Resources Connection 10-K 27 Feb 14 2013 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Feb. 24, 2014	Jun. 29, 2012
Document And Entity Information [Abstract]	'	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
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	'	214,891,703	'
Preferred Stock, Shares Outstanding	'	6,274,483	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Public Float	'	'	$4,880,664,374
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Current Assets:	'	'
Cash and cash equivalents	$19	$53
Trade accounts receivable	292	222
Related party receivables	28	8
Inventories	42	27
Other current assets	19	30
Total current assets	400	340
Property, Plant and Equipment:	'	'
Gathering and transmission systems	1,671	1,308
Compression equipment	1,627	1,326
Gas plants and buildings	825	568
Other property, plant and equipment	414	377
Construction-in-progress	513	507
Total property, plant and equipment	5,050	4,086
Less accumulated depreciation	-632	-400
Property, plant and equipment, net	4,418	3,686
Other Assets:	'	'
Investments in unconsolidated affiliates	2,097	2,214
Other, net of accumulated amortization of debt issuance costs of $24 and $17	57	43
Total other assets	2,154	2,257
Intangible Assets and Goodwill:	'	'
Intangible assets, net of accumulated amortization of $107 and $77	682	712
Goodwill	1,128	1,128
Total intangible assets and goodwill	1,810	1,840
TOTAL ASSETS	8,782	8,123
Current Liabilities:	'	'
Drafts payable	26	10
Trade accounts payable	291	255
Related party payables	69	95
Accrued interest	38	30
Other current liabilities	51	99
Total current liabilities	475	489
Long-term derivative liabilities	19	25
Other long-term liabilities	30	39
Long-term debt, net	3,310	2,157
Commitments and contingencies	'	'
Series A Preferred Units, redemption amount of $38 and $85	32	73
Partners’ Capital and Noncontrolling Interest:	'	'
Common units (214,287,955 and 174,574,175 units authorized; 210,850,232 and 170,951,457 units issued and outstanding at December 31, 2013 and 2012)	3,886	3,207
Class F common units	146	0
General partner interest	782	326
Predecessor equity	0	1,733
Accumulated other comprehensive loss	0	-3
Total partners’ capital	4,814	5,263
Noncontrolling interest	102	77
Total partners’ capital and noncontrolling interest	4,916	5,340
TOTAL LIABILITIES AND PARTNERS’ CAPITAL AND NONCONTROLLING INTEREST	$8,782	$8,123

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified
Other, accumulated amortization of debt issuance costs	$24	$17
Intangible assets, accumulated amortization	107	77
Series A preferred units, redemption amount	$38	$85
Common units, authorized	214,287,955	174,574,175
Common units, issued	210,850,232	170,951,457
Common units, outstanding	210,850,232	170,951,457
Class F Units [Member]	'	'
Partners' Capital Account, Units	6,274,483	0

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
REVENUES	'	'	'
Gas sales, including related party amounts of $71, $42, and $23	$826	$508	$456
NGL sales, including related party amounts of $81, $28, and $365	1,053	991	603
Gathering, transportation and other fees, including related party amounts of $26, $29, and $24	545	401	351
Net realized and unrealized gain (loss) from derivatives	-8	23	-19
Other, including related party amounts of $-, $1, and $10	105	77	43
Total revenues	2,521	2,000	1,434
OPERATING COSTS AND EXPENSES	'	'	'
Cost of sales, including related party amounts of $56, $35, and $22	1,793	1,387	1,013
Operation and maintenance	296	228	147
General and administrative, including related party amounts of $11, $15, and $17	88	100	67
Loss (gain) on asset sales, net	2	3	-2
Depreciation and amortization	287	252	169
Total operating costs and expenses	2,466	1,970	1,394
OPERATING INCOME	55	30	40
Income from unconsolidated affiliates	135	105	120
Interest expense, net	-164	-122	-103
Loss on debt refinancing, net	-7	-8	0
Other income and deductions, net	7	29	17
INCOME BEFORE INCOME TAXES	26	34	74
Income tax benefit	-1	0	0
NET INCOME	27	34	74
Net income attributable to noncontrolling interest	-8	-2	-2
NET INCOME ATTRIBUTABLE TO REGENCY ENERGY PARTNERS LP	19	32	72
Amounts attributable to Series A preferred units	6	10	8
General partner’s interest, including IDRs	'	9	7
Beneficial conversion feature for Class F units	'	0	0
Pre-acquisition loss from SUGS allocated to predecessor equity	'	-14	0
Limited partners’ interest in net income	34	27	57
Basic and diluted income per common unit:	'	'	'
Weighted average number of common units outstanding	196,227,348	167,492,735	145,490,869
Basic income per common unit	$0.17	$0.16	$0.39
Diluted income per common unit	$0.17	$0.13	$0.32
Distributions per common unit	$1.87	$1.84	$1.81
Amount allocated to Class F units due to beneficial conversion feature	$4	$0	$0
Total number of Class F units outstanding	6,274,483	0	0
Income per Class F unit due to beneficial conversion feature	$0.72	$0	$0

Consolidated_Statements_of_Ope1

Consolidated Statements of Operations (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Gas sales, related party amounts	$71	$42	$23
NGL sales, related party amounts	81	28	365
Gathering, transportation and other fees, related party amounts	26	29	24
Other revenues, related party amounts	0	1	10
Cost of sales, related party amounts	56	35	22
General and administrative, related party amounts	$11	$15	$17

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (Loss) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statement of Comprehensive Income [Abstract]	'	'	'
Net income	$27	$34	$74
Net cash flow hedge amounts reclassified to earnings	0	6	19
Change in fair value of cash flow hedges	0	-4	-13
Total other comprehensive income	0	2	6
Comprehensive income	27	36	80
Comprehensive income attributable to noncontrolling interest	8	2	2
Comprehensive income attributable to Regency Energy Partners LP	$19	$34	$78

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
OPERATING ACTIVITIES	'	'	'
Net income	$27	$34	$74
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	293	259	175
Income from unconsolidated affiliates	-135	-105	-120
Derivative valuation changes	6	-12	-21
Loss (gain) on asset sales, net	2	3	-2
Unit-based compensation expenses	7	5	3
Cash flow changes in current assets and liabilities:	'	'	'
Trade accounts receivable and related party receivables	-96	0	-8
Other current assets and other current liabilities	-54	10	11
Trade accounts payable, related party payables and deferred revenues	119	18	23
Distributions of earnings received from unconsolidated affiliates	142	121	119
Cash flow changes in other assets and liabilities	125	-9	0
Net cash flows provided by operating activities	436	324	254
INVESTING ACTIVITIES	'	'	'
Capital expenditures	-1,034	-560	-406
Capital contributions to unconsolidated affiliates	-148	-356	-53
Distributions in excess of earnings of unconsolidated affiliates	249	83	74
Acquisition of investment in unconsolidated affiliates, net of cash received	0	0	-594
Acquisitions, net of cash received	-475	0	0
Proceeds from asset sales	15	26	24
Net cash flows used in investing activities	-1,393	-807	-955
FINANCING ACTIVITIES	'	'	'
Borrowings (repayments) under revolving credit facility, net	318	-140	47
Proceeds from issuance of senior notes	1,000	700	500
Redemptions of senior notes	-163	-88	0
Debt issuance costs	-24	-15	-10
Partner distributions and distributions on unvested unit awards	-386	-322	-274
Contributions from noncontrolling interest	17	42	0
Contributions from previous parent	0	51	0
Drafts payable	18	4	2
Common units issued under LTIP, net of forfeitures and tax withholding	0	-1	0
Common unit offerings, net of issuance costs	0	297	436
Common units issued under equity distribution program, net of costs	149	15	0
Distributions to Series A Preferred Units	-6	-8	-8
Net cash flows provided by financing activities	923	535	693
Net change in cash and cash equivalents	-34	52	-8
Cash and cash equivalents at beginning of period	53	1	9
Cash and cash equivalents at end of period	19	53	1
Supplemental cash flow information:	'	'	'
Accrued capital expenditures	60	136	24
Issuance of Class F and common units in connection with SUGS Acquisition	961	0	0
Interest paid, net of amounts capitalized	146	112	83
Income taxes paid	0	0	2
Accrued capital contribution to unconsolidated affiliate	$13	$23	$0

Consolidated_Statements_of_Par

Consolidated Statements of Partners' Capital and Noncontrolling Interest (USD $)	Total	Common Unitholders	Class F Units [Member]	General Partner Interest	Predecessor Equity [Member]	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interest
In Millions
Balance at Dec. 31, 2010	$3,294	$2,941	'	$333	'	($11)	$31
Common unit offerings, net of costs	436	436	'	'	'	'	'
Unit-based compensation expenses	3	3	'	'	'	'	'
Partner distributions	-274	-264	'	-10	'	'	'
Net income (loss)	74	65	'	7	'	'	2
Distributions to Series A Preferred Units	-8	-8	'	'	'	'	'
Net cash flow hedge amounts reclassified to earnings	19	'	'	'	'	19	'
Net change in fair value of cash flow hedges	'	'	'	'	'	-13	'
Net change in fair value of cash flow hedges	-13	'	'	'	'	'	'
Common units issued under equity distribution program, net of costs	0	'	'	'	'	'	'
Balance at Dec. 31, 2011	3,531	3,173	'	330	'	-5	33
Common unit offerings, net of costs	297	297	'	'	'	'	'
Unit-based compensation expenses	5	5	'	'	'	'	'
Partner distributions	-322	-309	'	-13	'	'	'
Common units issued under LTIP, net of forfeitures and tax withholding	-1	-1	'	'	'	'	'
Net income (loss)	34	37	'	9	-14	'	2
Contributions from noncontrolling interest	42	'	'	'	'	'	42
Distributions to Series A Preferred Units	-8	-8	'	'	'	'	'
Accretion of Series A Preferred Units	-2	-2	'	'	'	'	'
Net cash flow hedge amounts reclassified to earnings	5	'	'	'	'	5	'
Net change in fair value of cash flow hedges	-4	'	'	'	'	'	'
Common units issued under equity distribution program, net of costs	15	15	'	'	'	'	'
Contribution of net investment to unitholders	1,744	'	'	'	1,747	-3	'
Balance at Dec. 31, 2012	5,340	3,207	'	326	1,733	-3	77
Common unit offerings, net of costs	0	'	'	'	'	'	'
Unit-based compensation expenses	7	7	'	'	'	'	'
Partner distributions	-386	-371	'	-15	'	'	'
Contribution of net investment to the Partnership	'	'	'	1,925	-1,928	3	'
Net income (loss)	27	40	4	-11	-36	0	8
Contributions from noncontrolling interest	17	'	'	'	'	'	17
Distributions to Series A Preferred Units	-6	-6	'	'	'	'	'
Net change in fair value of cash flow hedges	0	'	'	'	'	'	'
Issuance of common units in connection with the SUGS Acquisition, net of costs	'	819	'	-819	'	'	'
Issuance of Class F common units in connection with the SUGS Acquisition, net of costs	'	'	142	-142	'	'	'
Contribution of assets between entities under common control below historical cost	-273	'	'	-504	231	'	'
Common units issued under equity distribution program, net of costs	149	149	'	'	'	'	'
Conversion of Series A Preferred Units for common units	41	41	'	'	'	'	'
Balance at Dec. 31, 2013	$4,916	$3,886	$146	$782	'	'	$102

Organization_and_Basis_of_Pres

Organization and Basis of Presentation (Notes)	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization, Consolidation and Presentation of Financial Statements Disclosure	'
	Organization and Basis of Presentation
	Organization. The consolidated financial statements presented herein contain the results of Regency Energy Partners LP and its subsidiaries (the “Partnership”), a Delaware limited partnership. The Partnership was formed on September 8, 2005, and completed its IPO on February 3, 2006. 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 is the managing general partner of the Partnership and the general partner of Regency GP LP.
	SUGS Acquisition. In April 2013, the Partnership 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 of common units and 6,274,483 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 agreed to forgo IDR payments on the Partnership common units issued with this transaction for the twenty-four months post-transaction closing and to suspend the $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(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 net proceeds of $600 million of senior notes issued by the Partnership on April 30, 2013 in a private placement. In December 2013, these senior notes were exchanged for senior notes that are substantially identical, except that the exchange senior notes are registered under federal securities law and do not have any transfer restrictions. In January 2014, Panhandle Eastern Pipe Line Company, LP (“PEPL”) entered into an agreement and plan of merger with Southern Union and PEPL Holdings, pursuant to which each of Southern Union and PEPL Holdings were merged with and into PEPL, with PEPL as the surviving entity.  In connection with this merger, PEPL assumed the guarantee of collection with respect to the payment of the principal amounts of the senior notes issued.
	The Partnership accounted for the SUGS 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 assets acquired and liabilities assumed in the SUGS Acquisition were as follows:
		30-Apr-13
	Current assets	$	113
	Property, plant and equipment, net	1,608
	Goodwill	337
	Other non-current assets	1
	Total assets acquired	$	2,059
	Less:
	Current liabilities	(93		)
	Non-current liabilities	(36		)
	Net assets acquired	$	1,930
	The following table presents the revenues and net income for the previously separate entities and combined amounts presented herein:
		Years Ended December 31,
		2013			2012
	Revenues:
	Partnership	$	2,253		$	1,339
	SUGS (1)	268			661
	Combined	$	2,521		$	2,000
	Net income (loss):
	Partnership	$	63		$	48
	SUGS (1)	(36		)	(14		)
	Combined	$	27		$	34
	-1	Combined amounts attributable to SUGS include the period from March 26, 2012 to December 31, 2012 for the year ended December 31, 2012, and the period from January 1, 2013 to April 30, 2013 for the year ended December 31, 2013. Subsequent to the closing of the SUGS Acquisition on April 30, 2013, the results of SUGS were attributable to the Partnership.
	Basis of presentation. The consolidated financial statements of the Partnership have been prepared in accordance with GAAP and include the accounts of all controlled subsidiaries after the elimination of all intercompany accounts and transactions. Certain prior year numbers have been conformed to the current year presentation

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	Summary of Significant Accounting Policies
	Use of Estimates. These consolidated financial statements have been prepared in conformity with GAAP, which includes the use of estimates and assumptions 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 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.
	Common Control Transactions. Entities and assets acquired from ETE and its affiliates are accounted for as common control transactions whereby the net assets acquired are combined with the Partnership’s net assets at their historical amounts. If consideration transferred differs from the carrying value of the net assets acquired, the excess or deficiency is treated as a capital transaction similar to a dividend or capital contribution. To the extent that such transactions require prior periods to be recast, historical net equity amounts prior to the transaction date are reflected in predecessor equity.
	Cash and Cash Equivalents. Cash and cash equivalents include temporary cash investments with original maturities of three months or less.
	Equity Method Investments. The equity method of accounting is used to account for the Partnership’s interest in investments of greater than 20% voting interest or where the Partnership exerts significant influence over an investee but lacks control over the investee.
	Inventories. Inventories are valued at the lower of cost or market and include materials and parts primarily utilized by the Contract Services segment.
	Property, Plant and Equipment. Property, plant and equipment is recorded at historical cost of construction or, upon acquisition, the fair value of the assets acquired. Gains or losses on sales or retirements of assets are included in operating income unless the disposition is treated as discontinued operations. Natural gas and NGLs used to maintain pipeline minimum pressures is and classified as property, plant and equipment. Financing costs associated with the construction of larger assets requiring ongoing efforts over a period of time are capitalized. For the years ended December 31, 2013, 2012 and 2011, the Partnership capitalized interest of $2 million, $1 million and $1 million, respectively. The costs of maintenance and repairs, which are not significant improvements, are expensed when incurred. Expenditures to extend the useful lives of the assets are capitalized.
	Depreciation expense related to property, plant and equipment was $258 million, $219 million, and $138 million for the years ended December 31, 2013, 2012 and 2011, respectively. In March 2012, the Partnership recorded a $7 million “out-of-period” adjustment to depreciation expense to correct the estimated useful lives of certain assets to comply with its policy.
	Depreciation of property, plant and equipment is recorded on a straight-line basis over the following estimated useful lives:
	Functional Class of Property	Useful Lives (Years)
	Gathering and Transmission Systems	Oct-50
	Compression Equipment	Feb-30
	Gas Plants and Buildings	May-35
	Other property, plant and equipment	15-Mar
	Intangible Assets. As of December 31, 2013, intangible assets consisted of trade names and customer relations, and are amortized on a straight line basis over their estimated useful lives, which is the period over which the assets are expected to contribute directly or indirectly to the Partnership’s future cash flows. The estimated useful lives range from 20 to 30 years.
	The Partnership assesses long-lived assets, including property, plant and equipment and intangible assets, for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability is assessed by comparing the carrying amount of an asset to undiscounted future net cash flows expected to be generated by the asset. If such assets are considered to be impaired, the impairment to be recognized is measured as the amount by which the carrying amounts exceed the fair value of the assets. The Partnership did not record any impairment in 2013, 2012 or 2011.
	Goodwill. Goodwill represents the excess of the purchase price over the fair value of identifiable net assets acquired in a business combination. Goodwill is not amortized, but is tested for impairment annually based on the carrying values as of November 30 or December 31 depending upon the reporting unit, or more frequently if impairment indicators arise that suggest the carrying value of goodwill may not be recovered. The Partnership has the option to first assess qualitative factors to determine whether it is more likely than not that the fair value of the reporting unit is less than its carrying amount as a basis for determining whether further impairment testing is necessary. Impairment is indicated when the carrying amount of a reporting unit exceeds its fair value. To estimate the fair value of the reporting units, the Partnership makes estimates and judgments about future cash flows, as well as revenues, cost of sales, operating expenses, capital expenditures and net working capital based on assumptions that are consistent with the Partnership’s most recent forecast. At the time it is determined that an impairment has occurred, the carrying value of the goodwill is written down to its fair value. The Partnership did not record any impairment in 2013, 2012 or 2011.
	Other Assets, net. Other assets, net primarily consists of debt issuance costs, which are capitalized and amortized to interest expense, net over the life of the related debt.
	Gas Imbalances. Quantities of natural gas or NGLs over-delivered or under-delivered related to imbalance agreements are recorded monthly as other current assets or other current liabilities using then current market prices or the weighted average prices of natural gas or NGLs at the plant or system pursuant to imbalance agreements for which settlement prices are not contractually established. Within certain volumetric limits determined at the sole discretion of the creditor, these imbalances are generally settled by deliveries of natural gas. Imbalance receivables and payables as of December 31, 2013 and 2012 were immaterial.
	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 were immaterial as of December 31, 2013.
	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 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.
	Predecessor Equity. Predecessor equity included on the consolidated statement of partners' capital and noncontrolling interest represents SUGS member's capital prior to the acquisition date (April 30, 2013).
	Revenue Recognition. The Partnership earns revenue from (i) domestic sales of natural gas, NGLs and condensate, (ii) natural gas gathering, processing and transportation, and (iii) contract compression and treating services. Revenue associated with sales of natural gas, NGLs and condensate are recognized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery occurs. Revenue associated with transportation and processing fees are recognized when the service is provided. For contract compression and contract treating services, revenue is recognized when the service is performed. For gathering and processing services, the Partnership receives either fees or commodities from natural gas producers depending on the type of contract. Commodities received are in turn sold and recognized as revenue in accordance with the criteria outlined above. Under the percentage-of-proceeds contract type, the Partnership is paid for its services by keeping a percentage of the NGLs produced and a percentage of the residue gas resulting from processing the natural gas. Under the percentage-of-index contract type, the Partnership earns revenue by purchasing wellhead natural gas at a percentage of the index price and selling processed natural gas and NGLs at a price approximating the index price to third parties. The Partnership generally reports revenue gross in the consolidated statements of operations when it acts as the principal, takes title to the product, and incurs the risks and rewards of ownership. Revenue for fee-based arrangements is presented net, because the Partnership takes the role of an agent for the producers. Allowance for doubtful accounts is determined based on historical write-off experience and specific identification.
	Derivative Instruments. The Partnership's net income and cash flows are subject to volatility stemming from changes in market prices such as natural gas prices, NGLs prices, processing margins and interest rates. The Partnership uses product-specific swaps to create offsetting positions to specific commodity price exposures, and uses interest rate swap contracts to create offsetting positions to specific interest rate exposures. Derivative financial instruments are recorded on the balance sheet at their fair value based on their settlement date. The Partnership employs derivative financial instruments in connection with an underlying asset, liability and/or anticipated transaction and not for speculative purposes. Furthermore, the Partnership regularly assesses the creditworthiness of counterparties to manage the risk of default. Derivative financial instruments qualifying for hedge accounting treatment may be designated by the Partnership as cash flow hedges. The Partnership enters into cash flow hedges to hedge the variability in cash flows related to a forecasted transaction. At inception, the Partnership formally documents the relationship between the hedging instrument and the hedged item, the risk management objectives, and the methods used for assessing and testing correlation and hedge effectiveness. The Partnership also assesses, both at the inception of the hedge and on an on-going basis, whether the derivatives are highly effective in offsetting changes in cash flows of the hedged item. If the Partnership determines that a derivative is no longer highly effective as a hedge, it would discontinues hedge accounting prospectively by including changes in the fair value of the derivative in current earnings. For cash flow hedges, changes in the derivative fair values, to the extent that the hedges are effective, are recorded as a component of accumulated other comprehensive income (loss) until the hedged transactions occur and are recognized in earnings. Any ineffective portion of a cash flow hedge's change in value is recognized immediately in earnings. In the statement of cash flows, the effects of settlements of derivative instruments are classified consistent with the related hedged transactions.
	Benefits. The Partnership provides medical, dental, and other healthcare benefits to employees. The total amount incurred by the Partnership for the years ended December 31, 2013, 2012 and 2011, was $9 million, $9 million and $6 million, respectively, in operation and maintenance and general and administrative expenses, as appropriate. The Partnership also provides a matching contribution to its employee’s 401(k) accounts. Effective January 1, 2011, the Partnership’s 401(k) plan merged with and into that of ETP. As a result of the merger, the Partnership’s matching contributions that had not yet fully vested became fully vested. All future matching contributions from the Partnership to the employee 401(k) accounts vest immediately. In addition, SUGS maintained a separate defined contribution plan during March 26, 2012 to December 31, 2012. The total amount of matching contributions for the years ended December 31, 2013, 2012 and 2011 was $7 million, $4 million and $3 million, respectively, and were recorded in operation and maintenance and general and administrative expenses as appropriate. The Partnership has no pension obligations or other post-employment benefits. Beginning January 1, 2013, the Partnership provides a 3% profit sharing contribution to employee 401(k) accounts for all employees with base compensation below a specified threshold. The contribution is in addition to the 401(k) matching contribution and employees become vested based on years of service.
	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 has deferred tax liabilities of $22 million as of December 31, 2013 and 2012 related to the difference between the book and tax basis of property, plant and equipment and intangible assets and they are 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 December 31, 2013 and 2012. The Partnership recognized an immaterial amount for current federal income tax expense and deferred income tax benefit for the years ended December 31, 2013, 2012, and 2011.
	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, SUGS’s operations are now treated as a pass-through entity. Therefore, other than one wholly-owned subsidiary, SUGS’s 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.
	The IRS commenced audits of our 2007 and 2008 federal income tax returns on January 27, 2010. The IRS has now completed its audit of these returns and proposed certain adjustments. The Partnership filed a protest with the IRS to initiate the appeals process and appeal certain of these adjustments. Until this matter is fully resolved, it is not known whether any amounts ultimately recorded would be material, or how such adjustments would affect unitholders. The statute of limitations for these audits has been extended to December 31, 2014. In January 2014, the Partnership settled the 2007 through 2009 tax returns audit for a wholly-owned subsidiary for an immaterial amount.
	Equity-Based Compensation. The Partnership accounts for equity-based compensation by recognizing the grant-date fair value of awards into expense as they are earned, using an estimated forfeiture rate. The forfeiture rate assumption is reviewed annually to determine whether any adjustments to expense are required.
	Earnings per Unit. Basic net income per common unit is computed through the use of the two-class method, which allocates earnings to each class of equity security based on their participation in distributions and deemed distributions. Accretion of the Series A Preferred Units is considered as deemed distributions. Distributions and deemed distributions to the Series A Preferred Units reduce the amount of net income available to the general partner and limited partner interests. The general partners’ interest in net income or loss consists of its respective percentage interest, make-whole allocations for any losses allocated in a prior tax year and IDRs. After deducting the General Partner’s interest, the limited partners’ interest in the remaining net income or loss is allocated to each class of equity units based on distributions and beneficial conversion feature amounts, if applicable, then divided by the weighted average number of common and subordinated units outstanding in each class of security. Diluted net income per common unit is computed by dividing limited partners’ interest in net income, after deducting the General Partner’s interest, by the weighted average number of units outstanding and the effect of non-vested phantom units, Series A Preferred Units and unit options. For special classes of common units, such as the Class F units issued with a beneficial conversion feature, the amount of the benefit associated with the period is added back to net income and the unconverted class is added to the denominator.

Partners_Capital_and_Distribut

Partners' Capital and Distributions	12 Months Ended
	Dec. 31, 2013
Partners’ Capital and Distributions [Abstract]	'
Partners' Capital and Distributions	'
	Partners’ Capital and Distributions
	Units Activity. The changes in common and Class F units were as follows:
		Common			Class F
	Balance - December 31, 2010	137,281,336			—
	Common unit offerings, net of costs	20,000,001			—
	Issuance of common units under LTIP, net of forfeitures and tax withholding	156,271			—
	Balance - December 31, 2011	157,437,608			—
	Common unit offerings, net of costs	12,650,000			—
	Issuance of common units under the equity distribution agreement, net of cost	691,129			—
	Issuance of common units under LTIP, net of forfeitures and tax withholding	172,720			—
	Balance - December 31, 2012	170,951,457			—
	Issuance of common units under LTIP, net of forfeitures and tax withholding	184,995			—
	Issuance of common units under the equity distribution agreement, net of cost	5,712,138			—
	Conversion of Series A preferred units for common 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 - December 31, 2013	210,850,232			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. In June 2012, the Partnership entered into an Equity Distribution Agreement with Citi under which the Partnership may offer and sell common units, representing limited partner interests, having an aggregate offering price of up to $200 million, from time to time through Citi, as sales agent for the Partnership. Sales of these units, if any, made from time to time under the Equity Distribution Agreement will be made by means of ordinary brokers’ transactions on the New York Stock Exchange at market prices, in block transactions, or as otherwise agreed upon by the Partnership and Citi. The Partnership may also sell common units to Citi as principal for its own account at a price agreed upon at the time of sale. Any sale of common units to Citi as principal would be pursuant to the terms of a separate agreement between the Partnership and Citi. The Partnership intends to use the net proceeds from the sale of these units for general partnership purposes. For the years ended December 31, 2013 and 2012, the Partnership received net proceeds of $149 million and $15 million, respectively, from units issued pursuant to this Equity Distribution Agreement. As of December 31, 2013, $34 million remains available to be issued under this agreement.
	Public Common Unit Offerings. In March 2012, the Partnership issued 12,650,000 common units representing limited partner interests in a public offering at a price of $24.47 per common unit, resulting in net proceeds of $297 million. In May 2012, the Partnership used the net proceeds from this offering to redeem 35%, or $88 million, in aggregate principal amounts of its outstanding senior notes due 2016; pay related premium, expenses and accrued interest; and repay outstanding borrowings under the revolving credit facility. In August 2010, the Partnership sold 17,537,500 common units and received $408 million in proceeds, inclusive of the General Partner’s proportionate capital contribution. In October 2011, the Partnership issued 11,500,000 common units representing limited partnership interests in a public offering at a price of $20.92 per common unit, resulting in net proceeds of $232 million which were used to repay outstanding borrowings under the revolving credit facility.
	Private Common Unit Offerings. In May 2011, the Partnership sold 8,500,001 common units representing limited partnership interests resulting in net proceeds of $204 million, to partially fund its capital contribution to Lone Star. These units were issued in a private placement conducted in accordance with the exemption from the registration requirements of the Securities Act of 1933, as amended, under section 4(2) thereof. These units were subsequently registered with the SEC.
	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 per unit 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.
	Noncontrolling Interest. The Partnership operates ELG, a gas gathering joint venture in south Texas in which other third party companies own a 40% interest, which is reflected on the Partnership’s consolidated balance sheet as noncontrolling interest.
	Distributions. The partnership agreement requires the distribution of all of the Partnership’s Available Cash (defined below) within 45 days after the end of each quarter to unitholders of record on the applicable record date, as determined by the General Partner.
	Available Cash. Available Cash, for any quarter, generally consists of all cash and cash equivalents on hand at the end of that quarter less the amount of cash reserves established by the general partner to: (i) provide for the proper conduct of the Partnership’s business; (ii) comply with applicable law, any debt instruments or other agreements; or (iii) provide funds for distributions to the unitholders and to the General Partner for any one or more of the next four quarters and plus, all cash on hand on that date of determination of available cash for the quarter resulting from working capital borrowings made after the end of the quarter for which the determination is being made.
	General Partner Interest and Incentive Distribution Rights. The General Partner is entitled to its proportionate share of all quarterly distributions that the Partnership makes prior to its liquidation. The General Partner has the right, but not the obligation, to contribute a proportionate amount of capital to the Partnership to maintain its current general partner interest. The General Partner’s initial 2% interest in these distributions has been reduced since the Partnership has issued additional units and the General Partner has not contributed a proportionate amount of capital to the Partnership to maintain its General Partner interest. The General Partner ownership interest as of December 31, 2013 was 1.3%. This General Partner interest is represented by 2,834,381 equivalent units as of December 31, 2013.
	The IDRs held by the General Partner entitle it to receive an increasing share of Available Cash when pre-defined distribution targets are achieved. The General Partner’s IDRs are not reduced if the Partnership issues additional units in the future and the general partner does not contribute a proportionate amount of capital to the Partnership to maintain its general partner interest.
	In connection with the SUGS Acquisition, ETE agreed to forgo IDR payments on the Partnership common units issued with this transaction for the twenty-four months post-transaction closing.
	Distributions. The Partnership made the following cash distributions per unit during the years ended December 31, 2013 and 2012:
	Distribution Date		Cash Distribution
			(per common unit)
	November 14, 2013		$	0.47
	August 14, 2013		0.465
	May 13, 2013		0.46
	February 14, 2013		0.46
	November 14, 2012		$	0.46
	August 14, 2012		0.46
	May 14, 2012		0.46
	February 13, 2012		0.46
	The Partnership paid a cash distribution of $0.475 per common unit on February 14, 2014.

Income_Per_Limited_Partner_Uni

Income Per Limited Partner Unit (Notes)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Income (Loss) Per Limited Partner Unit	'
	Income per Limited Partner Unit
	The following table provides a reconciliation of the numerator and denominator of the basic and diluted earnings per unit computations for the years ended December 31, 2013, 2012, and 2011.
		For the Years Ended December 31,
		2013					2012						2011
		Income		Units	Per-Unit		Income			Units	Per-Unit		Income			Units	Per-Unit
		(Numerator)		(Denominator)	Amount		(Numerator)			(Denominator)	Amount		(Numerator)			(Denominator)	Amount
	Basic income per unit
	Limited Partners’ interest in net income	$	34	196,227,348	$	0.17	$	27		167,492,735	$	0.16	$	57		145,490,869	$	0.39
	Effect of Dilutive Securities:
	Common unit options	—		22,714			—			10,854			—			19,192
	Phantom units *	—		357,230			—			223,325			—			148,388
	Series A Preferred Units	—		2,050,854			(5		)	4,658,700			(10		)	4,632,389
	Diluted income per unit	$	34	198,658,146	$	0.17	$	22		172,385,614	$	0.13	$	47		150,290,838	$	0.32
	__________________
	*	Amount assumes maximum conversion rate for market condition awards.
	There were no securities that could potentially dilute earnings per unit in the future that were not included in the computation of diluted earnings per unit.
	The partnership agreement requires that the General Partner shall receive a 100% allocation of income until its capital account is made whole for all of the net losses allocated to it in prior years.

Acquisitions_And_Dispositions

Acquisitions And Dispositions	12 Months Ended
	Dec. 31, 2013
Acquisitions and Dispositions [Abstract]	'
Acquisitions and Dispositions	'
	Acquisitions and Dispositions
	2013
	SUGS Acquisition. The SUGS Acquisition is discussed in footnote 1 - Organization and Basis of Presentation.
	PVR Acquisition. In October 2013, the Partnership announced that it entered into a merger agreement with PVR (“PVR Acquisition”) pursuant to which the Partnership intends to merge with PVR. This merger will be a unit-for-unit transaction plus a one-time $37 million cash payment to PVR unitholders which represents 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. In November 2013, the Partnership received approval of the PVR Acquisition under the Hart-Scott-Rodino Antitrust Improvements Act. The transaction is subject to the approval of PVR’s unitholders and other customary closing conditions, and is expected to close in March 2014.
	The PVR Acquisition is expected to enhance our geographic diversity with a strategic presence in the Marcellus and Utica shales in the Appalachian Basin and the Granite Wash in the Mid-Continent region.
	Eagle Rock Acquisition. In December, 2013, the Partnership entered into an agreement to purchase Eagle Rock’s midstream business (the “Eagle Rock Midstream Acquisition”) for approximately $1.3 billion. This acquisition is expected to complement the Partnership’s core gathering and processing business, and when combined with the PVR Acquisition, is expected to further diversify the Partnership’s basin exposure in the Texas Panhandle, east Texas and south Texas. The Eagle Rock Midstream Acquisition is expected to close in the second quarter of 2014, and is subject to the approval of Eagle Rock unitholders, Hart-Scott-Rodino Antitrust Improvements Act approval and other customary closing conditions.
	Hoover Energy Acquisition. On February 3, 2014, the Partnership completed its previously announced acquisition of the subsidiaries of Hoover that are engaged in crude oil gathering, transportation and terminaling, condensate handling, natural gas gathering, treating and processing, and water gathering and disposal services in the southern Delaware Basin in west Texas. The consideration paid by the Partnership was valued at $281.6 million (subject to customary post-closing adjustments) and consisted of (i) 4,040,471 common units issued to Hoover and (ii) $183.6 million in cash. A portion of the consideration is being held in escrow as security for certain indemnification claims. The Partnership financed the cash portion of the purchase price through borrowings under its revolving credit facility. The Partnership will account for the acquisition of Hoover using the acquisition method of accounting, which requires, among other things, that assets acquired and liabilities assumed be recognized on the balance sheet at their fair values as of the acquisition date. Management’s evaluation of the assigned fair values is ongoing as the transaction was recently completed and therefore the Partnership was not able to complete the preliminary allocation of the purchase price to the acquired assets and liabilities prior to the issuance of these financial statements.
	2011
	Lone Star. On May 2, 2011, the Partnership contributed $593 million in cash to Lone Star, in exchange for its 30% interest. Lone Star, a newly formed joint venture that is owned 70% by ETP and 30% by the Partnership, completed its acquisition of all of the membership interest in LDH, a wholly-owned subsidiary of Louis Dreyfus Highbridge Energy LLC for $1.98 billion in cash. To fund a portion of this capital contribution, the Partnership issued 8,500,001 common units representing limited partnership interests with net proceeds of $204 million. The remaining portion of the Partnership’s capital contribution was funded by additional borrowings under its revolving credit facility.
	Ranch JV. On December 2, 2011, Ranch JV was formed by the Partnership, APM and CM, each owning a 33.33% interest in the joint venture. Ranch JV processes natural gas delivered from the NGLs-rich Bone Spring and Avalon shale formations in west Texas.

Investment_In_Unconsolidated_A

Investment In Unconsolidated Affiliates (Notes)	12 Months Ended
	Dec. 31, 2013
Investment In Unconsolidated Affiliates [Abstract]	'
Investment In Unconsolidated Affiliates	'
	Investments in Unconsolidated Affiliates
	As of December 31, 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% membership interest in Grey Ranch. The Partnership acquired a 33.33% membership interest in Ranch JV in December 2011, a 30% interest in Lone Star in May 2011, a 49.9% interest in MEP in May 2010 and a 0.1% interest in MEP in September 2011. The carrying value of the Partnership’s investment in each of the unconsolidated affiliates as of December 31, 2013 and 2012 is as follows:
		December 31,
		2013			2012
	HPC	$	442		$	650
	MEP	548			581
	Lone Star	1,070			948
	Ranch JV	36			35
	Grey Ranch	1			—
		$	2,097		$	2,214
	The following tables summarize the changes in the Partnership’s investment activities in each of the unconsolidated affiliates for the years ended December 31, 2013, 2012 and 2011:
		Year Ended December 31, 2013
		HPC (2)			MEP		Lone Star		Ranch JV			Grey Ranch
	Contributions	$	—		$	—	$	137	$	2		$	—
	Distributions	238			72		79		2			—
	Share of net income	36			39		64		1			1
	Amortization of excess fair value of investment (1)	(6		)	—		—		—			—
		Year Ended December 31, 2012
		HPC			MEP		Lone Star		Ranch JV			Grey Ranch
	Contributions	$	—		$	—	$	343	$	36		$	—
	Distributions	61			75		68		—			—
	Share of net income	35			42		44		(1		)	(9		)
	Amortization of excess fair value of investment (1)	(6		)	—		—		—			—
		Year Ended December 31, 2011
		HPC			MEP(3)		Lone Star(4)		Ranch JV			Grey Ranch
	Contributions	$	—		$	—	$	645	$	—		N/A
	Purchase of additional interest	—			1		—		—			N/A
	Distributions	65			83		22		—			N/A
	Return of investment	—			—		23		—			N/A
	Share of net income	55			43		28		—			N/A
	Amortization of excess fair value of investment (1)	(6		)	—		—		—			N/A
	__________________
	-1	The Partnership’s investment in HPC was adjusted to its fair value on May 26, 2010 and the excess fair value over net book value was comprised of two components: (1) $155 million was attributed to HPC’s long-lived assets and is being amortized as a reduction of income from unconsolidated affiliates over the useful lives of the respective assets, which vary from 15 to 30 years, and (2) $32 million could not be attributed to a specific asset and therefore will not be amortized in future periods.
	-2	HPC entered into a $500 million 5-year revolving credit facility in September 2013, pursuant to which the Partnership pledged its 49.99% equity interest in HPC. Upon closing such credit facility, HPC borrowed $370 million to fund a non-recurring return of investment to its partners of which the Partnership received $185 million. The amount outstanding under this facility was $445 million as of December 31, 2013. The Partnership’s contingent obligation with respect to the outstanding borrowings under this facility was $222 million at December 31, 2013.
	-3	In September 2011, the Partnership purchased an additional 0.1% interest in MEP from ETP for $1 million in cash, bringing the total membership interest to 50%.
	-4	For the period from initial contribution, May 2, 2011, to December 31, 2011.
	N/A	The Partnership acquired a 50% interest in Grey Ranch in March 2012, as part of the SUGS Acquisition in April 2013.

Derivative_Instruments_Notes

Derivative Instruments (Notes)	12 Months Ended
	Dec. 31, 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 the supply and demand as well as other 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 to 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 settled against NGLs (propane, butane, and natural gasoline), condensate and natural gas market prices. The Partnership also had put options settled against ethane, which expired in December 2012.
	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, 2013, the Partnership had an immaterial amount in net hedging gains in AOCI, all of which will be amortized to earnings over the next three months.
	As of December 31, 2012, SUGS had outstanding receive-fixed natural gas price swaps with a total notional amount of 4,562,500 MMBtu for 2012. These natural gas price swaps were accounted for as cash flow hedges, with effective portion of changes in their fair value recorded to AOCI and reclassified into revenues in the same period 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. The Partnership's $250 million interest rate swaps expired in April 2012. As of December 31, 2013, the Partnership had $510 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 monitors credit exposure and attempts to ensure that it issues credit only to creditworthy 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 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 December 31, 2013 was $4 million, which would be reduced by less than $1 million due to the netting feature. The Partnership has elected to present assets and liabilities under master netting agreements gross on the 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 December 31, 2013 and 2012 are detailed below:
		Assets								Liabilities
		December 31,								December 31,
		2013				2012				2013				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	$	3			$	4			$	9			$	1
	Long-term amounts
	Commodity contracts	1				1				—				—
	Embedded derivatives in Series A Preferred Units	—				—				19				25
	Total derivatives	$	4			$	5			$	28			$	31
	The Partnership’s statements of operations for the years ended December 31, 2013, 2012 and 2011 were impacted by derivative instruments activities as detailed below:
			Years Ended December 31,
			2013				2012				2011
	Derivatives in cash flow hedging relationships:		Change in Value Recognized in AOCI on Derivatives
			(Effective Portion)
	Commodity derivatives		$	—			$	(4	)		$	(13	)
	Derivatives in cash flow hedging relationships:	Location of Gain/(Loss)	Amount of Gain/(Loss) Reclassified from AOCI into Income
		Recognized in Income	(Effective Portion)
	Commodity derivatives	Revenue	$	—			$	6			$	(19	)
			Years Ended December 31,
			2013				2012				2011
	Derivatives not designated in a hedging relationship:	Location of Gain/(Loss)	Amount of Gain/(Loss) from De-designation Amortized from AOCI into Income
		Recognized in Income
	Commodity derivatives	Revenue	$	—			$	(5	)		$	—
	Derivatives not designated in a hedging relationship:	Location of Gain/(Loss)	Amount of Gain/(Loss) Recognized in Income on Derivatives
		Recognized in Income
	Commodity derivatives	Revenue	$	(9	)		$	16			$	—
	Embedded derivatives	Other income & deductions	6				14				18
			$	(3	)		$	30			$	18

LongTerm_Debt_Notes

Long-Term Debt (Notes)	12 Months Ended
	Dec. 31, 2013
Long-Term Debt Disclosure [Abstract]	'
Long-Term Debt	'
	Long-term Debt
	Obligations in the form of senior notes and borrowings under the credit facilities are as follows:
		December 31,
		2013			2012
	Senior notes	$	2,800		$	1,965
	Revolving loans	510			192
	Total	3,310			2,157
	Less: current portion	—			—
	Long-term debt	$	3,310		$	2,157
	Availability under revolving credit facility:
	Total credit facility limit	$	1,200		$	1,150
	Revolving loans	(510		)	(192		)
	Letters of credit	(14		)	(12		)
	Total available	$	676		$	946
	Long-term debt maturities as of December 31, 2013 for each of the next five years are as follows:
	Year Ended December 31,	Amount
	2014	$	—
	2015	—
	2016	—
	2017	—
	2018	600
	Thereafter	2,710
	Total	$	3,310
	Revolving Credit Facility
	In the year ended December 31, 2013, 2012 and 2011 the Partnership borrowed $1.46 billion, $1.56 billion and $940 million, respectively, under its revolving credit facility; these borrowings were to fund capital expenditures and acquisitions. During the same periods, the Partnership repaid $1.1 billion, $1.70 billion and $893 million, respectively, with proceeds from equity offerings and issuances of senior notes.
	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 Partnership capitalized $6 million of net loan fees which is being amortized over the remaining term.
	The revolving credit facility and the guarantees are senior to the Partnership’s and the guarantors’ unsecured obligations, to the extent of the value of the assets securing such obligations.
	As of December 31, 2013, the Partnership was in compliance in all material respects with all of the financial covenants contained within the new credit agreement.
	The outstanding balance under the revolving credit facility bears interest at LIBOR plus a margin or alternate base rate (equivalent to the U.S. prime lending rate) plus a margin, or a combination of both. The alternate base rate used to calculate interest on base rate loans will be calculated based on the greatest to occur of a base rate, a federal funds effective rate plus 0.50% and an adjusted one-month LIBOR rate plus 1.00%. The applicable margin shall range from 0.625% to 1.50% for base rate loans, 1.625% to 2.50% for Eurodollar loans. The weighted average interest rate on the total amounts outstanding under the Partnership’s revolving credit facility was 2.17% and 2.93% as of December 31, 2013 and 2012, respectively.
	RGS must pay (i) a commitment fee ranging from 0.30% to 0.45% per annum of the unused portion of the revolving loan commitments, (ii) a participation fee for each revolving lender participating in letters of credit ranging from 1.625% to 2.50% per annum of the average daily amount of such lender’s letter of credit exposure and (iii) a fronting fee to the issuing bank of letters of credit equal to 0.20% per annum of the average daily amount of the letter of credit exposure. These fees are included in interest expense, net in the consolidated statement of operations.
	The revolving credit facility contains financial covenants requiring RGS and its subsidiaries to maintain a debt to consolidated EBITDA (as defined in the credit agreement) ratio less than 5.00 for the first eight quarters (after March 2015, an increase is allowed in the permitted total leverage ratio for the first two fiscal quarters following any $50 million or greater acquisition), consolidated EBITDA to consolidated interest expense ratio greater than 2.50 and a secured debt to consolidated EBITDA ratio less than 3.25. At December 31, 2013 and 2012, RGS and its subsidiaries were in compliance with these covenants.
	The revolving credit facility restricts the ability of RGS to pay dividends and distributions other than reimbursements of the Partnership for expenses and payment of dividends to the Partnership to the amount of available cash (as defined) so long as no default or event of default has occurred or is continuing. The revolving credit facility also contains various covenants that limit (subject to certain exceptions), among other things, the ability of RGS to:
	•	incur indebtedness;
	•	grant liens;
	•	enter into sale and leaseback transactions;
	•	make certain investments, loans and advances;
	•	dissolve or enter into a merger or consolidation;
	•	enter into asset sales or make acquisitions;
	•	enter into transactions with affiliates;
	•	prepay other indebtedness or amend organizational documents or transactions documents (as defined in the revolving credit facility);
	•	issue capital stock or create subsidiaries; or
	•	engage in any business other than those businesses in which it was engaged at the time of the effectiveness of the revolving credit facility or reasonable extension thereof.
	In February 2014, RGS entered into the first Amendment to the Sixth Amended and restated Credit Agreement to, among other things, expressly permit the pending PVR and Eagle Rock acquisitions, and to increase the commitment to $1.5 billion and increase the uncommitted incremental facility to $500 million. The amendment will specifically allows the Partnership to assume the series of PVR senior notes that mature prior to the credit agreement.
	Senior Notes
	In May 2009, the Partnership and Finance Corp. issued $250 million of senior notes that mature on June 1, 2016 (the “2016 Notes”). The 2016 Notes bear interest at 9.375% with interest payable semi-annually in arrears on June 1 and December 1. In May 2012, the Partnership redeemed 35%, or $88 million, of the 2016 Notes, bringing the total outstanding principal amount to $163 million. A redemption premium of $8 million was charged to loss on debt refinancing, net in the consolidated statement of operations and $4 million of accrued interest was paid. The Partnership also wrote off the unamortized loan fee of $1 million and unamortized bond premium of $2 million to loss on debt refinancing, net in the consolidated statement of operations. In June 2013, the Partnership redeemed all amounts outstanding 2016 Notes for $178 million cash, inclusive of accrued and unpaid interest of $7 million and other fees and expenses.
	The Partnership and Finance Corp. have outstanding the following series of senior notes (collectively “Senior Notes”):
	•	$600 million in aggregate principal amount of our 6.875% senior notes due December 1, 2018 (the “2018 Notes”) with interest payable semi-annually in arrears on June 1 and December 1;
	•	$400 million in aggregate principal amount of our 5.75% senior notes due September 1, 2020 (the “2020 Notes”) with interest payable semi-annually in arrears on March 1 and September 1;
	•	$500 million in aggregate principal amount of our 6.5% senior notes due July 15, 2021 (the “2021 Notes”) with interest payable semi-annually in arrears on January 15 and July 15;
	•	$900 million in aggregate principal of our 5.875% senior notes due March 1, 2022 (the “2022 Notes”), issued in February 2014, with interest payable semi-annually in arrears on March 1 and September 1;
	•	$700 million in aggregate principal amount of our 5.5% senior notes due April 15, 2023 (the “2023 5.5% Notes”) with interest payable semi-annually in arrears on April 15 and October 15; and
	•	$600 million in aggregate principal amount of our 4.5% senior notes due November 1, 2023 (the “2023 4.5% Notes”) with interest payable semi-annually in arrears on May 1 and November 1.
	The Senior Notes are guaranteed by our existing consolidated subsidiaries except Finance Corp and ELG.
	The Senior Notes are redeemable at any time prior to the dates specified below at a price equal to 100% of the principal amount of the applicable series, plus a make-whole premium and accrued and unpaid interest, if any, to the redemption date.
	•	2018 Notes - Beginning December 1, 2014 100% may be redeemed at fixed redemption price of 103.438% (December 1, 2015 - 101.719% and December 1, 2016 and thereafter - 100%) plus accrued and unpaid interest, if any, to the redemption date
	•	2020 Notes - Redeemable, in whole or in part, prior to June 1, 2020 at 100% of the principal amount plus a make-whole premium and accrued and unpaid interest, if any, to the redemption date; redeemable, in whole or in part, on or after June 1, 2020 at 100% of the principal amount thereof, plus accrued and unpaid interest, if any, to the redemption date
•	2021 Notes - Any time prior to July 15, 2014, up to 35% may be redeemed at a price of 106.5% plus accrued and unpaid interest, if any; beginning July 15, 2016, 100% may be redeemed at fixed redemption price of 103.25% (July 15, 2017 - 102.167%, July 15, 2018 - 101.083% and July 15, 2019 and thereafter - 100%) plus accrued and unpaid interest, if any, to the redemption date
•	2022 Notes - Redeemable, in whole or in part, prior to December 1, 2021 at 100% at the principal amount plus a make-whole premium and accrued and unpaid interest, if any, to the redemption date; redeemable, in whole or in part, on or after December 1, 2021 at 100% at the principal amount thereof, plus accrued and unpaid interest, if any, to the redemption date
•	2023 5.5% Notes - Any time prior to October 15, 2015, up to 35% may be redeemed at a price of 105.5% plus accrued and unpaid interest, if any; beginning October 15, 2017, 100% may be redeemed at fixed redemption price of 102.75% (October 15, 2018 - 101.833%, October 15, 2019 - 100.917% and October 15, 2020 and thereafter - 100%) plus accrued and unpaid interest, if any, to the redemption date
•	2023 4.5% Notes - Redeemable, in whole or in part, prior to August 1, 2023 at 100% of the principal amount plus a make-whole premium and accrued and unpaid interest, if any, to the redemption date; redeemable, in whole or in part, on or after August 1, 2023 at 100% of the principal amount thereof, plus accrued and unpaid interest, if any, to the redemption date
Upon a change of control followed by a ratings downgrade within 90 days of a change of control, each note holder of the Senior Notes will be entitled to require us to purchase all or a portion of its notes at a purchase price of 101% plus accrued and unpaid interest, if any. The Partnership’s ability to purchase the Senior Notes upon a change of control will be limited by the terms of our debt agreements, including the Partnership’s revolving credit facility.
The existing senior 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.
If the Senior Notes achieve investment grade ratings by both Moody’s and Standard & Poor’s and no default or event of default has occurred and is continuing, we will no longer be subject to many of the foregoing covenants. At December 31, 2013, we were in compliance with these covenants.

Intangible_Assets

Intangible Assets	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Intangible Assets	'
	Intangible Assets
	Activity related to intangible assets, net consisted of the following:
		Customer			Trade Names			Total
		Relations
	Balance at January 1, 2012	$	681		$	60		$	741
	Amortization	(26		)	(3		)	(29		)
	Balance at December 31, 2012	655			57			712
	Amortization	(26		)	(4		)	(30		)
	Balance at December 31, 2013	$	629		$	53		$	682
	The average remaining amortization periods for customer relations and trade names are 24 and 16 years, respectively. The expected amortization of the intangible assets for each of the five succeeding years is $30 million.

Fair_Value_Measures_Notes

Fair Value Measures (Notes)	12 Months Ended
	Dec. 31, 2013
Fair Value Measures [Abstract]	'
Fair Value Measures	'
	Fair Value Measures
	The fair value measurement provisions establish a three-tiered fair value hierarchy that prioritizes inputs to valuation techniques used in fair value calculations. The three levels of inputs are defined as follows:
	•	Level 1—unadjusted quoted prices for identical assets or liabilities in active accessible markets;
	•	Level 2—inputs that are observable in the marketplace other than those classified as Level 1; and
	•	Level 3—inputs that are unobservable in the marketplace and significant to the valuation.
	Entities are encouraged to maximize the use of observable inputs and minimize the use of unobservable inputs. If a financial instrument uses inputs that fall in different levels of the hierarchy, the instrument will be categorized based upon the lowest level of input that is significant to the fair value calculation.
	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 observable inputs for similar instruments and incorporate Level 1 and Level 2 inputs. Embedded derivatives related to the Series A Preferred Units are valued using a binomial lattice model. The market 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.
	The following table presents the Partnership’s derivative assets and liabilities measured at fair value on a recurring basis:
		Fair Value Measurement at December 31,
		2013							2012
		Fair Value			Level 2		Level 3		Fair Value		Level 2		Level 3
		Total							Total
	Assets
	Commodity Derivatives:
	Natural Gas	$	2		$	2	$	—	$	2	$	2	$	—
	Natural Gas Liquids	2			2		—		1		1		—
	Condensate	—			—		—		2		2		—
	Total Assets	$	4		$	4	$	—	$	5	$	5	$	—
	Liabilities
	Commodity Derivatives:
	Natural Gas	$	4		$	4	$	—	$	5	$	5	$	—
	Natural Gas Liquids	4			4		—		1		1		—
	Condensate	1			1		—		—		—		—
	Embedded Derivatives in Series A Preferred Units	19			—		19		25		—		25
	Total Liabilities	$	28		$	9	$	19	$	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		31-Dec-13
	Credit Spread		4.16	%
	Volatility		23.71	%
	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 years ended December 31, 2013 and 2012. There were no transfers between Level 2 and Level 3 derivatives for the years ended December 31, 2013 and 2012.
		Embedded Derivatives in
		Series A Preferred Units
	Balance at January 1, 2012	$	39
	Change in fair value	(14		)
	Balance at December 31, 2012	25
	Change in fair value, net of gain at conversion of $26 million	(6		)
	Balance at December 31, 2013	$	19
	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 December 31, 2013 was $2.83 billion and $2.80 billion, respectively. As of December 31, 2012, the aggregate fair value and carrying amount of the Senior Notes was $2.13 billion and $1.97 billion, respectively. The fair value of the Senior Notes is a Level 1 valuation based on third party market value quotations.

Leases_Notes

Leases (Notes)	12 Months Ended
	Dec. 31, 2013
Leases [Abstract]	'
Leases	'
	Leases
	The following table is a schedule of future minimum lease payments for office space and certain equipment leased by the Partnership, that had initial or remaining non-cancelable lease terms in excess of one year as of December 31, 2013:
	For the year ending December 31,	Operating Lease
	2014	$	3
	2015	3
	2016	2
	2017	2
	2018	2
	Thereafter	34
	Total minimum lease payments	$	46
	Total rent expense for operating leases, including those leases with terms of less than one year, was $11 million, $11 million and $3 million for the years ended December 31, 2013, 2012 and 2011, respectively.

Commitments_And_Contingencies_

Commitments And Contingencies (Notes)	12 Months Ended
	Dec. 31, 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.
	PVR Shareholder Litigation. Five putative class action lawsuits challenging the PVR Acquisition are currently pending. All of the cases name PVR, PVR GP and the current directors of PVR GP, as well as the Partnership and the General Partner (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, that PVR GP, PVR and the Regency Defendants aided and abetted the directors of PVR GP in the alleged breach of these fiduciary duties, and, as to the actions in federal court, that some or all of PVR, PVR GP, and the directors of PVR GP violated Section 14(a) of the Exchange Act and Rule 14a-9 promulgated thereunder and Section 20(a) of the Exchange Act. The lawsuits purport to seek, in general, (i) injunctive relief, (ii) disclosure of certain additional information concerning the transaction, (iii) in the event the merger is consummated, rescission or an award of rescissory damages, (iv) an award of plaintiffs’ costs and (v) the accounting for damages allegedly causes by the defendants to these actions, and, (iv) such further relief as the court deems just and proper. The styles of the pending cases are as follows: David Naiditch v. PVR Partners, L.P., et al. (Case No. 9015-VCL) in the Court of Chancery of the State of Delaware); Charles Monatt v. PVR Partners, LP, et al. (Case No. 2013-10606) and Saul Srour v. PVR Partners, L.P., et al. (Case No. 2013-011015), each pending in the Court of Common Pleas for Delaware County, Pennsylvania; Stephen Bushansky v. PVR Partners, L.P., et al. (C.A. No. 2:13-cv-06829-HB); and Mark Hinnau v. PVR Partners, L.P., et al. (C.A. No. 2:13-cv-07496-HB), pending in the United States District Court for the Eastern District of Pennsylvania.
	On January 28, 2014, the defendants entered into a Memorandum of Understanding (“MOU”) with Monatt, Srour, Bushansky, Naiditch and Hinnau pursuant to which defendants and the referenced plaintiffs agreed in principle to a settlement of their lawsuits (“Settled Lawsuits”), which will be memorialized in a separate settlement agreement, subject to customary conditions, including consummation of the PVR Acquisition, completion of certain confirmatory discovery, class certification and final approval by the Court of Common Pleas for Delaware County, Pennsylvania. If the Court approves the settlement, the Settled Lawsuits will be dismissed with prejudice and all defendants will be released from any and all claims relating to the Settled Lawsuits.
	The settlement will not affect any provisions of the merger agreement or the form or amount of consideration to be received by PVR unitholders in the PVR Acquisition. The defendants have denied and continue to deny any wrongdoing or liability with respect to the plaintiffs’ claims in the aforementioned litigation and have entered into the settlement to eliminate the uncertainty, burden, risk, expense, and distraction of further litigation.
	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 in the consolidated balance sheet at December 31, 2013 and 2012 where management believes a loss is probable and reasonably estimable. The Partnership does not have any material environmental remediation matters assessed as reasonably possible that would require disclosure in the financial statements.
		December 31,
		2013		2012
	Current	$	2	$	5
	Noncurrent	6		7
	Total environmental liabilities	$	8	$	12
	The Partnership made expenditures related to environmental remediation of $5 million for the year ended December 31, 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 SUGS 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, the Partnership is 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, none of which are believed to be potentially material to the Partnership at this time.

Series_A_Preferred_Units_Notes

Series A Preferred Units (Notes)	12 Months Ended
	Dec. 31, 2013
Temporary Equity Disclosure [Abstract]	'
Series A Preferred Units	'
	Series A Preferred Units
	On September 2, 2009, the Partnership issued 4,371,586 Series A Preferred Units at a price of $18.30 per unit, less issuance costs and a 4% discount of $3 million for net proceeds of $77 million, exclusive of the General Partner’s contribution of $2 million. The Series A Preferred Units are convertible to common units under terms described below, and if outstanding, are mandatorily redeemable on September 2, 2029 for $35 million plus all accrued but unpaid distributions thereon (the “Series A Liquidation Value”) and accrued interest. The Series A Preferred Units receive fixed quarterly cash distributions of $0.445 per unit which began with the quarter ending March 31, 2010.
	Holders may elect to convert Series A Preferred Units to common units at any time. 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 December 31, 2013, the remaining Series A Preferred Units were convertible into 2,050,854 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.
	Distributions on the Series A Preferred Units were accrued for the first two quarters (and not paid in cash) and will result in an increase in the number of common units issuable upon conversion. If on any distribution payment date beginning March 31, 2010, the Partnership (1) fails to pay distributions on the Series A Preferred Units, (2) reduces the distributions on the common units to zero and (3) is prohibited by its material financing agreements from paying cash distributions, such distributions shall automatically accrue and accumulate until paid in cash. If the Partnership has failed to pay cash distributions in full for two quarters (whether or not consecutive) from and including the quarter ended on March 31, 2010, then if the Partnership fails to pay cash distributions on the Series A Preferred Units, all future distributions on the Series A Preferred Units that are accrued rather than being paid in cash by the Partnership will consist of the following: (1) $0.35375 per Series A Preferred Unit per quarter, (2) $0.09125 per Series A Preferred Unit per quarter (the “Common Unit Distribution Amount”), payable solely in common units, and (3) $0.09125 per Series A Preferred Unit per quarter (the “PIK Distribution Additional Amount”), payable solely in common units. The total number of common units payable in connection with the Common Unit Distribution Amount or the PIK Distribution Additional Amount cannot exceed $2 million in any period of 20 consecutive fiscal quarters.
	Upon the Partnership’s breach of certain covenants (a “Covenant Default”), the holders of the Series A Preferred Units will be entitled to an increase of $0.1825 per quarterly distribution, payable solely in common units (the “Covenant Default Additional Amount”). All accumulated and unpaid distributions will accrue interest (i) at a rate of 2.432% per quarter, or (ii) if the Partnership has failed to pay all PIK Distribution Additional Amounts or Covenant Default Additional Amounts or any Covenant Default has occurred and is continuing, at a rate of 3.429% per quarter while such failure to pay or such Covenant Default continues.
	The Series A Preferred Units are convertible, at the holder’s option, into common units, provided that the holder must request conversion of at least 375,000 Series A Preferred Units. The conversion price will initially be $18.30, subject to adjustment for customary events (such as unit splits). The number of common units issuable is equal to the issue price of the Series A Preferred Units (i.e. $18.30) being converted plus all accrued but unpaid distributions and accrued but unpaid interest thereon (the “Redeemable Face Amount”), divided by the applicable conversion price.
	Commencing on September 2, 2014, if at any time the volume-weighted average trading price of the common units over the trailing 20-trading day period (the “VWAP Price”) is less than the then-applicable conversion price, the conversion ratio will be increased to: the quotient of (1) the Redeemable Face Amount on the date that the holder’s conversion notice is delivered, divided by (2) the product of (x) the VWAP Price set forth in the applicable conversion notice and (y) 91%, but will not be less than $10.
	Also commencing on September 2, 2014, the Partnership will have the right at any time to convert all or part of the Series A Preferred Units into common units, if (1) the daily volume-weighted average trading price of the common units is greater than 150% of the then-applicable conversion price for 20 out of the trailing 30 trading days, and (2) certain minimum public float and trading volume requirements are satisfied.
	In the event of a change of control, the Partnership will be required to make an offer to the holders of the Series A Preferred Units to purchase their Series A Preferred Units for an amount equal to 101% of their Series A Liquidation Value. In addition, in the event of certain business combinations or other transactions involving the Partnership in which the holders of common units receive cash consideration exclusively in exchange for their common units (a “Cash Event”), the Partnership must use commercially reasonable efforts to ensure that the holders of the Series A Preferred Units will be entitled to receive a security issued by the surviving entity in the Cash Event with comparable powers, preferences and rights to the Series A Preferred Units. If the Partnership is unable to ensure that the holders of the Series A Preferred Units will be entitled to receive such a security, then the Partnership will be required to make an offer to the holders of the Series A Preferred Units to purchase their Series A Preferred Units for an amount equal to 120% of their Series A Liquidation Value. If the Partnership enters into any recapitalization, reorganization, consolidation, merger, spin-off that is not a Cash Event, the Partnership will make appropriate provisions to ensure that the holders of the Series A Preferred Units receive a security with comparable powers, preferences and rights to the Series A Preferred Units upon consummation of such transaction. Subsequent to the ETE Acquisition, no unitholder exercised this option.
	As of December 31, 2013, the Series A Preferred Units were convertible to 2,050,854 common units.
	The following table provides a reconciliation of the beginning and ending balances of the Series A Preferred Units for the year ended December 31, 2013 and 2012:
		Units		Amount
	Balance at January 1, 2012	4,371,586		$	71
	Accretion to redemption value	N/A		2
	Balance at December 31, 2012	4,371,586		73
	Series A Preferred Units converted into common units	(2,459,017	)	(41		)
	Balance at December 31, 2013	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. Accretion during 2013
	was immaterial.

Related_Party_Transactions_Not

Related Party Transactions (Notes)	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	As of December 31, 2013 and 2012, details of the Partnership’s related party receivables and related party payables were as follows:
		December 31,
		2013		2012
	Related party receivables
	HPC	$	1	$	1
	ETE and its subsidiaries	25		5
	Ranch JV	2		2
	Total related party receivables	$	28	$	8
	Related party payables
	HPC	$	1	$	1
	ETE and its subsidiaries	68		94
	Total related party payables	$	69	$	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 services agreement has a five year term ending 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, this agreement was amended to provide for a waiver of the $10 million annual fee effective as of May 1, 2013 through and including April 30, 2015 and to clarify 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 $11 million for the year ended December 31, 2013, and $17 million for the years ended December 31, 2012 and 2011.
	In conjunction with distributions made by the Partnership to the limited and general partner interests, ETE received cash distributions of $63 million, $62 million and $57 million for the years ended December 31, 2013, 2012 and 2011, respectively.
	The General Partner has the right, but not the obligation, to contribute a proportionate amount of capital to the Partnership to maintain its general partner interest. No capital contributions were contributed during the years ended December 31, 2013 and 2012, respectively.
	In September 2011, the Partnership purchased a 0.1% interest in MEP from ETP for $1 million in cash.
	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’s Contract Services segment provides contract compression services to ETP and records revenue in gathering, transportation and other fees on the statement of operations. The Partnership’s Contract Services segment did not sell compression equipment to a subsidiary of ETP for the year ended December 31, 2013, and sold $1 million for the year ended December 31, 2012. As these transactions are between entities under common control, partners’ capital was increased, which represented a deemed contribution of the excess sales price over the carrying amounts. The Partnership’s Contract Services segment purchased compression equipment from a subsidiary of ETP for $95 million and $29 million during the years ended December 31, 2013 and 2012, respectively.
	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. The amounts were $21 million and $1 million for the period from March 26, 2012 to December 31, 2012. These administrative services were 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. For the years ended December 31, 2013, 2012, and 2011, the related party general and administrative expenses reimbursed to the Partnership were $18 million, $20 million, and $17 million, respectively, which is recorded in gathering, transportation and other fees on the statements of operations.
	The Partnership’s Contract Services segment provides compression services to HPC and records revenue in gathering, transportation and other fees on the statement of operations. The Partnership also receives transportation services from HPC and records the cost as cost of sales.
	Transactions with Lone Star. In 2013, the Partnership entered into a nineteen month agreement to sell NGL to Lone Star for approximately $5 million per month. For the year ended December 31, 2013, the Partnership had recorded $26 million in NGL sales under this contract.
	Transactions with EPD and its subsidiaries. In January 2012, EPD sold a significant portion of its ownership in ETE’s common units, and subsequent to that transaction, owns less than 5% of ETE’s outstanding common units. As such, EPD is no longer considered a related party. During 2011, EPD owned a portion of ETE’s outstanding common units and therefore was considered a related party along with any of its subsidiaries. The Partnership, in the ordinary course of business, sells natural gas and NGLs to subsidiaries of EPD and records the revenue in gas sales and NGL sales. The Partnership also incurs NGL processing fees and transportation fees with subsidiaries of EPD and records these fees as cost of sales.

Concentration_Risk_Notes

Concentration Risk (Notes)	12 Months Ended
	Dec. 31, 2013
Risks and Uncertainties [Abstract]	'
Concentration Risk	'
	Concentration Risk
	The following table provides information about the extent of reliance on major customers and gas suppliers. Total revenues and cost of sales from transactions with an external customer or supplier amounting to 10% or more of revenue or cost of gas and liquids are disclosed below, together with the identity of the reporting segment.
			Years Ended December 31,
		Reportable Segment	2013		2012		2011
	Customer
	Customer A	Gathering and Processing	$	381	$	367	$	366
	Customer B	Gathering and Processing	362		451		—
	Supplier
	Supplier A	Gathering and Processing	164		171		133
	Supplier B	Gathering and Processing	185		—		—
	The Partnership is a party to various commercial netting agreements that allow it and contractual counterparties to net receivable and payable obligations. These agreements are customary and the terms follow standard industry practice. In the opinion of management, these agreements reduce the overall counterparty risk exposure.

Segment_Information_Notes

Segment Information (Notes)	12 Months Ended
	Dec. 31, 2013
Segment Information [Abstract]	'
Segment Information	'
	16. Segment Information
	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 which was a reorganization of entities under common control. Therefore, the Gathering and Processing segment amounts have been retrospectively adjusted to reflect the SUGS Acquisition beginning March 26, 2012, the date upon which common control began.
	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, 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 the states of Texas, New Mexico, 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, revenue generating horsepower and revenue generating gallons per minute. 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 period, together with amounts related to each segment are shown below:
		Years Ended December 31,
		2013			2012				2011
	External Revenue
	Gathering and Processing	$	2,287		$	1,797			$	1,226
	Natural Gas Transportation	1			1				1
	NGL Services	—			—				—
	Contract Services	215			183				190
	Corporate	18			19				17
	Eliminations	—			—				—
	Total	$	2,521		$	2,000			$	1,434
	Intersegment Revenue
	Gathering and Processing	$	—		$	—			$	—
	Natural Gas Transportation	—			—				—
	NGL Services	—			—				—
	Contract Services	15			21				17
	Corporate	—			—				—
	Eliminations	(15		)	(21		)		(17		)
	Total	$	—		$	—			$	—
	Cost of Sales
	Gathering and Processing	$	1,767		$	1,373			$	993
	Natural Gas Transportation	—			(1		)		(2		)
	NGL Services	—			—				—
	Contract Services	26			15				22
	Corporate	—			—				—
	Eliminations	—			—				—
	Total	$	1,793		$	1,387			$	1,013
	Segment Margin
	Gathering and Processing	$	521		$	423			$	233
	Natural Gas Transportation	—			2				3
	NGL Services	—			—				—
	Contract Services	204			189				185
	Corporate	18			20				17
	Eliminations	(15		)	(21		)		(17		)
	Total	$	728		$	613			$	421
	Operation and Maintenance
	Gathering and Processing	$	237		$	183			$	98
	Natural Gas Transportation	—			—				—
	NGL Services	—			—				—
	Contract Services	72			66				66
	Corporate	1			—				—
	Eliminations	(14		)	(21		)		(17		)
	Total	$	296		$	228			$	147
	Depreciation and Amortization
	Gathering and Processing	$	186		$	159			$	87
	Natural Gas Transportation	—			—				—
	NGL Services	—			—				—
	Contract Services	98			86				78
	Corporate	3			7				4
	Eliminations	—			—				—
	Total	$	287		$	252			$	169
		Years Ended December 31,
		2013			2012				2011
Income from Unconsolidated Affiliates
Gathering and Processing	$	1		$	(10	)		$	—
Natural Gas Transportation	70			71				92
NGL Services	64			44				28
Contract Services	—			—				—
Corporate	—			—				—
Eliminations	—			—				—
Total	$	135		$	105			$	120
Expenditures for Long-Lived Assets
Gathering and Processing	$	721		$	395			$	282
Natural Gas Transportation	—			—				—
NGL Services	—			—				—
Contract Services	311			164				120
Corporate	2			1				4
Eliminations	—			—				—
Total	$	1,034		$	560			$	406
	31-Dec-13
	2013			2012				2011
Assets
Gathering and Processing	$	4,748		$	4,210			$	1,960
Natural Gas Transportation	991			1,232				1,297
NGL Services	1,070			948				629
Contract Services	1,897			1,672				1,621
Corporate	76			61				61
Eliminations	—			—				—
Total	$	8,782		$	8,123			$	5,568
Investment in Unconsolidated Affiliates
Gathering and Processing	$	36		$	35			$	—
Natural Gas Transportation	991			1,231				1,296
NGL Services	1,070			948				629
Contract Services	—			—				—
Corporate	—			—				—
Eliminations	—			—				—
Total	$	2,097		$	2,214			$	1,925
Goodwill
Gathering and Processing	$	651		$	651			$	313
Natural Gas Transportation	—			—				—
NGL Services	—			—				—
Contract Services	477			477				477
Corporate	—			—				—
Eliminations	—			—				—
Total	$	1,128		$	1,128			$	790
The table below provides a reconciliation of total segment margin to income before income taxes:
	Years Ended December 31,
	2013			2012				2011
Total segment margin	$	728		$	613			$	421
Operation and maintenance	(296		)	(228		)		(147		)
General and administrative	(88		)	(100		)		(67		)
(Loss) gain on assets sales, net	(2		)	(3		)		2
Depreciation and amortization	(287		)	(252		)		(169		)
Income from unconsolidated affiliates	135			105				120
Interest expense, net	(164		)	(122		)		(103		)
Loss on debt refinancing, net	(7		)	(8		)		—
Other income and deductions, net	7			29			*	17
Income before income taxes	$	26		$	34			$	74
__________________
*	Other income and deductions, net for the year ended December 31, 2012, included a one-time producer payment of $16 million related to an assignment of certain contracts.

EquityBased_Compensation_Notes

Equity-Based Compensation (Notes)	12 Months Ended
	Dec. 31, 2013
Equity-Based Compensation [Abstract]	'
Equity-Based Compensation	'
	Equity-Based Compensation
	In December 2011, the Partnership’s unitholders approved the Regency Energy Partners LP 2011 Long-Term Incentive Plan (the “2011 Incentive Plan”), which provides for awards of options to purchase the Partnership’s common units; awards of the Partnership’s restricted units, phantom units and common units; awards of distribution equivalent rights; awards of common unit appreciation rights; and other unit-based awards to employees, directors and consultants of the Partnership and its affiliates and subsidiaries. The 2011 Incentive Plan will be administered by the Compensation Committee of the board of directors, which may, in its sole discretion, delegate its powers and duties under the 2011 Incentive Plan to the Chief Executive Officer. Up to 3,000,000 of the Partnership’s common units may be granted as awards under the 2011 Incentive Plan, with such amount subject to adjustment as provided for under the terms of the 2011 Incentive Plan.
	The 2011 Incentive Plan may be amended or terminated at any time by the board of directors or the Compensation Committee without the consent of any participant or unitholder, including an amendment to increase the number of common units available for awards under the plan; however, any material amendment, such as a change in the types of awards available under the plan, would require the approval of the unitholders of the Partnership. The Compensation Committee is also authorized to make adjustments in the terms and conditions of, and the criteria included in awards under the 2011 Incentive Plan in specified circumstances. The 2011 Incentive Plan is effective until December 19, 2021 or, if earlier, the time at which all available units under the 2011 Incentive Plan have been issued to participants or the time of termination of the plan by the board of directors.
	Unit-based compensation expense of $7 million, $5 million, and $3 million is recorded in general and administrative expense in the statement of operations for the years ended December 31, 2013, 2012 and 2011, respectively.
	Common Unit Options. The fair value of each option award is estimated on the date of grant using the Black-Scholes Option Pricing Model. Upon the exercise of the common unit options, the Partnership intends to settle these obligations with new issues of common units on a net basis. The common unit options activity for the years ended December 31, 2013, 2012, and 2011 is as follows:
	2013
	Common Unit Options	Units		Weighted Average Exercise Price
	Outstanding at the beginning of period	156,550		$	21.96
	Exercised	(14,000	)	21.14
	Outstanding at end of period	142,550		22.04
	Exercisable at the end of the period	142,550
	2012
	Common Unit Options	Units		Weighted Average Exercise Price
	Outstanding at the beginning of period	156,850		$	21.99
	Forfeited or expired	(300	)	23.73
	Outstanding at end of period	156,550		21.96
	Exercisable at the end of the period	156,550
	2011
	Common Unit Options	Units		Weighted Average Exercise Price
	Outstanding at the beginning of period	201,950		$	21.93
	Exercised	(38,300	)	20.84
	Forfeited or expired	(6,800	)	26.72
	Outstanding at end of period	156,850		21.99
	Exercisable at the end of the period	156,850
	The common unit options have an intrinsic value of less than $1 million related to non-vested units with a weighted average contractual term of 2.4 years. Intrinsic value is the closing market price of a unit less the option strike price, multiplied by the number of unit options outstanding as of the end of the period presented. Unit options with an exercise price greater than the end of the period closing market price are excluded.
	Phantom Units. In January 2014, the Partnership awarded 668,074 phantom units to senior management and certain key employees. These awards are service condition (time-based) grants that vest 60% at the end of the third year of service and 40% at the end of the fifth year of service.
	During 2013, the Partnership awarded 62,360 phantom units to senior management and certain key employees. These awards are service condition (time-based) grants that generally vest 60% at the end of the third year of service and 40% at the end of the fifth year of service. Distributions on the phantom units will be paid concurrent with the Partnership’s distribution for common units.
	In December 2012, the Partnership awarded 495,375 phantom units to senior management and certain key employees. These awards are service condition (time-based) grants that vest 60% at the end of the third year of service and 40% at the end of the fifth year of service. Also during 2012, 8,250 phantom units were awarded to senior management and key employees as service condition (time-based) grants that generally vest ratably over the next 5 years. Distributions on the phantom units (including non-vested units) will be paid concurrent with the Partnership’s distribution for common units.
	During 2011, the Partnership awarded 596,320 phantom units to senior management and certain key employees. These awards are service condition (time-based) grants that generally vest ratably over the next 5 years. Distributions on the phantom units (including non-vested units) will be paid concurrent with the Partnership’s distribution for common units.
	The following table presents phantom unit activity for the years ended December 31, 2013, 2012 and 2011:
	2013
	Phantom Units	Units		Weighted Average
				Grant Date
				Fair Value
	Outstanding at the beginning of the period	1,231,342		$	23.22
	Service condition grants	62,360		25.44
	Vested service condition	(231,163	)	24.8
	Forfeited service condition	(35,900	)	23.22
	Forfeited market condition	(44,397	)	19.52
	Total outstanding at end of period	982,242		23.16
	2012
	Phantom Units	Units		Weighted Average
				Grant Date
				Fair Value
	Outstanding at the beginning of the period	1,086,393		$	24.51
	Service condition grants	503,625		21.39
	Vested service condition	(223,258	)	24.71
	Vested market condition	(10,200	)	19.52
	Forfeited service condition	(120,868	)	24.85
	Forfeited market condition	(4,350	)	19.52
	Total outstanding at end of period	1,231,342		23.22
	2011
	Phantom Units	Units		Weighted Average
				Grant Date
				Fair Value
	Outstanding at the beginning of the period	742,517		$	23.61
	Service condition grants	596,320		24.55
	Vested service condition	(142,520	)	24.73
	Vested market condition	(8,550	)	19.52
	Forfeited service condition	(88,474	)	24.99
	Forfeited market condition	(12,900	)	19.52
	Total outstanding at end of period	1,086,393		24.51
	The Partnership expects to recognize $19 million of unit-based compensation expense related to non-vested phantom units over a period of 3.3 years.

Quarterly_Financial_Data_Unaud

Quarterly Financial Data (Unaudited) (Notes)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Quarterly Financial Data (Unaudited)	'
	Quarterly Financial Data (Unaudited)
		Quarter Ended
	2013	31-Dec			September 30			30-Jun		31-Mar
	Operating revenues	$	677		$	665		$	639	$	540
	Operating income (loss)	12			24			34		(15		)
	Net (loss) income attributable to Regency Energy Partners LP	(1		)	39			10		(29		)
	Earnings per common units:
	Basic net (loss) income per common unit	(0.03		)	0.16			0.07		(0.06		)
	Diluted net (loss) income per common unit	(0.03		)	0.05			0.07		(0.06		)
		Quarter Ended
	2012 *	31-Dec			September 30			30-Jun		31-Mar
	Operating revenues	$	587		$	527		$	511	$	375
	Operating income (loss)	8			5			22		(5		)
	Net (loss) income attributable to Regency Energy Partners LP	(8		)	(1		)	26		15
	Earnings per common units:
	Basic net (loss) income per common unit	(0.08		)	(0.04		)	0.14		0.15
	Diluted net (loss) income per common unit	(0.08		)	(0.04		)	0.1		0.14
	_______________________
	*	Due to the SUGS Acquisition, these quarterly results have been retrospectively adjusted to include the operations of SUGS beginning March 26, 2012, the date upon which common control began.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies [Abstract]	'
Inventory, Policy [Policy Text Block]	'
	Inventories. Inventories are valued at the lower of cost or market and include materials and parts primarily utilized by the Contract Services segment.
Use of Estimates	'
	Use of Estimates. These consolidated financial statements have been prepared in conformity with GAAP, which includes the use of estimates and assumptions 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 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.
Cash and Cash Equivalents	'
	Cash and Cash Equivalents. Cash and cash equivalents include temporary cash investments with original maturities of three months or less.
Equity Method Investments	'
	Equity Method Investments. The equity method of accounting is used to account for the Partnership’s interest in investments of greater than 20% voting interest or where the Partnership exerts significant influence over an investee but lacks control over the investee.
Property, Plant and Equipment	'
	Property, Plant and Equipment. Property, plant and equipment is recorded at historical cost of construction or, upon acquisition, the fair value of the assets acquired. Gains or losses on sales or retirements of assets are included in operating income unless the disposition is treated as discontinued operations. Natural gas and NGLs used to maintain pipeline minimum pressures is and classified as property, plant and equipment. Financing costs associated with the construction of larger assets requiring ongoing efforts over a period of time are capitalized. For the years ended December 31, 2013, 2012 and 2011, the Partnership capitalized interest of $2 million, $1 million and $1 million, respectively. The costs of maintenance and repairs, which are not significant improvements, are expensed when incurred. Expenditures to extend the useful lives of the assets are capitalized.
	Depreciation expense related to property, plant and equipment was $258 million, $219 million, and $138 million for the years ended December 31, 2013, 2012 and 2011, respectively. In March 2012, the Partnership recorded a $7 million “out-of-period” adjustment to depreciation expense to correct the estimated useful lives of certain assets to comply with its policy.
	Depreciation of property, plant and equipment is recorded on a straight-line basis over the following estimated useful lives:
	Functional Class of Property	Useful Lives (Years)
	Gathering and Transmission Systems	Oct-50
	Compression Equipment	Feb-30
	Gas Plants and Buildings	May-35
	Other property, plant and equipment	15-Mar
Intangible Assets and Goodwill	'
	Intangible Assets. As of December 31, 2013, intangible assets consisted of trade names and customer relations, and are amortized on a straight line basis over their estimated useful lives, which is the period over which the assets are expected to contribute directly or indirectly to the Partnership’s future cash flows. The estimated useful lives range from 20 to 30 years.
	The Partnership assesses long-lived assets, including property, plant and equipment and intangible assets, for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability is assessed by comparing the carrying amount of an asset to undiscounted future net cash flows expected to be generated by the asset. If such assets are considered to be impaired, the impairment to be recognized is measured as the amount by which the carrying amounts exceed the fair value of the assets. The Partnership did not record any impairment in 2013, 2012 or 2011.
	Goodwill. Goodwill represents the excess of the purchase price over the fair value of identifiable net assets acquired in a business combination. Goodwill is not amortized, but is tested for impairment annually based on the carrying values as of November 30 or December 31 depending upon the reporting unit, or more frequently if impairment indicators arise that suggest the carrying value of goodwill may not be recovered. The Partnership has the option to first assess qualitative factors to determine whether it is more likely than not that the fair value of the reporting unit is less than its carrying amount as a basis for determining whether further impairment testing is necessary. Impairment is indicated when the carrying amount of a reporting unit exceeds its fair value. To estimate the fair value of the reporting units, the Partnership makes estimates and judgments about future cash flows, as well as revenues, cost of sales, operating expenses, capital expenditures and net working capital based on assumptions that are consistent with the Partnership’s most recent forecast. At the time it is determined that an impairment has occurred, the carrying value of the goodwill is written down to its fair value. The Partnership did not record any impairment in 2013, 2012 or 2011.
Other Assets, net	'
	Other Assets, net. Other assets, net primarily consists of debt issuance costs, which are capitalized and amortized to interest expense, net over the life of the related debt.
Gas Imbalances	'
	Gas Imbalances. Quantities of natural gas or NGLs over-delivered or under-delivered related to imbalance agreements are recorded monthly as other current assets or other current liabilities using then current market prices or the weighted average prices of natural gas or NGLs at the plant or system pursuant to imbalance agreements for which settlement prices are not contractually established. Within certain volumetric limits determined at the sole discretion of the creditor, these imbalances are generally settled by deliveries of natural gas. Imbalance receivables and payables as of December 31, 2013 and 2012 were immaterial.
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 were immaterial as of December 31, 2013.
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 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.
Stockholders' Equity Note Disclosure [Text Block]	'
	Predecessor Equity. Predecessor equity included on the consolidated statement of partners' capital and noncontrolling interest represents SUGS member's capital prior to the acquisition date (April 30, 2013).
Revenue Recognition	'
	Revenue Recognition. The Partnership earns revenue from (i) domestic sales of natural gas, NGLs and condensate, (ii) natural gas gathering, processing and transportation, and (iii) contract compression and treating services. Revenue associated with sales of natural gas, NGLs and condensate are recognized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery occurs. Revenue associated with transportation and processing fees are recognized when the service is provided. For contract compression and contract treating services, revenue is recognized when the service is performed. For gathering and processing services, the Partnership receives either fees or commodities from natural gas producers depending on the type of contract. Commodities received are in turn sold and recognized as revenue in accordance with the criteria outlined above. Under the percentage-of-proceeds contract type, the Partnership is paid for its services by keeping a percentage of the NGLs produced and a percentage of the residue gas resulting from processing the natural gas. Under the percentage-of-index contract type, the Partnership earns revenue by purchasing wellhead natural gas at a percentage of the index price and selling processed natural gas and NGLs at a price approximating the index price to third parties. The Partnership generally reports revenue gross in the consolidated statements of operations when it acts as the principal, takes title to the product, and incurs the risks and rewards of ownership. Revenue for fee-based arrangements is presented net, because the Partnership takes the role of an agent for the producers. Allowance for doubtful accounts is determined based on historical write-off experience and specific identification.
Derivatives Instruments	'
	Derivative Instruments. The Partnership's net income and cash flows are subject to volatility stemming from changes in market prices such as natural gas prices, NGLs prices, processing margins and interest rates. The Partnership uses product-specific swaps to create offsetting positions to specific commodity price exposures, and uses interest rate swap contracts to create offsetting positions to specific interest rate exposures. Derivative financial instruments are recorded on the balance sheet at their fair value based on their settlement date. The Partnership employs derivative financial instruments in connection with an underlying asset, liability and/or anticipated transaction and not for speculative purposes. Furthermore, the Partnership regularly assesses the creditworthiness of counterparties to manage the risk of default. Derivative financial instruments qualifying for hedge accounting treatment may be designated by the Partnership as cash flow hedges. The Partnership enters into cash flow hedges to hedge the variability in cash flows related to a forecasted transaction. At inception, the Partnership formally documents the relationship between the hedging instrument and the hedged item, the risk management objectives, and the methods used for assessing and testing correlation and hedge effectiveness. The Partnership also assesses, both at the inception of the hedge and on an on-going basis, whether the derivatives are highly effective in offsetting changes in cash flows of the hedged item. If the Partnership determines that a derivative is no longer highly effective as a hedge, it would discontinues hedge accounting prospectively by including changes in the fair value of the derivative in current earnings. For cash flow hedges, changes in the derivative fair values, to the extent that the hedges are effective, are recorded as a component of accumulated other comprehensive income (loss) until the hedged transactions occur and are recognized in earnings. Any ineffective portion of a cash flow hedge's change in value is recognized immediately in earnings. In the statement of cash flows, the effects of settlements of derivative instruments are classified consistent with the related hedged transactions.
Benefits	'
	Benefits. The Partnership provides medical, dental, and other healthcare benefits to employees. The total amount incurred by the Partnership for the years ended December 31, 2013, 2012 and 2011, was $9 million, $9 million and $6 million, respectively, in operation and maintenance and general and administrative expenses, as appropriate. The Partnership also provides a matching contribution to its employee’s 401(k) accounts. Effective January 1, 2011, the Partnership’s 401(k) plan merged with and into that of ETP. As a result of the merger, the Partnership’s matching contributions that had not yet fully vested became fully vested. All future matching contributions from the Partnership to the employee 401(k) accounts vest immediately. In addition, SUGS maintained a separate defined contribution plan during March 26, 2012 to December 31, 2012. The total amount of matching contributions for the years ended December 31, 2013, 2012 and 2011 was $7 million, $4 million and $3 million, respectively, and were recorded in operation and maintenance and general and administrative expenses as appropriate. The Partnership has no pension obligations or other post-employment benefits. Beginning January 1, 2013, the Partnership provides a 3% profit sharing contribution to employee 401(k) accounts for all employees with base compensation below a specified threshold. The contribution is in addition to the 401(k) matching contribution and employees become vested based on years of service.
Income Tax, Policy	'
	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 has deferred tax liabilities of $22 million as of December 31, 2013 and 2012 related to the difference between the book and tax basis of property, plant and equipment and intangible assets and they are 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 December 31, 2013 and 2012. The Partnership recognized an immaterial amount for current federal income tax expense and deferred income tax benefit for the years ended December 31, 2013, 2012, and 2011.
	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, SUGS’s operations are now treated as a pass-through entity. Therefore, other than one wholly-owned subsidiary, SUGS’s 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.
	The IRS commenced audits of our 2007 and 2008 federal income tax returns on January 27, 2010. The IRS has now completed its audit of these returns and proposed certain adjustments. The Partnership filed a protest with the IRS to initiate the appeals process and appeal certain of these adjustments. Until this matter is fully resolved, it is not known whether any amounts ultimately recorded would be material, or how such adjustments would affect unitholders. The statute of limitations for these audits has been extended to December 31, 2014. In January 2014, the Partnership settled the 2007 through 2009 tax returns audit for a wholly-owned subsidiary for an immaterial amount.
Equity-Based Compensation	'
	Equity-Based Compensation. The Partnership accounts for equity-based compensation by recognizing the grant-date fair value of awards into expense as they are earned, using an estimated forfeiture rate. The forfeiture rate assumption is reviewed annually to determine whether any adjustments to expense are required.
Earnings per Unit	'
	Earnings per Unit. Basic net income per common unit is computed through the use of the two-class method, which allocates earnings to each class of equity security based on their participation in distributions and deemed distributions. Accretion of the Series A Preferred Units is considered as deemed distributions. Distributions and deemed distributions to the Series A Preferred Units reduce the amount of net income available to the general partner and limited partner interests. The general partners’ interest in net income or loss consists of its respective percentage interest, make-whole allocations for any losses allocated in a prior tax year and IDRs. After deducting the General Partner’s interest, the limited partners’ interest in the remaining net income or loss is allocated to each class of equity units based on distributions and beneficial conversion feature amounts, if applicable, then divided by the weighted average number of common and subordinated units outstanding in each class of security. Diluted net income per common unit is computed by dividing limited partners’ interest in net income, after deducting the General Partner’s interest, by the weighted average number of units outstanding and the effect of non-vested phantom units, Series A Preferred Units and unit options. For special classes of common units, such as the Class F units issued with a beneficial conversion feature, the amount of the benefit associated with the period is added back to net income and the unconverted class is added to the denominator.

Organization_and_Basis_of_Pres1

Organization and Basis of Presentation (Tables)	4 Months Ended				12 Months Ended
	Apr. 30, 2013				Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'				'
Schedule of Purchase Price Allocation [Table Text Block]	'				'
	The assets acquired and liabilities assumed in the SUGS Acquisition were as follows:
		30-Apr-13
	Current assets	$	113
	Property, plant and equipment, net	1,608
	Goodwill	337
	Other non-current assets	1
	Total assets acquired	$	2,059
	Less:
	Current liabilities	(93		)
	Non-current liabilities	(36		)
	Net assets acquired	$	1,930
Revenue by Combined Entity [Table Text Block]	'				'
					The following table presents the revenues and net income for the previously separate entities and combined amounts presented herein:
						Years Ended December 31,
						2013			2012
					Revenues:
					Partnership	$	2,253		$	1,339
					SUGS (1)	268			661
					Combined	$	2,521		$	2,000
					Net income (loss):
					Partnership	$	63		$	48
					SUGS (1)	(36		)	(14		)
					Combined	$	27		$	34
					-1	Combined amounts attributable to SUGS include the period from March 26, 2012 to December 31, 2012 for the year ended December 31, 2012, and the period from January 1, 2013 to April 30, 2013 for the year ended December 31, 2013. Subsequent to the closing of the SUGS Acquisition on April 30, 2013, the results of SUGS were attributable to the Partnership.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies [Abstract]	'
Schedule Of Property, Plant, And Equipment, Useful Lifes	'
	Depreciation of property, plant and equipment is recorded on a straight-line basis over the following estimated useful lives:
	Functional Class of Property	Useful Lives (Years)
	Gathering and Transmission Systems	Oct-50
	Compression Equipment	Feb-30
	Gas Plants and Buildings	May-35
	Other property, plant and equipment	15-Mar

Partners_Capital_and_Distribut1

Partners' Capital and Distributions (Tables)	12 Months Ended
	Dec. 31, 2013
Partners’ Capital and Distributions [Abstract]	'
Schedule of Stockholders Equity [Table Text Block]	'
	Units Activity. The changes in common and Class F units were as follows:
		Common			Class F
	Balance - December 31, 2010	137,281,336			—
	Common unit offerings, net of costs	20,000,001			—
	Issuance of common units under LTIP, net of forfeitures and tax withholding	156,271			—
	Balance - December 31, 2011	157,437,608			—
	Common unit offerings, net of costs	12,650,000			—
	Issuance of common units under the equity distribution agreement, net of cost	691,129			—
	Issuance of common units under LTIP, net of forfeitures and tax withholding	172,720			—
	Balance - December 31, 2012	170,951,457			—
	Issuance of common units under LTIP, net of forfeitures and tax withholding	184,995			—
	Issuance of common units under the equity distribution agreement, net of cost	5,712,138			—
	Conversion of Series A preferred units for common 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 - December 31, 2013	210,850,232			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.
Quarterly Distributions Of Available Cash	'
	Distributions. The Partnership made the following cash distributions per unit during the years ended December 31, 2013 and 2012:
	Distribution Date		Cash Distribution
			(per common unit)
	November 14, 2013		$	0.47
	August 14, 2013		0.465
	May 13, 2013		0.46
	February 14, 2013		0.46
	November 14, 2012		$	0.46
	August 14, 2012		0.46
	May 14, 2012		0.46
	February 13, 2012		0.46

Income_Per_Limited_Partner_Uni1

Income Per Limited Partner Unit (Tables)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Basic And Diluted Income (Loss) From Continuing Operations	'
	The following table provides a reconciliation of the numerator and denominator of the basic and diluted earnings per unit computations for the years ended December 31, 2013, 2012, and 2011.
		For the Years Ended December 31,
		2013					2012						2011
		Income		Units	Per-Unit		Income			Units	Per-Unit		Income			Units	Per-Unit
		(Numerator)		(Denominator)	Amount		(Numerator)			(Denominator)	Amount		(Numerator)			(Denominator)	Amount
	Basic income per unit
	Limited Partners’ interest in net income	$	34	196,227,348	$	0.17	$	27		167,492,735	$	0.16	$	57		145,490,869	$	0.39
	Effect of Dilutive Securities:
	Common unit options	—		22,714			—			10,854			—			19,192
	Phantom units *	—		357,230			—			223,325			—			148,388
	Series A Preferred Units	—		2,050,854			(5		)	4,658,700			(10		)	4,632,389
	Diluted income per unit	$	34	198,658,146	$	0.17	$	22		172,385,614	$	0.13	$	47		150,290,838	$	0.32
	__________________
	*	Amount assumes maximum conversion rate for market condition awards.
Weighted Average Outstanding Amount Of Securities	'
	There were no securities that could potentially dilute earnings per unit in the future that were not included in the computation of diluted earnings per unit

Investment_In_Unconsolidated_A1

Investment In Unconsolidated Affiliates (Tables)	12 Months Ended
	Dec. 31, 2013
Investment In Unconsolidated Affiliates [Abstract]	'
Carrying value of limited and general partnership interest	'
	The carrying value of the Partnership’s investment in each of the unconsolidated affiliates as of December 31, 2013 and 2012 is as follows:
		December 31,
		2013			2012
	HPC	$	442		$	650
	MEP	548			581
	Lone Star	1,070			948
	Ranch JV	36			35
	Grey Ranch	1			—
		$	2,097		$	2,214
Changes In The Partnership's Investment	'
	The following tables summarize the changes in the Partnership’s investment activities in each of the unconsolidated affiliates for the years ended December 31, 2013, 2012 and 2011:
		Year Ended December 31, 2013
		HPC (2)			MEP		Lone Star		Ranch JV			Grey Ranch
	Contributions	$	—		$	—	$	137	$	2		$	—
	Distributions	238			72		79		2			—
	Share of net income	36			39		64		1			1
	Amortization of excess fair value of investment (1)	(6		)	—		—		—			—
		Year Ended December 31, 2012
		HPC			MEP		Lone Star		Ranch JV			Grey Ranch
	Contributions	$	—		$	—	$	343	$	36		$	—
	Distributions	61			75		68		—			—
	Share of net income	35			42		44		(1		)	(9		)
	Amortization of excess fair value of investment (1)	(6		)	—		—		—			—
		Year Ended December 31, 2011
		HPC			MEP(3)		Lone Star(4)		Ranch JV			Grey Ranch
	Contributions	$	—		$	—	$	645	$	—		N/A
	Purchase of additional interest	—			1		—		—			N/A
	Distributions	65			83		22		—			N/A
	Return of investment	—			—		23		—			N/A
	Share of net income	55			43		28		—			N/A
	Amortization of excess fair value of investment (1)	(6		)	—		—		—			N/A
	__________________
	-1	The Partnership’s investment in HPC was adjusted to its fair value on May 26, 2010 and the excess fair value over net book value was comprised of two components: (1) $155 million was attributed to HPC’s long-lived assets and is being amortized as a reduction of income from unconsolidated affiliates over the useful lives of the respective assets, which vary from 15 to 30 years, and (2) $32 million could not be attributed to a specific asset and therefore will not be amortized in future periods.
	-2	HPC entered into a $500 million 5-year revolving credit facility in September 2013, pursuant to which the Partnership pledged its 49.99% equity interest in HPC. Upon closing such credit facility, HPC borrowed $370 million to fund a non-recurring return of investment to its partners of which the Partnership received $185 million. The amount outstanding under this facility was $445 million as of December 31, 2013. The Partnership’s contingent obligation with respect to the outstanding borrowings under this facility was $222 million at December 31, 2013.
	-3	In September 2011, the Partnership purchased an additional 0.1% interest in MEP from ETP for $1 million in cash, bringing the total membership interest to 50%.
	-4	For the period from initial contribution, May 2, 2011, to December 31, 2011.
	N/A	The Partnership acquired a 50% interest in Grey Ranch in March 2012, as part of the SUGS Acquisition in April 2013.

Derivative_Instruments_Derivat

Derivative Instruments Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments [Abstract]	'
Schedule Of Derivative Assets And Liabilities Statement	'
	The Partnership’s derivative assets and liabilities, including credit risk adjustments, as of December 31, 2013 and 2012 are detailed below:
		Assets								Liabilities
		December 31,								December 31,
		2013				2012				2013				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	$	3			$	4			$	9			$	1
	Long-term amounts
	Commodity contracts	1				1				—				—
	Embedded derivatives in Series A Preferred Units	—				—				19				25
	Total derivatives	$	4			$	5			$	28			$	31
Detail Effect Of Derivative Assets And Liabilities In Statement Of Operations	'
	The Partnership’s statements of operations for the years ended December 31, 2013, 2012 and 2011 were impacted by derivative instruments activities as detailed below:
			Years Ended December 31,
			2013				2012				2011
	Derivatives in cash flow hedging relationships:		Change in Value Recognized in AOCI on Derivatives
			(Effective Portion)
	Commodity derivatives		$	—			$	(4	)		$	(13	)
	Derivatives in cash flow hedging relationships:	Location of Gain/(Loss)	Amount of Gain/(Loss) Reclassified from AOCI into Income
		Recognized in Income	(Effective Portion)
	Commodity derivatives	Revenue	$	—			$	6			$	(19	)
			Years Ended December 31,
			2013				2012				2011
	Derivatives not designated in a hedging relationship:	Location of Gain/(Loss)	Amount of Gain/(Loss) from De-designation Amortized from AOCI into Income
		Recognized in Income
	Commodity derivatives	Revenue	$	—			$	(5	)		$	—
	Derivatives not designated in a hedging relationship:	Location of Gain/(Loss)	Amount of Gain/(Loss) Recognized in Income on Derivatives
		Recognized in Income
	Commodity derivatives	Revenue	$	(9	)		$	16			$	—
	Embedded derivatives	Other income & deductions	6				14				18
			$	(3	)		$	30			$	18

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Instrument	'
Partnership's Long-Term Debt	'
	Obligations in the form of senior notes and borrowings under the credit facilities are as follows:
		December 31,
		2013			2012
	Senior notes	$	2,800		$	1,965
	Revolving loans	510			192
	Total	3,310			2,157
	Less: current portion	—			—
	Long-term debt	$	3,310		$	2,157
	Availability under revolving credit facility:
	Total credit facility limit	$	1,200		$	1,150
	Revolving loans	(510		)	(192		)
	Letters of credit	(14		)	(12		)
	Total available	$	676		$	946
Long-Term Debt Maturities	'
	Long-term debt maturities as of December 31, 2013 for each of the next five years are as follows:
	Year Ended December 31,	Amount
	2014	$	—
	2015	—
	2016	—
	2017	—
	2018	600
	Thereafter	2,710
	Total	$	3,310

Intangible_Assets_Tables

Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Finite-Lived Intangible Assets by Major Class	'
	Activity related to intangible assets, net consisted of the following:
		Customer			Trade Names			Total
		Relations
	Balance at January 1, 2012	$	681		$	60		$	741
	Amortization	(26		)	(3		)	(29		)
	Balance at December 31, 2012	655			57			712
	Amortization	(26		)	(4		)	(30		)
	Balance at December 31, 2013	$	629		$	53		$	682

Fair_Value_Measures_Tables

Fair Value Measures (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Measures [Abstract]	'
Partnership's Derivative Assets And Liabilities Measured At Fair Value On A Recurring Basis	'
	The following table presents the Partnership’s derivative assets and liabilities measured at fair value on a recurring basis:
		Fair Value Measurement at December 31,
		2013							2012
		Fair Value			Level 2		Level 3		Fair Value		Level 2		Level 3
		Total							Total
	Assets
	Commodity Derivatives:
	Natural Gas	$	2		$	2	$	—	$	2	$	2	$	—
	Natural Gas Liquids	2			2		—		1		1		—
	Condensate	—			—		—		2		2		—
	Total Assets	$	4		$	4	$	—	$	5	$	5	$	—
	Liabilities
	Commodity Derivatives:
	Natural Gas	$	4		$	4	$	—	$	5	$	5	$	—
	Natural Gas Liquids	4			4		—		1		1		—
	Condensate	1			1		—		—		—		—
	Embedded Derivatives in Series A Preferred Units	19			—		19		25		—		25
	Total Liabilities	$	28		$	9	$	19	$	31	$	6	$	25
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	'
	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		31-Dec-13
	Credit Spread		4.16	%
	Volatility		23.71	%
Changes In Level 3 Derivatives Measured On A Recurring Basis	'
	The following table presents the changes in Level 3 derivatives measured on a recurring basis for the years ended December 31, 2013 and 2012. There were no transfers between Level 2 and Level 3 derivatives for the years ended December 31, 2013 and 2012.
		Embedded Derivatives in
		Series A Preferred Units
	Balance at January 1, 2012	$	39
	Change in fair value	(14		)
	Balance at December 31, 2012	25
	Change in fair value, net of gain at conversion of $26 million	(6		)
	Balance at December 31, 2013	$	19

Leases_Tables

Leases (Tables)	12 Months Ended
	Dec. 31, 2013
Leases [Abstract]	'
Schedule Of Future Minimum Lease Payments That Had Initial Or Remaining Noncancelable Lease Terms	'
	The following table is a schedule of future minimum lease payments for office space and certain equipment leased by the Partnership, that had initial or remaining non-cancelable lease terms in excess of one year as of December 31, 2013:
	For the year ending December 31,	Operating Lease
	2014	$	3
	2015	3
	2016	2
	2017	2
	2018	2
	Thereafter	34
	Total minimum lease payments	$	46

Commitments_And_Contingencies_1

Commitments And Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Accrued Liabilities [Table Text Block]	'
	The table below reflects the environmental liabilities recorded in the consolidated balance sheet at December 31, 2013 and 2012 where management believes a loss is probable and reasonably estimable. The Partnership does not have any material environmental remediation matters assessed as reasonably possible that would require disclosure in the financial statements.
		December 31,
		2013		2012
	Current	$	2	$	5
	Noncurrent	6		7
	Total environmental liabilities	$	8	$	12

Series_A_Preferred_Units_Table

Series A Preferred Units (Tables)	12 Months Ended
	Dec. 31, 2013
Temporary Equity Disclosure [Abstract]	'
Beginning And Ending Balances Of The Series A Preferred Units	'
	The following table provides a reconciliation of the beginning and ending balances of the Series A Preferred Units for the year ended December 31, 2013 and 2012:
		Units		Amount
	Balance at January 1, 2012	4,371,586		$	71
	Accretion to redemption value	N/A		2
	Balance at December 31, 2012	4,371,586		73
	Series A Preferred Units converted into common units	(2,459,017	)	(41		)
	Balance at December 31, 2013	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. Accretion during 2013
	was immaterial.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2013
Related Party Balances [Abstract]	'
Related Party Receivable and Payable Balances [Table Text Block]	'
	As of December 31, 2013 and 2012, details of the Partnership’s related party receivables and related party payables were as follows:
		December 31,
		2013		2012
	Related party receivables
	HPC	$	1	$	1
	ETE and its subsidiaries	25		5
	Ranch JV	2		2
	Total related party receivables	$	28	$	8
	Related party payables
	HPC	$	1	$	1
	ETE and its subsidiaries	68		94
	Total related party payables	$	69	$	95

Concentration_Risk_Tables

Concentration Risk (Tables)	12 Months Ended
	Dec. 31, 2013
Risks and Uncertainties [Abstract]	'
Schedule Of Revenues And Cost Of Sales By Major Customer And Supplier	'
	The following table provides information about the extent of reliance on major customers and gas suppliers. Total revenues and cost of sales from transactions with an external customer or supplier amounting to 10% or more of revenue or cost of gas and liquids are disclosed below, together with the identity of the reporting segment.
			Years Ended December 31,
		Reportable Segment	2013		2012		2011
	Customer
	Customer A	Gathering and Processing	$	381	$	367	$	366
	Customer B	Gathering and Processing	362		451		—
	Supplier
	Supplier A	Gathering and Processing	164		171		133
	Supplier B	Gathering and Processing	185		—		—

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Information [Abstract]	'
Amounts Related To Balance Sheets For Each Segment	'
	Results for each period, together with amounts related to each segment are shown below:
		Years Ended December 31,
		2013			2012				2011
	External Revenue
	Gathering and Processing	$	2,287		$	1,797			$	1,226
	Natural Gas Transportation	1			1				1
	NGL Services	—			—				—
	Contract Services	215			183				190
	Corporate	18			19				17
	Eliminations	—			—				—
	Total	$	2,521		$	2,000			$	1,434
	Intersegment Revenue
	Gathering and Processing	$	—		$	—			$	—
	Natural Gas Transportation	—			—				—
	NGL Services	—			—				—
	Contract Services	15			21				17
	Corporate	—			—				—
	Eliminations	(15		)	(21		)		(17		)
	Total	$	—		$	—			$	—
	Cost of Sales
	Gathering and Processing	$	1,767		$	1,373			$	993
	Natural Gas Transportation	—			(1		)		(2		)
	NGL Services	—			—				—
	Contract Services	26			15				22
	Corporate	—			—				—
	Eliminations	—			—				—
	Total	$	1,793		$	1,387			$	1,013
	Segment Margin
	Gathering and Processing	$	521		$	423			$	233
	Natural Gas Transportation	—			2				3
	NGL Services	—			—				—
	Contract Services	204			189				185
	Corporate	18			20				17
	Eliminations	(15		)	(21		)		(17		)
	Total	$	728		$	613			$	421
	Operation and Maintenance
	Gathering and Processing	$	237		$	183			$	98
	Natural Gas Transportation	—			—				—
	NGL Services	—			—				—
	Contract Services	72			66				66
	Corporate	1			—				—
	Eliminations	(14		)	(21		)		(17		)
	Total	$	296		$	228			$	147
	Depreciation and Amortization
	Gathering and Processing	$	186		$	159			$	87
	Natural Gas Transportation	—			—				—
	NGL Services	—			—				—
	Contract Services	98			86				78
	Corporate	3			7				4
	Eliminations	—			—				—
	Total	$	287		$	252			$	169
		Years Ended December 31,
		2013			2012				2011
	Income from Unconsolidated Affiliates
	Gathering and Processing	$	1		$	(10	)		$	—
	Natural Gas Transportation	70			71				92
	NGL Services	64			44				28
	Contract Services	—			—				—
	Corporate	—			—				—
	Eliminations	—			—				—
	Total	$	135		$	105			$	120
	Expenditures for Long-Lived Assets
	Gathering and Processing	$	721		$	395			$	282
Natural Gas Transportation	—			—				—
NGL Services	—			—				—
Contract Services	311			164				120
Corporate	2			1				4
Eliminations	—			—				—
Total	$	1,034		$	560			$	406
	31-Dec-13
	2013			2012				2011
Assets
Gathering and Processing	$	4,748		$	4,210			$	1,960
Natural Gas Transportation	991			1,232				1,297
NGL Services	1,070			948				629
Contract Services	1,897			1,672				1,621
Corporate	76			61				61
Eliminations	—			—				—
Total	$	8,782		$	8,123			$	5,568
Investment in Unconsolidated Affiliates
Gathering and Processing	$	36		$	35			$	—
Natural Gas Transportation	991			1,231				1,296
NGL Services	1,070			948				629
Contract Services	—			—				—
Corporate	—			—				—
Eliminations	—			—				—
Total	$	2,097		$	2,214			$	1,925
Goodwill
Gathering and Processing	$	651		$	651			$	313
Natural Gas Transportation	—			—				—
NGL Services	—			—				—
Contract Services	477			477				477
Corporate	—			—				—
Eliminations	—			—				—
Total	$	1,128		$	1,128			$	790
Reconciliation Of Total Segment Margin To Net Income (Loss) From Continuing Operations Before Income Taxes	'
	The table below provides a reconciliation of total segment margin to income before income taxes:
		Years Ended December 31,
		2013			2012				2011
	Total segment margin	$	728		$	613			$	421
	Operation and maintenance	(296		)	(228		)		(147		)
	General and administrative	(88		)	(100		)		(67		)
	(Loss) gain on assets sales, net	(2		)	(3		)		2
	Depreciation and amortization	(287		)	(252		)		(169		)
	Income from unconsolidated affiliates	135			105				120
	Interest expense, net	(164		)	(122		)		(103		)
	Loss on debt refinancing, net	(7		)	(8		)		—
	Other income and deductions, net	7			29			*	17
	Income before income taxes	$	26		$	34			$	74
	__________________
	*	Other income and deductions, net for the year ended December 31, 2012, included a one-time producer payment of $16 million related to an assignment of certain contracts.

EquityBased_Compensation_Table

Equity-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2013
Common Unit Options [Member]	'
Common Unit Options Activity	'
	The common unit options activity for the years ended December 31, 2013, 2012, and 2011 is as follows:
	2013
	Common Unit Options	Units		Weighted Average Exercise Price
	Outstanding at the beginning of period	156,550		$	21.96
	Exercised	(14,000	)	21.14
	Outstanding at end of period	142,550		22.04
	Exercisable at the end of the period	142,550
	2012
	Common Unit Options	Units		Weighted Average Exercise Price
	Outstanding at the beginning of period	156,850		$	21.99
	Forfeited or expired	(300	)	23.73
	Outstanding at end of period	156,550		21.96
	Exercisable at the end of the period	156,550
	2011
	Common Unit Options	Units		Weighted Average Exercise Price
	Outstanding at the beginning of period	201,950		$	21.93
	Exercised	(38,300	)	20.84
	Forfeited or expired	(6,800	)	26.72
	Outstanding at end of period	156,850		21.99
	Exercisable at the end of the period	156,850
Phantom Units	'
Restricted (Non-Vested) Common Unit Activity	'
	The following table presents phantom unit activity for the years ended December 31, 2013, 2012 and 2011:
	2013
	Phantom Units	Units		Weighted Average
				Grant Date
				Fair Value
	Outstanding at the beginning of the period	1,231,342		$	23.22
	Service condition grants	62,360		25.44
	Vested service condition	(231,163	)	24.8
	Forfeited service condition	(35,900	)	23.22
	Forfeited market condition	(44,397	)	19.52
	Total outstanding at end of period	982,242		23.16
	2012
	Phantom Units	Units		Weighted Average
				Grant Date
				Fair Value
	Outstanding at the beginning of the period	1,086,393		$	24.51
	Service condition grants	503,625		21.39
	Vested service condition	(223,258	)	24.71
	Vested market condition	(10,200	)	19.52
	Forfeited service condition	(120,868	)	24.85
	Forfeited market condition	(4,350	)	19.52
	Total outstanding at end of period	1,231,342		23.22
	2011
	Phantom Units	Units		Weighted Average
				Grant Date
				Fair Value
	Outstanding at the beginning of the period	742,517		$	23.61
	Service condition grants	596,320		24.55
	Vested service condition	(142,520	)	24.73
	Vested market condition	(8,550	)	19.52
	Forfeited service condition	(88,474	)	24.99
	Forfeited market condition	(12,900	)	19.52
	Total outstanding at end of period	1,086,393		24.51

Quarterly_Financial_Data_Unaud1

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of Quarterly Financial Information	'
	Quarterly Financial Data (Unaudited)
		Quarter Ended
	2013	31-Dec			September 30			30-Jun		31-Mar
	Operating revenues	$	677		$	665		$	639	$	540
	Operating income (loss)	12			24			34		(15		)
	Net (loss) income attributable to Regency Energy Partners LP	(1		)	39			10		(29		)
	Earnings per common units:
	Basic net (loss) income per common unit	(0.03		)	0.16			0.07		(0.06		)
	Diluted net (loss) income per common unit	(0.03		)	0.05			0.07		(0.06		)
		Quarter Ended
	2012 *	31-Dec			September 30			30-Jun		31-Mar
	Operating revenues	$	587		$	527		$	511	$	375
	Operating income (loss)	8			5			22		(5		)
	Net (loss) income attributable to Regency Energy Partners LP	(8		)	(1		)	26		15
	Earnings per common units:
	Basic net (loss) income per common unit	(0.08		)	(0.04		)	0.14		0.15
	Diluted net (loss) income per common unit	(0.08		)	(0.04		)	0.1		0.14
	_______________________
	*	Due to the SUGS Acquisition, these quarterly results have been retrospectively adjusted to include the operations of SUGS beginning March 26, 2012, the date upon which common control began.

Organization_and_Basis_of_Pres2

Organization and Basis of Presentation Narrative (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Apr. 30, 2013
Business Acquisition, Cost of Acquired Entity, Purchase Price	'	'	'	$1,500
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	6,274,483	0	0	'
Estimated Closing Adjustments	'	'	'	107
Capital Units [Member]	'	'	'	'
Noncash or Part Noncash Acquisition, Noncash Financial or Equity Instrument Consideration, Shares Issued	31,372,419	'	'	'
Class F Units [Member]	'	'	'	'
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	6,274,483	'	'	'
May Twenty Six Service Agreement [Member] | ETE [Member]	'	'	'	'
Management Fee, Amount Paid	10	'	'	'
4.5% Senior Notes Due Two Thousand Twenty Three [Member]	'	'	'	'
Business Acquisition, Cost of Acquired Entity, Cash Payment	'	'	'	$600

Organization_and_Basis_of_Pres3

Organization and Basis of Presentation SUGS PPA (Details) (USD $)	Apr. 30, 2013
In Millions, unless otherwise specified
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Business Acquisition, Purchase Price Allocation, Current Assets	$113
Business Acquisition, Purchase Price Allocation, Property, Plant and Equipment	1,608
Business Acquisition, Purchase Price Allocation, Goodwill Amount	337
Business Acquisition, Purchase Price Allocation, Other Noncurrent Assets	1
Business Acquisition, Purchase Price Allocation, Assets Acquired	2,059
Business Acquisition, Purchase Price Allocation, Current Liabilities	-93
Business Acquisition, Purchase Price Allocation, Other Noncurrent Liabilities	-36
Business Acquisition, Purchase Price Allocation, Assets Acquired (Liabilities Assumed), Net	$1,930

Organization_and_Basis_of_Pres4

Organization and Basis of Presentation Combined Information (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Revenues	$677	$665	$639	$540	$587	$527	$511	$375	$2,521	$2,000	$1,434
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	27	34	74
Regency [Member]	'	'	'	'	'	'	'	'	'	'	'
Revenues	'	'	'	'	'	'	'	'	2,253	1,339	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	63	48	'
SUGS [Member]	'	'	'	'	'	'	'	'	'	'	'
Revenues	'	'	'	'	'	'	'	'	268	661	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	-36	-14	'
Combined [Member]	'	'	'	'	'	'	'	'	'	'	'
Revenues	'	'	'	'	'	'	'	'	2,521	2,000	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	$27	$34	'

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Property, Plant and Equipment	'	'	'
Capitalized Interest Costs	$2	$1	$1
Equity Method Investment, Ownership Percentage	20.00%	'	'
Accounting Policies [Abstract]	'	'	'
Depreciation out of period adjustment	'	7	'
Contributions by employer	7	4	3
Deferred tax liabilities related to property, plant, and equipment	22	22	'
Profit Sharing Plan Employer Percentage Contribution	3.00%	'	'
Policyholder Benefits and Claims Incurred, Net, Health	9	9	6
Successor	'	'	'
Accounting Policies [Abstract]	'	'	'
Depreciation expense	$258	$219	$138
Minimum [Member]	'	'	'
Accounting Policies [Abstract]	'	'	'
Intangible assets useful life, minimum	'20 years 0 months 0 days	'	'
Minimum [Member] | Gathering and Transmission Systems	'	'	'
Property, Plant and Equipment	'	'	'
Property, Plant and Equipment, Useful Life	'10 years 0 months 0 days	'	'
Minimum [Member] | Compression Equipment	'	'	'
Property, Plant and Equipment	'	'	'
Property, Plant and Equipment, Useful Life	'2 years 0 months 0 days	'	'
Minimum [Member] | Gas Plants and Buildings	'	'	'
Property, Plant and Equipment	'	'	'
Property, Plant and Equipment, Useful Life	'5 years 0 months 0 days	'	'
Minimum [Member] | Other property, plant and equipment	'	'	'
Property, Plant and Equipment	'	'	'
Property, Plant and Equipment, Useful Life	'3 years 0 months 0 days	'	'
Maximum [Member]	'	'	'
Accounting Policies [Abstract]	'	'	'
Intangible assets useful life, minimum	'30 years 0 months 0 days	'	'
Maximum [Member] | Gathering and Transmission Systems	'	'	'
Property, Plant and Equipment	'	'	'
Property, Plant and Equipment, Useful Life	'50 years 0 months 0 days	'	'
Maximum [Member] | Compression Equipment	'	'	'
Property, Plant and Equipment	'	'	'
Property, Plant and Equipment, Useful Life	'30 years 0 months 0 days	'	'
Maximum [Member] | Gas Plants and Buildings	'	'	'
Property, Plant and Equipment	'	'	'
Property, Plant and Equipment, Useful Life	'35 years 0 months 0 days	'	'
Maximum [Member] | Other property, plant and equipment	'	'	'
Property, Plant and Equipment	'	'	'
Property, Plant and Equipment, Useful Life	'15 years 0 months 0 days	'	'

Partners_Capital_and_Distribut2

Partners' Capital and Distributions Narrative (Details) (USD $)

3 Months Ended

12 Months Ended

1 Months Ended

3 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 27, 2013

Oct. 31, 2011

Aug. 31, 2010

Mar. 31, 2012

2-May-11

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

days

days

Common Unit Offering

Common Unit Offering

Common Unit Offering

Private Common Unit Offering

Common Units

Common Units

Common Units

Common Units

Common Units

Common Unitholders

Common Unitholders

Common Unitholders

Common Unitholders

Class F Units [Member]

Class F Units [Member]

Gathering And Processing

General Partner Interest

Senior Notes Due Two Thousand Sixteen [Member]

Capital Unit [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Distribution Agreement Maximum Aggregate Value Of Common Units Sold

'

'

'

'

'

'

'

'

'

$200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common units issued under equity distribution program, net of costs

'

'

'

'

'

'

'

'

'

149,000,000

15,000,000

0

'

'

'

'

'

'

'

'

'

'

'

149,000,000

15,000,000

'

'

'

'

'

'

Remaining amount available to be issued under the Equity Distribution Agreement

34,000,000

'

'

'

'

'

'

'

'

34,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Shares, New Issues

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12,650,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Common Issuance Price Per Unit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$24.47

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Issuance or Sale of Equity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

297,000,000

'

'

'

'

'

'

'

'

Senior notes redemption percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35.00%

Repayments of Long-term Debt

'

'

'

'

'

'

'

'

'

163,000,000

88,000,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

88,000,000

Public common units offerings, units

'

'

'

'

'

'

'

'

'

'

'

'

'

11,500,000

17,537,500

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Price per common unit issued in public offering

'

'

'

'

'

'

'

'

'

'

'

'

'

$20.92

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common unit offerings, net of costs

'

'

'

'

'

'

'

'

'

0

297,000,000

436,000,000

'

232,000,000

408,000,000

'

204,000,000

'

'

'

'

'

'

'

297,000,000

436,000,000

'

'

'

'

'

Private common unit offering, units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,500,001

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Noncontrolling interest ownership percentage in joint ventures, by third party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40.00%

'

'

Required distribution of all Partnership's available cash, number of days after each quarter

45

'

'

'

'

'

'

'

'

45

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General partners interest in initial distribution

'

'

'

'

'

'

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current general partners ownership interest

1.31%

'

'

'

'

'

'

'

'

1.31%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital Account, Units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

210,850,232

170,951,457

157,437,608

137,281,336

'

'

'

'

6,274,483

0

'

2,834,381

'

Payment Date

14-Feb-14

14-Nov-13

14-Aug-13

13-May-13

14-Feb-13

14-Nov-12

14-Aug-12

14-May-12

13-Feb-12

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions per common unit

$0.48

$0.47

$0.47

$0.46

$0.46

$0.46

$0.46

$0.46

$0.46

$1.87

$1.84

$1.81

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

'

'

'

'

'

'

'

'

'

6,274,483

0

0

'

'

'

'

'

'

31,372,419

'

'

'

'

'

'

'

6,274,483

'

'

'

'

Sales price per Class F common unit

'

'

'

'

'

'

'

'

'

'

'

'

23.91

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Discount per Class F common unit

'

'

'

'

'

'

'

'

'

'

'

'

$2.19

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners_Capital_and_Distribut3

Partners' Capital and Distributions Quarterly Distributions Of Available Cash (Details) (USD $)

3 Months Ended

12 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Partners’ Capital and Distributions [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Distribution date

14-Feb-14

14-Nov-13

14-Aug-13

13-May-13

14-Feb-13

14-Nov-12

14-Aug-12

14-May-12

13-Feb-12

'

'

'

Cash distribution per unit

$0.48

$0.47

$0.47

$0.46

$0.46

$0.46

$0.46

$0.46

$0.46

$1.87

$1.84

$1.81

Partners_Capital_and_Distribut4

Partners' Capital and Distributions Units Activity (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	6,274,483	0	0	'
Common Units	'	'	'	'
Partners' Capital Account, Units	210,850,232	170,951,457	157,437,608	137,281,336
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures, Net of Tax	184,995	172,720	156,271	'
Partners' Capital Account, Units, Sale of Units	'	12,650,000	20,000,001	'
Stock Issued During Period, Shares, Issued for Cash	5,712,138	691,129	'	'
Partners' Capital Account, Units, Converted	2,629,223	'	'	'
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	31,372,419	'	'	'
Class F Units [Member]	'	'	'	'
Partners' Capital Account, Units	6,274,483	0	'	'
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	6,274,483	'	'	'

Income_Per_Limited_Partner_Uni2

Income Per Limited Partner Unit Narrative (Details)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
General Partner Make Whole Amount	100.00%

Table_Basic_And_Diluted_EPU_De

Table - Basic And Diluted EPU (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net income allocated to limited partners	$34	$27	$57
Diluted income from continuing operations amount	34	22	47
Basic income from continuing operations units	196,227,348	167,492,735	145,490,869
Diluted income from continuing operations units	198,658,146	172,385,614	150,290,838
Basic and diluted income from continuing operations per common unit	$0.17	$0.16	$0.39
Diluted income from continuing operations per common unit	$0.17	$0.13	$0.32
Common Unit Options [Member]	'	'	'
Dilutive Securities, Effect on Basic Earnings Per Share, Including Options and Restrictive Stock Units	0	0	0
Incremental Common Shares Attributable to Written Put Options	22,714	10,854	19,192
Phantom Units	'	'	'
Dilutive Securities, Effect on Basic Earnings Per Share, Including Options and Restrictive Stock Units	0	0	0
Incremental Common Shares Attributable to Share-based Payment Arrangements	357,230	223,325	148,388
Series A Preferred Units	'	'	'
Dilutive Securities, Effect on Basic Earnings Per Share, Including Options and Restrictive Stock Units	$0	($5)	($10)
Incremental Common Shares Attributable to Conversion of Preferred Stock	2,050,854	4,658,700	4,632,389

Acquisitions_And_Dispositions_

Acquisitions And Dispositions Narrative (Details) (USD $)

12 Months Ended

1 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

1 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Oct. 10, 2013

Apr. 30, 2013

Feb. 28, 2014

2-May-11

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Sep. 01, 2011

Dec. 31, 2011

Dec. 31, 2013

Sep. 02, 2011

Dec. 31, 2011

Dec. 31, 2013

2-May-11

Dec. 31, 2012

Dec. 31, 2011

Oct. 10, 2013

Dec. 23, 2013

Feb. 03, 2014

Feb. 28, 2014

Hoover Energy [Member]

Lone Star [Member]

Lone Star [Member]

Lone Star [Member]

ETP [Member]

MEP [Member]

MEP [Member]

MEP [Member]

MEP [Member]

Ranch JV [Member]

Ranch JV [Member]

Private Common Unit Offering

Capital Units [Member]

Capital Units [Member]

PVR [Member]

Eagle Rock [Member]

Hoover Energy [Member]

Hoover Energy [Member]

Private Common Unit Offering

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments to Acquire Interest in Subsidiaries and Affiliates

$148,000,000

$356,000,000

$53,000,000

'

'

'

$593,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership in affiliate

20.00%

'

'

'

'

'

'

'

30.00%

70.00%

'

'

50.00%

'

'

33.33%

'

'

'

'

'

'

'

Business acquisition, cost of acquired entity, purchase price

'

'

'

'

1,500,000,000

'

'

'

1,980,000,000

'

'

'

'

'

'

'

'

'

'

'

'

281,600,000

'

Private common unit offering, units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,500,001

'

'

'

'

'

4,040,471

Business Combination, Acquisition Related Costs

'

'

'

'

'

183,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common unit offerings, net of issuance costs

0

297,000,000

436,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

204,000,000

297,000,000

436,000,000

'

'

'

'

Addtional ownership in affiliate acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

0.10%

'

'

'

'

'

'

'

'

'

Payments to Acquire Additional Interest in Subsidiaries and Affiliates

'

'

'

'

'

'

'

0

'

'

1,000,000

1,000,000

'

'

0

'

'

'

'

'

'

'

'

Proposed Business Combination, Acquisition Related Costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

37,000,000

'

'

'

Proposed Business Acquisition, Cost of Acquired Entity, Purchase Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,600,000,000

1,300,000,000

'

'

Proposed Business Acquisition, Cost of Acquired Entity, Liabilities Incurred

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,800,000,000

'

'

'

Number of Share Received in Exchange of Each Share

'

'

'

1.02

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment_In_Unconsolidated_A2

Investment In Unconsolidated Affiliates Narrative (Details) (USD $)

Dec. 31, 2013

25-May-10

Dec. 31, 2011

Dec. 31, 2013

Sep. 01, 2011

31-May-10

Dec. 31, 2011

Dec. 31, 2013

Sep. 02, 2011

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Apr. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

In Millions, unless otherwise specified

HPC [Member]

HPC [Member]

HPC [Member]

MEP [Member]

MEP [Member]

MEP [Member]

MEP [Member]

MEP [Member]

Lone Star [Member]

Lone Star [Member]

Ranch JV [Member]

Ranch JV [Member]

Grey Ranch JV [Member]

Grey Ranch JV [Member]

Minimum [Member]

Maximum [Member]

HPC [Member]

HPC [Member]

Schedule of Equity Method Investments [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment Excess Fair Value Over Book Value Adjustment Long Lived Assets

'

$155

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

20.00%

'

'

49.99%

'

'

'

50.00%

'

'

30.00%

'

33.33%

50.00%

50.00%

'

'

Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest

'

'

'

'

'

49.90%

'

'

'

'

'

'

'

'

'

'

'

Property, Plant and Equipment, Useful Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'15 years 0 months 0 days

'30 years 0 months 0 days

Equity Method Investment Excess Fair Value Over Book Value Adjustment Not Attributed To Specific Assets

'

32

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Additional Ownership Percentage Acquired

'

'

'

'

'

'

'

'

0.10%

'

'

'

'

'

'

'

'

Payments to Acquire Additional Interest in Subsidiaries and Affiliates

'

'

$0

'

$1

'

$1

'

'

$0

'

$0

'

'

'

'

'

Investment_In_Unconsolidated_A3

Investment In Unconsolidated Affiliates Table - Carrying Value of Investment In Unconsolidated Affiliates (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Schedule of Investments	'	'
Investment in Unconsolidated Affiliates, Carrying Value	$2,097	$2,214
HPC [Member]	'	'
Schedule of Investments	'	'
Investment in Unconsolidated Affiliates, Carrying Value	442	650
MEP [Member]	'	'
Schedule of Investments	'	'
Investment in Unconsolidated Affiliates, Carrying Value	548	581
Lone Star [Member]	'	'
Schedule of Investments	'	'
Investment in Unconsolidated Affiliates, Carrying Value	1,070	948
Ranch JV [Member]	'	'
Schedule of Investments	'	'
Investment in Unconsolidated Affiliates, Carrying Value	36	35
Grey Ranch JV [Member]	'	'
Schedule of Investments	'	'
Investment in Unconsolidated Affiliates, Carrying Value	$1	$0

Table_Investment_In_Unconsolid

Table - Investment In Unconsolidated Affiliates (Details) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

25-May-10

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 01, 2011

31-May-10

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 02, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Apr. 30, 2013

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

HPC [Member]

HPC [Member]

HPC [Member]

HPC [Member]

HPC [Member]

MEP [Member]

MEP [Member]

MEP [Member]

MEP [Member]

MEP [Member]

MEP [Member]

Lone Star [Member]

Lone Star [Member]

Lone Star [Member]

Ranch JV [Member]

Ranch JV [Member]

Ranch JV [Member]

Grey Ranch JV [Member]

Grey Ranch JV [Member]

Grey Ranch JV [Member]

Non-recurring Distribution [Member]

Minimum [Member]

Maximum [Member]

HPC [Member]

HPC [Member]

Equity Method Investment Excess Fair Value Over Book Value Adjustment Long Lived Assets

'

'

'

'

$155

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contributions

'

'

'

'

'

'

0

0

0

'

'

0

0

[1]

0

'

137

343

[2]

645

2

36

0

0

0

'

'

'

'

Payments to Acquire Additional Interest in Subsidiaries and Affiliates

'

'

'

'

'

'

'

'

0

1

'

'

'

1

'

'

'

0

'

'

0

'

'

'

'

'

'

Distributions of earnings received from unconsolidated affiliates

'

'

'

'

'

'

238

61

65

'

'

72

75

[1]

83

'

79

68

[2]

22

2

0

0

0

0

'

'

'

'

Equity Method Investment, Return of Investment

'

'

'

'

'

'

'

'

0

'

'

'

'

0

'

'

'

23

'

'

0

'

'

'

'

'

'

Share of net income

'

135

105

120

'

'

36

35

55

'

'

39

42

[1]

43

'

64

44

[2]

28

1

-1

0

1

-9

'

'

'

'

Amortization of excess fair value of investment (1)

'

'

'

'

'

'

-6

[3]

-6

[3]

-6

[3]

'

'

0

0

[1]

0

'

0

0

[2]

0

0

0

0

0

0

'

'

'

'

Addtional ownership in affiliate acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.10%

'

'

'

'

'

'

'

'

'

'

'

'

Ownership in affiliate

'

20.00%

'

'

'

'

49.99%

'

'

'

'

50.00%

'

'

'

30.00%

'

'

33.33%

'

'

50.00%

'

50.00%

'

'

'

Partneship ownership interest percentage

'

'

'

'

'

'

'

'

'

'

49.90%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Property, Plant and Equipment, Useful Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'15 years 0 months 0 days

'30 years 0 months 0 days

Equity Method Investment Excess Fair Value Over Book Value Adjustment Not Attributed To Specific Assets

'

'

'

'

32

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

185

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

1,200

1,150

'

'

500

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing Amount for Return of Capital Distribution

'

'

'

'

'

370

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Interest pledged by Regency Energy Partners LP in Regency Intrastate Gas LP

49.99%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amount Outstanding

'

510

192

'

'

'

445

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Guarantor Obligations, Maximum Exposure, Undiscounted

'

$222

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

HPC entered into a $500 million 5-year revolving credit facility in September 2013, pursuant to which the Partnership pledged its 49.99% equity interest in HPC. Upon closing such credit facility, HPC borrowed $370 million to fund a non-recurring return of investment to its partners of which the Partnership received $185 million. The amount outstanding under this facility was $445 million as of December 31, 2013. The Partnership’s contingent obligation with respect to the outstanding borrowings under this facility was $222 million at December 31, 2013.

[2]

In September 2011, the Partnership purchased an additional 0.1% interest in MEP from ETP for $1 million in cash, bringing the total membership interest to 50%.

[3]

The Partnership’s investment in HPC was adjusted to its fair value on May 26, 2010 and the excess fair value over net book value was comprised of two components: (1) $155 million was attributed to HPC’s long-lived assets and is being amortized as a reduction of income from unconsolidated affiliates over the useful lives of the respective assets, which vary from 15 to 30 years, and (2) $32 million could not be attributed to a specific asset and therefore will not be amortized in future periods.

Derivative_Instruments_Narrati

Derivative Instruments Narrative (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Apr. 30, 2012
In Millions, unless otherwise specified
Derivative	'	'	'
Borrowings subject to interest rate hedges	'	'	$250
Outstanding borrowings in interest rate risk	510	192	'
Maximum [Member]	'	'	'
Derivative	'	'	'
Credit risk of derivatives	4	'	'
Reduction in credit risk of derivatives due to netting feature	$1	'	'
SUGS [Member]	'	'	'
Derivative	'	'	'
Derivative, Nonmonetary Notional Amount	'	4,562,500	'

Derivative_Instruments_Table_S

Derivative Instruments Table - Schedule Of Derivative Assets And Liabilities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivative asset, fair value, gross asset	$4	$5
Derivative liability, fair value, gross liability	28	31
Derivatives Designated as Cash Flow Hedges	'	'
Derivative asset, fair value, gross asset	0	0
Derivative liability, fair value, gross liability	0	5
Current | Derivatives Designated as Cash Flow Hedges | 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 | Commodity Derivatives	'	'
Derivative asset, fair value, gross asset	3	4
Derivative liability, fair value, gross liability	9	1
Long Term | Derivatives Not Designated as Cash Flow Hedges | 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 | Embedded Derivatives	'	'
Derivative asset, fair value, gross asset	0	0
Derivative liability, fair value, gross liability	$19	$25

Derivative_Instruments_Table_I

Derivative Instruments Table - I/S Impact (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Change in value recognized in AOCI on derivatives (effective portion)	$0	($4)	($13)
Derivatives Not Designated In A Hedging Relationships	'	'	'
Amount of gain/(loss) recognized in income on derivatives	-3	30	18
Revenue [Member] | Derivatives In Cash Flow Hedging Relationship | Commodity Derivatives	'	'	'
Amount of gain/(loss) reclassified from AOCI into income (effective portion)	0	6	-19
Revenue [Member] | Derivatives Not Designated In A Hedging Relationships | Commodity Derivatives	'	'	'
Amount of gain/(loss) from de-designation amortized from AOCI into income	'0	'-5	'0
Amount of gain/(loss) recognized in income on derivatives	-9	16	0
Other Income and Deductions [Member] | Derivatives Not Designated In A Hedging Relationships | Embedded Derivatives	'	'	'
Amount of gain/(loss) recognized in income on derivatives	$6	$14	$18

LongTerm_Debt_Narrative_Detail

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

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 28, 2014

31-May-13

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

31-May-12

31-May-09

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Senior Notes Due Two Thousand Sixteen [Member]

Senior Notes Due Two Thousand Sixteen [Member]

Senior Notes Due Two Thousand Sixteen [Member]

Senior Notes Due Two Thousand Sixteen [Member]

Senior Notes Due Two Thousand Eighteen [Member]

Senior Notes Due Two Thousand And Twenty One [Member]

Senior Notes Due Two Thousand And Twenty Two [Member]

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

5.5% Senior Notes Due Two Thousand Twenty Three [Member]

5.75% Senior Notes Due Two Thousand and Twenty [Member]

Federal Funds Effective Rate [Member]

LIBOR [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Redemption After December 1 2014 [Member]

Redemption After December 1 2015 [Member]

Redemption December 1 2016 And Thereafter [Member]

Redemption Before June 1, 2020 [Member]

Redemption After June 1, 2020 [Member]

Redemption Before July 15. 2014 [Member]

Redemption After July 15 2016 [Member]

Redemption After July 15 2017 [Member]

Redemption After July 15 2018 [Member]

Redemption July 15 2019 And Thereafter [Member]

Redemption Before December 1, 2021 [Member]

Redemption After December 1, 2021 [Member]

Redemption Before August 1, 2023 [Member]

Redemption After August 1, 2023 [Member]

Redemption Before October 15, 2017 [Member]

Redemption After October 15, 2017 [Member]

Redemption After October 15, 2018 [Member]

Redemption After October 15, 2019 [Member]

Redemption October 15, 2020 and Thereafter [Member]

Base Rate Loans [Member]

Eurodollar [Member]

Base Rate Loans [Member]

Eurodollar [Member]

Senior Notes Due Two Thousand Eighteen [Member]

Senior Notes Due Two Thousand Eighteen [Member]

Senior Notes Due Two Thousand Eighteen [Member]

5.75% Senior Notes Due Two Thousand and Twenty [Member]

5.75% Senior Notes Due Two Thousand and Twenty [Member]

Senior Notes Due Two Thousand And Twenty One [Member]

Senior Notes Due Two Thousand And Twenty One [Member]

Senior Notes Due Two Thousand And Twenty One [Member]

Senior Notes Due Two Thousand And Twenty One [Member]

Senior Notes Due Two Thousand And Twenty One [Member]

Senior Notes Due Two Thousand And Twenty Two [Member]

Senior Notes Due Two Thousand And Twenty Two [Member]

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

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

5.5% Senior Notes Due Two Thousand Twenty Three [Member]

5.5% Senior Notes Due Two Thousand Twenty Three [Member]

5.5% Senior Notes Due Two Thousand Twenty Three [Member]

5.5% Senior Notes Due Two Thousand Twenty Three [Member]

5.5% Senior Notes Due Two Thousand Twenty Three [Member]

Write off of Deferred Debt Issuance Cost

'

'

'

'

'

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Increase, Additional Borrowings

1,460

1,560

940

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Decrease, Repayments

1,100

1,700

893

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

1,200

1,150

'

1,500

1,200

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Additional Borrowing Capacity

'

'

'

500

300

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Covenant Terms

'

'

'

'

'50

'50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Costs Capitalized

6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Basis Spread on Variable Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

1.00%

'

0.63%

1.63%

'

1.50%

2.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revolving Credit Facility Weighted Average Rate

'

'

'

'

'

2.17%

2.93%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Unused Capacity, Commitment Fee Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.30%

'

'

0.45%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line Of Credit Facility Fronting Fee Percentage

0.20%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Covenant Maximum Debt To Ebitda Ratio

5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated Interest Expense Ratio

2.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Secured Debt to Consolidated EBITDA Ratio

3.25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Face Amount

2,800

1,965

'

'

'

'

'

'

'

'

250

600

500

900

600

700

400

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

'

'

'

'

'

9.38%

6.88%

6.50%

5.88%

4.50%

5.50%

5.75%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior Note Redeemable Portion

'

'

'

'

'

'

'

'

35.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

100.00%

100.00%

35.00%

100.00%

'

'

'

100.00%

100.00%

'

'

35.00%

100.00%

'

'

'

Debt Instrument, Redemption Price, Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

103.44%

101.72%

100.00%

'

'

106.50%

103.25%

102.17%

101.08%

100.00%

'

'

'

'

105.50%

102.75%

101.83%

100.92%

100.00%

Repayments of Long-term Debt

163

88

0

'

'

'

'

'

88

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt

3,310

2,157

'

'

'

'

'

'

'

163

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt, Maturities, Repayments of Principal in Year Four

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Redemption Premium

'

'

'

'

'

'

'

'

8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Writeoff of unamortized loan fee

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Writeoff of unamortized bond premium

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Extinguishment of Debt, Amount

'

'

'

'

'

'

'

178

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Increase, Accrued Interest

'

'

'

'

'

'

'

$7

$4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior Note Redemption Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

100.00%

'

'

'

'

'

Table_Partnerships_LongTerm_De

Table - Partnership's Long-Term Debt (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Long-Term Debt Disclosure [Abstract]	'	'
Debt Instrument, Face Amount	$2,800	$1,965
Revolving loans	510	192
Total	3,310	2,157
Less: current portion	0	0
Long-term debt, net	3,310	2,157
Total credit facility limit	1,200	1,150
Revolving loans	-510	-192
Letters of credit	-14	-12
Total available	$676	$946

Table_LongTerm_Debt_Maturities

Table - Long-Term Debt Maturities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Long-Term Debt Disclosure [Abstract]	'	'
2014	$0	'
2015	0	'
2016	0	'
2017	0	'
2018	600	'
Thereafter	2,710	'
Total	$3,310	$2,157

Intangible_Assets_Schedule_of_

Intangible Assets (Schedule of Finite-Lived Intangible Assets by Major Class) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Finite-Lived Intangible Assets	'	'
Net finite-lived intangible assets, beginning of period	$712	$741
Amortization	-30	-29
Net finite-lived intangible assets, end of period	682	712
Finite-Lived Intangible Assets, Future Amortization	'	'
Future annual amortization of finite intangible assets	30	'
Customer Relations	'	'
Finite-Lived Intangible Assets	'	'
Net finite-lived intangible assets, beginning of period	655	681
Amortization	-26	26
Net finite-lived intangible assets, end of period	629	655
Finite-Lived Intangible Assets, Future Amortization	'	'
Average remaining amortization periods, years	'24 years 0 months 0 days	'
Trade Names	'	'
Finite-Lived Intangible Assets	'	'
Net finite-lived intangible assets, beginning of period	57	60
Amortization	-4	3
Net finite-lived intangible assets, end of period	$53	$57
Finite-Lived Intangible Assets, Future Amortization	'	'
Average remaining amortization periods, years	'16 years 0 months 0 days	'

Fair_Value_Measures_Narrative_

Fair Value Measures Narrative (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions	'	'
Transfers Between Level 2 Level 3 Derivatives Amount	$0	'
Senior notes, fair value	2,830	2,130
Debt Instrument, Face Amount	$2,800	$1,965

Table_FV_of_Partnerships_Deriv

Table - FV of Partnership's Derivative Assets And Liabilities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
Fair Value Measurement, Assets	$4	$5	'
Fair Value Measurement, Liabilities	28	31	'
Embedded Derivatives in Series A Preferred Units	19	25	'
Embedded Derivative, Fair Value of Embedded Derivative, Net	19	25	39
Significant Observable Inputs (Level 2)	'	'	'
Fair Value Measurement, Assets	4	5	'
Fair Value Measurement, Liabilities	9	6	'
Embedded Derivatives in Series A Preferred Units	0	0	'
Unobservable Inputs (Level 3)	'	'	'
Fair Value Measurement, Assets	0	0	'
Fair Value Measurement, Liabilities	19	25	'
Embedded Derivatives in Series A Preferred Units	'	25	'
Natural Gas	'	'	'
Fair Value Measurement, Assets	2	2	'
Fair Value Measurement, Liabilities	4	5	'
Natural Gas | Significant Observable Inputs (Level 2)	'	'	'
Fair Value Measurement, Assets	2	2	'
Fair Value Measurement, Liabilities	4	5	'
Natural Gas | Unobservable Inputs (Level 3)	'	'	'
Fair Value Measurement, Assets	0	0	'
Fair Value Measurement, Liabilities	0	0	'
NGLs	'	'	'
Fair Value Measurement, Assets	2	1	'
Fair Value Measurement, Liabilities	4	1	'
NGLs | Significant Observable Inputs (Level 2)	'	'	'
Fair Value Measurement, Assets	2	1	'
Fair Value Measurement, Liabilities	4	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	1	0	'
Condensate | Significant Observable Inputs (Level 2)	'	'	'
Fair Value Measurement, Assets	0	2	'
Fair Value Measurement, Liabilities	1	0	'
Condensate | Unobservable Inputs (Level 3)	'	'	'
Fair Value Measurement, Assets	0	0	'
Fair Value Measurement, Liabilities	$0	$0	'

Fair_Value_Measures_Table_Sign

Fair Value Measures Table - Significant Quantitative Unobservable Inputs (Details)	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value, Embedded Derivatives Significant Unobservable Input, Credit Spread	4.16%
Fair Value, Embedded Derivatives Significant Unobservable Input, Volatility	23.71%

Table_Changes_In_Level_3_Deriv

Table - Changes In Level 3 Derivatives (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Fair Value Measures [Abstract]	'	'
Beginning Balance	$25	$39
Change in fair value	6	14
Ending Balance	$19	$25

Leases_Narrative_Details

Leases Narrative (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Leased Assets	'	'	'
Future minimum lease payments	$46	'	'
Operating Leases, Rent Expense	$11	$11	$3

Table_Schedule_Of_Future_Minim

Table - Schedule Of Future Minimum Lease Payments (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Operating Leased Assets	'
2014	$3
2015	3
2016	2
2017	2
2018	2
Thereafter	34
Total minimum lease payments	$46

Commitments_And_Contingencies_2

Commitments And Contingencies Narrative (Details) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Accrual for Environmental Loss Contingencies, Provision for New Losses	$0
Environmental Remediation Expense	$5

Commitments_And_Contingencies_3

Commitments And Contingencies Table - Environmental Remediation Schedule (Details) (USD $)	Dec. 31, 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	6	7
Accrual for Environmental Loss Contingencies	$8	$12

Series_A_Preferred_Units_Narra

Series A Preferred Units Narrative (Details) (USD $)

1 Months Ended

3 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Sep. 30, 2009

Dec. 31, 2013

Dec. 31, 2013

Sep. 02, 2029

Dec. 31, 2012

Dec. 31, 2011

Sep. 02, 2009

Dec. 31, 2013

Sep. 02, 2009

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

quarters

Series A Preferred Unit

Series A Preferred Unit

Common Unit Distribution

PIK Distribution

Maximum [Member]

Minimum [Member]

Commencing On September 2, 2014

Commencing On September 2, 2014

Series A Preferred Stock [Member]

Series A Preferred Stock [Member]

Series A Preferred Stock [Member]

Series A Preferred Unit

Series A Preferred Unit

Minimum [Member]

days

Series A Preferred Unit

Other Ownership Interests

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Series A Preferred Units, shares issued

'

1,912,569

1,912,569

'

4,371,586

4,371,586

4,371,586

'

'

'

'

'

'

'

'

'

'

'

Series A price per unit

'

'

'

'

'

'

'

'

$18.30

'

'

'

'

'

'

'

'

'

Preferred units issue discount percentage

'

'

'

'

'

'

4.00%

'

'

'

'

'

'

'

'

'

'

'

Preferred units issued at a discount

'

'

'

'

'

'

$3,000,000

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of preferred units, net

77,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General Partners' Contributed Capital

'

'

'

'

'

'

2,000,000

'

'

'

'

'

'

'

'

'

'

'

Series A Preferred Units mandatory redemption date

'

'

2-Sep-29

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Stock, Redemption Amount

'

'

'

35,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions paid per unit

'

'

'

'

'

'

'

$0.35

'

$0.09

$0.09

'

'

'

'

'

'

'

Maximum Distribution amount for Preferred Units

'

'

'

'

'

'

'

'

'

'

'

2,000,000

'

'

'

'

'

'

Maximum distribution made to member or Limited Partner, period of consecutive fiscal quarters

'

'

20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase in distribution made to member or Limited Partner distributions, declared per unit, due to covenant default

'

'

'

'

'

'

'

$0.18

'

'

'

'

'

'

'

'

'

'

Accumulated and unpaid distributions, quarterly accrual interest rate percentage

'

'

'

'

'

'

'

2.43%

'

'

'

'

'

'

'

'

'

'

Covenant default, accumulated and unpaid distributions, quarterly accrual interest rate percentage

'

'

'

'

'

'

'

3.43%

'

'

'

'

'

'

'

'

'

'

Minimum unit conversion request by holders

'

'

'

'

'

'

'

'

'

'

'

'

375,000

'

'

'

'

'

Percenatge component of denominator, used in conversion ratio when conversion price is less than volume-weighted average trading price

'

'

'

'

'

'

'

'

'

'

'

'

'

91.00%

'

'

'

'

Conversion price, per share minimum

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$10

'

'

'

Conversion requirements, daily volume-weighted average trading price over conversion price, percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

150.00%

'

'

'

'

Conversion price requirements met, number of trading days

'

'

'

'

'

'

'

'

'

'

'

'

'

20

'

'

'

'

Range of trailing trading days, assess conversion price requirements

'

'

'

'

'

'

'

'

'

'

'

'

'

30

'

'

'

'

Change Of Control Required Purchase Offer As Percentage Of Liquidation Value

'

'

'

'

'

'

'

101.00%

'

'

'

'

'

'

'

'

'

'

Cash event, required purchase offer as percentage of liquidation value

'

'

'

'

'

'

'

120.00%

'

'

'

'

'

'

'

'

'

'

Limited Partners' Capital Account, Distribution Amount

'

0.445

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Conversion of Stock, Shares Converted

'

'

-2,459,017

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,050,854

4,658,700

4,632,389

Table_Reconciliation_of_Series

Table - Reconciliation of Series A Preferred Units (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Sep. 02, 2009
Temporary Equity Disclosure [Abstract]	'	'	'
Conversion of Stock, Shares Converted	-2,459,017	'	'
Conversion of Stock, Amount Converted	($41)	'	'
Beginning balance Series A Preferred Units, shares	4,371,586	4,371,586	4,371,586
Ending balance Series A Preferred Units, shares	1,912,569	4,371,586	4,371,586
Beginning balance Series A Preferred Units	73	71	'
Accretion to redemption, value	'	2	'
Ending balance Series A Preferred Units	$32	$73	'
Series A Preferred Units mandatory redemption date	2-Sep-29	'	'

Related_Party_Transactions_Nar

Related Party Transactions Narrative (Details) (USD $)

12 Months Ended

3 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Sep. 01, 2011

Dec. 31, 2011

Sep. 02, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2011

Jan. 18, 2012

Dec. 31, 2012

Dec. 31, 2012

ETE [Member]

ETE [Member]

ETE [Member]

ETE [Member]

MEP [Member]

MEP [Member]

MEP [Member]

ETP [Member]

ETP [Member]

HPC [Member]

HPC [Member]

HPC [Member]

Lone Star [Member]

Lone Star [Member]

Lone Star [Member]

EPD [Member]

Management Fee [Member]

Royalty Fee [Member]

May Twenty Six Service Agreement [Member]

Management Fee Waived

'

'

'

'

'

'

$10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Related Party Transaction, Expenses from Transactions with Related Party

'

'

'

11

17

17

'

'

'

'

'

'

'

'

'

'

'

'

'

21

1

Distribution Made to Limited Partner, Cash Distributions Paid

'

'

'

63

62

57

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Additional Ownership Percentage Acquired

'

'

'

'

'

'

'

'

'

0.10%

'

'

'

'

'

'

'

'

'

'

'

Payments to Acquire Additional Interest in Subsidiaries and Affiliates

'

'

'

'

'

'

'

1

1

'

'

'

'

'

0

'

'

0

'

'

'

Proceeds from Sale of Machinery and Equipment

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

Payments to Acquire Machinery and Equipment

'

'

'

'

'

'

'

'

'

'

95

29

'

'

'

'

'

'

'

'

'

General and Administrative Expense

88

100

67

'

'

'

'

'

'

'

'

'

18

20

17

'

'

'

'

'

'

Related Party Transaction, NGL Sales

$81

$28

$365

'

'

'

'

'

'

'

'

'

'

'

'

$5

$26

'

'

'

'

Related party ownership in parent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.00%

'

'

Table_Related_Party_Receivable

Table - Related Party Receivables and Payables (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Related party receivables	$28	$8
Related party payables	69	95
ETE And Its Subsidiaries	'	'
Related party receivables	25	5
Related party payables	68	94
Ranch JV [Member]	'	'
Related party receivables	2	2
HPC [Member]	'	'
Related party receivables	1	1
Related party payables	$1	$1

Concentration_Risk_Table_Sched

Concentration Risk Table - Schedule Of Revenues And Cost Of Sales By Major Customer And Supplier (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Concentration Risk	'	'	'	'	'	'	'	'	'	'	'
Concentration Risk, Percentage	'	'	'	'	'	'	'	'	10.00%	'	'
Major customer, revenue amount	$677	$665	$639	$540	$587	$527	$511	$375	$2,521	$2,000	$1,434
Gathering And Processing	'	'	'	'	'	'	'	'	'	'	'
Concentration Risk	'	'	'	'	'	'	'	'	'	'	'
Major customer, revenue amount	'	'	'	'	'	'	'	'	2,287	1,797	1,226
Gathering And Processing | Customer A	'	'	'	'	'	'	'	'	'	'	'
Concentration Risk	'	'	'	'	'	'	'	'	'	'	'
Major customer, revenue amount	'	'	'	'	'	'	'	'	381	367	366
Gathering And Processing | Customer B [Member]	'	'	'	'	'	'	'	'	'	'	'
Concentration Risk	'	'	'	'	'	'	'	'	'	'	'
Major customer, revenue amount	'	'	'	'	'	'	'	'	362	451	0
Gathering And Processing | Supplier A	'	'	'	'	'	'	'	'	'	'	'
Concentration Risk	'	'	'	'	'	'	'	'	'	'	'
Major supplier, cost of sales amount	'	'	'	'	'	'	'	'	164	171	133
Gathering And Processing | Supplier B [Member]	'	'	'	'	'	'	'	'	'	'	'
Concentration Risk	'	'	'	'	'	'	'	'	'	'	'
Major supplier, cost of sales amount	'	'	'	'	'	'	'	'	$185	$0	$0

Segment_Information_Narrative_

Segment Information Narrative (Details)	12 Months Ended
	Dec. 31, 2013
Ownership in affiliate	20.00%
Ranch JV [Member]	'
Ownership in affiliate	33.33%
Lone Star [Member]	'
Ownership in affiliate	30.00%
HPC [Member]	'
Ownership in affiliate	49.99%
Length Of Gas Pipeline System	450
MEP [Member]	'
Ownership in affiliate	50.00%
Length Of Gas Pipeline System	500

Table_IS_Data_for_Each_Segment

Table - I/S Data for Each Segment (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
External Revenue	$677	$665	$639	$540	$587	$527	$511	$375	$2,521	$2,000	$1,434
Intersegment Revenue	'	'	'	'	'	'	'	'	0	0	0
Cost of Sales	'	'	'	'	'	'	'	'	1,793	1,387	1,013
Total segment margin	'	'	'	'	'	'	'	'	728	613	421
Operation and maintenance	'	'	'	'	'	'	'	'	296	228	147
Depreciation and Amortization	'	'	'	'	'	'	'	'	287	252	169
Share of net income	'	'	'	'	'	'	'	'	135	105	120
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	'	'	'	'	'	'	'	'	1,034	560	406
Gathering And Processing	'	'	'	'	'	'	'	'	'	'	'
External Revenue	'	'	'	'	'	'	'	'	2,287	1,797	1,226
Intersegment Revenue	'	'	'	'	'	'	'	'	0	0	0
Cost of Sales	'	'	'	'	'	'	'	'	1,767	1,373	993
Total segment margin	'	'	'	'	'	'	'	'	521	423	233
Operation and maintenance	'	'	'	'	'	'	'	'	237	183	98
Depreciation and Amortization	'	'	'	'	'	'	'	'	186	159	87
Share of net income	'	'	'	'	'	'	'	'	1	-10	0
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	'	'	'	'	'	'	'	'	721	395	282
Natural Gas Transportation	'	'	'	'	'	'	'	'	'	'	'
External Revenue	'	'	'	'	'	'	'	'	1	1	1
Intersegment Revenue	'	'	'	'	'	'	'	'	0	0	0
Cost of Sales	'	'	'	'	'	'	'	'	0	-1	-2
Total segment margin	'	'	'	'	'	'	'	'	0	2	3
Operation and maintenance	'	'	'	'	'	'	'	'	0	0	0
Depreciation and Amortization	'	'	'	'	'	'	'	'	0	0	0
Share of net income	'	'	'	'	'	'	'	'	70	71	92
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	'	'	'	'	'	'	'	'	0	0	0
NGL Services	'	'	'	'	'	'	'	'	'	'	'
External Revenue	'	'	'	'	'	'	'	'	0	0	0
Intersegment Revenue	'	'	'	'	'	'	'	'	0	0	0
Cost of Sales	'	'	'	'	'	'	'	'	0	0	0
Total segment margin	'	'	'	'	'	'	'	'	0	0	0
Operation and maintenance	'	'	'	'	'	'	'	'	0	0	0
Depreciation and Amortization	'	'	'	'	'	'	'	'	0	0	0
Share of net income	'	'	'	'	'	'	'	'	64	44	28
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	'	'	'	'	'	'	'	'	0	0	0
Contract Services	'	'	'	'	'	'	'	'	'	'	'
External Revenue	'	'	'	'	'	'	'	'	215	183	190
Intersegment Revenue	'	'	'	'	'	'	'	'	15	21	17
Cost of Sales	'	'	'	'	'	'	'	'	26	15	22
Total segment margin	'	'	'	'	'	'	'	'	204	189	185
Operation and maintenance	'	'	'	'	'	'	'	'	72	66	66
Depreciation and Amortization	'	'	'	'	'	'	'	'	98	86	78
Share of net income	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	'	'	'	'	'	'	'	'	311	164	120
Corporate	'	'	'	'	'	'	'	'	'	'	'
External Revenue	'	'	'	'	'	'	'	'	18	19	17
Intersegment Revenue	'	'	'	'	'	'	'	'	0	0	0
Cost of Sales	'	'	'	'	'	'	'	'	0	0	0
Total segment margin	'	'	'	'	'	'	'	'	18	20	17
Operation and maintenance	'	'	'	'	'	'	'	'	1	0	0
Depreciation and Amortization	'	'	'	'	'	'	'	'	3	7	4
Share of net income	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	'	'	'	'	'	'	'	'	2	1	4
Eliminations	'	'	'	'	'	'	'	'	'	'	'
External Revenue	'	'	'	'	'	'	'	'	0	0	0
Intersegment Revenue	'	'	'	'	'	'	'	'	-15	-21	-17
Cost of Sales	'	'	'	'	'	'	'	'	0	0	0
Total segment margin	'	'	'	'	'	'	'	'	-15	-21	-17
Operation and maintenance	'	'	'	'	'	'	'	'	-14	-21	-17
Depreciation and Amortization	'	'	'	'	'	'	'	'	0	0	0
Share of net income	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting Information, Expenditures for Additions to Long-Lived Assets	'	'	'	'	'	'	'	'	$0	$0	$0

Segment_Information_Table_BS_D

Segment Information Table - B/S Data for Each Segment(Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
Segment Reporting, Asset Reconciling Item	'	'	'
Assets	$8,782	$8,123	$5,568
Investments in unconsolidated affiliates	2,097	2,214	1,925
Goodwill	1,128	1,128	790
Gathering And Processing	'	'	'
Segment Reporting, Asset Reconciling Item	'	'	'
Assets	4,748	4,210	1,960
Investments in unconsolidated affiliates	36	35	0
Goodwill	651	651	313
Natural Gas Transportation	'	'	'
Segment Reporting, Asset Reconciling Item	'	'	'
Assets	991	1,232	1,297
Investments in unconsolidated affiliates	991	1,231	1,296
Goodwill	0	0	0
NGL Services	'	'	'
Segment Reporting, Asset Reconciling Item	'	'	'
Assets	1,070	948	629
Investments in unconsolidated affiliates	1,070	948	629
Goodwill	0	0	0
Contract Services	'	'	'
Segment Reporting, Asset Reconciling Item	'	'	'
Assets	1,897	1,672	1,621
Investments in unconsolidated affiliates	0	0	0
Goodwill	477	477	477
Corporate	'	'	'
Segment Reporting, Asset Reconciling Item	'	'	'
Assets	76	61	61
Investments in unconsolidated affiliates	0	0	0
Goodwill	0	0	0
Eliminations	'	'	'
Segment Reporting, Asset Reconciling Item	'	'	'
Assets	0	0	0
Investments in unconsolidated affiliates	0	0	0
Goodwill	$0	$0	$0

Table_Reconciliation_of_Total_

Table - Reconciliation of Total Segment Margin (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Total segment margin	$728	$613	$421
Operation and maintenance	-296	-228	-147
General and administrative	-88	-100	-67
(Loss) gain on asset sales, net	-2	-3	2
Depreciation and amortization	-287	-252	-169
Income from unconsolidated affiliates	135	105	120
Interest expense, net	-164	-122	-103
Loss on debt refinancing, net	-7	-8	0
Other income and deductions, net	7	29	17
INCOME BEFORE INCOME TAXES	26	34	74
Customer Contracts [Member]	'	'	'
Other income and deductions, net	'	$16	'

EquityBased_Compensation_Narra

Equity-Based Compensation Narrative (Details) (USD $)	1 Months Ended	12 Months Ended
In Millions, except Share data, unless otherwise specified	Jan. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangements by Share-based Payment Award, Options, Grants in Period, Weighted Average Exercise Price	'	1	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	'	3,000,000	'	'
Share-based Compensation	'	7	5	3
Phantom Share Units (PSUs) [Member] | Management [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	668,074	62,360	495,375	596,320
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	'	'	'5 years 0 months 0 days	'5 years 0 months 0 days
5 year [Member] | Phantom Share Units (PSUs) [Member] | Management [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	'	'	8,250	'
Phantom Units Service Condition Grants Vesting by Percentage Rate	40.00%	40.00%	40.00%	'
3 year [Member] | Phantom Share Units (PSUs) [Member] | Management [Member]	'	'	'	'
Phantom Units Service Condition Grants Vesting by Percentage Rate	60.00%	60.00%	60.00%	'
Common Unit Options [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual Term	'	'2 years 4 months 22 days	'	'
Phantom Share Units (PSUs) [Member]	'	'	'	'
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	'	19	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	'	62,360	503,625	596,320
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Remaining Contractual Term	'	'3 years 3 months 5 days	'	'

Table_Common_Unit_Options_Acti

Table - Common Unit Options Activity (Details) (Common Unit Options [Member], USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Common Unit Options [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number	142,550	156,550	156,850	201,950
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price	$22.04	$21.96	$21.99	$21.93
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	142,550	156,550	156,850	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period	'	300	6,800	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price	'	$23.73	$26.72	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period	-14,000	'	-38,300	'
Share-based Compensation Arrangements by Share-based Payment Award, Options, Exercises in Period, Weighted Average Exercise Price	$21.14	'	$20.84	'

Table_Phantom_Units_Activity_D

Table - Phantom Units Activity (Details) (Phantom Units, USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Phantom Units	'	'	'
Outstanding at the beginning of the period, Units	1,231,342	1,086,393	742,517
Service condition grants, Units	62,360	503,625	596,320
Vested service condition, Units	-231,163	-223,258	-142,520
Vested market condition, Units	'	-10,200	-8,550
Forfeited service condition, Units	-35,900	-120,868	-88,474
Forfeited market condition, Units	-44,397	-4,350	-12,900
Outstanding at the end of period, Units	982,242	1,231,342	1,086,393
Outstanding at the beginning of the period, Weighted Average Grant Date Fair Value	$23.22	$24.51	$23.61
Service condition grants, Weighted Average Grant Date Fair Value	$25.44	$21.39	$24.55
Vested service condition, Weighted Average Grant Date Fair Value	$24.80	$24.71	$24.73
Vested market condition, Weighted Average Grant Date Fair Value	'	$19.52	$19.52
Forfeited service condition, Weighted Average Grant Date Fair Value	$23.22	$24.85	$24.99
Forfeited market condition, Weighted Average Grant Date Fair Value	$19.52	$19.52	$19.52
Outstanding at the end of the period, Weighted Average Grant Date Fair Value	$23.16	$23.22	$24.51
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	$19	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Remaining Contractual Term	'3 years 3 months 5 days	'	'

Quarterly_Financial_Data_Unaud2

Quarterly Financial Data (Unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Quarterly Financial Information Disclosure [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Operating revenues	$677	$665	$639	$540	$587	$527	$511	$375	$2,521	$2,000	$1,434
Operating income (loss)	12	24	34	-15	8	5	22	-5	55	30	40
Net (loss) income attributable to Regency Energy Partners LP	($1)	$39	$10	($29)	($8)	($1)	$26	$15	$19	$32	$72
Basic net (loss) income per common unit	($0.03)	$0.16	$0.07	($0.06)	($0.08)	($0.04)	$0.14	$0.15	'	'	'
Diluted net (loss) income per common unit	($0.03)	$0.05	$0.07	($0.06)	($0.08)	($0.04)	$0.10	$0.14	'	'	'