assets	Assets held-for-sale		6,017			Liabilities held-for-sale		1,973
	Commodity derivatives - liabilities	Current assets		(1,282		)	Current liabilities		(3,193		)
Commodity derivatives - liabilities	Long-term assets		(798		)	Long-term liabilities		(143		)
Commodity derivatives - liabilities	Assets held-for-sale		(824		)	Liabilities held-for-sale		(5,658		)
Total derivatives			$	14,623				$	(14,871	)
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							Six Months Ended
			June 30,							June 30,
			2014			2013				2014			2013
			($ in thousands)
Interest rate derivatives	Interest rate risk management losses, net		$	(571	)	$	(151	)		$	(861	)	$	(307	)
Commodity derivatives	Commodity risk management losses, net		(18,081		)	17,338				(28,114		)	10,502
Commodity derivatives	Discontinued operations		(10,968		)	13,155				(15,879		)	2,083
Commodity derivatives - trading	Discontinued operations		(1,416		)	1,134				(2,404		)	(16		)
	Total		$	(31,036	)	$	31,476			$	(47,258	)	$	12,262

Fair_Value_of_Financial_Instru

Fair Value of Financial Instruments	6 Months Ended
	Jun. 30, 2014
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 June 30, 2014, the Partnership 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 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.
	The following tables disclose the fair value of the Partnership's derivative instruments as of June 30, 2014 and December 31, 2013:
		As of June 30, 2014
		Level 1		Level 2			Level 3		Netting (a)			Total
		($ in thousands)
	Assets:
	Crude oil derivatives	$	—	$	1,085		$	—	$	(1,085	)	$	—
	Natural gas derivatives	—		2,551			—		(2,467		)	84
	NGL derivatives	—		8			—		(8		)	—
	Total	$	—	$	3,644		$	—	$	(3,560	)	$	84
	Liabilities:
	Crude oil derivatives	$	—	$	(15,412	)	$	—	$	1,085		$	(14,327	)
	Natural gas derivatives	—		(3,753		)	—		2,467			(1,286		)
	NGL derivatives	—		(342		)	—		8			(334		)
	Interest rate swaps	—		(6,531		)	—		—			(6,531		)
	Total	$	—	$	(26,038	)	$	—	$	3,560		$	(22,478	)
	____________________________
	(a)	Represents counterparty netting under the agreement governing such derivative contracts.
		As of December 31, 2013
		Level 1		Level 2			Level 3		Netting (a)			Total
		($ in thousands)
	Assets:
	Crude oil derivatives	$	—	$	6,151		$	—	$	(1,716	)	$	4,435
	Natural gas derivatives	—		6,562			—		(1,567		)	4,995
	NGL derivatives	—		42			—		(42		)	—
	Total	$	—	$	12,755		$	—	$	(3,325	)	$	9,430
	Liabilities:
	Crude oil derivatives	$	—	$	(1,792	)	$	—	$	1,716		$	(76	)
	Natural gas derivatives	—		(2,503		)	—		1,567			(936		)
	NGL derivatives	—		(1,121		)	—		42			(1,079		)
	Interest rate swaps	—		(9,095		)	—		—			(9,095		)
	Total	$	—	$	(14,511	)	$	—	$	3,325		$	(11,186	)
	____________________________
	(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 and 6 for a further discussion of the impairment charges recorded during the three and six months ended June 30, 2014. 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 June 30, 2014:
		Six Months Ended
		June 30,
		2014		Level 1			Level 2		Level 3			Total Losses
		($ in thousands)
	Plant assets	$	52	$	—		$	—	$	52		$	132
	Pipeline assets	$	746	$	—		$	—	$	746		$	1,904
	Rights-of-way	$	24	$	—		$	—	$	24		$	61
	The assets and impairment losses included in the table above are all related to the Partnership's Midstream Business and have been classified as assets held for sale within the unaudited condensed consolidated balance sheet and as discontinued operations within the unaudited condensed consolidated statement of operations, respectively (see Note 16).
	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 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 amount of cash equivalents is believed to approximate their fair values because of the short maturities of these instruments. The fair value of accounts receivable and accounts payable are not materially different from their carrying amounts because of the short-term nature of these instruments.
	As of June 30, 2014, 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 bears interest at a fixed rate; based on the market price of the Senior Notes as of June 30, 2014 and December 31, 2013, the Partnership estimates that the fair value of the Senior Notes was $55.5 million and $55.7 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	6 Months Ended
	Jun. 30, 2014
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 June 30, 2014 or December 31, 2013 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. Lawsuits the Partnership and its operating subsidiaries was subject to relating solely to its midstream business were assumed by Regency on July 1, 2014 as part of the Midstream Business Contribution.
	In March and April 2014, alleged unitholders of the Partnership filed three class action lawsuits in the United States District Court for the Southern District of Texas on behalf of the Partnership's public unitholders. The lawsuits name the Partnership, its Board of Directors, Regency Energy Partners, L.P. (“Regency”), and Regal Midstream LLC as defendants. One of the lawsuits also names the Partnership's general partner and its general partner’s general partner as defendants. Plaintiffs in each lawsuit allege a variety of causes of action challenging Regency’s acquisition of the Partnership's midstream assets, including alleged breaches of fiduciary or contractual duties, alleged aiding and abetting these alleged breaches of duty, and alleged violations of the Securities Exchange Act of 1934. The lawsuits allege that the Partnership (i) sold its midstream assets for inadequate value, (ii) engaged in an unfair sales process, (iii) agreed to contractual terms (the no-solicitation, fiduciary out, superior proposal, and termination fee provisions and the voting and support agreement) that would dissuade other potential acquirors from seeking to purchase the midstream assets, and (iv) failed to disclose material information in its definitive proxy statement concerning the analysis of our financial advisors, potential conflicts of the advisors (and directors), management’s financial projections, strategic alternatives, other potential acquirors, the bases for certain actions, and the background of the transaction. Based on these allegations, the plaintiffs seek to have the sale rescinded, monetary damages and attorneys’ fees. The United States District Court for the Southern District of Texas has yet to resolve a pending motion to consolidate the three lawsuits or two pending motions to appoint a lead plaintiff. The Partnership believes that the lawsuits are without merit.
	As reported in the Partnership's Form 10-Q for the first quarter of 2014, the Partnership was the defendant in a lawsuit filed by a plaintiff who was alleging an entitlement to participate in various wells drilled by the Partnership in a defined area of land. The Partnership filed for, and was granted, a motion to dismiss such lawsuit.
	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.
	Environmental—The operation of pipelines, plants and other facilities for gathering, transporting, processing, treating, or storing natural gas, NGLs and other products is subject to stringent and complex laws and regulations pertaining to health, safety and the environment. As an owner or operator of these facilities, 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 planning, designing, constructing and operating pipelines, plants, and other facilities 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. As of July 1, 2014, in connection with the Midstream Business Contribution, Regency agreed to indemnify the Partnership for losses arising from the Midstream Business, including potential losses associated with these laws and regulations, and the Partnership agreed to use commercially reasonable efforts to mitigate such losses. At June 30, 2014 and December 31, 2013, the Partnership had accrued approximately $2.4 million and $2.5 million for environmental matters related to the Partnership's upstream business, respectively. Environmental accruals related to the Partnership's Midstream Business have been classified as liabilities held-for-sale within the unaudited condensed consolidated balance sheet (see Note 16).
	Retained Revenue Interest—Certain 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 2013 and does not anticipate doing so in 2014. 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, including leases with no continuing commitment, amounted to approximately $0.8 million, $1.6 million, $0.4 million and $0.9 million for the three and six months ended June 30, 2014 and 2013, respectively. Rental expense for leases with escalation clauses is recognized on a straight-line basis over the initial lease term.

Income_Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2014
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 Partnership unitholders. In addition, certain of the Partnership's subsidiaries are Subchapter C-corporations subject to federal and state income taxes. During the three and six months ended June 30, 2014 and 2013, the Partnership recognized an income tax benefit of $0.9 million, $1.8 million, $0.5 million and $2.1 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	6 Months Ended
	Jun. 30, 2014
Share-based Compensation [Abstract]	'
Equity-based Compensation	'
	EQUITY-BASED COMPENSATION
	Eagle Rock Energy G&P, LLC, the general partner of the general partner of the Partnership, 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 June 30, 2014, a total of 7,937,294 common units remained available for issuance. Grants under the LTIP are made at the discretion of the board and as of June 30, 2014 have only been made in the form of restricted units. 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. No options or phantom units have been issued to date.
	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 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 six months ended June 30, 2014 is provided below:
		Number of		Weighted
		Restricted		Average
		Units		Fair Value
	Outstanding at December 31, 2013	2,743,807		$	9.37
	Granted	1,287,360		$	4.63
	Vested	(963,392	)	$	9.6
	Forfeited	(557,554	)	$	9.19
	Outstanding at June 30, 2014	2,510,221		$	6.89
	For the three and six months ended June 30, 2014 and 2013, non-cash compensation expense of approximately $1.5 million, $4.0 million, $2.7 million and $4.7 million, respectively, was recorded related to the granted restricted units as general and administrative expense on the unaudited condensed consolidated statements of operations.
	As of June 30, 2014, unrecognized compensation costs related to the outstanding restricted units under the LTIP totaled approximately $13.4 million. The remaining expense is to be recognized over a weighted average of 1.84 years.
	In connection with the vesting of certain restricted units during the three months ended June 30, 2014, the Partnership cancelled 0.3 million of the newly-vested common units in satisfaction of $1.1 million of 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	6 Months Ended
	Jun. 30, 2014
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 June 30, 2014 and 2013, 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					Six Months Ended
		June 30,					June 30,
		2014			2013		2014		2013
		(in thousands)
	Weighted average units outstanding during period:
	Common units - Basic and diluted	156,955			155,269		156,802		150,860
	Effect of Dilutive Securities:
	Restricted Units (non-participating securities)	—			285		—		—
	Restricted Units (participating securities)	—			1,156		—		—
	Common units - Diluted	156,955			156,710		156,802		150,860
	For the three months ended June 30, 2013, the Partnership determined that it is more dilutive to apply the two-class method versus the treasury stock method in calculating dilutive earnings per unit. Thus, the unvested restricted common units are included in the computation of the diluted weighted average common units outstanding calculation, but the denominator in the computation of diluted earnings per unit only includes the basic weighted average common units and restricted units (non-participating securities) outstanding.
	Due to the distribution being suspended for both the quarters ended March 31, 2014 and June 30, 2013 (see Notes 8) and the Partnership generating a net loss during each period, earnings per unit for the three and six months ended June 30, 2014 was only calculated for the common units as the net loss was only allocated to the common units.
	The following table presents the Partnership's basic and diluted income per unit for the three months ended June 30, 2014:
			Total			Common Units			Restricted Common Units*
			($ in thousands, except for per unit amounts)
	Loss from continuing operations		$	(17,395	)
	Distributions**		—			$	—		$	—
	Assumed loss from continuing operations after distribution to be allocated		(17,395		)	(17,395		)	—
	Assumed allocation of loss from continuing operations		(17,395		)	(17,395		)	—
	Discontinued operations		(25,646		)	(25,646		)	—
	Assumed net loss to be allocated		$	(43,041	)	$	(43,041	)	$	—
	Basic loss from continuing operations per unit					$	(0.11	)
	Basic discontinued operations per unit					$	(0.16	)
	Basic and diluted loss per unit					$	(0.27	)
	Diluted income from continuing operations per unit					$	(0.11	)
	Diluted discontinued operations per unit					$	(0.16	)
	Diluted income per unit					$	(0.27	)
	_____________________________
	*	Restricted common units granted under the LTIP that contain non-forfeitable rights to the distributions declared by the Partnership.
	**	No distribution was declared or paid for this period as the distribution was suspended for this period.
	The following table presents the Partnership's basic and diluted income per unit for the three months ended June 30, 2013:
			Total			Common Units			Restricted Common Units
			($ in thousands, except for per unit amounts)
	Income from continuing operations		$	12,131
	Distributions		34,972			$	34,337		$	635
	Assumed income from continuing operations after distribution to be allocated		(22,841		)	(22,841		)	—
	Assumed allocation of income from continuing operations		12,131			11,496			635
	Discontinued operations		3,901			3,901			—
	Assumed net income to be allocated		$	16,032		$	15,397		$	635
	Basic income from continuing operations per unit					$	0.07
	Basic discontinued operations per unit					$	0.03
	Basic and diluted income per unit					$	0.1
	Diluted income from continuing operations per unit					$	0.07
	Diluted discontinued operations per unit					$	0.03
	Diluted income per unit					$	0.1
	The following table presents the Partnership's basic and diluted income per unit for the six months ended June 30, 2014:
			Total			Common Units			Restricted Common Units*
			($ in thousands, except for per unit amounts)
	Loss from continuing operations		$	(25,355	)
	Distributions **		—			$	—		$	—
	Assumed loss from continuing operations after distribution to be allocated		(25,355		)	(25,355		)	—
	Assumed allocation of loss from continuing operations		(25,355		)	(25,355		)	—
	Discontinued operations, net of tax		(36,249		)	(36,249		)	—
	Assumed net loss to be allocated		$	(61,604	)	$	(61,604	)	$	—
	Basic income from continuing operations per unit					$	(0.16	)
	Basic discontinued operations per unit					$	(0.23	)
	Basic and diluted loss per unit					$	(0.39	)
	Diluted income from continuing operations per unit					$	(0.16	)
Diluted discontinued operations per unit					$	(0.23	)
Diluted income per unit					$	(0.39	)
_____________________________
*	Restricted common units granted under the LTIP that contain non-forfeitable rights to the distributions declared by the Partnership.
**	No distribution was declared or paid for this period as the distribution was suspended for this period.
The following table presents the Partnership's basic and diluted income per unit for the six months ended June 30, 2013:
		Total			Common Units			Restricted Common Units
		($ in thousands, except for per unit amounts)
Loss from continuing operations		$	207
Distributions		69,670			$	68,443		$	1,227
Assumed loss from continuing operations after distribution to be allocated		(69,463		)	(69,463		)	—
Assumed allocation of loss from continuing operations		207			(1,020		)	1,227
Discontinued operations, net of tax		(17,689		)	(17,689		)	—
Assumed net loss to be allocated		$	(17,482	)	$	(18,709	)	$	1,227
Basic income from continuing operations per unit					$	(0.01	)
Basic discontinued operations per unit					$	(0.12	)
Basic and diluted loss per unit					$	(0.13	)
Diluted income from continuing operations per unit					$	(0.01	)
Diluted discontinued operations per unit					$	(0.12	)
Diluted income per unit					$	(0.13	)

Divestiture_Related_Activities

Divestiture Related Activities Divestiture Related Activites (Notes)	6 Months Ended
	Jun. 30, 2014
Discontinued Operations and Disposal Groups [Abstract]	'
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	'
	DIVESTITURE RELATED ACTIVITIES
	As discussed in Note 1, as of June 30, 2014, the Partnership met the criteria for classifying the assets and liabilities of its Midstream Business as held-for-sale and the operations as discontinued.
	The following is the reconciliation of the major classes of assets and liabilities classified as held for sale.
		June 30,				December 31,
		2014				2013
	Assets held-for-sale
	Accounts Receivable	$	111,131			$	128,713
	Property, plant and equipment	989,755				1,004,317
	Intangible assets	99,830				102,352
	Other current assets	750				5,663
	Other long-term assets	9,764				18,337
	Total assets held-for-sale	$	1,211,230			$	1,259,382
	Liabilities held-for-sale
	Long-term debt	$	494,898			$	494,582
	Accounts payable and accrued liabilities	99,653				119,966
	Other current liabilities	11,778				9,471
	Other long-term liabilities	20,403				13,719
	Total liabilities held-for-sale	$	626,732			$	637,738
	The following following is the reconciliation of the major classes of line items classified as discontinued operations.
			Three Months Ended							Six Months Ended
			June 30,							June 30,
			2014				2013			2014			2013
	Class of statement of operations line item of discontinued operations:
	Revenue		$	245,210			$	253,485		$	548,081		$	470,750
	Cost of natural gas, natural gas liquids, condensate and helium		199,700				185,760			444,673			365,748
	Operations, maintenance and taxes other than income		25,078				27,020			50,127			48,989
	General and administrative		12,107				6,055			20,208			11,592
	Depreciation, amortization and impairment		19,737				19,097			41,936			38,038
	Interest expense		(14,118		)		(12,110		)	(27,350		)	(24,129		)
	Other expense		(60		)		140			(68		)	140
	Operating income (loss) from discontinued operations before taxes		(25,590		)		3,583			(36,281		)	(17,606		)
	Income tax expense (benefit)		56				(318		)	(32		)	83
	Discontinued operations		$	(25,646	)		$	3,901		$	(36,249	)	$	(17,689	)

Subsidiary_Guarantors

Subsidiary Guarantors	6 Months Ended
	Jun. 30, 2014
SUBSIDIARY GUARANTORS [Abstract]	'
Subsidiary Guarantors	'
	SUBSIDIARY GUARANTORS
	The Partnership has issued registered debt securities guaranteed by its subsidiaries.  As of June 30, 2014, 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 SEC Regulation S-X, the Partnership has prepared Unaudited Condensed Consolidating Financial Statements as supplemental information.  The following unaudited condensed consolidating balance sheets at June 30, 2014 and December 31, 2013, and unaudited condensed consolidating statements of operations for the three and six months ended June 30, 2014 and 2013, and unaudited condensed consolidating statements of cash flows for the six months ended June 30, 2014 and 2013, 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 parent, 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. Pursuant to the Contribution of the Midstream Business, all of the Partnership's Midstream Subsidiaries were contributed to Regency on July 1, 2014 and released from their guarantees under the indenture and Credit Agreement.
	Unaudited Condensed Consolidating Balance Sheet
	June 30, 2014
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating			Total
													Entries
		($ in thousands)
	ASSETS:
	Accounts receivable – related parties	$	676,812		$	—	$	—		$	—		$	(676,812	)	$	—
	Assets held for sale	9,401			—		1,201,829			—			—			$	1,211,230
	Other current assets	6,055			1		42,804			—			—			48,860
	Total property, plant and equipment, net	1,966			—		857,929			—			—			859,895
	Investment in subsidiaries	1,161,226			—		—			884			(1,162,110		)	—
	Total other long-term assets	1,423			—		9,357			—			—			10,780
	Total assets	$	1,856,883		$	1	$	2,111,919		$	884		$	(1,838,922	)	$	2,130,765
	LIABILITIES AND EQUITY:
	Accounts payable – related parties	$	—		$	—	$	676,812		$	—		$	(676,812	)	$	—
	Current portion of long-term debt	439,000			—		—			—			—			439,000
	Liabilities held for sale	509,767			—		116,965			—			—			626,732
	Other current liabilities	23,828			—		74,174			—			—			98,002
	Other long-term liabilities	10,574			—		82,743			—			—			93,317
	Long-term debt	380,712			—		—			—			—			380,712
	Equity	493,002			1		1,161,225			884			(1,162,110		)	493,002
	Total liabilities and equity	$	1,856,883		$	1	$	2,111,919		$	884		$	(1,838,922	)	$	2,130,765
	Unaudited Condensed Consolidating Balance Sheet
	December 31, 2013
		Parent Issuer			Co-Issuer		Subsidiary			Non-Guarantor Investments			Consolidating Entries			Total
							Guarantors
		($ in thousands)
	ASSETS:
	Accounts receivable – related parties	$	691,588		$	—	$	—		$	—		$	(691,588	)	$	—
	Assets held for sale	7,333			—		1,252,049			—			—			1,259,382
	Other current assets	6,927			1		22,080			—			—			29,008
	Total property, plant and equipment, net	2,318			—		822,133			—			—			824,451
	Investment in subsidiaries	1,133,217			—		—			908			(1,134,125		)	—
	Total other long-term assets	11,441			—		3,268			—			—			14,709
	Total assets	$	1,852,824		$	1	$	2,099,530		$	908		$	(1,825,713	)	$	2,127,550
	LIABILITIES AND EQUITY:
	Accounts payable – related parties	$	—		$	—	$	691,588		$	—		$	(691,588	)	$	—
	Current portion of long-term debt	—			—		—			—			—			—
	Liabilities held for sale	500,110			—		137,628			—			—			637,738
	Other current liabilities	15,688			—		66,141			—			—			81,829
	Other long-term liabilities	5,667			—		70,957			—			—			76,624
	Long-term debt	757,480			—		—			—			—			757,480
	Equity	573,879			1		1,133,216			908			(1,134,125		)	573,879
	Total liabilities and equity	$	1,852,824		$	1	$	2,099,530		$	908		$	(1,825,713	)	$	2,127,550
	Unaudited Condensed Consolidating Statement of Operations
	For the Three Months Ended June 30, 2014
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating			Total
													Entries
		($ in thousands)
	Total revenues	$	(18,081	)	$	—	$	52,125		$	—		$	—		$	34,044
	Operations and maintenance	3			—		10,904			—			—			10,907
	Taxes other than income	—			—		3,596			—			—			3,596
	General and administrative	2,064			—		9,941			—			—			12,005
Depreciation, depletion and amortization	295			—		20,004			—			—			20,299
Loss from operations	(20,443		)	—		7,680			—			—			(12,763		)
Interest expense, net	(4,946		)	—		(2		)	—			—			(4,948		)
Other non-operating income	2,163			—		2,291			—			(4,454		)	—
Other non-operating expense	(1,987		)	—		(3,036		)	—			4,454			(569		)
Income (loss) before income taxes	(25,213		)	—		6,933			—			—			(18,280		)
Income tax benefit	82			—		(967		)	—			—			(885		)
Equity in earnings of subsidiaries	9,377			—		—			—			(9,377		)	—
Income (loss) from continuing operations	(15,918		)	—		7,900			—			(9,377		)	(17,395		)
Discontinued operations, net of tax	(27,123		)	—		1,479			(2		)	—			(25,646		)
Net income (loss)	$	(43,041	)	$	—	$	9,379		$	(2	)	$	(9,377	)	$	(43,041	)
Unaudited Condensed Consolidating Statement of Operations
For the Three Months Ended June 30, 2013
	Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
	($ in thousands)
Total revenues	$	17,338		$	—	$	49,328		$	—		$	—		$	66,666
Operations and maintenance	—			—		9,579			—			—			9,579
Taxes other than income	—			—		3,583			—			—			3,583
General and administrative	3,031			—		10,310			—			—			13,341
Depreciation, depletion and amortization	299			—		21,761			—			—			22,060
Impairment	—			—		1,839			—			—			1,839
Income from operations	14,008			—		2,256			—			—			16,264
Interest expense, net	(4,446		)	—		(53		)	—			—			(4,499		)
Other non-operating income	2,238			—		2,325			—			(4,563		)	—
Other non-operating expense	(1,602		)	—		(3,139		)	—			4,563			(178		)
Income (loss) before income taxes	10,198			—		1,389			—			—			11,587
Income tax provision (benefit)	(98		)	—		(446		)	—			—			(544		)
Equity in earnings of subsidiaries	9,962			—		—			—			(9,962		)	—
Income (loss) from continuing operations	20,258			—		1,835			—			(9,962		)	12,131
Discontinued operations, net of tax	(4,226		)	—		8,128			(1		)	—			3,901
Net income (loss)	$	16,032		$	—	$	9,963		$	(1	)	$	(9,962	)	$	16,032
Unaudited Condensed Consolidating Statement of Operations
For the Six Months Ended June 30, 2014
	Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating			Total
												Entries
	($ in thousands)
Total revenues	$	(28,114	)	$	—	$	107,361		$	—		$	—		$	79,247
Operations and maintenance	3			—		22,402			—			—			22,405
Taxes other than income	—			—		7,387			—			—			7,387
General and administrative	4,961			—		20,334			—			—			25,295
Depreciation, depletion and amortization	348			—		40,357			—			—			40,705
(Loss) income from operations	(33,426		)	—		16,881			—			—			(16,545		)
Interest expense, net	(9,700		)	—		(2		)	—			—			(9,702		)
Other non-operating income	4,384			—		4,592			—			(8,976		)	—
Other non-operating expense	(3,703		)	—		(6,131		)	—			8,976			(858		)
(Loss) income before income taxes	(42,445		)	—		15,340			—			—			(27,105		)
Income tax benefit	(185		)	—		(1,565		)	—			—			(1,750		)
Equity in earnings of subsidiaries	28,011			—		—			—			(28,011		)	—
Income (loss) from continuing operations	(14,249		)	—		16,905			—			(28,011		)	(25,355		)
Discontinued operations, net of tax	(47,355		)	—		11,115			(9		)	—			(36,249		)
Net (loss) income	$	(61,604	)	$	—	$	28,020		$	(9	)	$	(28,011	)	$	(61,604	)
Unaudited Condensed Consolidating Statement of Operations
For the Six Months Ended June 30, 2013
	Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
	($ in thousands)
Total revenues	$	10,502		$	—	$	96,630		$	—		$	—		$	107,132
Operations and maintenance	—			—		21,279			—			—			21,279
Taxes other than income	—			—		5,999			—			—			5,999
General and administrative	6,679			—		19,972			—			—			26,651
Depreciation, depletion and amortization	346			—		43,010			—			—			43,356
Impairment	—			—		1,839			—			—			1,839
Income from operations	3,477			—		4,531			—			—			8,008
Interest expense, net	(8,731		)	—		(833		)	—			—			(9,564		)
Other non-operating income	4,519			—		4,659			—			(9,178		)	—
Other non-operating expense	(3,218		)	—		(6,302		)	—			9,178			(342		)
Loss before income taxes	(3,953		)	—		2,055			—			—			(1,898		)
Income tax benefit	(673		)	—		(1,432		)	—			—			(2,105		)
Equity in earnings of subsidiaries	(907		)	—		—			—			907			—
Income (loss) from continuing operations	(4,187		)	—		3,487			—			907			207
Discontinued operations, net of tax	(13,295		)	—		(4,388		)	(6		)	—			(17,689		)
Net loss	$	(17,482	)	$	—	$	(901	)	$	(6	)	$	907		$	(17,482	)
Unaudited Condensed Consolidating Statement of Cash Flows
For the Six Months Ended June 30, 2014
	Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
	($ in thousands)
Net cash flows provided by operating activities	$	2,594		$	—	$	23,080		$	—		$	—		$	25,674
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to property, plant and equipment	4			—		(63,793		)	—			—			(63,789		)
Net cash flows used in investing activities	4			—		(63,793		)	—			—			(63,789		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term debt	315,150			—		—			—			—			315,150
Repayment of long-term debt	(252,950		)	—		—			—			—			(252,950		)
Payment of debt issuance cost	(410		)	—		—			—			—			(410		)
Proceeds from derivative contracts	(3,425		)	—		—			—			—			(3,425		)
Repurchase of common units	(1,084		)	—		—			—			—			(1,084		)
Distributions to members and affiliates	(23,801		)	—		—			—			—			(23,801		)
Net cash flows used in financing activities	33,480			—		—			—			—			33,480
Net cash flows used in discontinued operations	(34,973		)	—		40,251			22			—			5,300
Net increase (decrease) in cash and cash equivalents	1,105			—		(462		)	22			—			665
Cash and cash equivalents at beginning of period	1,237			1		(1,389		)	227			—			76
Cash and cash equivalents at end of period	$	2,342		$	1	$	(1,851	)	$	249		$	—		$	741
Unaudited Condensed Consolidating Statement of Cash Flows
For the Six Months Ended June 30, 2013
	Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
	($ in thousands)
Net cash flows (used in) provided by operating activities	$	(31,423	)	$	—	$	88,507		$	—		$	—		$	57,084
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to property, plant and equipment	(855		)	—		(82,540		)	—			—			(83,395		)
Net cash flows used in investing activities	(855		)	—		(82,540		)	—			—			(83,395		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term debt	316,700			—		—			—			—			316,700
Repayment of long-term debt	(312,200		)	—		—			—			—			(312,200		)
Proceeds from derivative contracts	877			—		—			—			—			877
Common unit issued in equity offerings	102,388			—		—			—			—			102,388
Issuance costs for equity offerings	(4,181		)	—		—			—			—			(4,181		)
Repurchase of common units	(1,000		)	—		—			—			—			(1,000		)
Distributions to members and affiliates	(67,117		)	—		—			—			—			(67,117		)
Net cash flows provided by financing activities	35,467			—		—			—			—			35,467
Net cash flows used in discontinued operations	(3,660		)	—		(5,447		)	21			—			(9,086		)
Net (decrease) increase in cash and cash equivalents	(471		)	—		520			21			—			70
Cash and cash equivalents at beginning of period	1,670			1		(1,832		)	186			—			25
Cash and cash equivalents at end of period	$	1,199		$	1	$	(1,312	)	$	207		$	—		$	95

Subsequent_Events

Subsequent Events	6 Months Ended
	Jun. 30, 2014
Subsequent Events [Abstract]	'
Subsequent Events [Text Block]	'
	SUBSEQUENT EVENTS
	Contribution of the Midstream Business
	On July 1, 2014, the Partnership completed the contribution of its Midstream Business to Regency (see Note 1).
	Amendment to Senior Note Indenture
	$51.1 million of the Partnership's Senior Notes did not exchange and remain outstanding; however, the Partnership secured a sufficient number of consents as part of the exchange offer to, and did, amend the indenture governing its remaining outstanding unsecured senior notes to eliminate substantially all of the restrictive covenants and certain events of default pertaining to its Senior Notes.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Basis of Accounting [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, 2013. 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 and six months ended June 30, 2014 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2014.
	As of June 30, 2014, the Partnership owned non-operating undivided interests in certain gas processing plants and gas gathering systems. The Partnership owned these interests as tenants-in-common with the majority owner-operator of the facilities. Accordingly, the Partnership includes its pro-rata share of assets, liabilities, revenues and expenses related to these assets in its financial statements. The assets and liabilities related to these undivided interests have been classified as assets and liabilities held-for-sale within the unaudited condensed consolidated balance sheet, while the operations related to these interests have been classified as discontinued within the unaudited condensed consolidated statement of operations (see Note 16).
	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 Annual Report on Form 10-K for the year ended December 31, 2013. 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.
Inventory Finished Goods, Policy [Policy Text Block]	'
	Inventory—Inventory is stated at the lower of cost or market, with cost being determined using the average cost method. At June 30, 2014 and December 31, 2013, the Partnership had $0.3 million and $1.0 million, respectively, of crude oil finished goods inventory, which is recorded as part of assets held for sale within the unaudited condensed consolidated balance sheet.
Impairment or Disposal 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, accounted for utilizing the successful efforts method, the Partnership reviews its proved properties at the depletion unit 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 to the proved reserves estimates, unfavorable projections of future prices, the timing of future production and estimates of future costs to produce the oil and natural gas. Unproved properties (both individually significant and insignificant) are assessed periodically within specific geographic areas and, if necessary, impairments are charged to expense.
	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 Notes 4 and 6 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 for the Partnership's Midstream Business include 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 are recognized in the period when the services are 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. Material imbalances are reflected as adjustments to reported natural gas reserves and future cash flows.  The Partnership had long-term imbalance payables totaling $0.3 million and $0.3 million as of June 30, 2014 and December 31, 2013, respectively.
Gas Balancing Arrangements, Policy [Policy Text Block]	'
	Transportation and Exchange Imbalances—In the course of transporting natural gas and NGLs for others, the Partnership may receive for redelivery different quantities of natural gas or NGLs than the quantities actually delivered. These transactions result in transportation and exchange imbalance receivables or payables which are recovered or repaid through the receipt or delivery of natural gas or NGLs in future periods, if not subject to cash out provisions. Imbalance receivables are included in accounts receivable and imbalance payables are included in accounts payable on the unaudited condensed consolidated balance sheets and marked-to-market using current market prices in effect for the reporting period of the outstanding imbalances. As of June 30, 2014, the Partnership had imbalance receivables totaling $2.3 million and imbalance payables totaling $1.9 million. As of December 31, 2013, the Partnership had imbalance receivables totaling $0.7 million and imbalance payables totaling $1.6 million. Imbalance receivables and imbalance payables have been classified as assets and liabilities held for sale, respectively, within the unaudited condensed consolidated balance sheet. Changes in market value and the settlement of any such imbalance at a price greater than or less than the recorded imbalance results in either an upward or downward adjustment, as appropriate, to the cost of natural gas sold, and have been classified as discontinued operations within the unaudited condensed consolidated statements of operations.
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 purchases and sales are contracts which provide for the purchase or sale of something, other than a financial instrument or derivative instrument, that 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, with the exception of certain contracts with it's natural gas trading and marketing business. 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.
Reclassification, Policy [Policy Text Block]	'
	Other Reclassifications—The prior period within the unaudited condensed consolidated statements of cash flows has been reclassified to conform to current period presentation. Amounts have been reclassified to new rows titled “Loss from risk management activities, net” that combines settled and mark-to-market gains/losses on derivative instruments and “Derivative settlements” that includes cash attributable to derivative instruments that settled during the periods. The revisions to the cash flow presentation had no impact on “Net cash provided by operating activities.”
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 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 obligations 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 June 30, 2014 and 2013, 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)	6 Months Ended
	Jun. 30, 2014
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment [Table Text Block]	'
	Fixed assets consisted of the following:
		June 30,			December 31,
		2014			2013
		($ in thousands)
	Equipment and machinery	$	101		$	101
	Vehicles and transportation equipment	212			212
	Office equipment, furniture, and fixtures	3,019			1,391
	Computer equipment	13,538			12,247
	Proved properties	1,233,079			1,156,895
	Unproved properties	9,209			10,022
	Construction in progress	2,174			6,636
		1,261,332			1,187,504
	Less: accumulated depreciation, depletion and amortization	(401,437		)	(363,053		)
	Net property, plant and equipment	$	859,895		$	824,451
	Amounts in the table above do not include the property, plant and equipment related to the Partnership's Midstream Business, as these amounts have been classified as assets held for sale within the unaudited condensed consolidated balance sheet (see Note 16).
	The following table sets forth the total depreciation, depletion, capitalized interest costs and impairment expense by type of asset within the Partnership's unaudited condensed consolidated statements of operations:
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014		2013
		($ in thousands)
	Depreciation	$	889		$	612		$	1,586	$	1,003
	Depletion	$	19,334		$	21,399		$	39,006	$	42,270
	Impairment expense:
	Proved properties (a)	$	—		$	1,839		$	—	$	1,839
	________________________________
	(a)	During the three and six months ended June 30, 2013, the Partnership incurred impairment charges in its Upstream Business related to certain proved property primarily in the Permian region due to lower commodity prices and continued high operating costs.
	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)	6 Months Ended
	Jun. 30, 2014
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:
		2014			2013
		($ in thousands)
	Asset retirement obligations—January 1 (a)	$	48,564		$	38,991
	Additional liabilities	21			919
	Liabilities settled	(826		)	(730		)
	Revision to liabilities	(105		)	6,624
	Accretion expense	1,620			1,401
	Asset retirement obligations—June 30 (a)	$	49,274		$	47,205
	_____________________________________
	(a)	As of June 30, 2014 and December 31, 2013, $2.0 million and $11.3 million, respectively, were included within accrued liabilities in the unaudited condensed consolidated balance sheets.
	Amounts in the table above do not include the balances or the activity related to asset retirement obligations related to the Partnership's Midstream Business as these amount have been classified as liabilities held for sale within the unaudited condensed consolidated balance sheet and discontinued operations within the unaudited condensed consolidated statement of operations (see Note 16).
	During the six months ended June 30, 2014 and 2013, the Partnership made decrease revisions of $0.1 million and increase of $6.6 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)	6 Months Ended
	Jun. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Finite-Lived Intangible Assets [Table Text Block]	'
	Intangible assets consisted of the following:
		June 30,			December 31,
		2014			2013
		($ in thousands)
	Rights-of-way and easements—at cost	$	3,920		$	3,920
	Less: accumulated amortization	(750		)	(652		)
	Net intangible assets	$	3,170		$	3,268
	Amounts in the table above do not include the intangible assets related to the Partnership's Midstream Business, as these amounts have been classified as assets held for sale within the unaudited condensed consolidated balance sheet (see Note 16).
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						Six Months Ended
		June 30,						June 30,
		2014			2013			2014		2013
		($ in thousands)
	Amortization	$	49		$	49		$	98	$	98
	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 June 30, 2014, is as follows (in thousands):
	Year ending December 31,
	2014	$	98
	2015	$	196
	2016	$	196
	2017	$	196
	2018	$	196
	Thereafter	$	2,288

Long_Term_Debt_LongTerm_Debt_T

Long Term Debt Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Long-term Debt, by Current and Noncurrent [Abstract]	'
Schedule of Long-term Debt Instruments [Table Text Block]	'
	Long-term debt consisted of the following:
		June 30,			December 31,
		2014			2013
		($ in thousands)
	Revolving credit facility:	$	769,000		$	706,800
	Senior notes:
	8.375% Senior Notes due 2019	51,120			51,120
	Unamortized bond discount	(408		)	(440		)
	Total Senior Notes	50,712			50,680
	Total debt	819,712			757,480
	Less: current maturities (1)	439,000			—
	Total long-term debt	$	380,712		$	757,480
	_____________________________
	1)	Per the Credit Agreement (as defined below), as a result of the contribution of the Midstream Business, the Partnership is required to pay down outstanding debt to the amount of the upstream portion of the borrowing base. As of June 30, 2014 and December 31, 2013, the Partnership has classified as current the difference between the amount outstanding under its credit facility and the upstream portion of the borrowing base.
	Amounts in the table above do not include the portion of the unsecured senior notes that were exchanged for Regency unsecured senior notes upon the completion of the Midstream Business Contribution on July 1, 2014 (see Note 1). These notes have been classified as part of liabilities held for sale within the unaudited condensed consolidated balance sheet.
Schedule of Debt Covenants [Table Text Block]	'
	The following table presents the debt covenant levels specified in the Credit Agreement as of June 30, 2014:
	Quarter Ended	Total Leverage Ratio (a)		Senior Secured Leverage Ratio (a)	Interest Coverage Ratio (b)		Current Ratio (b)
	30-Jun-14	5.85		3.4	2.5		1
	30-Sep-14	4.75		2.95	2.5		1
	Thereafter	4.5		N/A	2.5		1
	_____________________
	(a)	Amount represents the maximum ratio for the period presented.
	(b)	Amount represents the minimum ratio for the period presented.
	The following table presents the Partnership's actual covenant ratios as of June 30, 2014:
	Interest coverage ratio	2.9
	Total leverage ratio	5.77
	Senior secured leverage ratio	3.37
	Current ratio	1
	The calculation of the ratios above includes the amounts classified in the unaudited condensed consolidated financial statements as held for sale and as discontinued operations.

Members_Equity_Members_Equity_

Members' Equity Members' Equity (Tables)	6 Months Ended
	Jun. 30, 2014
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 six months ended June 30, 2014.
	Quarter Ended		Distribution		Record Date*	Payment Date
			per Common Unit
	December 31, 2013+*		$	0.15	February 7, 2014	February 14, 2014
	March 31, 2014**		$	—	N/A	N/A
	June 30, 2014**		$	—	N/A	N/A
	_____________________________
	+	The distribution excludes certain restricted unit grants.
	*	The "Record Date" set forth in the table above means the close of business on each of the listed Record Dates.
	**	No distribution was declared or paid for this period.

Related_Party_Transactions_Rel

Related Party Transactions Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2014
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				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
	Affiliates of Natural Gas Partners:	($ in thousands)
	Natural gas purchases from affiliates	$	949	$	419	$	2,091	$	542
		June 30, 2014		December 31, 2013
	Affiliates of Natural Gas Partners:	($ in thousands)
	Payable (related to natural gas purchases)	$	51	$	18
	The transactions above are 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 and liabilities held for sale within the unaudited condensed consolidated balance sheet (see Note 16).

Risk_Management_Activities_Ris

Risk Management Activities Risk Management Activities (Tables)	6 Months Ended
	Jun. 30, 2014
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 June 30, 2014:
	Effective Date		Expiration		Notional			Fixed
			Date		Amount			Rate
	6/22/11		6/22/15		$	250,000,000		2.95	%
Schedule of Price Risk Derivatives [Table Text Block]	'
	Commodity derivatives, as of June 30, 2014, that will mature during the years ended December 31, 2014, 2015 and 2016:
	Underlying		Type		Notional		Floor				Cap
					Volumes		Strike				Strike
					(units) (a)		Price				Price
							($/unit)(b)				($/unit)(b)
	Portion of Contracts Maturing in 2014
	Natural Gas		Swap (Pay Floating/Receive Fixed)		5,880,000		$	4.51
	Crude Oil		Swap (Pay Floating/Receive Fixed)		624,000		$	96.14
	Crude Oil		Swap (Pay Fixed/Receive Floating)		99,570		$	92.53
	Propane		Swap (Pay Floating/Receive Fixed)		4,788,000		$	1.06
	IsoButane		Swap (Pay Floating/Receive Fixed)		1,134,000		$	1.31
	Normal Butane		Swap (Pay Floating/Receive Fixed)		2,066,400		$	1.3
	Contracts Maturing in 2015
	Natural Gas		Swap (Pay Floating/Receive Fixed)		10,800,000		$	4.07
	Crude Oil		Costless Collar		480,000		$	90			$	97.55
	Crude Oil		Swap (Pay Floating/Receive Fixed)		630,000		$	89.78
	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
	_______________________
	(a)	Volumes of natural gas are measured in MMbtu, volumes of crude oil are measured in barrels, and volumes of natural gas liquids are measured in gallons.
	(b)	Amounts represent the weighted average price in $/MMbtu for natural gas, $/barrel for crude oil and $/gallon for natural gas liquids.
	The table above does not include derivative contracts that have been classified as assets or liabilities held for sale within the unaudited condensed consolidated balance sheet (see Note 16).
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	'
	The following tables set forth the fair values of interest rate and commodity derivative instruments not designated as hedging instruments and their location within the unaudited condensed consolidated balance sheet as of June 30, 2014 and December 31, 2013:
		As of June 30, 2014
		Derivative Assets					Derivative Liabilities
		Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
		($ in thousands)
	Interest rate derivatives - liabilities	Current assets		$	—		Current liabilities		$	(6,531	)
	Commodity derivatives - assets	Current assets		18			Current liabilities		3,238
	Commodity derivatives - assets	Long-term assets		66			Long-term liabilities		323
	Commodity derivatives - assets	Assets held-for-sale		745			Liabilities held-for-sale		572
	Commodity derivatives - liabilities	Current assets		—			Current liabilities		(11,173		)
	Commodity derivatives - liabilities	Long-term assets		—			Long-term liabilities		(8,334		)
	Commodity derivatives - liabilities	Assets held-for-sale		—			Liabilities held-for-sale		(12,796		)
	Total derivatives			$	829				$	(34,701	)
		As of December 31, 2013
		Derivative Assets					Derivative Liabilities
		Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
		($ in thousands)
	Interest rate derivatives - liabilities	Current assets		$	—		Current liabilities		$	(6,210	)
	Interest rate derivatives - liabilities	Long-term assets		—			Long-term liabilities		(2,885		)
	Commodity derivatives - assets	Current assets		6,841			Current liabilities		1,043
	Commodity derivatives - assets	Long-term assets		4,669			Long-term liabilities		202
	Commodity derivatives - assets	Assets held-for-sale		6,017			Liabilities held-for-sale		1,973
	Commodity derivatives - liabilities	Current assets		(1,282		)	Current liabilities		(3,193		)
	Commodity derivatives - liabilities	Long-term assets		(798		)	Long-term liabilities		(143		)
	Commodity derivatives - liabilities	Assets held-for-sale		(824		)	Liabilities held-for-sale		(5,658		)
	Total derivatives			$	14,623				$	(14,871	)
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							Six Months Ended
				June 30,							June 30,
				2014			2013				2014			2013
				($ in thousands)
	Interest rate derivatives	Interest rate risk management losses, net		$	(571	)	$	(151	)		$	(861	)	$	(307	)
	Commodity derivatives	Commodity risk management losses, net		(18,081		)	17,338				(28,114		)	10,502
	Commodity derivatives	Discontinued operations		(10,968		)	13,155				(15,879		)	2,083
	Commodity derivatives - trading	Discontinued operations		(1,416		)	1,134				(2,404		)	(16		)
		Total		$	(31,036	)	$	31,476			$	(47,258	)	$	12,262

Fair_Value_of_Financial_Instru1

Fair Value of Financial Instruments Fair Value of Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
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 as of June 30, 2014 and December 31, 2013:
		As of June 30, 2014
		Level 1		Level 2			Level 3		Netting (a)			Total
		($ in thousands)
	Assets:
	Crude oil derivatives	$	—	$	1,085		$	—	$	(1,085	)	$	—
	Natural gas derivatives	—		2,551			—		(2,467		)	84
	NGL derivatives	—		8			—		(8		)	—
	Total	$	—	$	3,644		$	—	$	(3,560	)	$	84
	Liabilities:
	Crude oil derivatives	$	—	$	(15,412	)	$	—	$	1,085		$	(14,327	)
	Natural gas derivatives	—		(3,753		)	—		2,467			(1,286		)
	NGL derivatives	—		(342		)	—		8			(334		)
	Interest rate swaps	—		(6,531		)	—		—			(6,531		)
	Total	$	—	$	(26,038	)	$	—	$	3,560		$	(22,478	)
	____________________________
	(a)	Represents counterparty netting under the agreement governing such derivative contracts.
		As of December 31, 2013
		Level 1		Level 2			Level 3		Netting (a)			Total
		($ in thousands)
	Assets:
	Crude oil derivatives	$	—	$	6,151		$	—	$	(1,716	)	$	4,435
	Natural gas derivatives	—		6,562			—		(1,567		)	4,995
	NGL derivatives	—		42			—		(42		)	—
	Total	$	—	$	12,755		$	—	$	(3,325	)	$	9,430
	Liabilities:
	Crude oil derivatives	$	—	$	(1,792	)	$	—	$	1,716		$	(76	)
	Natural gas derivatives	—		(2,503		)	—		1,567			(936		)
	NGL derivatives	—		(1,121		)	—		42			(1,079		)
	Interest rate swaps	—		(9,095		)	—		—			(9,095		)
	Total	$	—	$	(14,511	)	$	—	$	3,325		$	(11,186	)
	____________________________
	(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 June 30, 2014:
		Six Months Ended
		June 30,
		2014		Level 1			Level 2		Level 3			Total Losses
		($ in thousands)
	Plant assets	$	52	$	—		$	—	$	52		$	132
	Pipeline assets	$	746	$	—		$	—	$	746		$	1,904
	Rights-of-way	$	24	$	—		$	—	$	24		$	61

Equity_Based_Compensation_Equi

Equity Based Compensation Equity Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2014
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 six months ended June 30, 2014 is provided below:
		Number of		Weighted
		Restricted		Average
		Units		Fair Value
	Outstanding at December 31, 2013	2,743,807		$	9.37
	Granted	1,287,360		$	4.63
	Vested	(963,392	)	$	9.6
	Forfeited	(557,554	)	$	9.19
	Outstanding at June 30, 2014	2,510,221		$	6.89

Earnings_Per_Unit_Earnings_Per

Earnings Per Unit Earnings Per Unit (Tables)	6 Months Ended
	Jun. 30, 2014
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					Six Months Ended
		June 30,					June 30,
		2014			2013		2014		2013
		(in thousands)
	Weighted average units outstanding during period:
	Common units - Basic and diluted	156,955			155,269		156,802		150,860
	Effect of Dilutive Securities:
	Restricted Units (non-participating securities)	—			285		—		—
	Restricted Units (participating securities)	—			1,156		—		—
	Common units - Diluted	156,955			156,710		156,802		150,860
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]	'
			Total			Common Units			Restricted Common Units*
			($ in thousands, except for per unit amounts)
	Loss from continuing operations		$	(17,395	)
	Distributions**		—			$	—		$	—
	Assumed loss from continuing operations after distribution to be allocated		(17,395		)	(17,395		)	—
	Assumed allocation of loss from continuing operations		(17,395		)	(17,395		)	—
	Discontinued operations		(25,646		)	(25,646		)	—
	Assumed net loss to be allocated		$	(43,041	)	$	(43,041	)	$	—
	Basic loss from continuing operations per unit					$	(0.11	)
	Basic discontinued operations per unit					$	(0.16	)
	Basic and diluted loss per unit					$	(0.27	)
	Diluted income from continuing operations per unit					$	(0.11	)
	Diluted discontinued operations per unit					$	(0.16	)
	Diluted income per unit					$	(0.27	)
	_____________________________
	*	Restricted common units granted under the LTIP that contain non-forfeitable rights to the distributions declared by the Partnership.
	**	No distribution was declared or paid for this period as the distribution was suspended for this period.
	The following table presents the Partnership's basic and diluted income per unit for the three months ended June 30, 2013:
			Total			Common Units			Restricted Common Units
			($ in thousands, except for per unit amounts)
	Income from continuing operations		$	12,131
	Distributions		34,972			$	34,337		$	635
	Assumed income from continuing operations after distribution to be allocated		(22,841		)	(22,841		)	—
	Assumed allocation of income from continuing operations		12,131			11,496			635
	Discontinued operations		3,901			3,901			—
	Assumed net income to be allocated		$	16,032		$	15,397		$	635
	Basic income from continuing operations per unit					$	0.07
	Basic discontinued operations per unit					$	0.03
	Basic and diluted income per unit					$	0.1
	Diluted income from continuing operations per unit					$	0.07
	Diluted discontinued operations per unit					$	0.03
	Diluted income per unit					$	0.1
	The following table presents the Partnership's basic and diluted income per unit for the six months ended June 30, 2014:
			Total			Common Units			Restricted Common Units*
			($ in thousands, except for per unit amounts)
	Loss from continuing operations		$	(25,355	)
	Distributions **		—			$	—		$	—
	Assumed loss from continuing operations after distribution to be allocated		(25,355		)	(25,355		)	—
	Assumed allocation of loss from continuing operations		(25,355		)	(25,355		)	—
	Discontinued operations, net of tax		(36,249		)	(36,249		)	—
	Assumed net loss to be allocated		$	(61,604	)	$	(61,604	)	$	—
	Basic income from continuing operations per unit					$	(0.16	)
	Basic discontinued operations per unit					$	(0.23	)
	Basic and diluted loss per unit					$	(0.39	)
	Diluted income from continuing operations per unit					$	(0.16	)
	Diluted discontinued operations per unit					$	(0.23	)
	Diluted income per unit					$	(0.39	)
	_____________________________
	*	Restricted common units granted under the LTIP that contain non-forfeitable rights to the distributions declared by the Partnership.
	**	No distribution was declared or paid for this period as the distribution was suspended for this period.
	The following table presents the Partnership's basic and diluted income per unit for the six months ended June 30, 2013:
			Total			Common Units			Restricted Common Units
			($ in thousands, except for per unit amounts)
	Loss from continuing operations		$	207
	Distributions		69,670			$	68,443		$	1,227
	Assumed loss from continuing operations after distribution to be allocated		(69,463		)	(69,463		)	—
	Assumed allocation of loss from continuing operations		207			(1,020		)	1,227
	Discontinued operations, net of tax		(17,689		)	(17,689		)	—
	Assumed net loss to be allocated		$	(17,482	)	$	(18,709	)	$	1,227
	Basic income from continuing operations per unit					$	(0.01	)
	Basic discontinued operations per unit					$	(0.12	)
	Basic and diluted loss per unit					$	(0.13	)
	Diluted income from continuing operations per unit					$	(0.01	)
Diluted discontinued operations per unit					$	(0.12	)
Diluted income per unit					$	(0.13	)

Divestiture_Related_Activities1

Divestiture Related Activities Divestiture Related Activites(Tables)	6 Months Ended
	Jun. 30, 2014
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 is the reconciliation of the major classes of assets and liabilities classified as held for sale.
		June 30,				December 31,
		2014				2013
	Assets held-for-sale
	Accounts Receivable	$	111,131			$	128,713
	Property, plant and equipment	989,755				1,004,317
	Intangible assets	99,830				102,352
	Other current assets	750				5,663
	Other long-term assets	9,764				18,337
	Total assets held-for-sale	$	1,211,230			$	1,259,382
	Liabilities held-for-sale
	Long-term debt	$	494,898			$	494,582
	Accounts payable and accrued liabilities	99,653				119,966
	Other current liabilities	11,778				9,471
	Other long-term liabilities	20,403				13,719
	Total liabilities held-for-sale	$	626,732			$	637,738
	The following following is the reconciliation of the major classes of line items classified as discontinued operations.
			Three Months Ended							Six Months Ended
			June 30,							June 30,
			2014				2013			2014			2013
	Class of statement of operations line item of discontinued operations:
	Revenue		$	245,210			$	253,485		$	548,081		$	470,750
	Cost of natural gas, natural gas liquids, condensate and helium		199,700				185,760			444,673			365,748
	Operations, maintenance and taxes other than income		25,078				27,020			50,127			48,989
	General and administrative		12,107				6,055			20,208			11,592
	Depreciation, amortization and impairment		19,737				19,097			41,936			38,038
	Interest expense		(14,118		)		(12,110		)	(27,350		)	(24,129		)
	Other expense		(60		)		140			(68		)	140
	Operating income (loss) from discontinued operations before taxes		(25,590		)		3,583			(36,281		)	(17,606		)
	Income tax expense (benefit)		56				(318		)	(32		)	83
	Discontinued operations		$	(25,646	)		$	3,901		$	(36,249	)	$	(17,689	)

Subsidiary_Guarantors_Subsidia

Subsidiary Guarantors Subsidiary Guarantors (Tables)	6 Months Ended
	Jun. 30, 2014
SUBSIDIARY GUARANTORS [Abstract]	'
Subsidiary Guarantor Consolidating Balance Sheet [Table Text Block]	'
	Condensed Consolidating Balance Sheet
	June 30, 2014
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating			Total
													Entries
		($ in thousands)
	ASSETS:
	Accounts receivable – related parties	$	676,812		$	—	$	—		$	—		$	(676,812	)	$	—
	Assets held for sale	9,401			—		1,201,829			—			—			$	1,211,230
	Other current assets	6,055			1		42,804			—			—			48,860
	Total property, plant and equipment, net	1,966			—		857,929			—			—			859,895
	Investment in subsidiaries	1,161,226			—		—			884			(1,162,110		)	—
	Total other long-term assets	1,423			—		9,357			—			—			10,780
	Total assets	$	1,856,883		$	1	$	2,111,919		$	884		$	(1,838,922	)	$	2,130,765
	LIABILITIES AND EQUITY:
	Accounts payable – related parties	$	—		$	—	$	676,812		$	—		$	(676,812	)	$	—
	Current portion of long-term debt	439,000			—		—			—			—			439,000
	Liabilities held for sale	509,767			—		116,965			—			—			626,732
	Other current liabilities	23,828			—		74,174			—			—			98,002
	Other long-term liabilities	10,574			—		82,743			—			—			93,317
	Long-term debt	380,712			—		—			—			—			380,712
	Equity	493,002			1		1,161,225			884			(1,162,110		)	493,002
	Total liabilities and equity	$	1,856,883		$	1	$	2,111,919		$	884		$	(1,838,922	)	$	2,130,765
	Unaudited Condensed Consolidating Balance Sheet
	December 31, 2013
		Parent Issuer			Co-Issuer		Subsidiary			Non-Guarantor Investments			Consolidating Entries			Total
							Guarantors
		($ in thousands)
	ASSETS:
	Accounts receivable – related parties	$	691,588		$	—	$	—		$	—		$	(691,588	)	$	—
	Assets held for sale	7,333			—		1,252,049			—			—			1,259,382
	Other current assets	6,927			1		22,080			—			—			29,008
	Total property, plant and equipment, net	2,318			—		822,133			—			—			824,451
	Investment in subsidiaries	1,133,217			—		—			908			(1,134,125		)	—
	Total other long-term assets	11,441			—		3,268			—			—			14,709
	Total assets	$	1,852,824		$	1	$	2,099,530		$	908		$	(1,825,713	)	$	2,127,550
	LIABILITIES AND EQUITY:
	Accounts payable – related parties	$	—		$	—	$	691,588		$	—		$	(691,588	)	$	—
	Current portion of long-term debt	—			—		—			—			—			—
	Liabilities held for sale	500,110			—		137,628			—			—			637,738
	Other current liabilities	15,688			—		66,141			—			—			81,829
	Other long-term liabilities	5,667			—		70,957			—			—			76,624
	Long-term debt	757,480			—		—			—			—			757,480
	Equity	573,879			1		1,133,216			908			(1,134,125		)	573,879
	Total liabilities and equity	$	1,852,824		$	1	$	2,099,530		$	908		$	(1,825,713	)	$	2,127,550
Subsidiary Guarantors Consolidating Statements of Operations [Table Text Block]	'
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating			Total
													Entries
		($ in thousands)
	Total revenues	$	(18,081	)	$	—	$	52,125		$	—		$	—		$	34,044
	Operations and maintenance	3			—		10,904			—			—			10,907
	Taxes other than income	—			—		3,596			—			—			3,596
	General and administrative	2,064			—		9,941			—			—			12,005
	Depreciation, depletion and amortization	295			—		20,004			—			—			20,299
	Loss from operations	(20,443		)	—		7,680			—			—			(12,763		)
	Interest expense, net	(4,946		)	—		(2		)	—			—			(4,948		)
	Other non-operating income	2,163			—		2,291			—			(4,454		)	—
	Other non-operating expense	(1,987		)	—		(3,036		)	—			4,454			(569		)
	Income (loss) before income taxes	(25,213		)	—		6,933			—			—			(18,280		)
	Income tax benefit	82			—		(967		)	—			—			(885		)
	Equity in earnings of subsidiaries	9,377			—		—			—			(9,377		)	—
	Income (loss) from continuing operations	(15,918		)	—		7,900			—			(9,377		)	(17,395		)
	Discontinued operations, net of tax	(27,123		)	—		1,479			(2		)	—			(25,646		)
	Net income (loss)	$	(43,041	)	$	—	$	9,379		$	(2	)	$	(9,377	)	$	(43,041	)
	Unaudited Condensed Consolidating Statement of Operations
	For the Three Months Ended June 30, 2013
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
		($ in thousands)
	Total revenues	$	17,338		$	—	$	49,328		$	—		$	—		$	66,666
	Operations and maintenance	—			—		9,579			—			—			9,579
	Taxes other than income	—			—		3,583			—			—			3,583
	General and administrative	3,031			—		10,310			—			—			13,341
	Depreciation, depletion and amortization	299			—		21,761			—			—			22,060
	Impairment	—			—		1,839			—			—			1,839
	Income from operations	14,008			—		2,256			—			—			16,264
	Interest expense, net	(4,446		)	—		(53		)	—			—			(4,499		)
	Other non-operating income	2,238			—		2,325			—			(4,563		)	—
	Other non-operating expense	(1,602		)	—		(3,139		)	—			4,563			(178		)
	Income (loss) before income taxes	10,198			—		1,389			—			—			11,587
	Income tax provision (benefit)	(98		)	—		(446		)	—			—			(544		)
	Equity in earnings of subsidiaries	9,962			—		—			—			(9,962		)	—
	Income (loss) from continuing operations	20,258			—		1,835			—			(9,962		)	12,131
	Discontinued operations, net of tax	(4,226		)	—		8,128			(1		)	—			3,901
	Net income (loss)	$	16,032		$	—	$	9,963		$	(1	)	$	(9,962	)	$	16,032
	Unaudited Condensed Consolidating Statement of Operations
	For the Six Months Ended June 30, 2014
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating			Total
													Entries
		($ in thousands)
	Total revenues	$	(28,114	)	$	—	$	107,361		$	—		$	—		$	79,247
	Operations and maintenance	3			—		22,402			—			—			22,405
	Taxes other than income	—			—		7,387			—			—			7,387
	General and administrative	4,961			—		20,334			—			—			25,295
	Depreciation, depletion and amortization	348			—		40,357			—			—			40,705
	(Loss) income from operations	(33,426		)	—		16,881			—			—			(16,545		)
	Interest expense, net	(9,700		)	—		(2		)	—			—			(9,702		)
	Other non-operating income	4,384			—		4,592			—			(8,976		)	—
	Other non-operating expense	(3,703		)	—		(6,131		)	—			8,976			(858		)
	(Loss) income before income taxes	(42,445		)	—		15,340			—			—			(27,105		)
	Income tax benefit	(185		)	—		(1,565		)	—			—			(1,750		)
	Equity in earnings of subsidiaries	28,011			—		—			—			(28,011		)	—
	Income (loss) from continuing operations	(14,249		)	—		16,905			—			(28,011		)	(25,355		)
	Discontinued operations, net of tax	(47,355		)	—		11,115			(9		)	—			(36,249		)
	Net (loss) income	$	(61,604	)	$	—	$	28,020		$	(9	)	$	(28,011	)	$	(61,604	)
	Unaudited Condensed Consolidating Statement of Operations
	For the Six Months Ended June 30, 2013
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
		($ in thousands)
	Total revenues	$	10,502		$	—	$	96,630		$	—		$	—		$	107,132
Operations and maintenance	—			—		21,279			—			—			21,279
Taxes other than income	—			—		5,999			—			—			5,999
General and administrative	6,679			—		19,972			—			—			26,651
Depreciation, depletion and amortization	346			—		43,010			—			—			43,356
Impairment	—			—		1,839			—			—			1,839
Income from operations	3,477			—		4,531			—			—			8,008
Interest expense, net	(8,731		)	—		(833		)	—			—			(9,564		)
Other non-operating income	4,519			—		4,659			—			(9,178		)	—
Other non-operating expense	(3,218		)	—		(6,302		)	—			9,178			(342		)
Loss before income taxes	(3,953		)	—		2,055			—			—			(1,898		)
Income tax benefit	(673		)	—		(1,432		)	—			—			(2,105		)
Equity in earnings of subsidiaries	(907		)	—		—			—			907			—
Income (loss) from continuing operations	(4,187		)	—		3,487			—			907			207
Discontinued operations, net of tax	(13,295		)	—		(4,388		)	(6		)	—			(17,689		)
Net loss	$	(17,482	)	$	—	$	(901	)	$	(6	)	$	907		$	(17,482	)
Subsidiary Guarantor Consolidating Statements of Cash Flows [Table Text Block]	'
	Unaudited Condensed Consolidating Statement of Cash Flows
	For the Six Months Ended June 30, 2014
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
		($ in thousands)
	Net cash flows provided by operating activities	$	2,594		$	—	$	23,080		$	—		$	—		$	25,674
	CASH FLOWS FROM INVESTING ACTIVITIES:
	Additions to property, plant and equipment	4			—		(63,793		)	—			—			(63,789		)
	Net cash flows used in investing activities	4			—		(63,793		)	—			—			(63,789		)
	CASH FLOWS FROM FINANCING ACTIVITIES:
	Proceeds from long-term debt	315,150			—		—			—			—			315,150
	Repayment of long-term debt	(252,950		)	—		—			—			—			(252,950		)
	Payment of debt issuance cost	(410		)	—		—			—			—			(410		)
	Proceeds from derivative contracts	(3,425		)	—		—			—			—			(3,425		)
	Repurchase of common units	(1,084		)	—		—			—			—			(1,084		)
	Distributions to members and affiliates	(23,801		)	—		—			—			—			(23,801		)
	Net cash flows used in financing activities	33,480			—		—			—			—			33,480
	Net cash flows used in discontinued operations	(34,973		)	—		40,251			22			—			5,300
	Net increase (decrease) in cash and cash equivalents	1,105			—		(462		)	22			—			665
	Cash and cash equivalents at beginning of period	1,237			1		(1,389		)	227			—			76
	Cash and cash equivalents at end of period	$	2,342		$	1	$	(1,851	)	$	249		$	—		$	741
	Unaudited Condensed Consolidating Statement of Cash Flows
	For the Six Months Ended June 30, 2013
		Parent Issuer			Co-Issuer		Subsidiary Guarantors			Non-Guarantor Investments			Consolidating Entries			Total
		($ in thousands)
	Net cash flows (used in) provided by operating activities	$	(31,423	)	$	—	$	88,507		$	—		$	—		$	57,084
	CASH FLOWS FROM INVESTING ACTIVITIES:
	Additions to property, plant and equipment	(855		)	—		(82,540		)	—			—			(83,395		)
	Net cash flows used in investing activities	(855		)	—		(82,540		)	—			—			(83,395		)
	CASH FLOWS FROM FINANCING ACTIVITIES:
	Proceeds from long-term debt	316,700			—		—			—			—			316,700
	Repayment of long-term debt	(312,200		)	—		—			—			—			(312,200		)
	Proceeds from derivative contracts	877			—		—			—			—			877
	Common unit issued in equity offerings	102,388			—		—			—			—			102,388
	Issuance costs for equity offerings	(4,181		)	—		—			—			—			(4,181		)
	Repurchase of common units	(1,000		)	—		—			—			—			(1,000		)
	Distributions to members and affiliates	(67,117		)	—		—			—			—			(67,117		)
	Net cash flows provided by financing activities	35,467			—		—			—			—			35,467
	Net cash flows used in discontinued operations	(3,660		)	—		(5,447		)	21			—			(9,086		)
	Net (decrease) increase in cash and cash equivalents	(471		)	—		520			21			—			70
	Cash and cash equivalents at beginning of period	1,670			1		(1,832		)	186			—			25
	Cash and cash equivalents at end of period	$	1,199		$	1	$	(1,312	)	$	207		$	—		$	95

Organization_and_Description_o1

Organization and Description of Business Narrative (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jul. 01, 2014	Jul. 01, 2014
			Scenario, Forecast [Member]	Scenario, Forecast [Member]
				Total Midstream Segments [Member]
Disposal Group, Including Discontinue Operation, Consideration, Cash	'	'	'	$576,000,000
Disposal Group, Including Discontinued Operations, Consideration, Equity Interests Received, Shares	'	'	'	8,245,859
Disposal Group, Including Discontinued Operation, Consideration, Equity Interests Received	'	'	'	265,000,000
Disposal Group, Including Discontinued Operation, Consideration, Debt Exchanged	'	'	'	498,900,000
8 3/8% senior notes due 2019	$51,120,000	$51,120,000	$51,100,000	$51,100,000

Summary_of_Significant_Account2

Summary of Significant Accounting Policies Narrative (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2012
In Millions, unless otherwise specified
Inventory, Finished Goods, Gross	$0.30	$1
Gas Balancing Payable	0.3	0.3
Transportation and exchange imbalance, receivable	2.3	0.7
Transportation and exchange imbalance, payable	$1.90	$1.60

Property_Plant_and_Equipment_P1

Property, Plant and Equipment Property, Plant and Equipment (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Property, Plant and Equipment - Gross	$1,261,332	$1,187,504
Accumulated depreciation, depletion and amortization	-401,437	-363,053
Property, Plant and Equipment — Net	859,895	824,451
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	3,019	1,391
Computer Equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, Plant and Equipment - Gross	13,538	12,247
Proved Oil and Gas Properties [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, Plant and Equipment - Gross	1,233,079	1,156,895
Unproved Oil and Gas Properties [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, Plant and Equipment - Gross	9,209	10,022
Construction in Progress [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, Plant and Equipment - Gross	$2,174	$6,636

Property_Plant_and_Equipment_D

Property, Plant and Equipment Depreciation, Depletion, Amortization and Impairment (Details) (USD $)	3 Months Ended			6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013		Jun. 30, 2014	Jun. 30, 2013
Depreciation	$889	$612		$1,586	$1,003
Depletion	19,334	21,399		39,006	42,270
Oil and Gas Properties [Member]	'	'		'	'
Impairment of Long-Lived Assets Held-for-use	$0	$1,839	[1]	$0	$1,839	[1]
[1]	During the three and six months ended June 30, 2013, the Partnership incurred impairment charges in its Upstream Business related to certain proved property primarily in the Permian region due to lower commodity prices and continued high operating costs.

Asset_Retirement_Obligations_S

Asset Retirement Obligations Schedule of Change in Asset Retirement Obligation (Details) (USD $)	6 Months Ended
	Jun. 30, 2014		Jun. 30, 2013	Dec. 31, 2013
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'		'	'
Asset Retirement Obligation - Beginning of Period	$48,564,000	[1]	$38,991,000	'
Additional liabilities	21,000		919,000	'
Liabilities settled	-826,000		-730,000	'
Revision to liabilities	-105,000		6,624,000	'
Accretion expense	1,620,000		1,401,000	'
Asset Retirement Obligation - End of Period	49,274,000	[1]	47,205,000	'
Asset Retirement Obligation, Current	$2,000,000		'	$11,300,000
[1]	As of June 30, 2014 and December 31, 2013, $2.0 million and $11.3 million, respectively, were included within accrued liabilities in the unaudited condensed consolidated balance sheets.

Intangible_Assets_Intangible_A1

Intangible Assets Intangible Assets (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Acquired Finite-Lived Intangible Assets [Line Items]	'	'
Intangible Assets — Net	$3,170	$3,268
Use Rights [Member]	'	'
Acquired Finite-Lived Intangible Assets [Line Items]	'	'
Rights-of-way and easements—at cost	3,920	3,920
Less: accumulated amortization	($750)	($652)

Intangible_Assets_Amortization

Intangible Assets Amortization and Impairment (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Amortization	$49	$49	$98	$98

Intangible_Assets_Future_Amort

Intangible Assets Future Amortization Expense (Details) (USD $)	Jun. 30, 2014
In Thousands, unless otherwise specified
Finite-Lived Intangible Assets [Line Items]	'
Finite-Lived Intangible Assets, Amortization Expense, Remainder of Fiscal Year	$98
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	$2,288

Intangible_Assets_Narrative_De

Intangible Assets Narrative (Details) (Use Rights [Member])	6 Months Ended
	Jun. 30, 2014
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 $)	Jun. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'		'
Revolving credit facility:	$769,000		$706,800
8 3/8% senior notes due 2019	51,120		51,120
Unamortized bond discount senior notes due 2019	-408		-440
Senior Notes	50,712		50,680
Total debt	819,712		757,480
Current portion of long-term debt	-439,000		0
Long-term debt	380,712		757,480
Line of Credit [Member]	'		'
Debt Instrument [Line Items]	'		'
Current portion of long-term debt	$439,000	[1]	$0
[1]	Per the Credit Agreement (as defined below), as a result of the contribution of the Midstream Business, the Partnership is required to pay down outstanding debt to the amount of the upstream portion of the borrowing base. As of June 30, 2014 and December 31, 2013, the Partnership has classified as current the difference between the amount outstanding under its credit facility and the upstream portion of the borrowing base.

Long_Term_Debt_Debt_Covenants_

Long Term Debt Debt Covenants (Details)

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2014

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2014

Sep. 30, 2014

Dec. 31, 2014

Sep. 30, 2014

Total Leverage Ratio [Member]

Senior Secured Leverage Ratio [Member]

Interest Coverage Ratio [Member]

Current Ratio [Member]

Maximum [Member]

Maximum [Member]

Minimum [Member]

Minimum [Member]

Scenario, Forecast [Member]

Scenario, Forecast [Member]

Scenario, Forecast [Member]

Scenario, Forecast [Member]

Scenario, Forecast [Member]

Scenario, Forecast [Member]

Scenario, Forecast [Member]

Total Leverage Ratio [Member]

Senior Secured Leverage Ratio [Member]

Interest Coverage Ratio [Member]

Current Ratio [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Total Leverage Ratio [Member]

Total Leverage Ratio [Member]

Senior Secured Leverage Ratio [Member]

Interest Coverage Ratio [Member]

Interest Coverage Ratio [Member]

Current Ratio [Member]

Current Ratio [Member]

Schedule of Debt Covenants [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Covenant Ratio

5.8

3.37

2.9

1

5.85

[1]

3.4

[1]

2.5

[2]

1

[2]

4.5

[1]

4.75

[1]

2.95

[1]

2.5

[2]

2.5

[2]

1

[2]

1

[2]

[1]

Amount represents the maximum ratio for the period presented.

[2]

Amount represents the minimum ratio for the period presented.

Long_Term_Debt_Narrative_Detai

Long Term Debt Narrative (Details) (USD $)	3 Months Ended	6 Months Ended		3 Months Ended
	Mar. 31, 2014	Jun. 30, 2014	Dec. 31, 2013	Sep. 30, 2014	Jul. 01, 2014
	Rate			Scenario, Forecast [Member]	Scenario, Forecast [Member]
Debt Instrument [Line Items]	'	'	'	'	'
Repayments of Debt	'	'	'	$570,400,000	'
Revolving credit facility:	'	769,000,000	706,800,000	'	198,600,000
Line of Credit Facility, Commitment Fee Percentage	0.50%	'	'	'	'
Letters of Credit Outstanding, Amount	4,400,000	'	'	'	'
Line of Credit Facility, Remaining Borrowing Capacity	45,800,000	'	'	'	'
Line of Credit Facility, Current Borrowing Capacity	$819,000,000	'	'	'	'
Borrowing Base Multiplier	4	'	3.75	'	'
Debt Instrument, Covenant Compliance	'	'As of June 30, 2014, the Partnership was in compliance with the financial covenants under the revolving credit facility.	'	'	'

Members_Equity_Narrative_Detai

Members' Equity Narrative (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2014	Jun. 30, 2014	Dec. 31, 2013
Capital Unit [Line Items]	'	'	'
Limited Partners' Capital Account, Units Outstanding	'	157,354,239	156,644,153
Unvested Restricted Units Outstanding	'	2,510,221	2,743,807
Equity Issuance, Market Value	$100	'	'
Equity Units, Issued	0	'	'

Members_Equity_Distributions_D

Members' Equity Distributions (Details) (USD $)	3 Months Ended
	Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2013
Dividends Payable [Line Items]	'		'		'
Common Stock, Dividends, Per Share, Cash Paid	$0	[1]	$0	[1]	$0.15	[2]
Record date	'		'		7-Feb-14	[3]
Payment Date	'		'		14-Feb-14
[1]	No distribution was declared or paid for this period.
[2]	The distribution excludes certain restricted unit grants.
[3]	The "Record Date" set forth in the table above means the close of business on each of the listed Record Dates.

Related_Party_Transactions_Sch

Related Party Transactions Schedule of Related Party Transactions (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Related Party Transaction [Line Items]	'	'	'	'	'
Natural gas purchases from affiliates	$949	$419	$2,091	$542	'
Due to Related Parties, Current	$51	'	$51	'	$18

Risk_Management_Activities_Int

Risk Management Activities Interest Rate Derivatives (Details) (Effective Date, 6/22/2011 [Member], Interest Rate Swap [Member], USD $)	Mar. 31, 2014	Sep. 30, 2015
	Rate	Scenario, Forecast [Member]
Derivative [Line Items]	'	'
Derivative, Maturity Date	'	22-Jun-15
Derivative, Notional Amount	$250,000,000	'
Derivative, Average Fixed Interest Rate	2.95%	'

Risk_Management_Activities_Com

Risk Management Activities Commodity Derivatives (Details)	Jun. 30, 2014
	MMbtu
Natural Gas Contract [Member] | Swap [Member] | Portion of contracts settling in 2014 [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	5,880,000	[1]
Derivative, Average Floor Price	4.51	[2]
Natural Gas Contract [Member] | Swap [Member] | Portion of contracts settling in 2015 [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	10,800,000	[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	480,000	[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 2014 [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	624,000	[1]
Derivative, Average Floor Price	96.14	[2]
Crude Oil Contract [Member] | Swap [Member] | Portion of contracts settling in 2015 [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	630,000	[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, Pay Fixed, Receive Floating [Member] | Portion of contracts settling in 2014 [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	99,570	[1]
Derivative, Average Floor Price	92.53	[2]
Propane Contract [Member] | Swap [Member] | Portion of contracts settling in 2014 [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	4,788,000	[1]
Derivative, Average Floor Price	1.06	[2]
IsoButane Contract [Member] | Swap [Member] | Portion of contracts settling in 2014 [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	1,134,000	[1]
Derivative, Average Floor Price	1.31	[2]
Normal Butane Contract [Member] | Swap [Member] | Portion of contracts settling in 2014 [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	2,066,400	[1]
Derivative, Average Floor Price	1.3	[2]
[1]	Volumes of natural gas are measured in MMbtu, volumes of crude oil are measured in barrels, and volumes of natural gas liquids are measured in gallons.
[2]	Amounts represent the weighted average price in $/MMbtu for natural gas, $/barrel for crude oil and $/gallon for natural gas liquids.

Risk_Management_Activities_Sch

Risk Management Activities Schedule of Derivative Instruments in the Statement of Financial Position (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Current	($14,467)	($8,360)
Derivative Liabilities, Noncurrent	-8,011	-2,826
Derivative assets, Current	18	5,559
Derivative assets, Noncurrent	66	3,871
Derivative Assets	829	14,623
Derivative Liabilities	-34,701	-14,871
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Current	0	0
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Long-term Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Noncurrent	'	0
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Current	-6,531	-6,210
Interest Rate Contract [Member] | Not Designated as Hedging Instrument [Member] | Long-term Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Noncurrent	'	-2,885
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Current	0	-1,282
Derivative assets, Current	18	6,841
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Long-term Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Noncurrent	0	-798
Derivative assets, Noncurrent	66	4,669
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Current	-11,173	-3,193
Derivative assets, Current	3,238	1,043
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Long-term Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Noncurrent	-8,334	-143
Derivative assets, Noncurrent	323	202
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Assets Held-for-sale [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Current	0	-824
Derivative assets, Current	745	6,017
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | Liabilities held for sale [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Current	-12,796	-5,658
Derivative assets, Current	$572	$1,973

Risk_Management_Activities_Sch1

Risk Management Activities Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Interest rate risk management losses	($571)	($151)	($861)	($307)
Commodity risk management (losses) gains	-18,081	17,338	-28,114	10,502
Derivative Instruments, Gain (Loss) Recognized in Income, Net	-31,036	31,476	-47,258	12,262
Interest Rate Contract [Member] | Other Expense [Member] | Not Designated as Hedging Instrument [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Interest rate risk management losses	-571	-151	-861	-307
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	-18,081	17,338	-28,114	10,502
Commodity Contract [Member] | Discontinued Operations [Member] | Not Designated as Hedging Instrument [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Commodity risk management (losses) gains	-10,968	13,155	-15,879	2,083
Commodity Contract [Member] | Forward Contracts [Member] | Not Designated as Hedging Instrument [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Commodity risk management (losses) gains	($1,416)	$1,134	($2,404)	($16)

Fair_Value_of_Financial_Instru2

Fair Value of Financial Instruments Fair Value, Assets and Liabilities Measured on a Recurring Basis (Details) (USD $)	Jun. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Assets:	'		'
Derivative Assets	$829		$14,623
Liabilities:	'		'
Derivative Liabilities	-34,701		-14,871
Fair Value, Measurements, Recurring [Member]	'		'
Assets:	'		'
Derivative Assets	84		9,430
Liabilities:	'		'
Derivative Liabilities	-22,478		-11,186
Fair Value, Measurements, Recurring [Member] | Crude Oil Contract [Member]	'		'
Assets:	'		'
Derivative Assets	0		4,435
Liabilities:	'		'
Derivative Liabilities	-14,327		-76
Fair Value, Measurements, Recurring [Member] | Natural Gas Contract [Member]	'		'
Assets:	'		'
Derivative Assets	84		4,995
Liabilities:	'		'
Derivative Liabilities	-1,286		-936
Fair Value, Measurements, Recurring [Member] | Natural Gas Liquids Contract [Member]	'		'
Assets:	'		'
Derivative Assets	0		0
Liabilities:	'		'
Derivative Liabilities	-334		1,079
Fair Value, Measurements, Recurring [Member] | Interest Rate Contract [Member]	'		'
Liabilities:	'		'
Derivative Liabilities	-6,531		-9,095
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]	'		'
Assets:	'		'
Derivative Assets	0		0
Liabilities:	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Crude Oil Contract [Member]	'		'
Assets:	'		'
Derivative Assets	0		0
Liabilities:	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural Gas Contract [Member]	'		'
Assets:	'		'
Derivative Assets	0		0
Liabilities:	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural Gas Liquids Contract [Member]	'		'
Assets:	'		'
Derivative Assets	0		0
Liabilities:	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Interest Rate Contract [Member]	'		'
Liabilities:	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'		'
Assets:	'		'
Derivative Assets	3,644		12,755
Liabilities:	'		'
Derivative Liabilities	-26,038		-14,511
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Crude Oil Contract [Member]	'		'
Assets:	'		'
Derivative Assets	1,085		6,151
Liabilities:	'		'
Derivative Liabilities	-15,412		-1,792
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural Gas Contract [Member]	'		'
Assets:	'		'
Derivative Assets	2,551		6,562
Liabilities:	'		'
Derivative Liabilities	-3,753		-2,503
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural Gas Liquids Contract [Member]	'		'
Assets:	'		'
Derivative Assets	8		42
Liabilities:	'		'
Derivative Liabilities	-342		1,121
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Interest Rate Contract [Member]	'		'
Liabilities:	'		'
Derivative Liabilities	-6,531		-9,095
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]	'		'
Assets:	'		'
Derivative Assets	0		0
Liabilities:	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Crude Oil Contract [Member]	'		'
Assets:	'		'
Derivative Assets	0		0
Liabilities:	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Contract [Member]	'		'
Assets:	'		'
Derivative Assets	0		0
Liabilities:	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Liquids Contract [Member]	'		'
Assets:	'		'
Derivative Assets	0		0
Liabilities:	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Interest Rate Contract [Member]	'		'
Liabilities:	'		'
Derivative Liabilities	0		0
Fair Value, Measurements, Recurring [Member] | Netting [Member]	'		'
Assets:	'		'
Derivative Assets	-3,560	[1]	-3,325	[1]
Liabilities:	'		'
Derivative Liabilities	3,560	[1]	3,325	[1]
Fair Value, Measurements, Recurring [Member] | Netting [Member] | Crude Oil Contract [Member]	'		'
Assets:	'		'
Derivative Assets	-1,085	[1]	-1,716	[1]
Liabilities:	'		'
Derivative Liabilities	1,085	[1]	1,716	[1]
Fair Value, Measurements, Recurring [Member] | Netting [Member] | Natural Gas Contract [Member]	'		'
Assets:	'		'
Derivative Assets	-2,467	[1]	-1,567	[1]
Liabilities:	'		'
Derivative Liabilities	2,467	[1]	1,567	[1]
Fair Value, Measurements, Recurring [Member] | Netting [Member] | Natural Gas Liquids Contract [Member]	'		'
Assets:	'		'
Derivative Assets	-8	[1]	-42	[1]
Liabilities:	'		'
Derivative Liabilities	8	[1]	-42	[1]
Fair Value, Measurements, Recurring [Member] | Netting [Member] | Interest Rate Contract [Member]	'		'
Liabilities:	'		'
Derivative Liabilities	$0	[1]	$0	[1]
[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) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014
Pipelines [Member]	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Property, Plant, and Equipment, Fair Value Disclosure	$746
Impairment of Long-Lived Assets Held-for-use	1,904
Pipelines [Member] | 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
Pipelines [Member] | 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
Pipelines [Member] | 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	746
Natural Gas Processing Plant [Member]	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Property, Plant, and Equipment, Fair Value Disclosure	52
Impairment of Long-Lived Assets Held-for-use	132
Natural Gas Processing Plant [Member] | 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
Natural Gas Processing Plant [Member] | 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
Natural Gas Processing Plant [Member] | 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	52
Use Rights [Member]	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Property, Plant, and Equipment, Fair Value Disclosure	24
Impairment of Long-Lived Assets Held-for-use	61
Use Rights [Member] | 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
Use Rights [Member] | 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
Use Rights [Member] | 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	$24

Fair_Value_of_Financial_Instru4

Fair Value of Financial Instruments Narrative (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Notes Payable, Fair Value Disclosure	$55.50	$55.70

Commitments_and_Contingencies_

Commitments and Contingencies Loss Contingencies (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Loss Contingencies [Line Items]	'	'
Accrual for Environmental Loss Contingencies	$2.40	$2.50

Commitments_and_Contingencies_1

Commitments and Contingencies Operating Leases (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Operating leases [Line Items]	'	'	'	'
Operating Leases, Rent Expense	$0.80	$0.40	$1.60	$0.90

Income_Taxes_Schedule_of_Incom

Income Taxes Schedule of Income Tax Expense (Benefit) (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Income Tax Expense (Benefit)	($885)	($544)	($1,750)	($2,105)

Equity_Based_Compensation_Shar

Equity Based Compensation Share-based Compensation Rollforward (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014
			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	2,510,221	2,743,807	2,743,807
Grants in Period	'	'	1,287,360
Vested in Period	'	'	963,392
Forfeited in Period	'	'	-557,554
Unvested Restricted Units Outstanding - Ending Balance	2,510,221	2,743,807	2,510,221
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	'	'	$9.37
Grants in Period, Weighted Average Grant Date Fair Value	'	'	$4.63
Vested in Period, Weighted Average Grant Date Fair Value	'	'	$9.60
Forfeitures in Period, Weighted Average Grant Price	'	'	$9.19
Weighted Average Grant Date Fair Value - Ending	'	'	$6.89

Equity_Based_Compensation_Narr

Equity Based Compensation Narrative (Details) (USD $)	3 Months Ended	6 Months Ended				3 Months Ended		6 Months Ended
	Mar. 31, 2014	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
				Common Units [Member]	Number of Common Units [Member]	Continuing Operations [Member]	Continuing Operations [Member]	Continuing Operations [Member]	Continuing Operations [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'	'	'	'	'	'
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	7,937,294	'	'	'	'	'	'	'	'
Equity-based compensation	'	$4,042,000	$4,705,000	'	'	$1,459,000	$2,694,000	$4,042,000	$4,705,000
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	13,400,000	'	'	'	'	'	'	'	'
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition	'1 year 10 months 1 day	'	'	'	'	'	'	'	'
Stock Repurchased During Period, Shares	'	'	'	'	253,306	'	'	'	'
Stock Repurchased During Period, Value	'	$1,084,000	'	$1,084,000	'	'	'	'	'

Earnings_Per_Unit_Schedule_of_

Earnings Per Unit Schedule of Weighted Average Number of Units(Details)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Weighted average common units outstanding - basic	156,955	155,269	156,802	150,860
Weighted average common units outstanding - Diluted	156,955	156,710	156,802	150,860
Restricted units, non-participating [Member]	'	'	'	'
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	0	285	0	0
Restricted units, participating [Member]	'	'	'	'
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	0	1,156	0	0

Earnings_Per_Unit_Calculation_

Earnings Per Unit Calculation of basic and diluted earnings per unit (Details) (USD $)	3 Months Ended			6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013	Jun. 30, 2014		Jun. 30, 2013
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'		'	'		'
Income (Loss) from Continuing Operations Attributable to Parent	($17,395)		$12,131	($25,355)		$207
Distributions	0	[1]	34,972	0	[1]	69,670
Assumed income (loss) from continuing operations after distribution to be allocated	-17,395		-22,841	-25,355		-69,463
Discontinued operations	-25,646		3,901	-36,249		-17,689
Net income (loss)	-43,041		16,032	-61,604		-17,482
Income (loss) from continuing operations per common unit - Basic	($0.11)		$0.07	($0.16)		($0.01)
Discontinued operations per common unit - Basic	($0.16)		$0.03	($0.23)		($0.12)
Net income (loss) per common unit - basic	($0.27)		$0.10	($0.39)		($0.13)
Net income (loss) per common unit - Diluted	($0.27)		$0.10	($0.39)		($0.13)
Common Units [Member]	'		'	'		'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'		'	'		'
Income (Loss) from Continuing Operations Attributable to Parent	-17,395		11,496	-25,355		-1,020
Distributions	0	[1]	34,337	0	[1]	68,443
Assumed income (loss) from continuing operations after distribution to be allocated	-17,395		-22,841	-25,355		-69,463
Discontinued operations	-25,646		3,901	-36,249		-17,689
Net income (loss)	-43,041		15,397	-61,604		-18,709
Income (loss) from continuing operations per common unit - Basic	($0.11)		$0.07	($0.16)		($0.01)
Discontinued operations per common unit - Basic	($0.16)		$0.03	($0.23)		($0.12)
Net income (loss) per common unit - basic	($0.27)		$0.10	($0.39)		($0.13)
Income (loss) from continuing operations per common unit - Diluted	($0.11)		$0.07	($0.16)		($0.01)
Discontinued operations per common unit - Diluted	($0.16)		$0.03	($0.23)		($0.12)
Net income (loss) per common unit - Diluted	($0.27)		$0.10	($0.39)		($0.13)
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	0	[2]	635	0	[2]	1,227
Distributions	0	[1],[2]	635	0	[1],[2]	1,227
Assumed income (loss) from continuing operations after distribution to be allocated	0	[2]	0	0	[2]	0
Discontinued operations	0	[2]	0	0	[2]	0
Net income (loss)	$0	[2]	$635	$0	[2]	$1,227
[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		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Assets held-for-sale	'	'	'	'	'
Accounts Receivable	$111,131	'	$111,131	'	$128,713
Property, plant and equipment	989,755	'	989,755	'	1,004,317
Intangible assets	99,830	'	99,830	'	102,352
Other current assets	750	'	750	'	5,663
Other long-term assets	9,764	'	9,764	'	18,337
Total assets held-for-sale	1,211,230	'	1,211,230	'	1,259,382
Liabilities held-for-sale	'	'	'	'	'
Disposal Group, Including Discontinued Operation, Long-term debt	494,898	'	494,898	'	494,582
Accounts payable	99,653	'	99,653	'	119,966
Other current liabilities	11,778	'	11,778	'	9,471
Other long-term liabilities	20,403	'	20,403	'	13,719
Total liabilities held-for-sale	626,732	'	626,732	'	637,738
Class of statement of operations line item of discontinued operations:	'	'	'	'	'
Revenue	245,210	253,485	548,081	470,750	'
Cost of natural gas, natural gas liquids, condensate and helium	199,700	185,760	444,673	365,748	'
Operations and maintenance	25,078	27,020	50,127	48,989	'
General and administrative	12,107	6,055	20,208	11,592	'
Depreciation, amortization and impairment	19,737	19,097	41,936	38,038	'
Interest expense	-14,118	-12,110	-27,350	-24,129	'
Other expense	-60	140	-68	140	'
Operating income (loss) from discontinued operations before taxes	-25,590	3,583	-36,281	-17,606	'
Income tax expense (benefit)	56	-318	-32	83	'
Discontinued operations	($25,646)	$3,901	($36,249)	($17,689)	'

Divestiture_Related_Activities3

Divestiture Related Activities Divestiture Related Activities - Restructuring Charges (Details) (One-time Termination Benefits [Member], USD $)	Jun. 30, 2014
In Millions, unless otherwise specified
One-time Termination Benefits [Member]	'
Restructuring Cost and Reserve [Line Items]	'
Severance Costs	$3.20

Subsidiary_Guarantors_Subsidia1

Subsidiary Guarantors Subsidiary Guarantors Condensed Consolidating Balance Sheets (Details) (USD $)	Jun. 30, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Subsidiary Guarantors [Line Items]	'		'
Accounts receivable – related parties	$0		$0
Assets held for sale	1,211,230		1,259,382
Other current assets	48,860		29,008
Property, Plant and Equipment — Net	859,895		824,451
Investment in subsidiaries	0		0
Total other long-term assets	10,780		14,709
Total assets	2,130,765		2,127,550
Accounts payable – related parties	0		0
Current portion of long-term debt	439,000		0
Liabilities held for sale	626,732		637,738
Other current liabilities	98,002		81,829
Other long-term liabilities	93,317		76,624
Long-term debt	380,712		757,480
Members' Equity	493,002	[1]	573,879	[1]
Total liabilities and equity	2,130,765		2,127,550
Parent Company [Member]	'		'
Subsidiary Guarantors [Line Items]	'		'
Accounts receivable – related parties	676,812		691,588
Assets held for sale	9,401		7,333
Other current assets	6,055		6,927
Property, Plant and Equipment — Net	1,966		2,318
Investment in subsidiaries	1,161,226		1,133,217
Total other long-term assets	1,423		11,441
Total assets	1,856,883		1,852,824
Accounts payable – related parties	0		0
Current portion of long-term debt	439,000		0
Liabilities held for sale	509,767		500,110
Other current liabilities	23,828		15,688
Other long-term liabilities	10,574		5,667
Long-term debt	380,712		757,480
Members' Equity	493,002		573,879
Total liabilities and equity	1,856,883		1,852,824
Co-issuer [Member]	'		'
Subsidiary Guarantors [Line Items]	'		'
Accounts receivable – related parties	0		0
Assets held for sale	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 assets	1		1
Accounts payable – related parties	0		0
Current portion of long-term debt	0		0
Liabilities held for sale	0		0
Other current liabilities	0		0
Other long-term liabilities	0		0
Long-term debt	0		0
Members' Equity	1		1
Total liabilities and equity	1		1
Guarantor Subsidiaries [Member]	'		'
Subsidiary Guarantors [Line Items]	'		'
Accounts receivable – related parties	0		0
Assets held for sale	1,201,829		1,252,049
Other current assets	42,804		22,080
Property, Plant and Equipment — Net	857,929		822,133
Investment in subsidiaries	0		0
Total other long-term assets	9,357		3,268
Total assets	2,111,919		2,099,530
Accounts payable – related parties	676,812		691,588
Current portion of long-term debt	0		0
Liabilities held for sale	116,965		137,628
Other current liabilities	74,174		66,141
Other long-term liabilities	82,743		70,957
Long-term debt	0		0
Members' Equity	1,161,225		1,133,216
Total liabilities and equity	2,111,919		2,099,530
Non-Guarantor Subsidiaries [Member]	'		'
Subsidiary Guarantors [Line Items]	'		'
Accounts receivable – related parties	0		0
Assets held for sale	0		0
Other current assets	0		0
Property, Plant and Equipment — Net	0		0
Investment in subsidiaries	884		908
Total other long-term assets	0		0
Total assets	884		908
Accounts payable – related parties	0		0
Current portion of long-term debt	0		0
Liabilities held for sale	0		0
Other current liabilities	0		0
Other long-term liabilities	0		0
Long-term debt	0		0
Members' Equity	884		908
Total liabilities and equity	884		908
Consolidation, Eliminations [Member]	'		'
Subsidiary Guarantors [Line Items]	'		'
Accounts receivable – related parties	-676,812		-691,588
Assets held for sale	0		0
Other current assets	0		0
Property, Plant and Equipment — Net	0		0
Investment in subsidiaries	-1,162,110		-1,134,125
Total other long-term assets	0		0
Total assets	-1,838,922		-1,825,713
Accounts payable – related parties	-676,812		-691,588
Current portion of long-term debt	0		0
Liabilities held for sale	0		0
Other current liabilities	0		0
Other long-term liabilities	0		0
Long-term debt	0		0
Members' Equity	-1,162,110		-1,134,125
Total liabilities and equity	($1,838,922)		($1,825,713)
[1]	157,354,239 and 156,644,153 common units were issued and outstanding as of June 30, 2014 and December 31, 2013, respectively. These amounts do not include unvested restricted common units granted under the Partnership's long-term incentive plan of 2,510,221 and 2,743,807 as of June 30, 2014 and December 31, 2013, respectively.

Subsidiary_Guarantors_Subsidia2

Subsidiary Guarantors Subsidiary Guarantors Condensed Consolidating Income Statement (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Subsidiary Guarantors [Line Items]	'	'	'	'
Total revenues	$34,044	$66,666	$79,247	$107,132
Operations and maintenance	10,907	9,579	22,405	21,279
Taxes other than income	3,596	3,583	7,387	5,999
General and administrative	12,005	13,341	25,295	26,651
Depreciation, depletion and amortization	20,299	22,060	40,705	43,356
Impairment	0	1,839	0	1,839
Operating income (loss)	-12,763	16,264	-16,545	8,008
Interest expense	-4,948	-4,499	-9,702	-9,564
Other non-operating income	0	0	0	0
Other (expense) income	-569	-178	-858	-342
Income (loss) before income taxes	-18,280	11,587	-27,105	-1,898
Income Tax Expense (Benefit)	-885	-544	-1,750	-2,105
Equity in earnings of subsidiaires	0	0	0	0
Income (loss) from continuing operations	-17,395	12,131	-25,355	207
Discontinued operations	-25,646	3,901	-36,249	-17,689
Net income (loss)	-43,041	16,032	-61,604	-17,482
Parent Company [Member]	'	'	'	'
Subsidiary Guarantors [Line Items]	'	'	'	'
Total revenues	-18,081	17,338	-28,114	10,502
Operations and maintenance	3	0	3	0
Taxes other than income	0	0	0	0
General and administrative	2,064	3,031	4,961	6,679
Depreciation, depletion and amortization	295	299	348	346
Impairment	'	0	'	0
Operating income (loss)	-20,443	14,008	-33,426	3,477
Interest expense	-4,946	-4,446	-9,700	-8,731
Other non-operating income	2,163	2,238	4,384	4,519
Other (expense) income	-1,987	-1,602	-3,703	-3,218
Income (loss) before income taxes	-25,213	10,198	-42,445	-3,953
Income Tax Expense (Benefit)	82	-98	-185	-673
Equity in earnings of subsidiaires	9,377	9,962	28,011	-907
Income (loss) from continuing operations	-15,918	20,258	-14,249	-4,187
Discontinued operations	-27,123	-4,226	-47,355	-13,295
Net income (loss)	-43,041	16,032	-61,604	-17,482
Co-issuer [Member]	'	'	'	'
Subsidiary Guarantors [Line Items]	'	'	'	'
Total revenues	0	0	0	0
Operations and maintenance	0	0	0	0
Taxes other than income	0	0	0	0
General and administrative	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Impairment	'	0	'	0
Operating income (loss)	0	0	0	0
Interest expense	0	0	0	0
Other non-operating income	0	0	0	0
Other (expense) income	0	0	0	0
Income (loss) before income taxes	0	0	0	0
Income Tax Expense (Benefit)	0	0	0	0
Equity in earnings of subsidiaires	0	0	0	0
Income (loss) from continuing operations	0	0	0	0
Discontinued operations	'	0	0	0
Net income (loss)	0	0	0	0
Guarantor Subsidiaries [Member]	'	'	'	'
Subsidiary Guarantors [Line Items]	'	'	'	'
Total revenues	52,125	49,328	107,361	96,630
Operations and maintenance	10,904	9,579	22,402	21,279
Taxes other than income	3,596	3,583	7,387	5,999
General and administrative	9,941	10,310	20,334	19,972
Depreciation, depletion and amortization	20,004	21,761	40,357	43,010
Impairment	'	1,839	'	1,839
Operating income (loss)	7,680	2,256	16,881	4,531
Interest expense	-2	-53	-2	-833
Other non-operating income	2,291	2,325	4,592	4,659
Other (expense) income	-3,036	-3,139	-6,131	-6,302
Income (loss) before income taxes	6,933	1,389	15,340	2,055
Income Tax Expense (Benefit)	-967	-446	-1,565	-1,432
Equity in earnings of subsidiaires	0	0	0	0
Income (loss) from continuing operations	7,900	1,835	16,905	3,487
Discontinued operations	1,479	8,128	11,115	-4,388
Net income (loss)	9,379	9,963	28,020	-901
Non-Guarantor Subsidiaries [Member]	'	'	'	'
Subsidiary Guarantors [Line Items]	'	'	'	'
Total revenues	0	0	0	0
Operations and maintenance	0	0	0	0
Taxes other than income	0	0	0	0
General and administrative	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Impairment	'	0	'	0
Operating income (loss)	0	0	0	0
Interest expense	0	0	0	0
Other non-operating income	0	0	0	0
Other (expense) income	0	0	0	0
Income (loss) before income taxes	0	0	0	0
Income Tax Expense (Benefit)	0	0	0	0
Equity in earnings of subsidiaires	0	0	0	0
Income (loss) from continuing operations	0	0	0	0
Discontinued operations	-2	-1	-9	-6
Net income (loss)	-2	-1	-9	-6
Consolidation, Eliminations [Member]	'	'	'	'
Subsidiary Guarantors [Line Items]	'	'	'	'
Total revenues	0	0	0	0
Operations and maintenance	0	0	0	0
Taxes other than income	0	0	0	0
General and administrative	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Impairment	'	0	'	0
Operating income (loss)	0	0	0	0
Interest expense	0	0	0	0
Other non-operating income	-4,454	-4,563	-8,976	-9,178
Other (expense) income	4,454	4,563	8,976	9,178
Income (loss) before income taxes	0	0	0	0
Income Tax Expense (Benefit)	0	0	0	0
Equity in earnings of subsidiaires	-9,377	-9,962	-28,011	907
Income (loss) from continuing operations	-9,377	-9,962	-28,011	907
Discontinued operations	0	0	0	0
Net income (loss)	($9,377)	($9,962)	($28,011)	$907

Subsidiary_Guarantors_Subsidia3

Subsidiary Guarantors Subsidiary Guarantor Condensed Consolidating Statements of Cash Flows (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Subsidiary Guarantors [Line Items]	'	'
Net cash flows provided by operating activities	$25,674	$57,084
Additions to property, plant and equipment	-63,789	-83,395
Net cash provided by (used in) investing activities	-63,789	-83,395
Proceeds from long-term debt	315,150	316,700
Repayment of long-term debt	-252,950	-312,200
Payment of debt issuance costs	410	0
Proceeds from derivative contracts	-3,425	877
Common unit issuance	0	102,388
Payments of Unit Issuance Costs	0	-4,181
Payments for repurchase of common units	1,084	1,000
Distributions to members and affiliates	-23,801	-67,117
Net cash provided by (used in) financing activities	33,480	35,467
Net Cash Provided by (Used in) Discontinued Operations	5,300	-9,086
Net increase in cash and cash equivalents	665	70
CASH AND CASH EQUIVALENTS—Beginning of period	76	25
CASH AND CASH EQUIVALENTS—End of period	741	95
Parent Company [Member]	'	'
Subsidiary Guarantors [Line Items]	'	'
Net cash flows provided by operating activities	2,594	-31,423
Additions to property, plant and equipment	4	-855
Net cash provided by (used in) investing activities	4	-855
Proceeds from long-term debt	315,150	316,700
Repayment of long-term debt	-252,950	-312,200
Payment of debt issuance costs	410	'
Proceeds from derivative contracts	-3,425	877
Common unit issuance	'	102,388
Payments of Unit Issuance Costs	'	-4,181
Payments for repurchase of common units	1,084	1,000
Distributions to members and affiliates	-23,801	-67,117
Net cash provided by (used in) financing activities	33,480	35,467
Net Cash Provided by (Used in) Discontinued Operations	-34,973	-3,660
Net increase in cash and cash equivalents	1,105	-471
CASH AND CASH EQUIVALENTS—Beginning of period	1,237	1,670
CASH AND CASH EQUIVALENTS—End of period	2,342	1,199
Co-issuer [Member]	'	'
Subsidiary Guarantors [Line Items]	'	'
Net cash flows provided by operating activities	0	0
Additions to property, plant and equipment	0	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
Common unit issuance	'	0
Payments of Unit Issuance Costs	'	0
Payments for repurchase of common units	0	0
Distributions to members and affiliates	0	0
Net cash provided by (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	23,080	88,507
Additions to property, plant and equipment	-63,793	-82,540
Net cash provided by (used in) investing activities	-63,793	-82,540
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
Common unit issuance	'	0
Payments of Unit Issuance Costs	'	0
Payments for repurchase of common units	0	0
Distributions to members and affiliates	0	0
Net cash provided by (used in) financing activities	0	0
Net Cash Provided by (Used in) Discontinued Operations	40,251	-5,447
Net increase in cash and cash equivalents	-462	520
CASH AND CASH EQUIVALENTS—Beginning of period	-1,389	-1,832
CASH AND CASH EQUIVALENTS—End of period	-1,851	-1,312
Non-Guarantor Subsidiaries [Member]	'	'
Subsidiary Guarantors [Line Items]	'	'
Net cash flows provided by operating activities	0	0
Additions to property, plant and equipment	0	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
Common unit issuance	'	0
Payments of Unit Issuance Costs	'	0
Payments for repurchase of common units	0	0
Distributions to members and affiliates	0	0
Net cash provided by (used in) financing activities	0	0
Net Cash Provided by (Used in) Discontinued Operations	22	21
Net increase in cash and cash equivalents	22	21
CASH AND CASH EQUIVALENTS—Beginning of period	227	186
CASH AND CASH EQUIVALENTS—End of period	249	207
Consolidation, Eliminations [Member]	'	'
Subsidiary Guarantors [Line Items]	'	'
Net cash flows provided by operating activities	0	0
Additions to property, plant and equipment	0	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
Common unit issuance	'	0
Payments of Unit Issuance Costs	'	0
Payments for repurchase of common units	0	0
Distributions to members and affiliates	0	0
Net cash provided by (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

Subsequent_Events_Narrative_De

Subsequent Events Narrative (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jul. 01, 2014
In Thousands, unless otherwise specified			Scenario, Forecast [Member]
8 3/8% senior notes due 2019	$51,120	$51,120	$51,100