Resources Connection 10-Q 7 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document	9 Months Ended
	Sep. 30, 2013	Nov. 01, 2013
Entity Information	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Sep-13	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'
Trading Symbol	'RGP	'
Entity Registrant Name	'Regency Energy Partners LP	'
Entity Central Index Key	'0001338613	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	210,714,852

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Current Assets:	'	'
Cash and cash equivalents	$12	$53
Trade accounts receivable, net	60	115
Accrued revenues	214	107
Related party receivables	18	8
Other current assets	63	57
Total current assets	367	340
Property, plant and equipment:	'	'
Property, plant and equipment	4,812	4,086
Less accumulated depreciation	-570	-400
Property, plant and equipment, net	4,242	3,686
Other Assets:	'	'
Investment in unconsolidated affiliates	2,081	2,214
Other, net of accumulated amortization of debt issuance costs of $22 and $17	58	43
Total other assets	2,139	2,257
Intangible assets, net of accumulated amortization of $99 and $77	690	712
Goodwill	1,128	1,128
TOTAL ASSETS	8,566	8,123
Current Liabilities:	'	'
Drafts payable	17	10
Trade accounts payable	134	122
Accrued cost of gas and liquids	163	133
Related party payables	57	95
Accrued interest	52	30
Other current liabilities	45	82
Deferred revenues	15	17
Total current liabilities	483	489
Long-term derivative liabilities	23	25
Other long-term liabilities	38	39
Long-term debt, net	2,976	2,157
Commitments and contingencies	'	'
Series A preferred units, redemption amounts of $37 and $85	32	73
Partners’ capital and noncontrolling interest:	'	'
Common units	3,990	3,207
Common Stock, Other Value, Outstanding	145	0
General partner interest	783	326
Predecessor equity	0	1,733
Accumulated other comprehensive loss	0	-3
Total partners’ capital	4,918	5,263
Noncontrolling interest	96	77
Total partners’ capital and noncontrolling interest	5,014	5,340
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	8,566	8,123
Class F Units [Member]	'	'
Partners’ capital and noncontrolling interest:	'	'
Total partners’ capital and noncontrolling interest	$145	$0

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets Balance Sheet (Paranthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Paranthetical [Abstract]	'	'
Other, accumulated amortization of debt issuance costs	$22	$17
Intangible assets, net of accumulated amortization	99	77
Series A preferred units, redemption amount	$37	$85

Condensed_Consolidated_Stateme

Condensed Consolidated Statements Of Operations (USD $)	3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
REVENUES	'	'	'	'
Gas sales, including related party amounts of $22, $14, $56 and $29	$213	$141	$600	$330
NGL sales, including related party amounts of $11, $—, $23 and $24	286	267	766	709
Gathering, transportation and other fees, including related party amounts of $6, $9, $20 and $23	147	101	405	297
Net realized and unrealized (loss) gain from derivatives	-10	1	0	20
Other	29	17	73	57
Total revenues	665	527	1,844	1,413
OPERATING COSTS AND EXPENSES	'	'	'	'
Cost of sales, including related party amounts of $8, $12, $35 and $25	477	369	1,309	959
Operation and maintenance, including related party amounts of $—, $2, $— and $21	78	61	220	159
General and administrative, including related party amounts of $2, $4, $9 and $13	13	21	64	78
(Gain) loss on asset sales, net	-1	0	1	2
Depreciation and amortization	74	71	207	193
Total operating costs and expenses	641	522	1,801	1,391
OPERATING INCOME	24	5	43	22
Income from unconsolidated affiliates	37	21	103	87
Interest expense, net	-41	-29	-119	-86
Loss on debt refinancing, net	0	0	-7	-8
Other income and deductions, net	24	1	3	26
INCOME (LOSS) BEFORE INCOME TAXES	44	-2	23	41
Income tax expense (benefit)	2	-1	-1	-1
NET INCOME (LOSS)	42	-1	24	42
Net income attributable to noncontrolling interest	-3	-1	-4	-2
NET INCOME (LOSS) ATTRIBUTABLE TO REGENCY ENERGY PARTNERS LP	39	-2	20	40
Amounts attributable to Series A preferred units	1	2	5	7
General partner’s interest, including IDRs	3	2	8	7
Beneficial conversion feature for Class F Units	2	0	3	0
Pre-acquisition Income from SUGS Allocated to Predecessor Equity	0	0	-36	-15
Limited partners’ interest in net income (loss)	33	-6	40	41
Basic and diluted net income (loss) per common unit:	'	'	'	'
Weighted average number of common units outstanding	209,559,854	170,264,621	191,334,032	166,368,178
Basic income (loss) per common unit	0.16	-0.04	0.21	0.25
Diluted income (loss) per common unit	0.05	-0.04	0.21	0.22
Distributions per common unit	$0.47	$0.46	$1.40	$1.38
Amount allocated to Class F units due to beneficial conversion feature	2	0	3	0
Income per Class F unit due to beneficial conversion feature	$0.27	$0	$0.45	$0
Class F Units [Member]	'	'	'	'
OPERATING COSTS AND EXPENSES	'	'	'	'
NET INCOME (LOSS)	'	'	$3	'
Basic and diluted net income (loss) per common unit:	'	'	'	'
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	6,274,483	0	6,274,483	0

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements Of Operations Statements of Operations (Paranthetical) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Paranthetical [Abstract]	'	'	'	'
Natural Gas Midstream Revenue	$22	$14	$56	$29
NGL sales, related party amounts	11	0	23	24
Gas Gathering, Transportation, Marketing and Processing Revenue	6	9	20	23
Other Revenue, Net	0	0	0	1
Cost of sales, related party amounts	8	12	35	25
Operating and Maintenance, related party amounts	0	2	0	21
General and administrative, related party amounts	$2	$4	$9	$13

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements Of Comprehensive Income (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Net income (loss)	$42	($1)	$24	$42
Other comprehensive income (loss):	'	'	'	'
Net cash flow hedge amounts reclassified to earnings	0	-6	0	-6
Change in fair value of cash flow hedges	0	-6	0	5
Total other comprehensive loss	0	-12	0	-1
Comprehensive income (loss)	42	-13	24	41
Comprehensive income attributable to noncontrolling interest	3	1	4	2
Comprehensive income (loss) attributable to Regency Energy Partners LP	$39	($14)	$20	$39

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements Of Cash Flows (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
OPERATING ACTIVITIES:	'	'
Net income (loss)	$24	$42
Reconciliation of net income to net cash flows provided by operating activities:	'	'
Depreciation and amortization, including debt issuance cost amortization and bond premium write-off and amortization	211	197
Income from unconsolidated affiliates	-103	-87
Derivative valuation changes	3	-11
Loss on asset sales, net	1	2
Unit-based compensation expenses	5	3
Cash flow changes in current assets and liabilities:	'	'
Trade accounts receivable, accrued revenues and related party receivables	-73	9
Other current assets and other current liabilities	-26	53
Trade accounts payable, accrued cost of gas and liquids, related party payables and deferred revenues	103	-33
Distributions of earnings received from unconsolidated affiliates	108	92
Cash flow changes in other assets and liabilities	128	-11
Net cash flows provided by operating activities	381	256
INVESTING ACTIVITIES:	'	'
Capital expenditures	-762	-380
Capital contributions to unconsolidated affiliates	-125	-273
Distributions in excess of earnings of unconsolidated affiliates	232	50
Payments to Acquire Businesses, Net of Cash Acquired	-463	0
Proceeds from asset sales	13	22
Net cash flows used in investing activities	-1,105	-581
FINANCING ACTIVITIES:	'	'
Borrowings (repayments) under revolving credit facility, net	-15	363
Proceeds from issuances of senior notes	1,000	0
Redemptions of senior notes	-163	-88
Debt issuance costs	-24	-1
Drafts payable	8	-6
Partner distributions and distributions on unvested unit awards	-282	-240
Common unit offering, net of issuance costs	0	297
Common units issued under equity distribution program, net of costs	149	15
Distributions to Series A preferred units	-5	-6
Contributions from noncontrolling interest	15	24
Contribution of Net Investment to the Partnership	0	2
Net cash flows provided by financing activities	683	360
Net change in cash and cash equivalents	-41	35
Cash and cash equivalents at beginning of period	53	1
Cash and cash equivalents at end of period	12	'
Supplemental cash flow information:	'	'
Accrued capital expenditures	70	29
Accrued capital contribution to unconsolidated affiliate	0	13
Issuance of Class F and common units in connection with SUGS acquisition	$961	$0

Condensed_Consolidated_Stateme4

Condensed Consolidated Statement of Partners' Capital and Noncontrolling Interest (USD $)	Total	Class F Units [Member]	Common Units [Member]	General Partner Interest	Predecessor Equity [Member]	Accumulated Other Comprehensive Loss	Noncontrolling Interest
In Millions
Balance at Dec. 31, 2012	$5,340	$0	$3,207	$326	$1,733	($3)	$77
Contribution of net investment to the Partnership	0	0	0	1,925	-1,928	3	0
Issuance of common units in connection with the SUGS Acquisition, net of costs	0	0	819	-819	0	0	0
Issuance of Class F common units in connection with the SUGS Acquisition, net of costs	0	142	0	-142	0	0	0
Contribution of assets between entities under common control below historical cost	-273	0	0	-504	231	0	0
Common units issued under equity distribution program, net of costs	149	0	149	0	0	0	0
Conversion of Stock, Amount Converted	41	0	41	0	0	0	0
Unit-based compensation expenses	5	0	5	0	0	0	0
Partner distributions	-280	0	269	11	0	0	0
Distributions on unvested unit awards	-2	0	-2	0	0	0	0
Contributions from noncontrolling interest	15	0	0	0	0	0	15
Net income (loss)	24	3	45	8	-36	0	4
Distributions to Series A Preferred Units	-5	0	-5	0	0	0	0
Balance at Sep. 30, 2013	$5,014	$145	$3,990	$783	$0	$0	$96

Organization_And_Summary_Of_Si

Organization And Summary Of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2013
Organization And Summary Of Significant Accounting Policies	'
Organization And Summary Of Significant Accounting Policies	'
	Organization and Summary of Significant Accounting Policies
	Organization. The unaudited condensed consolidated financial statements presented herein contain the results of Regency Energy Partners LP and its subsidiaries (the “Partnership”), a Delaware limited partnership. The Partnership and its subsidiaries are engaged in the business of gathering and processing, compression, treating and transportation of natural gas and the transportation, fractionation and storage of NGLs. Regency GP LP is the Partnership’s general partner and Regency GP LLC (collectively the “General Partner”) is the managing general partner of the Partnership and the general partner of Regency GP LP.
	SUGS Acquisition. On April 30, 2013, the Partnership and Regency Western acquired SUGS from Southern Union, a wholly owned subsidiary of Holdco, for $1.5 billion (the “SUGS Acquisition”). The Partnership financed the acquisition by issuing to Southern Union 31,372,419 Partnership common units and 6,274,483 recently created Class F common units. The Class F common units are not entitled to participate in the Partnership’s distributions for twenty-four months post-transaction closing. The remaining $600 million, less $107 million of closing adjustments, was paid in cash. In addition, ETE has agreed to forgo IDR payments on the Partnership common units issued with this transaction for twenty-four months post-transaction closing and to suspend a $10 million annual management fee paid by the Partnership for two years post-transaction close.
	The common units and Class F common units related to the SUGS Acquisition were issued in a private placement conducted in accordance with the exemption from registration requirements of the Securities Act of 1933, as amended, under Section 4(a)(2) thereof. The Class F common units will convert into common units on a one-for-one basis in May 2015.
	The cash portion of the SUGS Acquisition was funded from the proceeds of senior notes issued by the Partnership on April 30, 2013 in a private placement. PEPL Holdings provided a guarantee of collection with respect to the payment of the principal amounts of the senior notes issued by the Partnership.
	The Partnership accounted for the acquisition in a manner similar to the pooling of interest method of accounting as it was a transaction between commonly controlled entities. Under this method of accounting, the Partnership reflected historical balance sheet data for the Partnership and SUGS instead of reflecting the fair market value of SUGS assets and liabilities from the date of acquisition forward. The Partnership retrospectively adjusted its financial statements to include the balances and operations of SUGS from March 26, 2012 (the date upon which common control began). The SUGS Acquisition does not impact historical earnings per unit as pre-acquisition earnings were allocated to predecessor equity.
	The following table presents the revenues and net income for the previously separate entities and the combined amounts presented herein:
		Three Months Ended September 30,					Nine Months Ended September 30,
		2013		2012			2013 (1)			2012
	Revenues:
	Partnership	$	665	$	313		$	1,576		$	983
	SUGS	—		214			268			430
	Combined	$	665	$	527		$	1,844		$	1,413
	Net income (loss):
	Partnership	$	42	$	(1	)	$	60		$	57
	SUGS	—		—			(36		)	(15		)
	Combined	$	42	$	(1	)	$	24		$	42
	(1)	The SUGS Acquisition closed on April 30, 2013. Therefore, amounts attributable to SUGS only include four months of activity for the nine months ended September 30, 2013.
	PVR Acquisition. On October 10, 2013, the Partnership announced that it entered into a merger agreement with PVR (“PVR Acquisition”) pursuant to which, the Partnership intends to propose to acquire PVR. This acquisition will be a unit-for-unit transaction plus a one-time $40 million cash payment to PVR unitholders which represented total consideration of $5.6 billion, including the assumption of net debt of $1.8 billion. The holders of PVR common units, PVR Class B Units and PVR Special Units (“PVR Unit(s)”) will receive 1.02 Partnership common units in exchange for each PVR Unit held on the applicable record date. The transaction is subject to the approval of PVR’s unitholders, Hart-Scott-Rodino Antitrust Improvements Act and other customary closing conditions.
	The PVR Acquisition will enhance the Partnership’s geographic diversity with a strategic presence in the Marcellus and Utica shales in the Appalachian Basin and the Granite Wash shale in the Mid-Continent region.
	Basis of Presentation. The unaudited financial information included in this Form 10-Q has been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2012. In the opinion of the Partnership’s management, such financial information reflects all adjustments necessary for a fair presentation of the financial position and the results of operations for such interim periods in accordance with GAAP. All inter-company items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.
	Use of Estimates. The unaudited condensed consolidated financial statements have been prepared in conformity with GAAP, which includes the use of estimates and assumptions made by management that affect the reported amounts of assets, liabilities, revenues, expenses and disclosure of contingent assets and liabilities that exist at the date of the condensed consolidated financial statements. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could be different from those estimates.
	Derivative Financial Instruments. Derivative transactions are recognized in the accompanying consolidated balance sheet at their fair value. On the date the derivative contract is entered into, SUGS designated the derivative as a hedge of a forecasted transaction or the variability of cash flows to be received or paid in conjunction with a recognized asset or liability (a cash flow hedge). The effective portion of changes in fair value is recorded in accumulated other comprehensive income (loss) in the consolidated balance sheet until the related hedge items impact earnings. Any ineffective portion of a cash flow hedge is reported in current period earnings. Fair value is determined based upon quoted market prices and pricing models using assumptions that market participants would use. All outstanding SUGS derivative transactions as of April 30, 2013 were terminated upon acquisition by the Partnership.
	Asset Retirement Obligations. Legal obligations associated with the retirement of long-lived assets are recorded at fair value at the time the obligations are incurred, if a reasonable estimate of fair value can be made. Present value techniques are used which reflect assumptions such as removal and remediation costs, inflation,  and profit margins that third parties would demand to settle the amount of the future obligation. The Partnership does not include a market risk premium for unforeseeable circumstances in its fair value estimates because such a premium cannot be reliably estimated. Upon initial recognition of the liability, costs are capitalized as a part of the long-lived asset and allocated to expense over the useful life of the related asset. The liability is accreted to its present value each period with accretion being recorded to operating expense with a corresponding increase in the carrying amount of the liability. The ARO assets and liabilities as of September 30, 2013 and December 31, 2012 were $5 million.
	Environmental. The Partnership’s operations are subject to federal, state and local laws and rules and regulations regarding water quality, hazardous and solid waste management, air quality control and other environmental matters. These laws, rules and regulations require the Partnership to conduct its operations in a specified manner and to obtain and comply with a wide variety of environmental registrations, licenses, permits, inspections and other approvals. Failure to comply with applicable environmental laws, rules and regulations may expose the Partnership to significant fines, penalties and/or interruptions in its operations. The Partnership’s environmental policies and procedures are designed to achieve compliance with such applicable laws and regulations. These evolving laws and regulations and claims for damages to property, employees, other persons and the environment resulting from current or past operations may result in significant expenditures and liabilities in the future.
	Income Taxes. The Partnership is generally not subject to income taxes, except as discussed below, because its income is taxed directly to its partners. The Partnership is subject to the gross margins tax enacted by the state of Texas. The Partnership has two wholly-owned subsidiaries that are subject to income tax and provides for deferred income taxes using the asset and liability method. Accordingly, deferred taxes are recorded for differences between the tax and book basis that will reverse in future periods. The Partnership’s deferred tax liabilities of $21 million and $23 million as of September 30, 2013 and December 31, 2012, respectively, relate to the difference between the book and tax basis of property, plant and equipment and intangible assets and is included in other long-term liabilities in the accompanying consolidated balance sheets. The Partnership follows the guidance for uncertainties in income taxes where a liability for an unrecognized tax benefit is recorded for a tax position that does not meet the “more likely than not” criteria. The Partnership has not recorded any uncertain tax positions meeting the more likely than not criteria as of September 30, 2013 and December 31, 2012. The Partnership also recognized deferred income tax benefit of $5 million offset by a $4 million state deferred tax expense for the nine months ended September 30, 2013.
	Although the SUGS operations were included in the Southern Union consolidated federal income tax return prior to the SUGS Acquisition, following their acquisition by the Partnership, their operations are now treated as a partnership. Therefore, other than one wholly-owned subsidiary, the historical operations exclude income taxes for all periods presented.
	Effective with the Partnership’s acquisition of SUGS on April 30, 2013, SUGS is generally no longer subject to federal income taxes and subject only to gross margins tax in the state of Texas. Substantially all previously recorded current and deferred tax liabilities were settled with Southern Union, along with all other intercompany receivables and payables at the date of acquisition.

Partners_Capital_and_Distribut

Partners' Capital and Distributions (Notes)	9 Months Ended
	Sep. 30, 2013
Partners’ Capital and Distributions [Abstract]	'
Partners' Capital Notes Disclosure [Text Block]	'
	Partners’ Capital and Distributions
	Predecessor equity included on the condensed consolidated statement of partners’ capital and noncontrolling interest represents SUGS Member’s capital prior to the acquisition date (April 30, 2013).
	Beneficial Conversion Feature. The Partnership issued 6,274,483 Class F common units in connection with the SUGS Acquisition. At the commitment date (February 27, 2013), the sales price of $23.91 per unit represented a $2.19 discount from the fair value of the Partnership’s common units as of April 30, 2013. Under FASB ASC 470-20, “Debt with Conversion and Other Options,” the discount represents a beneficial conversion feature that is treated as a non-cash distribution for purposes of calculating earnings per unit. The beneficial conversion feature is reflected in income per unit using the effective yield method over the period the Class F common units are outstanding, as indicated on the statement of operations in the line item entitled “beneficial conversion feature for Class F common units.” The Class F common units are convertible to common units on a one-for-one basis on May 8, 2015.
	Units Activity. The change in common and Class F units during the nine months ended September 30, 2013 was as follows:
		Common			Class F
	Balance - December 31, 2012	170,951,457			—
	Issuance of common units under LTIP, net of forfeitures and tax withholding	35,615			—
	Issuance of common units under the Equity Distribution Agreement	5,712,138			—
	Issuance of common units in exchange for conversion of Series A preferred units	2,629,223			—
	Issuance of common units and Class F common units in connection with SUGS Acquisition	31,372,419		(1)	6,274,483	(2)
	Balance - September 30, 2013	210,700,852			6,274,483
	(1)	ETE has agreed to forgo IDR payments on the Partnership common units issued with the SUGS Acquisition for twenty-four months post-transaction closing.
	(2)	The Class F common units are not entitled to participate in the Partnership’s distributions or earnings for twenty-four months post-transaction closing.
	Equity Distribution Agreement. During the nine months ended September 30, 2013, the Partnership received net proceeds of $149 million from units issued pursuant to an Equity Distribution Agreement with Citi, which were used for general partnership purposes. As of September 30, 2013, $34 million remains available to be issued under this agreement.
	Quarterly Distributions of Available Cash. Following are distributions declared by the Partnership subsequent to December 31, 2012:
	Quarter Ended		Record Date		Payment Date	Cash Distributions
						(per common unit)
	December 31, 2012		February 7, 2013		February 14, 2013	$0.46
	March 31, 2013		May 6, 2013		May 13, 2013	$0.46
	June 30, 2013		August 5, 2013		August 14, 2013	$0.47
	September 30, 2013		November 4, 2013		November 14, 2013	$0.47

Income_Loss_Per_Limited_Partne

Income (Loss) Per Limited Partner Unit	9 Months Ended
	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Income (Loss) Per Limited Partner Unit	'
	Income (Loss) per Common Unit
	The following tables provide a reconciliation of the numerator and denominator of the basic and diluted earnings per common unit computations for the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30,
		2013							2012
		Income				Units	Per-Unit		Income			Units	Per-Unit
		(Numerator)				(Denominator)	Amount		(Numerator)			(Denominator)	Amount
	Basic income (loss) per unit
	Amounts allocated to common units	$	33			209,559,854	$	0.16	$	(6	)	170,264,621	$	(0.04	)
	Effect of Dilutive Securities:
	Common unit options	—				32,489			—			—
	Phantom units *	—				435,606			—			—
	Series A preferred units	(23		)		2,047,571			—			—
	Diluted income (loss) per unit	$	10			212,075,520	$	0.05	$	(6	)	170,264,621	$	(0.04	)
		Nine Months Ended September 30,
		2013							2012
		Income				Units	Per-Unit		Income			Units	Per-Unit
		(Numerator)				(Denominator)	Amount		(Numerator)			(Denominator)	Amount
	Basic income per unit
	Amounts allocated to common units	$	40			191,334,032	$	0.21	$	41		166,368,178	$	0.25
	Effect of Dilutive Securities:
	Common unit options	—				23,931			—			13,113
	Phantom units *	—				351,811			—			320,452
	Series A preferred units	—				—			(3		)	4,651,884
	Diluted income per unit	$	40			191,709,774	$	0.21	$	38		171,353,627	$	0.22
	*	Amount assumes maximum conversion rate for market condition awards.
	The following data show securities that could potentially dilute earnings per unit in the future that were not included in the computation of diluted earnings per unit because to do so would have been antidilutive for the periods presented:
		Nine Months Ended September 30, 2013			Three Months Ended September 30, 2012
	Common unit options	—			9,147
	Phantom units	—			313,378
	Series A preferred units	2,047,571			4,651,884

Investment_In_Unconsolidated_A

Investment In Unconsolidated Affiliates	9 Months Ended
	Sep. 30, 2013
Investment In Unconsolidated Subsidiaries [Abstract]	'
Investment In Unconsolidated Affiliates	'
	Investment in Unconsolidated Affiliates
	As of September 30, 2013, the Partnership has a 49.99% general partner interest in HPC, a 50% membership interest in MEP, a 30% membership interest in Lone Star, a 33.33% membership interest in Ranch JV, and a 50% interest in Grey Ranch. The carrying value of the Partnership’s investment in each of the unconsolidated affiliates as of September 30, 2013 and December 31, 2012 is as follows:
		September 30, 2013			December 31, 2012
	HPC	$	448		$	650
	MEP	556			581
	Lone Star	1,040			948
	Ranch JV	36			35
	Grey Ranch	1			—
		$	2,081		$	2,214
	The following tables summarize the Partnership’s investment activities in each of the unconsolidated affiliates for the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30, 2013
		HPC (1)			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	51		$	1
	Distributions from unconsolidated affiliates	(196		)	(18		)	(16		)	(1		)
	Share of earnings of unconsolidated affiliates’ net income	9			11			18			—
	Amortization of excess fair value of investment	(1		)	—			—			—
		Three Months Ended September 30, 2012
		HPC			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	78		$	10
	Distributions from unconsolidated affiliates	(16		)	(18		)	(21		)	—
	Share of earnings of unconsolidated affiliates’ net income	3			10			9			—
	Amortization of excess fair value of investment	(1		)	—			—			—
		Nine Months Ended September 30, 2013
		HPC (1)			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	100		$	2
	Distributions from unconsolidated affiliates	(226		)	(56		)	(56		)	(1		)
	Share of earnings of unconsolidated affiliates’ net income	28			31			48			—
	Amortization of excess fair value of investment	(4		)	—			—			—
		Nine Months Ended September 30, 2012
		HPC			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	253		$	33
	Distributions from unconsolidated affiliates	(46		)	(56		)	(39		)	—
	Share of earnings of unconsolidated affiliates’ net income	28			31			32			—
	Amortization of excess fair value of investment	(4		)	—			—			—
	(1) The Partnership received a non-recurring return of capital of $185 million from HPC in September 2013. HPC entered into a $500 million 5-year revolving credit facility in September 2013. Concurrent with the closing of this facility, HPC borrowed $370 million to fund a non-recurring return of capital to the partners. The Partnership pledged its 49.99% equity interest in Regency Intrastate Gas LP. The amounts outstanding under this facility was $445 million as of September 30, 2013. The Partnership’s contingent obligations with respect to the outstanding borrowings under this facility was $222 million at September 30, 2013.
	The following tables present selected income statement data for each of the unconsolidated affiliates, on a 100% basis, for the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	38		$	66		$	537		$	4
	Operating income	19			34			61			1
	Net income	18			21			61			1
		Three Months Ended September 30, 2012
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	42		$	65		$	165		$	—
	Operating income (loss)	21			33			31			(1		)
	Net income (loss)	6			21			31			(1		)
		Nine Months Ended September 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	116		$	194		$	1,320		$	10
	Operating income	58			101			162			2
	Net income	56			63			160			2
		Nine Months Ended September 30, 2012
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	130		$	196		$	490		$	—
	Operating income (loss)	71			101			110			(1		)
	Net income (loss)	55			63			110			(1		)

Derivative_Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2013
Derivative Instruments [Abstract]	'
Derivative Instruments	'
	Derivative Instruments
	Policies. The Partnership established comprehensive risk management policies and procedures to monitor and manage the market risks associated with commodity prices, counterparty credit and interest rates. The General Partner is responsible for delegation of transaction authority levels, and the Audit and Risk Committee of the General Partner is responsible for the overall management of these risks, including monitoring exposure limits. The Audit and Risk Committee receives regular briefings on exposures and overall risk management in the context of market activities.
	Commodity Price Risk. The Partnership is a net seller of NGLs, condensate and natural gas as a result of its gathering and processing operations. The prices of these commodities are impacted by changes in supply and demand as well as market forces. Both the Partnership’s profitability and cash flow are affected by the inherent volatility of these commodities which could adversely affect its ability to make distributions to its unitholders. The Partnership manages this commodity price exposure through an integrated strategy that includes management of its contract portfolio, matching sales prices of commodities with purchases, optimization of its portfolio by monitoring basis and other price differentials in operating areas, and the use of derivative contracts. In some cases, the Partnership may not be able to match pricing terms or cover its risk to price exposure with financial hedges, and it may be exposed to commodity price risk. Speculative positions with derivative contracts are prohibited under the Partnership’s policies.
	The Partnership has swap contracts that settle against certain NGLs, condensate and natural gas market prices. On January 1, 2012, the Partnership de-designated its swap contracts and began accounting for these contracts using the mark-to-market method of accounting. As of December 31, 2012, SUGS had outstanding receive-fixed natural gas price swaps that were accounted for as cash flow hedges, with the effective portion of changes in their fair value recorded in AOCI and reclassified into revenues in the same periods during which the forecasted natural gas sales impact earnings. As of April 30, 2013, in connection with the SUGS Acquisition, these outstanding hedges were terminated.
	Interest Rate Risk. The Partnership is exposed to variable interest rate risk as a result of borrowings under its revolving credit facility. As of September 30, 2013, the Partnership had $176 million of outstanding borrowings exposed to variable interest rate risk.
	Credit Risk. The Partnership’s resale of NGLs, condensate and natural gas exposes it to credit risk, as the margin on any sale is generally a very small percentage of the total sales price. Therefore, a credit loss can be very large relative to overall profitability on these transactions. The Partnership attempts to ensure that it issues credit only to credit-worthy counterparties and that in appropriate circumstances any such extension of credit is backed by adequate collateral, such as a letter of credit or parental guarantee from a parent company with potentially better credit.
	The Partnership is exposed to credit risk from its derivative contract counterparties. The Partnership does not require collateral from these counterparties. The Partnership deals primarily with financial institutions when entering into financial derivatives, and utilizes master netting agreements that allow for netting of swap contract receivables and payables in the event of default by either party. If the Partnership’s counterparties failed to perform under existing swap contracts, the Partnership’s maximum loss as of September 30, 2013 would be $7 million, which would be reduced by $2 million, due to the netting features. The Partnership has elected to present assets and liabilities under master netting agreements gross on the condensed consolidated balance sheets.
	Embedded Derivatives. The Series A preferred units contain embedded derivatives which are required to be bifurcated and accounted for separately, such as the holders’ conversion option and the Partnership’s call option. These embedded derivatives are accounted for using mark-to-market accounting. The Partnership does not expect the embedded derivatives to affect its cash flows.
	The Partnership’s derivative assets and liabilities, including credit risk adjustments, as of September 30, 2013 and December 31, 2012 are detailed below:
		Assets						Liabilities
		September 30, 2013			December 31, 2012			September 30, 2013		December 31, 2012
	Derivatives designated as cash flow hedges:
	Current amounts
	Commodity contracts	$	—		$	—		$	—	$	5
	Total cash flow hedging instruments	$	—		$	—		$	—	$	5
	Derivatives not designated as cash flow hedges:
	Current amounts
	Commodity contracts	$	6		$	4		$	5	$	1
	Long-term amounts
	Commodity contracts	1			1			—		—
	Embedded derivatives in Series A preferred units	—			—			23		25
	Total derivatives	$	7		$	5		$	28	$	31
	The Partnership’s statements of operations for the three and nine months ended September 30, 2013 and 2012 were impacted by derivative instruments activities as follows:
				Three Months Ended September 30,
				2013			2012
	Derivatives in cash flow hedging relationships:
				Change in Value Recognized in
				AOCI on Derivatives (Effective Portion)
	Commodity derivatives			$	—		$	(6	)
	Derivatives in cash flow hedging relationships:		Location of Gain/(Loss)	Amount of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)
			Recognized in Income
	Commodity derivatives		Revenues	$	—		$	6
	Derivatives not designated in a hedging relationship:		Location of Gain/(Loss)	Amount of Gain/(Loss) Recognized
			Recognized in Income	in Income on Derivatives
	Commodity derivatives		Revenues	$	(10	)	$	(5	)
	Embedded derivatives in Series A preferred units		Other income &  deductions, net	24			2
				$	14		$	(3	)
				Nine Months Ended September 30,
				2013			2012
	Derivatives in cash flow hedging relationships:
				Change in Value Recognized in
				AOCI on Derivatives (Effective Portion)
	Commodity derivatives			$	—		$	5
	Derivatives in cash flow hedging relationships:		Location of Gain/(Loss)	Amount of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)
			Recognized in Income
	Commodity derivatives		Revenues	$	—		$	12
	Derivatives not designated in a hedging relationship:		Location of Gain/(Loss)	Amount of Gain/(Loss) Amortized
			Recognized in Income	from AOCI into Income
	Commodity derivatives		Revenues	$	—		$	(6	)
	Derivatives not designated in a hedging relationship:		Location of Gain/(Loss)	Amount of Gain/(Loss) Recognized
			Recognized in Income	in Income on Derivatives
	Commodity derivatives		Revenues	$	—		$	14
	Embedded derivatives in Series A preferred units		Other income &  deductions, net	2			10
				$	2		$	24

LongTerm_Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2013
Long-Term Debt Disclosure [Abstract]	'
Long-Term Debt	'
	Long-term Debt
	Obligations in the form of senior notes and borrowings under the revolving credit facility are as follows:
		September 30, 2013			December 31, 2012
	Senior notes	$	2,800		$	1,965
	Revolving loans	176			192
	Total	2,976			2,157
	Less: current portion	—			—
	Long-term debt	$	2,976		$	2,157
	Availability under revolving credit facility:
	Total credit facility limit	$	1,200		$	1,150
	Revolving loans	(176		)	(192		)
	Letters of credit	(15		)	(12		)
	Total available	$	1,009		$	946
	Long-term debt maturities as of September 30, 2013 for each of the next five years are as follows:
	Years Ending December 31,		Amount
	2013 (remainder)		$	—
	2014		—
	2015		—
	2016		—
	2017		—
	Thereafter		2,976
	Total		$	2,976
	Revolving Credit Facility
	The weighted average interest rate on the total amounts outstanding under the Partnership’s revolving credit facility was 2.19% as of September 30, 2013.
	In May 2013, RGS entered into the Sixth Amended and Restated Credit Agreement to increase the commitment to $1.2 billion with a $300 million uncommitted incremental facility and extended the maturity date to May 21, 2018. The material differences between the Fifth and Sixth Amended and Restated Credit Agreement include:
	•	A 75 bps decrease in pricing, with an additional 50 bps decrease upon the achievement of an investment grade rating;
	•	No limitation on the maximum amount that the loan parties may invest in joint ventures existing on the date of the credit agreement so long as the Partnership is in pro forma compliance with the financial covenants;
	•	The addition of a “Restricted Subsidiary” structure such that certain designated subsidiaries are not subject to the credit facility covenants and do not guarantee the obligations thereunder or pledge their assets in support thereof;
	•	The addition of provisions such that upon the achievement of an investment grade rating by the Partnership, the collateral package will be released; the facility will become unsecured; and the covenant package will be significantly reduced;
	•	An eight-quarter increase in the permitted Total Leverage Ratio; and
	•	After March 2015, an increase in the permitted Total Leverage Ratio for the two fiscal quarters following any $50 million or greater acquisition.
	The new credit agreement and the guarantees are senior to the Partnership’s and the guarantors’ secured obligations, including the Series A preferred units. As of September 30, 2013, the Partnership was in compliance with all of the financial covenants contained within the new credit agreement.
	The Partnership treated the May 2013 amendment of the revolving credit facility as a modification of an existing revolving credit agreement and, therefore, wrote off debt issuance costs of less than $1 million to interest expense, net in the period from January 1, 2013 to September 30, 2013. In addition, the Partnership capitalized $7 million of loan fees which is being amortized over the remaining term.
	4.5% Senior Notes Due 2023
	In April 2013, in conjunction with financing the SUGS Acquisition, the Partnership and Finance Corp. issued $600 million senior notes in a private placement (the “2023 4.5% Notes”). The 2023 4.5% Notes bear interest at 4.5% payable semi-annually in arrears on May 1 and November 1, commencing November 1, 2013 and mature on November 1, 2023.
	At any time prior to August 1, 2023, the Partnership may redeem some or all of the 2023 4.5% Notes at a price equal to 100% of the principal amount plus a make-whole premium and accrued interest. On or after August 1, 2023, the Partnership may redeem some or all of the 2023 4.5% Notes at a price equal to 100% plus accrued interest.
	9.375% Senior Notes Due 2016
	In June 2013, the Partnership redeemed all of the $163 million outstanding 9.375% Senior Notes due 2016 for $178 million cash, inclusive of accrued and unpaid interest of $7 million and other fees and expenses.
	5.75% Senior Notes Due 2020
	In September 2013, the Partnership and Finance Corp. issued $400 million senior notes due September 1, 2020 (the “2020 Notes”). The 2020 Notes bear interest at 5.75% payable semi-annually on March 1 and September 1, commencing March 1, 2014, and mature on September 1, 2020.
	At any time prior to June 1, 2020, the Partnership may redeem some or all of the 2020 Notes at a price equal to 100% of the principal amount plus a make-whole premium and accrued interest. On or after June 1, 2020, the Partnership may redeem some or all of the 2020 Notes at a price equal to 100% plus accrued interest.
	Covenants
	Upon a change of control, as defined in the indentures, followed by a ratings decline within 90 days, each holder of the 2023 4.5% Notes and the 2020 Notes will be entitled to require us to purchase all or a portion of its notes at a purchase price of 101% of the principal amount plus accrued interest and liquidated damages, if any. Our ability to purchase the notes upon a change of control will be limited by the terms of our debt agreements, including our revolving credit facility.
	The 2023 4.5% Notes and the 2020 Notes contain various covenants that limit, among other things, our ability, and the ability of certain of our subsidiaries, to:
	•	incur additional indebtedness;
	•	pay distributions on, or repurchase or redeem our equity interests;
	•	make certain investments;
	•	incur liens;
	•	enter into certain types of transactions with affiliates; and
	•	sell assets or consolidate or merge with or into other companies.
	At September 30, 2013, the Partnership was in compliance with all covenants.
	If the 2023 4.5% Notes and the 2020 Notes achieve investment grade ratings by both Moody’s and S&P and no default or event of default has occurred and is continuing, we will no longer be subject to many of the foregoing covenants.
	The 2023 4.5% Notes and the 2020 Notes are jointly and severally guaranteed by all of our consolidated subsidiaries, other than Finance Corp. and a minor subsidiary. The senior notes and guarantees are unsecured and rank equally with all of our and the guarantors’ existing and future unsecured obligations. The senior notes and the guarantees will be senior in right of payment to any of our and the guarantor’s future obligations that are, by their terms, expressly subordinated in right of payment to the notes and the guarantees. The senior notes and the guarantees will be effectively subordinated to our and the guarantors’ secured obligations, including our revolving credit facility, to the extent of the value of the assets securing such obligations.
	Finance Corp. has no operations and will not have revenues other than as may be incidental as co-issuer of the Senior Notes. Since the guarantees are fully unconditional and joint and several of its subsidiaries, except for a minor subsidiary, the Partnership has not included condensed consolidated financial information of guarantors of the Senior Notes.

Commitments_And_Contingencies

Commitments And Contingencies	9 Months Ended
	Sep. 30, 2013
Commitments And Contingencies [Abstract]	'
Commitments And Contingencies	'
	Commitments and Contingencies
	Legal. The Partnership is involved in various claims, lawsuits and audits by taxing authorities incidental to its business. These claims and lawsuits in the aggregate are not expected to have a material adverse effect on the Partnership’s business, financial condition, results of operations or cash flows.
	Four putative class action lawsuits challenging the merger have been filed, two in the Court of Chancery of the State of Delaware: (i) David Naiditch v. PVR Partners, L.P., et al. (Case No. 9015-VCL); and (ii) Robert P. Frutkin v. Edward B. Cloues II, et al. (Case No. 9020-VCL), and two in the Court of Common Pleas for Delaware County, Pennsylvania: (i) Charles Monatt v. PVR Partners, LP, et al. (Case No. 2013-10606); and [(ii) Steven Keene v. James L. Gardner, et al. (Case No. 2013-010723)]. All of the cases name PVR, PVR GP and the current directors of PVR GP, as well as the Partnership, the General Partner and RVP LLC, a subsidiary of the Partnership (collectively, the "Regency Defendants"), as defendants. Each of the lawsuits has been brought by a purported unitholder of PVR, both individually and on behalf of a putative class consisting of public unitholders of PVR. The lawsuits generally allege, among other things, that the directors of PVR GP breached their fiduciary duties to unitholders of PVR by agreeing to a transaction with inadequate consideration and unfair terms and pursuant to an inadequate process. The lawsuits allege further that PVR GP and the Regency Defendants aided and abetted the directors of PVR GP in the alleged breach of their fiduciary duties. The Naiditch and Monatt lawsuits allege further that PVR also aided and abetted the directors of PVR GP in the alleged breach of their fiduciary duties. The lawsuits seek, in general, (i) injunctive relief enjoining the transactions contemplated by the merger agreement, (ii) in the event the merger is consummated, rescission or an award of rescissory damages, (iii) an award of plaintiffs’ costs, including reasonable attorneys’ and experts’ fees, (iv) the accounting by the defendants to plaintiffs for all damages caused by the defendants, and (v) such further relief as the court deems just and proper. Similar actions may be filed in the future.
	Environmental. The Partnership is responsible for environmental remediation at certain sites on its gathering and processing systems, resulting primarily from releases of hydrocarbons. The Partnership’s remediation program typically involves the management of contaminated soils and may involve remediation of groundwater. Activities vary with site conditions and locations, the extent and nature of the contamination, remedial requirements and complexity. The ultimate liability and total costs associated with these sites will depend upon many factors.
	The table below reflects the environmental liabilities recorded at September 30, 2013 and December 31, 2012. Except as described above, the Partnership does not have any material environmental remediation matters assessed as reasonably possible that would require disclosure in the financial statements.
		September 30, 2013		December 31, 2012
	Current	$	2	$	5
	Noncurrent	7		7
	Total environmental liabilities	$	9	$	12
	The Partnership recorded expenditures related to environmental remediation of $4 million for the nine months ended September 30, 2013.
	Air Quality Control. The Partnership is currently negotiating settlements to certain enforcement actions by the NMED and the TCEQ. The TCEQ recently initiated a state-wide emissions inventory for the sulfur dioxide emissions from sites with reported emissions of 10 tons per year or more. If this data demonstrates that any source or group of sources may cause or contribute to a violation of the National Ambient Air Quality Standards, they must be sufficiently controlled to ensure timely attainment of the standard. This may potentially affect three recovery units in Texas. It is unclear at this time how the NMED will address the sulfur dioxide standard.
	Compliance Orders from the NMED. SUGS has been in discussions with the NMED concerning allegations of violations of New Mexico air regulations related to the Jal #3 and Jal #4 facilities. Hearings on the COs were delayed until March 2014 to allow the parties to pursue substantive settlement discussions. The Partnership has meritorious defenses to the NMED claims and can offer significant mitigating factors to the claimed violations. The Partnership has recorded a liability of less than $1 million related to the claims and will continue to assess its potential exposure to the allegations as the matters progress.
	CDM Sales Tax Audit. CDM Resource Management LLC (“CDM”), a subsidiary of the Partnership, has historically claimed the manufacturing exemption from sales tax in Texas, as is common in the industry. The exemption is based on the fact that CDM’s natural gas compression equipment is used in the process of treating natural gas for ultimate use and sale. In a recent audit by the Texas Comptroller’s office, the Comptroller has challenged the applicability of the manufacturing exemption to CDM. The period being audited is from August 2006 to August 2007, and liability for that period is potentially covered by an indemnity obligation from CDM’s prior owners. CDM may also have liability for periods since 2008, and prospectively, if the Comptroller’s challenge is ultimately successful. An audit of the 2008 period has commenced. In April 2013, an independent audit review agreed with the Comptroller’s position. While CDM continues to disagree with this position and intends to seek redetermination and other relief, we are unable to predict the final outcome of this matter.
	In addition to the matters discussed above, the Partnership is involved in legal, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies regarding matters arising in the ordinary course of business.

Series_A_Preferred_Units_Notes

Series A Preferred Units (Notes)	9 Months Ended
	Sep. 30, 2013
Series A Preferred Units disclosure [Abstract]	'
Series A Preferred Units [Text Block]	'
	Series A Preferred Units
	In July 2013, certain holders of Series A Preferred Units exercised their right to convert 2,459,017 Series A Preferred Units into common units. Concurrent with this transaction, the Partnership recognized a $26 million gain in other income and deductions, net, related to the embedded derivative and reclassified $41 million from the Series A Preferred Units into common units. As of September 30, 2013, the remaining Series A Preferred Units were convertible into 2,047,571 common units, and if outstanding, are mandatorily redeemable on September 2, 2029 for $35 million plus all accrued but unpaid distributions and interest thereon. The Series A Preferred Units receive fixed quarterly cash distributions of $0.445 per unit if outstanding on the record dates of the Partnership’s common unit distributions. Holders can elect to convert Series A Preferred Units into common units at any time in accordance with the partnership agreement.
	The following table provides a reconciliation of the beginning and ending balances of the Series A Preferred Units for the nine months ended September 30, 2013:
		Units		Amount
	Outstanding at beginning of period	4,371,586		$	73
	Series A Preferred Units converted into common units	(2,459,017	)	(41		)
	Accretion to redemption value	N/A		—
	Outstanding at end of period	1,912,569		$	32		*
	* This amount will be accreted to $35 million plus any accrued but unpaid distributions and interest by deducting amounts from
	partners’ capital over the remaining periods until the mandatory redemption date of September 2, 2029.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	As of September 30, 2013 and December 31, 2012, details of the Partnership’s related party receivables and related party payables were as follows:
		September 30, 2013		December 31, 2012
	Related party receivables
	HPC	$	1	$	1
	ETE and its subsidiaries	17		5
	Ranch JV	—		2
	Total related party receivables	$	18	$	8
	Related party payables
	HPC	$	1	$	1
	ETE and its subsidiaries	56		94
	Total related party payables	$	57	$	95
	Transactions with ETE and its subsidiaries. Under the service agreement with Services Co., the Partnership paid Services Co.’s direct expenses for services performed, plus an annual fee of $10 million, and received the benefit of any cost savings recognized for these services. The service agreement had a five year term which was to expire May 26, 2015, subject to earlier termination rights in the event of a change in control, the failure to achieve certain cost savings for the Partnership or upon an event of default. On April 30, 2013, in conjunction with the SUGS Acquisition, the Partnership entered into the first amendment (the “Services Agreement Amendment”) to the Services Agreement, effective as of May 26, 2010, by and among the Partnership, ETE and Services Co. The Services Agreement Amendment provided for a waiver of the $10 million annual fee effective as of May 1, 2013 through and including April 30, 2015 and clarified the scope and expenses chargeable as direct expenses thereunder.
	On April 30, 2013, the Partnership entered into the second amendment (the “Operation and Service Amendment”) to the Operation and Service Agreement (the “Operation and Service Agreement”), by and among the Partnership, ETC, the General Partner and RGS. Under the Operation and Service Agreement, ETC performs certain operations, maintenance and related services reasonably required to operate and maintain certain facilities owned by the Partnership, and the Partnership reimburses ETC for actual costs and expenses incurred in connection with the provision of these services based on an annual budget agreed upon by both parties. The Operation and Service Agreement Amendment describes the services that ETC will provide in the future.
	The Partnership incurred total service fees related to the agreements described above from ETE and its subsidiaries of $2 million and $4 million for the three months ended September 30, 2013 and 2012, respectively, and $9 million and $13 million for the nine months ended September 30, 2013 and 2012, respectively.
	In conjunction with distributions by the Partnership to the limited and general partner interests, ETE received cash distributions of $16 million for each of the three months ended September 30, 2013 and 2012, and $47 million and $46 million for the nine months ended September 30, 2013 and 2012, respectively.
	The Partnership’s Gathering and Processing segment, in the ordinary course of business, sells natural gas and NGLs to subsidiaries of ETE and records the revenue in gas sales and NGL sales. The Partnership recorded $5 million for NGL sales to Lone Star under a short-term agreement during the three months ended September 30, 2013, and is included in the $17 million related party receivable from ETE and its subsidiaries. The Partnership’s Contract Services segment provides contract compression and treating services to subsidiaries of ETE and records revenue in gathering, transportation and other fees. The Partnership’s Contract Services segment purchased compression equipment from a subsidiary of ETE for $39 million and $76 million for the three and nine months ended September 30, 2013.
	Transactions with Southern Union. Prior to April 30, 2013, Southern Union provided certain administrative services for SUGS that were either based on SUGS’s pro-rata share of combined net investment, margin and certain expenses or direct costs incurred by Southern Union on the behalf of SUGS. Southern Union also charged a management and royalty fee to SUGS for certain management support services provided by Southern Union on the behalf of SUGS and for the use of certain Southern Union trademarks, trade names and service marks by SUGS. These administrative services are no longer being provided subsequent to the SUGS Acquisition.
	Transactions with HPC. Under a Master Services Agreement with HPC, the Partnership operates and provides all employees and services for the operation and management of HPC. The related party general and administrative expenses reimbursed to the Partnership were $4 million and $5 million for the three months ended September 30, 2013 and 2012, respectively, and $14 million each of the nine months ended September 30, 2013 and 2012, which are recorded in gathering, transportation and other fees.
	The Partnership’s Contract Services segment provides compression services to HPC and records revenues in gathering, transportation and other fees. The Partnership also receives transportation services from HPC and records it as cost of sales.

Segment_Information

Segment Information	9 Months Ended
	Sep. 30, 2013
Segment Information [Abstract]	'
Segment Information	'
	Segment Information
	During the fourth quarter of 2012, the Partnership realigned the composition of its segments and updated the segment names to reflect the realignment. Accordingly, the Partnership has restated the items of segment information for the three and nine months ended September 30, 2012 to reflect this new segment alignment.
	The Partnership has five reportable segments: Gathering and Processing, Natural Gas Transportation, NGL Services, Contract Services, and Corporate. The reportable segments are as described below:
	•	Gathering and Processing. The Partnership provides “wellhead-to-market” services to producers of natural gas, which include transporting raw natural gas from the wellhead through gathering systems, processing raw natural gas to separate NGLs from the raw natural gas and selling or delivering pipeline-quality natural gas and NGLs to various markets and pipeline systems. This segment also includes ELG and the Partnership’s 33.33% membership interest in Ranch JV, which processes natural gas delivered from the NGLs-rich Bone Spring and Avalon shale formations in west Texas. The Partnership completed the SUGS Acquisition on April 30, 2013; therefore, the Gathering and Processing segment amounts have been retrospectively adjusted to reflect the SUGS Acquisition beginning March 26, 2012.
	•	Natural Gas Transportation. The Partnership owns a 49.99% general partner interest in HPC, which owns RIGS, a 450- mile intrastate pipeline that delivers natural gas from northwest Louisiana to downstream pipelines and markets, and a 50% membership interest in MEP, which owns a 500-mile interstate natural gas pipeline stretching from southeast Oklahoma through northeast Texas, northern Louisiana and central Mississippi to an interconnect with the Transcontinental Gas Pipe Line system in Butler, Alabama. This segment also includes Gulf States, which owns a 10-mile interstate pipeline that extends from Harrison County, Texas to Caddo Parish, Louisiana.
	•	NGL Services. The Partnership owns a 30% membership interest in Lone Star, an entity owning a diverse set of midstream energy assets including pipelines, storage, fractionation and processing facilities located in Texas, Mississippi and Louisiana.
	•	Contract Services. The Partnership owns and operates a fleet of compressors used to provide turn-key natural gas compression services for customer specific systems. The Partnership also owns and operates a fleet of equipment used to provide treating services, such as carbon dioxide and hydrogen sulfide removal, natural gas cooling, dehydration and BTU management.
	•	Corporate. The Corporate segment comprises the Partnership’s corporate assets.
	The Partnership accounts for intersegment revenues as if the revenues were to third parties, exclusive of certain cost of capital charges.
	Management evaluates the performance of each segment and makes capital allocation decisions through the separate consideration of segment margin and operation and maintenance expenses. Segment margin for the Gathering and Processing and the Natural Gas Transportation segments is defined as total revenues, including service fees, less cost of sales. In the Contract Services segment, segment margin is defined as revenues less direct costs.
	Management believes segment margin is an important measure because it directly relates to volume, commodity price changes and revenue generating horsepower. Operation and maintenance expenses are a separate measure used by management to evaluate performance of field operations. Direct labor, insurance, property taxes, repair and maintenance, utilities and contract services comprise the most significant portion of operation and maintenance expenses. These expenses fluctuate depending on the activities performed during a specific period. The Partnership does not deduct operation and maintenance expenses from total revenues in calculating segment margin because management separately evaluates commodity volume and price changes in segment margin. The Partnership does not record segment margin for its investments in unconsolidated affiliates (HPC, MEP, Lone Star, Ranch JV and Grey Ranch) because it records its ownership percentages of their net income as income from unconsolidated affiliates in accordance with the equity method of accounting.
	Results for each segment are shown below:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	External Revenues
	Gathering and Processing	$	603		$	475		$	1,671		$	1,262
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	58			47			159			137
	Corporate	4			5			14			14
	Eliminations	—			—			—			—
	Total	$	665		$	527		$	1,844		$	1,413
	Intersegment Revenues
	Gathering and Processing	$	—		$	—		$	—		$	—
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	4			5			11			15
	Corporate	—			—			—			—
	Eliminations	(4		)	(5		)	(11		)	(15		)
	Total	$	—		$	—		$	—		$	—
	Segment Margin
	Gathering and Processing	$	136		$	110		$	383		$	314
	Natural Gas Transportation	—			—			—			1
	NGL Services	—			—			—			—
	Contract Services	52			48			149			140
	Corporate	4			5			14			14
	Eliminations	(4		)	(5		)	(11		)	(15		)
	Total	$	188		$	158		$	535		$	454
	Operation and Maintenance
	Gathering and Processing	$	63		$	50		$	177		$	125
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	19			16			53			49
	Corporate	—			—			1			—
	Eliminations	(4		)	(5		)	(11		)	(15		)
	Total	$	78		$	61		$	220		$	159
	The table below provides a reconciliation of total segment margin to (loss) income before income taxes:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Total segment margin	$	188		$	158		$	535		$	454
	Operation and maintenance	(78		)	(61		)	(220		)	(159		)
	General and administrative	(13		)	(21		)	(64		)	(78		)
	Gain (loss) on asset sales, net	1			—			(1		)	(2		)
	Depreciation and amortization	(74		)	(71		)	(207		)	(193		)
	Income from unconsolidated affiliates	37			21			103			87
	Interest expense, net	(41		)	(29		)	(119		)	(86		)
	Loss on debt refinancing, net	—			—			(7		)	(8		)
	Other income and deductions, net	24			1			3			26			*
	Income (loss) before income taxes	$	44		$	(2	)	$	23		$	41
	__________________
	*	Other income and deductions, net for the nine months ended September 30, 2012 included a one-time producer payment of $16 million related to an assignment of certain contracts.
	The tables below provide amounts reflected in the consolidated balance sheet for each segment:
	Total Assets	September 30, 2013			December 31, 2012
Gathering and Processing	$	4,631		$	4,210
Natural Gas Transportation	1,005			1,232
NGL Services	1,040			948
Contract Services	1,812			1,672
Corporate	78			61
Total	$	8,566		$	8,123
Investment in Unconsolidated Affiliates	September 30, 2013			December 31, 2012
Gathering and Processing	$	37		$	35
Natural Gas Transportation	1,004			1,231
NGL Services	1,040			948
Total	$	2,081		$	2,214

EquityBased_Compensation

Equity-Based Compensation	9 Months Ended
	Sep. 30, 2013
Equity-Based Compensation [Abstract]	'
Equity-Based Compensation	'
	Equity-Based Compensation
	The Partnership’s LTIP for its employees, directors and consultants authorizes grants up to 5,865,584 common units. LTIP compensation expense of $2 million and $1 million was recorded in general and administrative expense for the three months ended September 30, 2013 and 2012, respectively, and $5 million and $3 million for the nine months ended September 30, 2013 and 2012, respectively.
	Phantom Units. All phantom units granted prior to November 2010 were in substance two grants composed of (1) service condition grants with graded vesting over three years or (2) market condition grants with cliff vesting based upon the Partnership’s relative ranking in total unitholder return among 20 peer companies. Distributions related to these unvested phantom units will be accrued and paid upon vesting. During 2013, all remaining market condition grants were forfeited due to the completion of the three year vesting period without attaining the market based incentive requirements.
	All phantom units granted from November 2010 to November 2012 were service condition grants with graded vesting over five years. Phantom units granted after November 2012 were service condition grants that (1) have graded vesting over five years or (2) vest over the next five years on a cliff basis; by vesting 60% at the end of the third year of service and vesting the remaining 40% at the end of the fifth year of service. Distributions related to these unvested phantom units will be paid concurrent with the Partnership’s distribution for common units.
	The following table presents phantom units activity for the nine months ended September 30, 2013:
	Phantom Units	Units		Weighted Average Grant
				Date Fair Value
	Outstanding at beginning of period	1,231,342		$	23.22
	Service condition grants	52,360		25.3
	Vested service condition	(45,158	)	24.34
	Forfeited service condition	(25,900	)	23.29
	Forfeited market condition	(44,397	)	19.52
	Outstanding at end of period	1,168,247		$	23.41
	The Partnership expects to recognize $20 million of compensation expense related to non-vested phantom units over a weighted-average period of 3.5 years.

Fair_Value_Measures

Fair Value Measures	9 Months Ended
	Sep. 30, 2013
Fair Value Measures [Abstract]	'
Fair Value Measures	'
	Fair Value Measures
	The Partnership’s financial assets and liabilities measured at fair value on a recurring basis are derivatives related to commodity swaps and embedded derivatives in the Series A preferred units. Derivatives related to commodity swaps are valued using discounted cash flow techniques. These techniques incorporate Level 1 and Level 2 inputs such as commodity prices. These market inputs are utilized in the discounted cash flow calculation considering the instrument’s term, notional amount, discount rate and credit risk and are classified as Level 2 in the hierarchy. Embedded derivatives related to Series A preferred units are valued using a binomial lattice model. The inputs utilized in the model include credit spread, probabilities of the occurrence of certain events, common unit price, dividend yield, and expected volatility, and are classified as Level 3 in the hierarchy.
	The following table presents the Partnership’s derivative assets and liabilities measured at fair value on a recurring basis:
		Fair Value Measurements at September 30, 2013							Fair Value Measurements at December 31, 2012
		Fair Value Total			Significant		Unobservable		Fair Value Total		Significant		Unobservable
					Observable		Inputs				Observable		Inputs
					Inputs		(Level 3)				Inputs		(Level 3)
					(Level 2)						(Level 2)
	Assets
	Commodity Derivatives:
	Natural Gas	$	6		$	6	$	—	$	2	$	2	$	—
	NGLs	1			1		—		1		1		—
	Condensate	—			—		—		2		2		—
	Total Assets	$	7		$	7	$	—	$	5	$	5	$	—
	Liabilities
	Commodity Derivatives:
	Natural Gas	$	1		$	1	$	—	$	5	$	5	$	—
	NGLs	2			2		—		1		1		—
	Condensate	2			2		—		—		—		—
	Embedded derivatives in Series A preferred units	23			—		23		25		—		25
	Total Liabilities	$	28		$	5	$	23	$	31	$	6	$	25
	The following table presents the material unobservable inputs used to estimate the fair value of the embedded derivatives in the Series A preferred units:
	Unobservable Input		September 30, 2013
	Credit Spread		6.39	%
	Volatility		19.96	%
	Changes in the Partnership’s cost of equity and U.S. Treasury yields would cause a change in the credit spread used to value the embedded derivatives. Changes in the Partnership’s historical unit price volatility would cause a change in the volatility used to value the embedded derivatives.
	The following table presents the changes in Level 3 derivatives measured on a recurring basis for the nine months ended September 30, 2013. There were no transfers between the fair value hierarchy levels for the nine months ended September 30, 2013.
		Embedded Derivatives in Series A Preferred Units
	Net liability balance at December 31, 2012	$	25
	Change in fair value, net of gain at conversion of $26 million	(2		)
	Net liability balance at September 30, 2013	$	23
	The carrying amount of cash and cash equivalents, accounts receivable and accounts payable approximates fair value due to their short-term maturities. Long-term debt, other than the senior notes, is comprised of borrowings under which interest accrues under a floating interest rate structure. Accordingly, the carrying value approximates fair value.
	The aggregate fair value and carrying amount of the Senior Notes at September 30, 2013 were $2.8 billion. As of December 31, 2012, the aggregate fair value and carrying amount of the Senior Notes was $2.1 billion and $2 billion, respectively. The fair value of the Senior Notes is a Level 1 valuation based on third party market value quotations.

Organization_And_Summary_Of_Si1

Organization And Summary Of Significant Accounting Policies (Policy)	9 Months Ended
	Sep. 30, 2013
Organization And Summary Of Significant Accounting Policies	'
Organization And Basis Of Presentation	'
	Organization. The unaudited condensed consolidated financial statements presented herein contain the results of Regency Energy Partners LP and its subsidiaries (the “Partnership”), a Delaware limited partnership. The Partnership and its subsidiaries are engaged in the business of gathering and processing, compression, treating and transportation of natural gas and the transportation, fractionation and storage of NGLs. Regency GP LP is the Partnership’s general partner and Regency GP LLC (collectively the “General Partner”) is the managing general partner of the Partnership and the general partner of Regency GP LP.
Basis of Presentation and Significant Accounting Policies [Text Block]	'
	Basis of Presentation. The unaudited financial information included in this Form 10-Q has been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2012. In the opinion of the Partnership’s management, such financial information reflects all adjustments necessary for a fair presentation of the financial position and the results of operations for such interim periods in accordance with GAAP. All inter-company items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.
Use Of Estimates	'
	Use of Estimates. The unaudited condensed consolidated financial statements have been prepared in conformity with GAAP, which includes the use of estimates and assumptions made by management that affect the reported amounts of assets, liabilities, revenues, expenses and disclosure of contingent assets and liabilities that exist at the date of the condensed consolidated financial statements. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could be different from those estimates.
Derivatives, Policy [Policy Text Block]	'
	Derivative Financial Instruments. Derivative transactions are recognized in the accompanying consolidated balance sheet at their fair value. On the date the derivative contract is entered into, SUGS designated the derivative as a hedge of a forecasted transaction or the variability of cash flows to be received or paid in conjunction with a recognized asset or liability (a cash flow hedge). The effective portion of changes in fair value is recorded in accumulated other comprehensive income (loss) in the consolidated balance sheet until the related hedge items impact earnings. Any ineffective portion of a cash flow hedge is reported in current period earnings. Fair value is determined based upon quoted market prices and pricing models using assumptions that market participants would use. All outstanding SUGS derivative transactions as of April 30, 2013 were terminated
Asset Retirement Obligations, Policy [Policy Text Block]	'
	Asset Retirement Obligations. Legal obligations associated with the retirement of long-lived assets are recorded at fair value at the time the obligations are incurred, if a reasonable estimate of fair value can be made. Present value techniques are used which reflect assumptions such as removal and remediation costs, inflation,  and profit margins that third parties would demand to settle the amount of the future obligation. The Partnership does not include a market risk premium for unforeseeable circumstances in its fair value estimates because such a premium cannot be reliably estimated. Upon initial recognition of the liability, costs are capitalized as a part of the long-lived asset and allocated to expense over the useful life of the related asset. The liability is accreted to its present value each period with accretion being recorded to operating expense with a corresponding increase in the carrying amount of the liability. The ARO assets and liabilities as of September 30, 2013 and December 31, 2012 were $5 million.
Environmental Costs, Policy [Policy Text Block]	'
	Environmental. The Partnership’s operations are subject to federal, state and local laws and rules and regulations regarding water quality, hazardous and solid waste management, air quality control and other environmental matters. These laws, rules and regulations require the Partnership to conduct its operations in a specified manner and to obtain and comply with a wide variety of environmental registrations, licenses, permits, inspections and other approvals. Failure to comply with applicable environmental laws, rules and regulations may expose the Partnership to significant fines, penalties and/or interruptions in its operations. The Partnership’s environmental policies and procedures are designed to achieve compliance with such applicable laws and regulations. These evolving laws and regulations and claims for damages to property, employees, other persons and the environment resulting from current or past operations may result in significant expenditures and liabilities in the future.
Income Tax Disclosure [Text Block]	'
	Income Taxes. The Partnership is generally not subject to income taxes, except as discussed below, because its income is taxed directly to its partners. The Partnership is subject to the gross margins tax enacted by the state of Texas. The Partnership has two wholly-owned subsidiaries that are subject to income tax and provides for deferred income taxes using the asset and liability method. Accordingly, deferred taxes are recorded for differences between the tax and book basis that will reverse in future periods. The Partnership’s deferred tax liabilities of $21 million and $23 million as of September 30, 2013 and December 31, 2012, respectively, relate to the difference between the book and tax basis of property, plant and equipment and intangible assets and is included in other long-term liabilities in the accompanying consolidated balance sheets. The Partnership follows the guidance for uncertainties in income taxes where a liability for an unrecognized tax benefit is recorded for a tax position that does not meet the “more likely than not” criteria. The Partnership has not recorded any uncertain tax positions meeting the more likely than not criteria as of September 30, 2013 and December 31, 2012. The Partnership also recognized deferred income tax benefit of $5 million offset by a $4 million state deferred tax expense for the nine months ended September 30, 2013.

Organization_And_Summary_Of_Si2

Organization And Summary Of Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2013
Organization And Summary Of Significant Accounting Policies	'
Revenue by Combined Entity [Table Text Block]	'
	The following table presents the revenues and net income for the previously separate entities and the combined amounts presented herein:
		Three Months Ended September 30,					Nine Months Ended September 30,
		2013		2012			2013 (1)			2012
	Revenues:
	Partnership	$	665	$	313		$	1,576		$	983
	SUGS	—		214			268			430
	Combined	$	665	$	527		$	1,844		$	1,413
	Net income (loss):
	Partnership	$	42	$	(1	)	$	60		$	57
	SUGS	—		—			(36		)	(15		)
	Combined	$	42	$	(1	)	$	24		$	42
	(1)	The SUGS Acquisition closed on April 30, 2013. Therefore, amounts attributable to SUGS only include four months of activity for the nine months ended September 30, 2013.

Partners_Capital_and_Distribut1

Partners' Capital and Distributions (Tables)	9 Months Ended
	Sep. 30, 2013
Partners’ Capital and Distributions [Abstract]	'
Schedule of Stockholders Equity [Table Text Block]	'
	The change in common and Class F units during the nine months ended September 30, 2013 was as follows:
		Common			Class F
	Balance - December 31, 2012	170,951,457			—
	Issuance of common units under LTIP, net of forfeitures and tax withholding	35,615			—
	Issuance of common units under the Equity Distribution Agreement	5,712,138			—
	Issuance of common units in exchange for conversion of Series A preferred units	2,629,223			—
	Issuance of common units and Class F common units in connection with SUGS Acquisition	31,372,419		(1)	6,274,483	(2)
	Balance - September 30, 2013	210,700,852			6,274,483
	(1)	ETE has agreed to forgo IDR payments on the Partnership common units issued with the SUGS Acquisition for twenty-four months post-transaction closing.
	(2)	The Class F common units are not entitled to participate in the Partnership’s distributions or earnings for twenty-four months post-transaction closing.
Schedule of Distributions Made to Members or Limited Partners, by Distribution [Table Text Block]	'
	Following are distributions declared by the Partnership subsequent to December 31, 2012:
	Quarter Ended		Record Date		Payment Date	Cash Distributions
						(per common unit)
	December 31, 2012		February 7, 2013		February 14, 2013	$0.46
	March 31, 2013		May 6, 2013		May 13, 2013	$0.46
	June 30, 2013		August 5, 2013		August 14, 2013	$0.47
	September 30, 2013		November 4, 2013		November 14, 2013	$0.47

Income_Loss_Per_Limited_Partne1

Income (Loss) Per Limited Partner Unit (Tables)	9 Months Ended
	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Basic And Diluted Income (Loss) From Continuing Operations	'
	The following tables provide a reconciliation of the numerator and denominator of the basic and diluted earnings per common unit computations for the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30,
		2013							2012
		Income				Units	Per-Unit		Income			Units	Per-Unit
		(Numerator)				(Denominator)	Amount		(Numerator)			(Denominator)	Amount
	Basic income (loss) per unit
	Amounts allocated to common units	$	33			209,559,854	$	0.16	$	(6	)	170,264,621	$	(0.04	)
	Effect of Dilutive Securities:
	Common unit options	—				32,489			—			—
	Phantom units *	—				435,606			—			—
	Series A preferred units	(23		)		2,047,571			—			—
	Diluted income (loss) per unit	$	10			212,075,520	$	0.05	$	(6	)	170,264,621	$	(0.04	)
		Nine Months Ended September 30,
		2013							2012
		Income				Units	Per-Unit		Income			Units	Per-Unit
		(Numerator)				(Denominator)	Amount		(Numerator)			(Denominator)	Amount
	Basic income per unit
	Amounts allocated to common units	$	40			191,334,032	$	0.21	$	41		166,368,178	$	0.25
	Effect of Dilutive Securities:
	Common unit options	—				23,931			—			13,113
	Phantom units *	—				351,811			—			320,452
	Series A preferred units	—				—			(3		)	4,651,884
	Diluted income per unit	$	40			191,709,774	$	0.21	$	38		171,353,627	$	0.22
	*	Amount assumes maximum conversion rate for market condition awards.
Weighted Average Outstanding Amount Of Securities	'
	The following data show securities that could potentially dilute earnings per unit in the future that were not included in the computation of diluted earnings per unit because to do so would have been antidilutive for the periods presented:
		Nine Months Ended September 30, 2013			Three Months Ended September 30, 2012
	Common unit options	—			9,147
	Phantom units	—			313,378
	Series A preferred units	2,047,571			4,651,884

Investment_In_Unconsolidated_A1

Investment In Unconsolidated Affiliates (Tables)	9 Months Ended
	Sep. 30, 2013
Carrying value of limited and general partnership interest	'
	The carrying value of the Partnership’s investment in each of the unconsolidated affiliates as of September 30, 2013 and December 31, 2012 is as follows:
		September 30, 2013			December 31, 2012
	HPC	$	448		$	650
	MEP	556			581
	Lone Star	1,040			948
	Ranch JV	36			35
	Grey Ranch	1			—
		$	2,081		$	2,214
Changes In The Partnership's Investment	'
	The following tables summarize the Partnership’s investment activities in each of the unconsolidated affiliates for the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30, 2013
		HPC (1)			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	51		$	1
	Distributions from unconsolidated affiliates	(196		)	(18		)	(16		)	(1		)
	Share of earnings of unconsolidated affiliates’ net income	9			11			18			—
	Amortization of excess fair value of investment	(1		)	—			—			—
		Three Months Ended September 30, 2012
		HPC			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	78		$	10
	Distributions from unconsolidated affiliates	(16		)	(18		)	(21		)	—
	Share of earnings of unconsolidated affiliates’ net income	3			10			9			—
	Amortization of excess fair value of investment	(1		)	—			—			—
		Nine Months Ended September 30, 2013
		HPC (1)			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	100		$	2
	Distributions from unconsolidated affiliates	(226		)	(56		)	(56		)	(1		)
	Share of earnings of unconsolidated affiliates’ net income	28			31			48			—
	Amortization of excess fair value of investment	(4		)	—			—			—
		Nine Months Ended September 30, 2012
		HPC			MEP			Lone Star			Ranch JV
	Contributions to unconsolidated affiliates	$	—		$	—		$	253		$	33
	Distributions from unconsolidated affiliates	(46		)	(56		)	(39		)	—
	Share of earnings of unconsolidated affiliates’ net income	28			31			32			—
	Amortization of excess fair value of investment	(4		)	—			—			—
	(1) The Partnership received a non-recurring return of capital of $185 million from HPC in September 2013. HPC entered into a $500 million 5-year revolving credit facility in September 2013. Concurrent with the closing of this facility, HPC borrowed $370 million to fund a non-recurring return of capital to the partners. The Partnership pledged its 49.99% equity interest in Regency Intrastate Gas LP. The amounts outstanding under this facility was $445 million as of September 30, 2013. The Partnership’s contingent obligations with respect to the outstanding borrowings under this facility was $222 million at September 30, 2013.
Condensed Consolidated Income Statements	'
	The following tables present selected income statement data for each of the unconsolidated affiliates, on a 100% basis, for the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	38		$	66		$	537		$	4
	Operating income	19			34			61			1
	Net income	18			21			61			1
		Three Months Ended September 30, 2012
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	42		$	65		$	165		$	—
	Operating income (loss)	21			33			31			(1		)
	Net income (loss)	6			21			31			(1		)
		Nine Months Ended September 30, 2013
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	116		$	194		$	1,320		$	10
	Operating income	58			101			162			2
	Net income	56			63			160			2
		Nine Months Ended September 30, 2012
		HPC			MEP			Lone Star			Ranch JV
	Total revenues	$	130		$	196		$	490		$	—
	Operating income (loss)	71			101			110			(1		)
	Net income (loss)	55			63			110			(1		)

Derivative_Instruments_Tables

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2013
Derivative Instruments [Abstract]	'
Schedule Of Derivative Assets And Liabilities Statement	'
	The Partnership’s derivative assets and liabilities, including credit risk adjustments, as of September 30, 2013 and December 31, 2012 are detailed below:
		Assets						Liabilities
		September 30, 2013			December 31, 2012			September 30, 2013		December 31, 2012
	Derivatives designated as cash flow hedges:
	Current amounts
	Commodity contracts	$	—		$	—		$	—	$	5
	Total cash flow hedging instruments	$	—		$	—		$	—	$	5
	Derivatives not designated as cash flow hedges:
	Current amounts
	Commodity contracts	$	6		$	4		$	5	$	1
	Long-term amounts
	Commodity contracts	1			1			—		—
	Embedded derivatives in Series A preferred units	—			—			23		25
	Total derivatives	$	7		$	5		$	28	$	31
Detail Effect Of Derivative Assets And Liabilities In Statement Of Operations	'
	The Partnership’s statements of operations for the three and nine months ended September 30, 2013 and 2012 were impacted by derivative instruments activities as follows:
				Three Months Ended September 30,
				2013			2012
	Derivatives in cash flow hedging relationships:
				Change in Value Recognized in
				AOCI on Derivatives (Effective Portion)
	Commodity derivatives			$	—		$	(6	)
	Derivatives in cash flow hedging relationships:		Location of Gain/(Loss)	Amount of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)
			Recognized in Income
	Commodity derivatives		Revenues	$	—		$	6
	Derivatives not designated in a hedging relationship:		Location of Gain/(Loss)	Amount of Gain/(Loss) Recognized
			Recognized in Income	in Income on Derivatives
	Commodity derivatives		Revenues	$	(10	)	$	(5	)
	Embedded derivatives in Series A preferred units		Other income &  deductions, net	24			2
				$	14		$	(3	)
				Nine Months Ended September 30,
				2013			2012
	Derivatives in cash flow hedging relationships:
				Change in Value Recognized in
				AOCI on Derivatives (Effective Portion)
	Commodity derivatives			$	—		$	5
	Derivatives in cash flow hedging relationships:		Location of Gain/(Loss)	Amount of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)
			Recognized in Income
	Commodity derivatives		Revenues	$	—		$	12
	Derivatives not designated in a hedging relationship:		Location of Gain/(Loss)	Amount of Gain/(Loss) Amortized
			Recognized in Income	from AOCI into Income
	Commodity derivatives		Revenues	$	—		$	(6	)
	Derivatives not designated in a hedging relationship:		Location of Gain/(Loss)	Amount of Gain/(Loss) Recognized
			Recognized in Income	in Income on Derivatives
	Commodity derivatives		Revenues	$	—		$	14
	Embedded derivatives in Series A preferred units		Other income &  deductions, net	2			10
				$	2		$	24

LongTerm_Debt_Tables

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2013
Long-Term Debt Disclosure [Abstract]	'
Partnership's Long-Term Debt	'
	Obligations in the form of senior notes and borrowings under the revolving credit facility are as follows:
		September 30, 2013			December 31, 2012
	Senior notes	$	2,800		$	1,965
	Revolving loans	176			192
	Total	2,976			2,157
	Less: current portion	—			—
	Long-term debt	$	2,976		$	2,157
	Availability under revolving credit facility:
	Total credit facility limit	$	1,200		$	1,150
	Revolving loans	(176		)	(192		)
	Letters of credit	(15		)	(12		)
	Total available	$	1,009		$	946
Long-Term Debt Maturities	'
	Long-term debt maturities as of September 30, 2013 for each of the next five years are as follows:
	Years Ending December 31,		Amount
	2013 (remainder)		$	—
	2014		—
	2015		—
	2016		—
	2017		—
	Thereafter		2,976
	Total		$	2,976

Commitments_And_Contingencies_

Commitments And Contingencies (Tables)	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Accrued Liabilities [Table Text Block]	'
	The table below reflects the environmental liabilities recorded at September 30, 2013 and December 31, 2012. Except as described above, the Partnership does not have any material environmental remediation matters assessed as reasonably possible that would require disclosure in the financial statements.
		September 30, 2013		December 31, 2012
	Current	$	2	$	5
	Noncurrent	7		7
	Total environmental liabilities	$	9	$	12

Series_A_Preferred_Units_Table

Series A Preferred Units (Tables)	9 Months Ended
	Sep. 30, 2013
Series A Preferred Units disclosure [Abstract]	'
Schedule of Preferred Units [Table Text Block]	'
	The following table provides a reconciliation of the beginning and ending balances of the Series A Preferred Units for the nine months ended September 30, 2013:
		Units		Amount
	Outstanding at beginning of period	4,371,586		$	73
	Series A Preferred Units converted into common units	(2,459,017	)	(41		)
	Accretion to redemption value	N/A		—
	Outstanding at end of period	1,912,569		$	32		*
	* This amount will be accreted to $35 million plus any accrued but unpaid distributions and interest by deducting amounts from
	partners’ capital over the remaining periods until the mandatory redemption date of September 2, 2029.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Schedule of Related Party Transactions [Table Text Block]	'
	As of September 30, 2013 and December 31, 2012, details of the Partnership’s related party receivables and related party payables were as follows:
		September 30, 2013		December 31, 2012
	Related party receivables
	HPC	$	1	$	1
	ETE and its subsidiaries	17		5
	Ranch JV	—		2
	Total related party receivables	$	18	$	8
	Related party payables
	HPC	$	1	$	1
	ETE and its subsidiaries	56		94
	Total related party payables	$	57	$	95

Segment_Information_Tables

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2013
Segment Information [Abstract]	'
Operating Results for Each Segment	'
	Results for each segment are shown below:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	External Revenues
	Gathering and Processing	$	603		$	475		$	1,671		$	1,262
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	58			47			159			137
	Corporate	4			5			14			14
	Eliminations	—			—			—			—
	Total	$	665		$	527		$	1,844		$	1,413
	Intersegment Revenues
	Gathering and Processing	$	—		$	—		$	—		$	—
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	4			5			11			15
	Corporate	—			—			—			—
	Eliminations	(4		)	(5		)	(11		)	(15		)
	Total	$	—		$	—		$	—		$	—
	Segment Margin
	Gathering and Processing	$	136		$	110		$	383		$	314
	Natural Gas Transportation	—			—			—			1
	NGL Services	—			—			—			—
	Contract Services	52			48			149			140
	Corporate	4			5			14			14
	Eliminations	(4		)	(5		)	(11		)	(15		)
	Total	$	188		$	158		$	535		$	454
	Operation and Maintenance
	Gathering and Processing	$	63		$	50		$	177		$	125
	Natural Gas Transportation	—			—			—			—
	NGL Services	—			—			—			—
	Contract Services	19			16			53			49
	Corporate	—			—			1			—
	Eliminations	(4		)	(5		)	(11		)	(15		)
	Total	$	78		$	61		$	220		$	159
Reconciliation of Total Segment Margin to Income (Loss) Before Income Taxes	'
	The table below provides a reconciliation of total segment margin to (loss) income before income taxes:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Total segment margin	$	188		$	158		$	535		$	454
	Operation and maintenance	(78		)	(61		)	(220		)	(159		)
	General and administrative	(13		)	(21		)	(64		)	(78		)
	Gain (loss) on asset sales, net	1			—			(1		)	(2		)
	Depreciation and amortization	(74		)	(71		)	(207		)	(193		)
	Income from unconsolidated affiliates	37			21			103			87
	Interest expense, net	(41		)	(29		)	(119		)	(86		)
	Loss on debt refinancing, net	—			—			(7		)	(8		)
	Other income and deductions, net	24			1			3			26			*
	Income (loss) before income taxes	$	44		$	(2	)	$	23		$	41
	__________________
	*	Other income and deductions, net for the nine months ended September 30, 2012 included a one-time producer payment of $16 million related to an assignment of certain contracts.
Schedule Of Assets Related To Balance Sheet	'
	The tables below provide amounts reflected in the consolidated balance sheet for each segment:
	Total Assets	September 30, 2013			December 31, 2012
	Gathering and Processing	$	4,631		$	4,210
	Natural Gas Transportation	1,005			1,232
	NGL Services	1,040			948
	Contract Services	1,812			1,672
	Corporate	78			61
	Total	$	8,566		$	8,123
	Investment in Unconsolidated Affiliates	September 30, 2013			December 31, 2012
	Gathering and Processing	$	37		$	35
	Natural Gas Transportation	1,004			1,231
	NGL Services	1,040			948
	Total	$	2,081		$	2,214

EquityBased_Compensation_Table

Equity-Based Compensation (Tables) (Phantom Units)	9 Months Ended
	Sep. 30, 2013
Phantom Units	'
Phantom Units Activity	'
	The following table presents phantom units activity for the nine months ended September 30, 2013:
	Phantom Units	Units		Weighted Average Grant
				Date Fair Value
	Outstanding at beginning of period	1,231,342		$	23.22
	Service condition grants	52,360		25.3
	Vested service condition	(45,158	)	24.34
	Forfeited service condition	(25,900	)	23.29
	Forfeited market condition	(44,397	)	19.52
	Outstanding at end of period	1,168,247		$	23.41

Fair_Value_Measures_Tables

Fair Value Measures (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value Measures [Abstract]	'
FV of Partnership's Derivative Assets and Liabilities	'
	The following table presents the Partnership’s derivative assets and liabilities measured at fair value on a recurring basis:
		Fair Value Measurements at September 30, 2013							Fair Value Measurements at December 31, 2012
		Fair Value Total			Significant		Unobservable		Fair Value Total		Significant		Unobservable
					Observable		Inputs				Observable		Inputs
					Inputs		(Level 3)				Inputs		(Level 3)
					(Level 2)						(Level 2)
	Assets
	Commodity Derivatives:
	Natural Gas	$	6		$	6	$	—	$	2	$	2	$	—
	NGLs	1			1		—		1		1		—
	Condensate	—			—		—		2		2		—
	Total Assets	$	7		$	7	$	—	$	5	$	5	$	—
	Liabilities
	Commodity Derivatives:
	Natural Gas	$	1		$	1	$	—	$	5	$	5	$	—
	NGLs	2			2		—		1		1		—
	Condensate	2			2		—		—		—		—
	Embedded derivatives in Series A preferred units	23			—		23		25		—		25
	Total Liabilities	$	28		$	5	$	23	$	31	$	6	$	25
Significant Unobservable Inputs for FV Estimation of Embedded Derivatives	'
	The following table presents the material unobservable inputs used to estimate the fair value of the embedded derivatives in the Series A preferred units:
	Unobservable Input		September 30, 2013
	Credit Spread		6.39	%
	Volatility		19.96	%
Valuation Changes in Level 3 Derivatives	'
	The following table presents the changes in Level 3 derivatives measured on a recurring basis for the nine months ended September 30, 2013. There were no transfers between the fair value hierarchy levels for the nine months ended September 30, 2013.
		Embedded Derivatives in Series A Preferred Units
	Net liability balance at December 31, 2012	$	25
	Change in fair value, net of gain at conversion of $26 million	(2		)
	Net liability balance at September 30, 2013	$	23

Organization_And_Summary_Of_Si3

Organization And Summary Of Significant Accounting Policies Narrative (Details) (USD $)	9 Months Ended				3 Months Ended	9 Months Ended	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Oct. 10, 2013	Apr. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
					May Twenty Six Service Agreement	Common Units [Member]	Class F Units [Member]	Class F Units [Member]	Class F Units [Member]	Class F Units [Member]
					ETE
Business Acquisition, Cost of Acquired Entity, Purchase Price	'	'	$1,500,000,000	'	'	'	'	'	'	'
Noncash or Part Noncash Acquisition, Noncash Financial or Equity Instrument Consideration, Shares Issued	'	'	'	'	'	31,372,419	'	'	6,274,483	'
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	'	'	'	'	'	'	6,274,483	0	6,274,483	0
Business Acquisition, Cost of Acquired Entity, Cash Paid	'	'	600,000,000	'	'	'	'	'	'	'
Estimated Closing Adjustments	'	'	107,000,000	'	'	'	'	'	'	'
Annual Fees To Affiliates	'	'	'	'	10,000,000	'	'	'	'	'
Proposed Business Combination, Acquisition Related Costs	'	40,000,000	'	'	'	'	'	'	'	'
Proposed Business Acquisition, Cost of Acquired Entity, Purchase Price	'	5,600,000,000	'	'	'	'	'	'	'	'
Proposed Business Acquisition, Cost of Acquired Entity, Liabilities Incurred	'	1,800,000,000	'	'	'	'	'	'	'	'
Number of Share Received in Exchange of Each Share	'	1.02	'	'	'	'	'	'	'	'
Asset Retirement Obligation	5,000,000	'	'	5,000,000	'	'	'	'	'	'
Deferred Tax Liabilities, Net	21,000,000	'	'	23,000,000	'	'	'	'	'	'
Deferred Income Tax Expense (Benefit)	5,000,000	'	'	'	'	'	'	'	'	'
Deferred State and Local Income Tax Expense (Benefit)	$4,000,000	'	'	'	'	'	'	'	'	'

Organization_And_Summary_Of_Si4

Organization And Summary Of Significant Accounting Policies Combined Information (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Revenues	$665	$527	$1,844	$1,413
Net income (loss)	42	-1	24	42
Regency [Member]	'	'	'	'
Revenues	665	313	1,576	983
Net income (loss)	42	-1	60	57
SUGS [Member]	'	'	'	'
Revenues	0	214	268	430
Net income (loss)	0	0	-36	-15
Combined [Member]	'	'	'	'
Revenues	665	527	1,844	1,413
Net income (loss)	$42	($1)	$24	$42

Partners_Capital_and_Distribut2

Partners' Capital and Distributions Narrative (Details) (USD $)	9 Months Ended		3 Months Ended		9 Months Ended
	Sep. 30, 2013	Feb. 27, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
			Class F Units [Member]	Class F Units [Member]	Class F Units [Member]	Class F Units [Member]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	'	'	6,274,483	0	6,274,483	0
Sales price per Class F common unit	'	$23.91	'	'	'	'
Discount per Class F common unit	'	2.19	'	'	'	'
Stock Issued During Period, Shares, Issued for Cash	149,000,000	'	'	'	'	'
Remaining amount available to be issued under the Equity Distribution Agreement	$34,000,000	'	'	'	'	'

Partners_Capital_and_Distribut3

Partners' Capital and Distributions Unit Activity (Details)	9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
Common Units [Member]	'	'
Capital Unit [Line Items]	'	'
Limited Partners' Capital Account, Units Outstanding	210,700,852	170,951,457
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures, Net of Tax	35,615	'
Stock Issued During Period, Shares, Issued for Cash	5,712,138	'
Partners' Capital Account, Units, Converted	2,629,223	'
Noncash or Part Noncash Acquisition, Noncash Financial or Equity Instrument Consideration, Shares Issued	31,372,419	'
Class F Units [Member]	'	'
Capital Unit [Line Items]	'	'
Limited Partners' Capital Account, Units Outstanding	6,274,483	0
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures, Net of Tax	0	'
Stock Issued During Period, Shares, Issued for Cash	0	'
Partners' Capital Account, Units, Converted	0	'
Noncash or Part Noncash Acquisition, Noncash Financial or Equity Instrument Consideration, Shares Issued	6,274,483	'

Partners_Capital_and_Distribut4

Partners' Capital and Distributions Quarterly Distributions of Available Cash (Details) (USD $)	3 Months Ended					9 Months Ended
	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Quarterly Distributions of Available Cash [Abstract]	'	'	'	'	'	'	'
Dividends Payable, Date of Record	4-Nov-13	5-Aug-13	6-May-13	7-Feb-13	'	'	'
Dividends Payable, Date of Payment	14-Nov-13	14-Aug-13	13-May-13	14-Feb-13	'	'	'
Distributions per common unit	$0.47	$0.47	$0.46	$0.46	$0.46	$1.40	$1.38

Income_Loss_Per_Limited_Partne2

Income (Loss) Per Limited Partner Unit Reconciliation of Numerator and Denominator of Basic and Diluted Earnings Per Common Unit (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Net Income (Loss) Allocated to Limited Partners	$33		($6)		$40		$41
Income Allocated to Dilutive Securities	'		0	[1]	'		'
Incremental Common Shares Attributable to Written Put Options	32,489		0		23,931		13,113
Incremental Common Shares Attributable to Share-based Payment Arrangements	435,606	[1]	0	[1]	351,811	[1]	320,452	[1]
Incremental Common Shares Attributable to Conversion of Preferred Stock	2,047,571		0		0		4,651,884
Diluted income from continuing operations amount	10		-6		40		38
Weighted average number of common units outstanding	209,559,854		170,264,621		191,334,032		166,368,178
Diluted weighted number of units outstanding	212,075,520		170,264,621		191,709,774		171,353,627
Basic income (loss) per common unit	0.16		-0.04		0.21		0.25
Diluted income (loss) per common unit	0.05		-0.04		0.21		0.22
Common Unit Options	'		'		'		'
Income Allocated to Dilutive Securities	0		'		0		0
Phantom Units	'		'		'		'
Income Allocated to Dilutive Securities	0	[1]	'		0	[1]	0
Series A Preferred Stock [Member]	'		'		'		'
Income Allocated to Dilutive Securities	($23)		'		$0		($3)
[1]	Amount assumes maximum conversion rate for market condition awards.

Income_Loss_Per_Limited_Partne3

Income (Loss) Per Limited Partner Unit Antidilutive Securities Excluded from Computations of Earnings Per Unit (Details)	3 Months Ended	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2013
Common Unit Options	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	9,147	0
Phantom Units	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	313,378	0
Series A Preferred Stock [Member]	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	4,651,884	2,047,571

Investment_In_Unconsolidated_A2

Investment In Unconsolidated Affiliates Narrative (Details)	Sep. 30, 2013
HPC [Member]	'
Ownership in affiliate	49.99%
MEP {Member]	'
Ownership in affiliate	50.00%
Lone Star {Member]	'
Ownership in affiliate	30.00%
Ranch JV {Member]	'
Ownership in affiliate	33.33%
Grey Ranch JV [Member]	'
Ownership in affiliate	50.00%

Investment_In_Unconsolidated_A3

Investment In Unconsolidated Affiliates Carrying Value of Unconsolidated Affiliates (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Equity Method Investments	$2,081	$2,214
HPC [Member]	'	'
Equity Method Investments	448	650
MEP {Member]	'	'
Equity Method Investments	556	581
Lone Star {Member]	'	'
Equity Method Investments	1,040	948
Ranch JV {Member]	'	'
Equity Method Investments	36	35
Grey Ranch JV [Member]	'	'
Equity Method Investments	$1	$0

Investment_In_Unconsolidated_A4

Investment In Unconsolidated Affiliates Changes In Partnership's Investment (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Proceeds from Equity Method Investment, Dividends or Distributions	'	'	$108	$92	'
Income (Loss) from Equity Method Investments	37	21	103	87	'
Line of Credit Facility, Maximum Borrowing Capacity	-1,200	'	-1,200	'	-1,150
Equity Interest pledged by Regency Energy Partners LP in Regency Intrastate Gas LP	49.99%	'	'	'	'
Line of Credit Facility, Amount Outstanding	176	'	176	'	192
Guarantor Obligations, Maximum Exposure, Undiscounted	222	'	222	'	'
HPC [Member]	'	'	'	'	'
Investments in and Advances to Affiliates, at Fair Value, Gross Additions	0	0	0	0	'
Proceeds from Equity Method Investment, Dividends or Distributions	-196	-16	-226	-46	'
Income (Loss) from Equity Method Investments	9	3	28	28	'
Amortization Of Excess Fair Value Of Unconsoldated Affilaite	-1	-1	-4	-4	'
Line of Credit Facility, Maximum Borrowing Capacity	500	'	500	'	'
Borrowing Amount for Return of Capital Distribution	370	'	'	'	'
Line of Credit Facility, Amount Outstanding	445	'	445	'	'
MEP {Member]	'	'	'	'	'
Investments in and Advances to Affiliates, at Fair Value, Gross Additions	0	0	0	0	'
Proceeds from Equity Method Investment, Dividends or Distributions	-18	-18	-56	-56	'
Income (Loss) from Equity Method Investments	11	10	31	31	'
Amortization Of Excess Fair Value Of Unconsoldated Affilaite	0	0	0	0	'
Lone Star {Member]	'	'	'	'	'
Investments in and Advances to Affiliates, at Fair Value, Gross Additions	51	78	100	253	'
Proceeds from Equity Method Investment, Dividends or Distributions	-16	-21	-56	-39	'
Income (Loss) from Equity Method Investments	18	9	48	32	'
Amortization Of Excess Fair Value Of Unconsoldated Affilaite	0	0	0	0	'
Ranch JV {Member]	'	'	'	'	'
Investments in and Advances to Affiliates, at Fair Value, Gross Additions	1	10	2	33	'
Proceeds from Equity Method Investment, Dividends or Distributions	-1	0	-1	0	'
Income (Loss) from Equity Method Investments	0	0	0	0	'
Amortization Of Excess Fair Value Of Unconsoldated Affilaite	0	0	0	0	'
Non-recurring Distribution [Member]	'	'	'	'	'
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	'	'	$185	'	'

Investment_In_Unconsolidated_A5

Investment In Unconsolidated Affiliates Selected I/S Data for each of the Unconsolidated Affiliates (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
HPC [Member]	'	'	'	'
Equity method investments, total revenues	$38	$42	$116	$130
Equity method investments, operating income	19	21	58	71
Equity method investments, net income	18	6	56	55
MEP {Member]	'	'	'	'
Equity method investments, total revenues	66	65	194	196
Equity method investments, operating income	34	33	101	101
Equity method investments, net income	21	21	63	63
Lone Star {Member]	'	'	'	'
Equity method investments, total revenues	537	165	1,320	490
Equity method investments, operating income	61	31	162	110
Equity method investments, net income	61	31	160	110
Ranch JV {Member]	'	'	'	'
Equity method investments, total revenues	4	0	10	0
Equity method investments, operating income	1	-1	2	-1
Equity method investments, net income	$1	($1)	$2	($1)

Derivative_Instruments_Narrati

Derivative Instruments Narrative (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Outstanding borrowings in interest rate risk	$176	$192
Maximum	'	'
Credit risk of derivatives	7	'
Reduction in credit risk of derivatives due to netting feature	$2	'

Derivative_Instruments_Schedul

Derivative Instruments Schedule Of Derivative Assets And Liabilities (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivative Asset, Fair Value, Gross Asset	$7	$5
Derivative Liability, Fair Value, Gross Liability	28	31
Derivatives Designated as Cash Flow Hedges [Member] | Commodity Derivatives	'	'
Derivative Asset, Fair Value, Gross Asset	0	0
Derivative Liability, Fair Value, Gross Liability	0	5
Current | Derivatives Designated as Cash Flow Hedges [Member] | Commodity Derivatives	'	'
Derivative Asset, Fair Value, Gross Asset	0	0
Derivative Liability, Fair Value, Gross Liability	0	5
Current | Derivatives Not Designated as Cash Flow Hedges [Member] | Commodity Derivatives	'	'
Derivative Asset, Fair Value, Gross Asset	6	4
Derivative Liability, Fair Value, Gross Liability	5	1
Long Term | Derivatives Not Designated as Cash Flow Hedges [Member] | Commodity Derivatives	'	'
Derivative Asset, Fair Value, Gross Asset	1	1
Derivative Liability, Fair Value, Gross Liability	0	0
Long Term | Derivatives Not Designated as Cash Flow Hedges [Member] | Embedded Derivatives in Series A Preferred Units [Member]	'	'
Derivative Asset, Fair Value, Gross Asset	0	0
Derivative Liability, Fair Value, Gross Liability	$23	$25

Derivative_Instruments_IS_Impa

Derivative Instruments I/S Impact of Derivative Instruments (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	$0	($6)	$0	$5
Derivatives in Cash Flow Hedging Relationship [Member] | Commodity Derivatives | Revenues	'	'	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	0	6	0	12
Derivatives Not Designated In a Hedging Relationships	'	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Income, Net	14	-3	2	24
Derivatives Not Designated In a Hedging Relationships | Commodity Derivatives | Revenues	'	'	'	'
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	'	'	0	-6
Derivative Instruments, Gain (Loss) Recognized in Income, Net	-10	-5	0	14
Derivatives Not Designated In a Hedging Relationships | Embedded Derivatives in Series A Preferred Units [Member] | Other Income and Deductions, Net	'	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Income, Net	$24	$2	$2	$10

LongTerm_Debt_Narrative_Detail

Long-Term Debt Narrative (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

31-May-13

Sep. 30, 2013

Sep. 30, 2013

Apr. 30, 2013

Sep. 04, 2013

Sep. 30, 2013

Sep. 30, 2013

Apr. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

In Millions, unless otherwise specified

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

9.375% Senior Notes Due 2016

9.375% Senior Notes Due 2016

5.75% Senior Notes Due 2020 [Member]

5.75% Senior Notes Due 2020 [Member]

5.75% Senior Notes Due 2020 [Member]

4.5% Senior Notes Due Two Thousand Twenty Three [Member]

4.5% Senior Notes Due Two Thousand Twenty Three [Member]

4.5% Senior Notes Due Two Thousand Twenty Three [Member]

5.75% Senior Notes Due 2020 [Member]

Redemption Before June 1, 2020 [Member]

Redemption After June 1, 2020 [Member]

Redemption Before August 1, 2023

Redemption After August 1, 2023

4.5% Senior Notes Due Two Thousand Twenty Three [Member]

Long-term debt weighted-average interest rate

'

'

'

2.19%

'

'

'

'

'

'

'

'

'

Revolving credit facility maximum allowable additional borrowings

$1,200

$1,150

$1,200

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Additional Borrowing Capacity

'

'

300

'

'

'

'

'

'

'

'

'

'

Acquisition threshold amount for an increase in the permitted Total Leverage Ratio for the revolver

'

'

'50

'

'

'

'

'

'

'

'

'

'

Write off of Deferred Debt Issuance Cost

'

'

'

1

'

'

'

'

'

'

'

'

'

Deferred Finance Costs, Net

'

'

'

7

'

'

'

'

'

'

'

'

'

Debt Instrument, Face Amount

'

'

'

'

'

'

400

'

'

600

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

9.38%

5.75%

'

'

4.50%

'

'

'

Senior Note Redemption Percentage

'

'

'

'

'

'

'

100.00%

100.00%

'

100.00%

100.00%

101.00%

Indenture Terms, Days of Rating Decline

'

'

'

'

'

'

'

'

'

'

'

'

'90

Repayments of Long-term Debt

'

'

'

'

163

'

'

'

'

'

'

'

'

Senior Note Redemption Price

'

'

'

'

178

'

'

'

'

'

'

'

'

Debt Instrument, Increase, Accrued Interest

'

'

'

'

$7

'

'

'

'

'

'

'

'

LongTerm_Debt_Partnerships_Lon

Long-Term Debt Partnership's Long-Term Debt Schedule (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Long-Term Debt Disclosure [Abstract]	'	'
Senior notes	$2,800	$1,965
Revolving loans	176	192
Total	2,976	2,157
Less: current portion	0	0
Long-term debt	2,976	2,157
Availability under revolving loans	-176	-192
Total credit facility limit	-1,200	-1,150
Letters of credit	-15	-12
Total available	($1,009)	($946)

LongTerm_Debt_LongTerm_Debt_Ma

Long-Term Debt Long-Term Debt Maturities Schedule (Details) (USD $)	Sep. 30, 2013
In Millions, unless otherwise specified
Long-Term Debt Disclosure [Abstract]	'
2013 (remainder)	$0
2014	0
2015	0
2016	0
2017	0
Thereafter	2,976
Total	$2,976

Commitments_And_Contingencies_1

Commitments And Contingencies Narrative (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Environmental Remediation Expense	$4
Accrual for Environmental Loss Contingencies	$1

Commitments_And_Contingencies_2

Commitments And Contingencies Environmental Remediation Schedule (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Commitments and Contingencies Disclosure [Abstract]	'	'
Accrued Environmental Loss Contingencies, Current	$2	$5
Accrued Environmental Loss Contingencies, Noncurrent	7	7
Accrual for Environmental Loss Contingencies	$9	$12

Series_A_Preferred_Units_Narra

Series A Preferred Units Narrative (Details) (USD $)	3 Months Ended	9 Months Ended		3 Months Ended	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Sep. 30, 2013
				Series A Preferred Stock [Member]	Series A Preferred Stock [Member]
Gain Recognized from Conversion of Series A Preferred Units	'	$26,000,000	'	'	'
Conversion of Stock, Amount Converted	'	-41,000,000	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	'	'	'	4,651,884	2,047,571
Temporary Equity, Shares Issued	1,912,569	1,912,569	4,371,586	'	'
Quarterly Cash Distribution for Series A Preferred Units	$0.45	'	'	'	'

Series_A_Preferred_Units_Recon

Series A Preferred Units Reconciliation of Beginning and Ending Balances of Series A Preferred Units (Details) (USD $)	9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 02, 2029	Dec. 31, 2012
Temporary Equity Disclosure [Abstract]	'	'	'
Redemption Amount for Series A Preferred Units	'	$35	'
Temporary Equity, Shares Issued	1,912,569	'	4,371,586
Series A preferred units, redemption amounts of $37 and $85	32	'	73
Conversion of Stock, Shares Converted	-2,459,017	'	'
Conversion of Stock, Amount Converted	41	'	'
Temporary Equity, Accretion to Redemption Value	$0	'	'

Related_Party_Transactions_Nar

Related Party Transactions Narrative (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Cash distributions received	'	'	$282	$240	'
Due from Related Parties	18	'	18	'	8
General and administrative, including related party amounts of $2, $4, $9 and $13	13	21	64	78	'
ETE	'	'	'	'	'
Related Party Transaction, Expenses from Transactions with Related Party	2	4	9	13	'
Cash distributions received	16	16	47	46	'
ETE | May Twenty Six Service Agreement	'	'	'	'	'
Management Fee, Amount Paid	10	'	'	'	'
ETP [Member]	'	'	'	'	'
Purchase of compression equipment	39	'	76	'	'
HPC [Member]	'	'	'	'	'
General and administrative, including related party amounts of $2, $4, $9 and $13	4	5	14	14	'
ETE And Its Subsidiaries [Member]	'	'	'	'	'
Related Party Transaction, Amounts of Transaction	5	'	'	'	'
Due from Related Parties	$17	'	$17	'	$5

Related_Party_Transactions_Rel

Related Party Transactions Related Party Receivables and Payables (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Related Party Transaction [Line Items]	'	'
Related party receivables	$18	$8
Related party payables	57	95
HPC [Member]	'	'
Related Party Transaction [Line Items]	'	'
Related party receivables	1	1
Related party payables	1	1
ETE And Its Subsidiaries [Member]	'	'
Related Party Transaction [Line Items]	'	'
Related party receivables	17	5
Related party payables	56	94
Ranch JV {Member]	'	'
Related Party Transaction [Line Items]	'	'
Related party receivables	$0	$2

Segment_Information_Narrative_

Segment Information Narrative (Details)	Sep. 30, 2013
HPC [Member]	'
Total general partner interest	49.99%
MEP {Member]	'
Total general partner interest	50.00%
Lone Star {Member]	'
Total general partner interest	30.00%
Ranch JV {Member]	'
Total general partner interest	33.33%

Segment_Information_Operating_

Segment Information Operating Results for Each Segment (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
External Revenues	$665	$527	$1,844	$1,413
Intersegment Revenues	0	0	0	0
Segment Margin	188	158	535	454
Operation and maintenance	78	61	220	159
Gathering and Processing	'	'	'	'
External Revenues	603	475	1,671	1,262
Intersegment Revenues	0	0	0	0
Segment Margin	136	110	383	314
Operation and maintenance	63	50	177	125
Natural Gas Transportation	'	'	'	'
External Revenues	0	0	0	0
Intersegment Revenues	0	0	0	0
Segment Margin	0	0	0	1
Operation and maintenance	0	0	0	0
NGL Services	'	'	'	'
External Revenues	0	0	0	0
Intersegment Revenues	0	0	0	0
Segment Margin	0	0	0	0
Operation and maintenance	0	0	0	0
Contract Services	'	'	'	'
External Revenues	58	47	159	137
Intersegment Revenues	4	5	11	15
Segment Margin	52	48	149	140
Operation and maintenance	19	16	53	49
Corporate	'	'	'	'
External Revenues	4	5	14	14
Intersegment Revenues	0	0	0	0
Segment Margin	4	5	14	14
Operation and maintenance	0	0	1	0
Eliminations	'	'	'	'
External Revenues	0	0	0	0
Intersegment Revenues	-4	-5	-11	-15
Segment Margin	-4	-5	-11	-15
Operation and maintenance	($4)	($5)	($11)	($15)

Segment_Information_Reconcilia

Segment Information Reconciliation of Total Segment Margin to Income (Loss) Before Income Taxes (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Segment Margin	$188	$158	$535	$454
Operation and maintenance	-78	-61	-220	-159
General and administrative, including related party	-13	-21	-64	-78
(Gain) loss on asset sales, net	1	0	-1	-2
Depreciation and amortization	-74	-71	-207	-193
Income (Loss) from Equity Method Investments	37	21	103	87
Interest Expense	-41	-29	-119	-86
Gains (Losses) on Extinguishment of Debt	0	0	-7	-8
Other income and deductions, net	24	1	3	26
INCOME (LOSS) BEFORE INCOME TAXES	44	-2	23	41
Customer Contracts [Member]	'	'	'	'
Other income and deductions, net	'	'	'	$16

Segment_Information_Total_Segm

Segment Information Total Segment Assets (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Segment Reporting Information	'	'
Total assets	$8,566	$8,123
Gathering and Processing	'	'
Segment Reporting Information	'	'
Total assets	4,631	4,210
Natural Gas Transportation	'	'
Segment Reporting Information	'	'
Total assets	1,005	1,232
NGL Services	'	'
Segment Reporting Information	'	'
Total assets	1,040	948
Contract Services [Member]	'	'
Segment Reporting Information	'	'
Total assets	1,812	1,672
Corporate and Others	'	'
Segment Reporting Information	'	'
Total assets	$78	$61

Segment_Information_Investment

Segment Information Investment in Unconsolidated Affiliates (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Segment Reporting Information	'	'
Investment in unconsolidated affiliates	$2,081	$2,214
Gathering and Processing	'	'
Segment Reporting Information	'	'
Investment in unconsolidated affiliates	37	35
Natural Gas Transportation	'	'
Segment Reporting Information	'	'
Investment in unconsolidated affiliates	1,004	1,231
NGL Services	'	'
Segment Reporting Information	'	'
Investment in unconsolidated affiliates	$1,040	$948

EquityBased_Compensation_Narra

Equity-Based Compensation Narrative (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Equity-Based Compensation [Abstract]	'	'	'	'
Partnership's LTIP units	5,865,584	'	5,865,584	'
Share-based Compensation	$2	$1	$5	$3
Partnership expects to recognize compensation expense	$20	'	$20	'
Non-vested phantom units period, in years	'	'	'3 years 6 months	'

EquityBased_Compensation_Phant

Equity-Based Compensation Phantom Units Activity (Details) (Phantom Units, USD $)	9 Months Ended
	Sep. 30, 2013
Phantom Units	'
Outstanding at the beginning of the period, Units	1,231,342
Service condition grants, Units	52,360
Vested service condition, Units	-45,158
Forfeited service condition, Units	-25,900
Forfeited market condition, Units	-44,397
Outstanding at the end of period, Units	1,168,247
Outstanding at the beginning of the period, Weighted Average Grant Date Fair Value	$23.22
Service condition grants, Weighted Average Grant Date Fair Value	$25.30
Vested service condition, Weighted Average Grant Date Fair Value	$24.34
Forfeited service condition, Weighted Average Grant Date Fair Value	$23.29
Forfeited market condition, Weighted Average Grant Date Fair Value	$19.52
Outstanding at the end of the period, Weighted Average Grant Date Fair Value	$23.41

Fair_Value_Measures_Narrative_

Fair Value Measures Narrative (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Fair Value Measures [Abstract]	'	'
Debt Instrument, Fair Value Disclosure	$2,800,000,000	$2,100,000,000
Unsecured Long-term Debt, Noncurrent	$2,800,000,000	$1,965,000,000

Fair_Value_Measures_FV_of_Part

Fair Value Measures FV of Partnership's Derivative Assets And Liabilities (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value Measurement, Assets	$7	$5
Fair Value Measurement, Liabilities	28	31
Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Assets	7	5
Fair Value Measurement, Liabilities	5	6
Unobservable Inputs (Level 3)	'	'
Fair Value Measurement, Assets	0	0
Fair Value Measurement, Liabilities	23	25
Natural Gas Transportation	'	'
Fair Value Measurement, Assets	6	2
Fair Value Measurement, Liabilities	1	5
Natural Gas Transportation | Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Assets	6	2
Fair Value Measurement, Liabilities	1	5
Natural Gas Transportation | Unobservable Inputs (Level 3)	'	'
Fair Value Measurement, Assets	0	0
Fair Value Measurement, Liabilities	0	0
NGLs	'	'
Fair Value Measurement, Assets	1	1
Fair Value Measurement, Liabilities	2	1
NGLs | Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Assets	1	1
Fair Value Measurement, Liabilities	2	1
NGLs | Unobservable Inputs (Level 3)	'	'
Fair Value Measurement, Assets	0	0
Fair Value Measurement, Liabilities	0	0
Condensate	'	'
Fair Value Measurement, Assets	0	2
Fair Value Measurement, Liabilities	2	0
Condensate | Significant Observable Inputs (Level 2)	'	'
Fair Value Measurement, Assets	0	2
Fair Value Measurement, Liabilities	2	0
Condensate | Unobservable Inputs (Level 3)	'	'
Fair Value Measurement, Assets	0	0
Fair Value Measurement, Liabilities	0	0
Embedded Derivatives in Series A Preferred Units [Member]	'	'
Embedded Derivatives in Series A Preferred Units	23	25
Embedded Derivatives in Series A Preferred Units [Member] | Significant Observable Inputs (Level 2)	'	'
Embedded Derivatives in Series A Preferred Units	0	0
Embedded Derivatives in Series A Preferred Units [Member] | Unobservable Inputs (Level 3)	'	'
Embedded Derivatives in Series A Preferred Units	$23	$25

Fair_Value_Measures_Significan

Fair Value Measures Significant Unobservable Inputs for FV Estimation of Embedded Derivatives (Details)	Sep. 30, 2013
Fair Value Measures [Abstract]	'
Fair Value, Embedded Derivatives Significant Unobservable Input, Credit Spread	6.39%
Fair Value, Embedded Derivatives Significant Unobservable Input, Volatility	19.96%

Fair_Value_Measures_Valuation_

Fair Value Measures Valuation Changes in Level 3 Derivatives (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Fair Value Measures [Abstract]	'
Beginning balance	$25
Change in fair value	-2
Ending balance	$23