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Document And Entity Information - shares	9 Months Ended
Document And Entity Information - shares	Sep. 30, 2011	Nov. 02, 2011
Entity Information
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2011
Entity Registrant Name	Energy Transfer Equity, L.P.
Entity Central Index Key	0001276187
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2011
Document Fiscal Period Focus	Q3
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		222,972,708

Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2011	Dec. 31, 2010
ASSETS
Cash and cash equivalents	$ 167,715	$ 86,264
Marketable securities	3,151	2,032
Accounts receivable, net of allowance for doubtful accounts of $7,123 and $6,706 as of September 30, 2011 and December 31, 2010, respectively	669,955	612,357
Accounts receivable from related companies	86,454	76,331
Inventories	328,841	366,384
Exchanges receivable	17,675	21,926
Price risk management assets	15,719	16,357
Other current assets	143,578	109,359
Total current assets	1,433,088	1,291,010
PROPERTY, PLANT AND EQUIPMENT	15,922,724	13,284,430
ACCUMULATED DEPRECIATION	(1,822,675)	(1,431,698)
PROPERTY, PLANT AND EQUIPMENT, net	14,100,049	11,852,732
ADVANCES TO AND INVESTMENTS IN AFFILIATES	1,515,604	1,359,979
LONG-TERM PRICE RISK MANAGEMENT ASSETS	23,523	13,971
GOODWILL	2,039,383	1,600,611
INTANGIBLE ASSETS, net	1,083,968	1,034,846
OTHER NON-CURRENT ASSETS, net	247,703	225,581
Total assets	20,443,318	17,378,730
LIABILITIES AND EQUITY
Accounts payable	468,480	421,556
Accounts payable to related companies	24,618	27,351
Exchanges payable	15,758	16,003
Price risk management liabilities	76,615	13,172
Accrued and other current liabilities	794,660	567,688
Current maturities of long-term debt	424,119	35,305
Total current liabilities	1,804,250	1,081,075
LONG-TERM DEBT, less current maturities	11,252,745	9,346,067
SERIES A CONVERTIBLE PREFERRED UNITS (Note 10)	314,980	317,600
LONG-TERM PRICE RISK MANAGEMENT LIABILITIES	73,261	79,465
OTHER NON-CURRENT LIABILITIES	243,473	235,848
COMMITMENTS AND CONTINGENCIES (Note 14)
PREFERRED UNITS OF SUBSIDIARY (Note 10)	71,091	70,943
EQUITY:
General Partner	306	520
Limited Partners:
Common Unitholders	47,483	115,350
Accumulated other comprehensive income	2,736	4,798
Total partners' capital	50,525	120,668
Noncontrolling interest	6,632,993	6,127,064
Total equity	6,683,518	6,247,732
Total liabilities and equity	$ 20,443,318	$ 17,378,730

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2011	Dec. 31, 2010
Statement of Financial Position [Abstract]
Accounts receivable, allowance for doubtful accounts	$ 7,123	$ 6,706

Consolidated Statements Of Operations $ in Thousands	3 Months Ended		9 Months Ended
Consolidated Statements Of Operations $ in Thousands	Sep. 30, 2011 USD ($) $ / shares shares	Sep. 30, 2010 USD ($) $ / shares shares	Sep. 30, 2011 USD ($) $ / shares shares	Sep. 30, 2010 USD ($) $ / shares shares
REVENUES:
Natural gas operations	$ 1,858,656	$ 1,380,029	$ 5,016,564	$ 3,827,506
Retail propane	213,496	183,786	962,258	914,372
Other	25,714	23,992	83,070	80,438
Total revenues	2,097,866	1,587,807	6,061,892	4,822,316
COSTS AND EXPENSES:
Cost of products sold - natural gas operations	1,203,537	883,716	3,210,163	2,520,157
Cost of products sold - retail propane	141,868	104,533	587,460	519,796
Cost of products sold - other	7,632	6,856	20,992	20,470
Operating expenses	234,282	208,809	677,695	559,302
Depreciation and amortization	157,952	120,315	445,738	304,681
Selling, general and administrative	82,587	61,526	225,032	177,673
Total costs and expenses	1,827,858	1,385,755	5,167,080	4,102,079
OPERATING INCOME	270,008	202,052	894,812	720,237
OTHER INCOME (EXPENSE):
Interest expense, net of interest capitalized	(193,772)	(209,871)	(543,218)	(460,578)
Equity in earnings of affiliates	28,374	22,349	82,634	40,723
Losses on non-hedged interest rate derivatives	(68,497)	(31,966)	(65,094)	(68,858)
Impairment of investments in affiliates	(5,355)	0	(5,355)	(52,620)
Other, net	33,231	14,379	21,081	10,819
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX EXPENSE	63,989	(3,057)	384,860	189,723
Income tax expense	3,290	2,093	18,417	11,357
INCOME (LOSS) FROM CONTINUING OPERATIONS	60,699	(5,150)	366,443	178,366
Income from discontinued operations	0	324	0	410
NET INCOME (LOSS)	60,699	(4,826)	366,443	178,776
LESS: NET INCOME (LOSS) ATTRIBUTABLE TO NONCONTROLLING INTEREST	(8,384)	10,511	142,435	62,069
NET INCOME (LOSS) ATTRIBUTABLE TO PARTNERS	69,083	(15,337)	224,008	116,707
GENERAL PARTNER'S INTEREST IN NET INCOME (LOSS)	214	(48)	693	361
LIMITED PARTNERS' INTEREST IN NET INCOME (LOSS)	$ 68,869	$ (15,289)	$ 223,315	$ 116,346
BASIC NET INCOME (LOSS) PER LIMITED PARTNER UNIT \| $ / shares	0.31	(0.07)	1.00	0.52
BASIC AVERAGE NUMBER OF UNITS OUTSTANDING \| shares	222,972,708	222,941,172	222,966,763	222,941,151
DILUTED NET INCOME (LOSS) PER LIMITED PARTNER UNIT \| $ / shares	0.31	(0.07)	1.00	0.52
DILUTED AVERAGE NUMBER OF UNITS OUTSTANDING \| shares	222,972,708	222,941,172	222,966,763	222,941,151

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Statement of Income and Comprehensive Income [Abstract]
Net income (loss)	$ 60,699	$ (4,826)	$ 366,443	$ 178,776
Other comprehensive income (loss), net of tax:
Reclassification to earnings of gains and losses on derivative instruments accounted for as cash flow hedges	288	64,644	(13,129)	67,199
Change in value of derivative instruments accounted for as cash flow hedges	16,412	25,791	9,403	30,291
Change in value of available-for-sale securities	(900)	(732)	(935)	(3,785)
Other comprehensive income (loss), net of tax, total	15,800	89,703	(4,661)	93,705
Comprehensive income	76,499	84,877	361,782	272,481
Less: Comprehensive income attributable to noncontrolling interest	4,323	32,197	139,836	89,915
Comprehensive income attributable to partners	$ 72,176	$ 52,680	$ 221,946	$ 182,566

Consolidated Statement Of Equity - 9 months ended Sep. 30, 2011 - USD ($) $ in Thousands	Total	General Partner [Member]	Common Unitholders [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]
Balance at Dec. 31, 2010	$ 6,247,732	$ 520	$ 115,350	$ 4,798	$ 6,127,064
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Distributions to ETE partners	(385,806)	(1,194)	(384,612)	0	0
Distributions to noncontrolling interest	(574,285)	0	0	0	(574,285)
Subsidiary units issued for cash	1,003,209	291	93,650	0	909,268
Subsidiary units issued in acquisition	3,000	0	0	0	3,000
Non-cash unit-based compensation expense, net of units tendered by employees for tax withholdings	33,174	0	846	0	32,328
Non-cash executive compensation	938	0	19	0	919
Other, net	(6,226)	(4)	(1,085)	0	(5,137)
Other comprehensive loss, net of tax	(4,661)	0	0	(2,062)	(2,599)
Net income	366,443	693	223,315	0	142,435
Balance at Sep. 30, 2011	$ 6,683,518	$ 306	$ 47,483	$ 2,736	$ 6,632,993

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES:
Net income	$ 366,443	$ 178,776
Reconciliation of net income to net cash provided by operating activities:
Impairment of investments in affiliates	5,355	52,620
Payments for termination of Parent Company interest rate derivatives	0	(168,550)
Proceeds from termination of interest rate derivatives	0	26,495
Depreciation and amortization	445,738	304,681
Amortization of finance costs charged to interest	14,581	13,299
Non-cash unit-based compensation expense	33,491	22,547
Non-cash executive compensation expense	938	938
Losses on disposal of assets	3,272	408
Distributions in excess of equity in earnings of affiliates, net	2,177	71,026
Other non-cash	(3,211)	(5,361)
Changes in operating assets and liabilities, net of effects of acquisitions (Note 4)	234,176	430,804
Net cash provided by operating activities	1,102,960	927,683
CASH FLOWS FROM INVESTING ACTIVITIES:
Cash paid for acquisitions, net of cash received	(1,971,438)	(323,705)
Capital expenditures (excluding allowance for equity funds used during construction)	(1,232,059)	(1,125,104)
Contributions in aid of construction costs	18,435	12,048
Advances to affiliates, net	(166,506)	(44,968)
Proceeds from the sale of assets	15,570	84,044
Net cash used in investing activities	(3,335,998)	(1,397,685)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings	6,429,107	2,927,042
Principal payments on debt	(4,130,493)	(3,133,678)
Subsidiary equity offering, net of issue costs	1,003,209	1,486,863
Distributions to partners	(385,806)	(362,286)
Debt issuance costs	(22,217)	(35,612)
Distributions to noncontrolling interests	(574,285)	(390,805)
Other, net	(5,026)	(1,724)
Net cash provided by financing activities	2,314,489	489,800
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	81,451	19,798
CASH AND CASH EQUIVALENTS, beginning of period	86,264	68,315
CASH AND CASH EQUIVALENTS, end of period	$ 167,715	$ 88,113

Operations And Organization

9 Months Ended

Sep. 30, 2011

Operations And Organization [Abstract]

Operations And Organization

OPERATIONS AND ORGANIZATION:

Energy Transfer Equity, L.P. (together with its subsidiaries, the “Partnership,” “we,” or “ETE”) is a publicly traded Delaware limited partnership that directly and indirectly owns equity interests in Energy Transfer Partners, L.P. (“ETP”) and Regency Energy Partners LP (“Regency”), both publicly traded master limited partnerships engaged in strategic diversified energy-related services.

At September 30, 2011, our equity interests consisted of:



	General Partner Interest (as a % of total partnership interest)		Incentive Distribution Rights (“IDRs”)		Common Units
ETP	1.6	%	100	%	50,226,967
Regency	1.9	%	100	%	26,266,791

The unaudited consolidated financial statements of ETE presented herein for the three and nine month periods ended September 30, 2011 and 2010 include the results of operations of:

•the Parent Company;


•	our controlled subsidiaries, ETP and Regency (see description of their respective operations below under “Business Operations”);

•ETP’s and Regency’s wholly-owned subsidiaries; and

•our wholly-owned subsidiaries that own the general partner and IDR interests in ETP and Regency.

ETE obtained control of Regency on May 26, 2010, and as such, the nine month period ended September 30, 2010 includes the results of Regency for the period from the acquisition date through the end of the period.

Unless the context requires otherwise, references to “we,” “us,” “our,” and “ETE” mean Energy Transfer Equity, L.P. and its consolidated subsidiaries, which include ETP, Energy Transfer Partners GP, L.P. (“ETP GP”), the General Partner of ETP, ETP GP’s General Partner, Energy Transfer Partners, L.L.C. (“ETP LLC”), Regency, Regency GP LP (“Regency GP”), the General Partner of Regency, and Regency GP’s General Partner, Regency GP LLC (“Regency LLC”). References to the “Parent Company” mean Energy Transfer Equity, L.P. on a stand-alone basis.

Business Operations

The Parent Company’s principal sources of cash flow are its direct and indirect investments in the limited partner and general partner interests in ETP and Regency. The Parent Company’s primary cash requirements are for general and administrative expenses, debt service requirements, distributions to its partners and holders of the Series A Convertible Preferred Units (the “Preferred Units”) and at ETE’s election, capital contributions to ETP and Regency in respect of ETE’s general partner interests in ETP and Regency. Parent Company-only assets are not available to satisfy the debts and other obligations of ETE’s subsidiaries. In order to fully understand the financial condition of the Parent Company on a stand-alone basis, see Note 19 for stand-alone financial information apart from that of the consolidated partnership information included herein.

The following is a brief description of ETP’s and Regency’s operations:

•

ETP is a publicly traded partnership owning and operating a diversified portfolio of energy assets. ETP has pipeline operations in Arizona, Arkansas, Colorado, Louisiana, New Mexico, Utah and West Virginia and owns the largest intrastate pipeline system in Texas. ETP currently has natural gas operations that include gathering and transportation pipelines, treating and processing assets, and storage facilities located in Texas. ETP also holds a 70% interest in Lone Star NGL LLC (“Lone Star”), a joint venture that owns and operates NGL storage, fractionation and transportation assets in Texas, Louisiana and Mississippi. ETP is also one of the largest retail marketers of propane in the United States.

•

Regency is a publicly traded partnership engaged in the gathering and processing, contract compression, treating, transportation, fractionation and storage of natural gas and NGLs. Regency focuses on providing midstream services in some of the most prolific natural gas producing regions in the United States, including the Haynesville, Eagle Ford, Barnett, Fayetteville, and Marcellus shales, as well as the Permian Delaware basin. Its assets are located in California, Louisiana, Texas, Arkansas, Pennsylvania, Mississippi, Alabama and the mid-continent region of the United States, which includes Kansas, Colorado and Oklahoma. Regency also holds a 30% interest in Lone Star.

Preparation of Interim Financial Statements

The accompanying consolidated balance sheet as of December 31, 2010, which has been derived from audited financial statements, and the unaudited interim consolidated financial statements and notes thereto of the Partnership, as of September 30, 2011 and for the three and nine month periods ended September 30, 2011 and 2010, have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim consolidated financial information and pursuant to the rules and regulations of the SEC. Accordingly, they do not include all the information and footnotes required by GAAP for complete consolidated financial statements. However, management believes that the disclosures made are adequate to make the information not misleading. The results of operations for interim periods are not necessarily indicative of the results to be expected for a full year due to the seasonal nature of the Partnership’s operations, maintenance activities of the Partnership’s subsidiaries and the impact of forward natural gas prices and differentials on certain derivative financial instruments that are accounted for using mark-to-market accounting. Management has evaluated subsequent events through the date the financial statements were issued.

In the opinion of management, all adjustments (all of which are normal and recurring) have been made that are necessary to fairly state the consolidated financial position of the Partnership as of September 30, 2011, and the Partnership’s results of operations and cash flows for the three and nine months ended September 30, 2011 and 2010. The unaudited interim consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto presented in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2010, as filed with the SEC on February 28, 2011.

Certain prior period amounts have been reclassified to conform to the 2011 presentation. These reclassifications had no impact on net income or total equity.

- Definition

The entire disclosure for organization, consolidation and basis of presentation of financial statements disclosure.

+ References

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-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
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-Paragraph 2-6
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
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+ Details

Estimates	9 Months Ended
Estimates	Sep. 30, 2011
Estimates Disclosure [Abstract]
Estimates	ESTIMATES: The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the accrual for and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The natural gas industry conducts its business by processing actual transactions at the end of the month following the month of delivery. Consequently, the most current month’s financial results for natural gas and NGL related operations are estimated using volume estimates and market prices. Any differences between estimated results and actual results are recognized in the following month’s financial statements. Management believes that the estimated operating results represent the actual results in all material respects. Some of the other significant estimates made by management include, but are not limited to, the timing of certain forecasted transactions that are hedged, the fair value of derivative instruments, useful lives for depreciation and amortization, purchase accounting allocations and subsequent realizability of intangible assets, fair value measurements used in the goodwill impairment test, market value of inventory, assets and liabilities resulting from the regulated ratemaking process, contingency reserves and environmental reserves. Actual results could differ from those estimates.

Acquisitions and Divestitures

9 Months Ended

Sep. 30, 2011

Acquisitions and Dispositions [Abstract]

Acquisitions and Divestitures

ACQUISITIONS AND DIVESTITURES:

LDH Acquisition

On May 2, 2011, ETP-Regency Midstream Holdings, LLC (“ETP-Regency LLC”), a joint venture owned 70% by ETP and 30% by Regency, acquired all of the membership interest in LDH Energy Asset Holdings LLC (“LDH”), from Louis Dreyfus Highbridge Energy LLC (“Louis Dreyfus”) for approximately $1.98 billion in cash (the “LDH Acquisition”), including working capital adjustments. ETP contributed approximately $1.38 billion to ETP-Regency LLC to fund its 70% share of the purchase price, while Regency contributed approximately $592.7 million to fund its 30% share of the purchase price. Subsequent to closing, ETP-Regency LLC was renamed Lone Star.

Lone Star owns and operates a natural gas liquids storage, fractionation and transportation business. Lone Star’s storage assets are primarily located in Mont Belvieu, Texas and its West Texas Pipeline transports NGLs through an intrastate pipeline system that originates in the Permian Basin in west Texas, passes through the Barnett Shale production area in north Texas and terminates at the Mont Belvieu storage and fractionation complex. Lone Star also owns and operates fractionation and processing assets located in Louisiana. The acquisition of LDH by Lone Star significantly expands ETP and Regency’s asset portfolios by adding a NGL platform with storage, transportation and fractionation capabilities. This acquisition is expected to provide ETP and Regency with additional consistent fee-based revenues.

ETP accounted for the LDH Acquisition using the acquisition method of accounting. Lone Star’s results of operations are consolidated into our ETP reporting segment, while Lone Star’s results are recorded as an equity method investment in our Regency reporting segment. Regency’s equity method investment in Lone Star is reflected by ETP as noncontrolling interest attributable to Lone Star. These amounts have been eliminated in our consolidated financial statements.

The following table summarizes the assets acquired and liabilities assumed recognized as of the acquisition date:



Total current assets	$	118,177
Property, plant and equipment⁽¹⁾	1,419,591
Goodwill	432,026
Intangible assets	81,000
Other assets	157
	2,050,951

Total current liabilities	74,964
Other long-term liabilities	438
	75,402
Total consideration	1,975,549
Cash received	31,231
Total consideration, net of cash received	$	1,944,318

(1)Property, plant and equipment (and estimated useful lives) consists of the following:



Land and improvements	$	30,759
Buildings and improvements (10 to 40 years)	3,123
Pipelines and equipment (20 to 65 years)	662,881
Natural gas liquids storage (40 years)	682,419
Linepack	704
Vehicles (3 to 20 years)	242
Furniture and fixtures (3 to 10 years)	49
Other (5 to 10 years)	8,526
Construction work-in-process	30,888
Property, plant and equipment	$	1,419,591

Pro Forma Results of Operations

The following unaudited pro forma consolidated results of operations for the three and nine months ended September 30, 2011 and 2010 are presented as if the acquisitions of LDH and Regency had been completed on January 1, 2010:



	Three Months Ended September 30,					Nine Months Ended September 30,
	2011		2010			2011		2010
Revenues	$	2,097,866	$	1,656,950		$	6,170,481	$	5,558,813
Net income (loss)	60,669		(10,114		)	358,230		203,747
Net income attributable to partners	69,083		(16,777		)	221,972		162,889
Basic net income (loss) per Limited Partner unit	$	0.31	$	(0.08	)	$	1.00	$	0.73
Diluted net income (loss) per Limited Partner unit	$	0.31	$	(0.08	)	$	1.00	$	0.73

The pro forma consolidated results of operations include adjustments to:

•include the results of LDH and Regency for all periods presented;


•	include the incremental expenses associated with the fair value adjustments recorded as a result of applying the acquisition method of accounting;

•include incremental interest expense related to financing the purchase price;

•adjust for one-time expenses; and

•adjust for relative changes in ownership resulting from both transactions.

The pro forma information is not necessarily indicative of the results of operations that would have occurred had the transactions been made at the beginning of the periods presented or the future results of the combined operations.

Pending Acquisition

On July 19, 2011, we entered into a Second Amended and Restated Plan of Merger (the “Second Amended SUG Merger Agreement”) with Sigma Acquisition Corporation, a Delaware corporation and our wholly-owned subsidiary (“Merger Sub”), and Southern Union Company (“SUG”), a Delaware corporation. The Second Amended SUG Merger Agreement modifies certain terms of the Amended and Restated Agreement and Plan of Merger entered into by us, Merger Sub and SUG on July 4, 2011. Under the terms of the Second Amended SUG Merger Agreement, Merger Sub will merge with and into SUG, with SUG continuing as the surviving entity and becoming our wholly-owned subsidiary (the “SUG Merger”) subject to certain conditions to close. Pursuant to the Second Amended SUG Merger Agreement, ETE will acquire all of the outstanding shares of SUG in a transaction valued at $9.4 billion at the time of the execution of the Second Amended SUG Merger Agreement, including $5.7 billion in cash and ETE Common Units and $3.7 billion of existing SUG indebtedness. Stockholders of SUG may elect to exchange each share of SUG stock for either $44.25 in cash or 1.00 ETE Common Unit. The maximum cash component is 60% of the aggregate consideration and the common unit component can fluctuate between 40% and 50%. Elections in excess of either the cash or common unit limits will be subject to proration.

Consummation of the SUG Merger is subject to customary conditions, including, without limitation: (i) the adoption of the Second Amended SUG Merger Agreement by the stockholders of SUG, (ii) the receipt of required approvals from the Federal Energy Regulatory Commission (“FERC”), the Missouri Public Service Commission and, if required, the Massachusetts Department of Public Utilities, (iii) the effectiveness of a registration statement on Form S-4 relating to the ETE Common Units to be issued in the SUG Merger, and (iv) the absence of any law, injunction, judgment or ruling prohibiting or restraining the SUG Merger or making the consummation of the SUG Merger illegal. On July 28, 2011, the waiting period applicable to the SUG Merger under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended (the "HSR Act") expired. On September 23, 2011, the FERC issued a letter order authorizing the transfer of FERC-jurisdictional facilities resulting from the SUG Merger. On October 27, 2011, the registration statement on Form S-4 was declared effective by the SEC.

Citrus Transaction

On July 19, 2011, ETP entered into an Amended and Restated Agreement and Plan of Merger with us (the “Amended Citrus Merger Agreement”). The Amended Citrus Merger Agreement modifies certain terms of the Agreement and Plan of Merger entered into by ETP and us on July 4, 2011. Pursuant to the terms of the Second Amended SUG Merger Agreement, immediately prior to the effective time of the SUG Merger, we will assign and SUG will assume the benefits and obligations of us under the Amended Citrus Merger Agreement.

Under the Amended Citrus Merger Agreement, it is anticipated that SUG will cause the contribution to ETP of a 50% interest in Citrus Corp., which owns 100% of the Florida Gas Transmission pipeline system and is currently jointly owned by SUG and El Paso Corporation (the “Citrus Transaction”). The Citrus Transaction will be effected through the merger of Citrus ETP Acquisition, L.L.C., a Delaware limited liability company and wholly-owned subsidiary of SUG that indirectly owns a 50% interest in Citrus Corp. (“CrossCountry”). In exchange for the interest in Citrus Corp., SUG will receive approximately $2 billion, consisting of approximately $1.9 billion in cash and $105 million of ETP Common Units, with the value of the ETP Common Units based on the volume-weighted average trading price for the 10 consecutive trading days ending immediately prior to the date that is three trading days prior to the closing date of the Citrus Transaction. In order to increase the expected accretion to be derived from the Citrus Transaction, we have agreed to relinquish our rights to approximately $220 million of incentive distributions from ETP that we would otherwise be entitled to receive over 16 consecutive quarters following the closing of the transaction.

The Amended Citrus Merger Agreement includes customer representations, warranties and covenants of ETP and us (including representations, warranties and covenants relating to SUG, CrossCountry and certain of CrossCountry’s affiliates). Consummation of the Citrus Transaction is subject to customary conditions, including, without limitation: (i) satisfaction or waiver of the closing conditions set forth in the Second Amended SUG Merger Agreement, (ii) the receipt by ETP of any necessary waivers or amendments to its credit agreements, (iii) the amendment of ETP’s partnership agreement to reflect the agreed upon relinquishment by us of incentive distributions from ETP discussed above, and (iv) the absence of any order, decree, injunction or law prohibiting or making the consummation of the transactions contemplated by the Amended Citrus Merger Agreement illegal. The Amended Citrus Merger Agreement contains certain termination rights for both us and ETP, including among others, the right to terminate if the Citrus Transaction is not completed by December 31, 2012 or if the Second Amended Merger SUG Agreement is terminated.

Pursuant to the Amended Citrus Merger Agreement, we have granted ETP a right of first offer with respect to any disposition by us or SUG of Southern Union Gas Services, a subsidiary of SUG that owns and operates a natural gas gathering and processing system serving the Permian Basin in West Texas and New Mexico.

Midcontinent Express Pipeline

In conjunction with the Regency Transactions in May 2010, Regency acquired an indirect 49.9% interest in the Midcontinent Express Pipeline LLC (“MEP”), and an option to acquire an additional 0.1% interest in MEP subsequent to May 2011. On September 1, 2011, Regency exercised its option to acquire the remaining 0.1% interest in MEP from ETP for approximately $1.2 million in cash.

Propane Operations

In October 2011, ETP entered into an agreement with AmeriGas Partners, L.P. (“AmeriGas”) to contribute its propane operations, consisting of Heritage Operating, L.P. (“HOLP”) and Titan Energy Partners, L.P. (“Titan”) (collectively, the “Propane Business”) to AmeriGas in exchange for consideration of approximately $2.9 billion. The consideration consists of $1.5 billion in cash and common units of AmeriGas valued at $1.32 billion at the time of the execution of the agreement, plus the assumption of certain liabilities of the Propane Business. One of ETP's closing deliverables under the agreement is that it enters into and delivers a support agreement with AmeriGas that ETP will provide contingent, residual support of senior notes issued by AmeriGas to finance the cash portion of the purchase price. The transaction is subject to customary closing conditions, including approval under the HSR Act, and is expected to close late 2011 or early 2012.

We have not reflected the Propane operations as discontinued operations as we expect to have a continuing involvement in this business as a result of the investment in AmeriGas that would be transferred to ETP as consideration for the transaction.

- Definition

The entire disclosure for a business combination (or series of individually immaterial business combinations) completed during the period, including background, timing, and recognized assets and liabilities. The disclosure may include leverage buyout transactions (as applicable).

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Emerging Issues Task Force (EITF)
-Number 88-16
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141
-Paragraph 51, 52
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Appendix F
-Paragraph F4
-Subparagraph e

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 67-73
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 30
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6911361&loc=d3e6927-128479

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 4
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 30
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-URI http://asc.fasb.org/extlink&oid=6911361&loc=d3e7008-128479

Reference 8: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-Publisher FASB
-Name Accounting Standards Codification
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-Publisher FASB
-Name Accounting Standards Codification
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Reference 19: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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+ Details

Cash And Cash Equivalents

9 Months Ended

Sep. 30, 2011

Supplemental Cash Flow Information [Abstract]

Cash And Cash Equivalents

CASH AND CASH EQUIVALENTS:

Cash and cash equivalents include all cash on hand, demand deposits, and investments with original maturities of three months or less. We consider cash equivalents to include short-term, highly liquid investments that are readily convertible to known amounts of cash and that are subject to an insignificant risk of changes in value.

We place our cash deposits and temporary cash investments with high credit quality financial institutions. At times, our cash and cash equivalents may be uninsured or in deposit accounts that exceed the Federal Deposit Insurance Corporation insurance limit.

The net change in operating assets and liabilities (net of effects of acquisitions) included in cash flows from operating activities is comprised as follows:



	Nine Months Ended September 30,
	2011			2010
Accounts receivable	$	15,492		$	200,962
Accounts receivable from related companies	(8,401		)	(10,637		)
Inventories	50,096			113,790
Exchanges receivable	4,251			4,757
Other current assets	(15,992		)	21,250
Other non-current assets, net	7,406			8,538
Accounts payable	(26,696		)	(107,895		)
Accounts payable to related companies	(2,733		)	(5,741		)
Exchanges payable	(244		)	(8,340		)
Accrued and other current liabilities	165,277			52,127
Other non-current liabilities	1,244			(741		)
Price risk management assets and liabilities, net	44,476			162,734
Net change in operating assets and liabilities, net of effects of acquisitions	$	234,176		$	430,804

Non-cash investing and financing activities are as follows:



	Nine Months Ended September 30,
	2011		2010
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures	$	154,378	$	83,834
Gain from subsidiary common unit transactions	$	93,941	$	343,714
NON-CASH FINANCING ACTIVITIES:
Subsidiary issuance of common units in connection with acquisition	$	3,000	$	—
Long-term debt assumed and non-compete agreement notes payable issued in acquisitions	$	4,166	$	1,240,481

Inventories (Notes)

9 Months Ended

Sep. 30, 2011

Inventory, Net [Abstract]

Inventories

INVENTORIES:

Inventories consisted of the following:



	September 30, 2011		December 31, 2010
Natural gas and NGLs, excluding propane	$	120,798	$	170,179
Propane	75,085		76,341
Appliances, parts and fittings and other	132,958		119,864
Total inventories	$	328,841	$	366,384

ETP utilizes commodity derivatives to manage price volatility associated with its natural gas inventory and designates certain of these derivatives as fair value hedges for accounting purposes. Changes in fair value of the designated hedged inventory have been recorded in inventory on our consolidated balance sheets and in cost of products sold in our consolidated statements of operations.

Goodwill And Intangible Assets

9 Months Ended

Sep. 30, 2011

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Intangible Assets

GOODWILL AND INTANGIBLE ASSETS:

A net increase in goodwill of $438.8 million was recorded during the nine months ended September 30, 2011 primarily due to the LDH Acquisition referenced in Note 3. This additional goodwill is expected to be deductible for tax purposes. In addition, ETP recorded customer contracts of $81 million with useful lives ranging from 3 to 15 years.

Components and useful lives of intangible assets were as follows:



	September 30, 2011					December 31, 2010
	Gross Carrying Amount		Accumulated Amortization			Gross Carrying Amount		Accumulated Amortization
Amortizable intangible assets:
Customer relationships, contracts and agreements (3 to 46 years)	$	1,056,948	$	(122,257	)	$	971,657	$	(88,583	)
Trade names (20 years)	65,500		(4,367		)	65,500		(1,910		)
Noncompete agreements (3 to 15 years)	15,893		(7,900		)	21,165		(11,888		)
Patents (9 years)	750		(181		)	750		(118		)
Other (10 to 15 years)	1,320		(566		)	1,320		(492		)
Total amortizable intangible assets	1,140,411		(135,271		)	1,060,392		(102,991		)
Non-amortizable intangible assets:
Trademarks	78,828		—			77,445		—
Total intangible assets	$	1,219,239	$	(135,271	)	$	1,137,837	$	(102,991	)

Aggregate amortization expense of intangible assets was as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2011		2010		2011		2010
Reported in depreciation and amortization	$	13,168	$	7,887	$	40,541	$	23,215

Estimated aggregate amortization expense related to intangible assets for the next five years is as follows:



Years Ending December 31:
2012	$	53,989
2013	49,652
2014	48,531
2015	47,644
2016	46,864

We review amortizable intangible assets for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. If such a review should indicate that the carrying amount of amortizable intangible assets is not recoverable, we reduce the carrying amount of such assets to fair value. We review goodwill and non-amortizable intangible assets for impairment annually, or more frequently if circumstances dictate. Our annual impairment test is performed as of August 31 for reporting units within ETP’s intrastate transportation and storage, midstream and retail propane operations and as of December 31 for all others, including all of Regency’s reporting units. We have not completed our annual impairment tests for 2011 and have not recorded any impairments related to amortizable intangible assets during the nine months ended September 30, 2011.

Recently Issued Accounting Standards

In September 2011, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2011-08, Intangibles - Goodwill and Other (Topic 350): Testing Goodwill for Impairment (“ASU 2011-08”), which simplifies how entities test goodwill for impairment. ASU 2011-08 gives entities the option, under certain circumstances, to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether further impairment testing is necessary. ASU 2011-08 is effective for fiscal years beginning after December 15, 2011, and early adoption is permitted. We are currently evaluating early adoption of ASU 2011-08, but we do not expect adoption of this standard will materially impact our financial position or results of operations.

- Definition

The entire disclosure for the aggregate amount of goodwill and a description of intangible assets, which may include (a) for amortizable intangible assets (also referred to as finite-lived intangible assets), the carrying amount, the amount of any significant residual value, and the weighted-average amortization period, (b) for intangible assets not subject to amortization (also referred to as indefinite-lived intangible assets), the carrying amount, and (c) the amount of research and development assets acquired and written off in the period, including the line item in the income statement in which the amounts written off are aggregated, if not readily apparent from the income statement. Also discloses (a) for amortizable intangibles assets in total and by major class, the gross carrying amount and accumulated amortization, the total amortization expense for the period, and the estimated aggregate amortization expense for each of the five succeeding fiscal years, (b) for intangible assets not subject to amortization the carrying amount in total and by major class, and (c) for goodwill, in total and for each reportable segment, the changes in the carrying amount of goodwill during the period (including the aggregate amount of goodwill acquired, the aggregate amount of impairment losses recognized, and the amount of goodwill included in the gain (loss) on disposal of a reporting unit). If any part of goodwill has not been allocated to a reportable segment, discloses the unallocated amount and the reasons for not allocating. For each impairment loss recognized related to an intangible asset (excluding goodwill), discloses: (a) a description of the impaired intangible asset and the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method for determining fair value, (c) the caption in the income statement or the statement of activities in which the impairment loss is aggregated, and (d) the segment in which the impaired intangible asset is reported. For each goodwill impairment loss recognized, discloses: (a) a description of the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method of determining the fair value of the associated reporting unit, and (c) if a recognized impairment loss is an estimate not finalized and the reasons why the estimate is not final. May also disclose the nature and amount of any significant adjustments made to a previous estimate of an impairment loss.

+ References + Details

Fair Value Measurements

9 Months Ended

Sep. 30, 2011

Fair Value Measurements [Abstract]

Fair Value Measurements

FAIR VALUE MEASUREMENTS:

The carrying amounts of cash and cash equivalents, accounts receivable and accounts payable approximate their fair value. Price risk management assets and liabilities are recorded at fair value.

Based on the estimated borrowing rates currently available to us and our subsidiaries for long-term loans with similar terms and average maturities, the aggregate fair value and carrying amount of our consolidated debt obligations as of September 30, 2011 was $12.27 billion and $11.68 billion, respectively. As of December 31, 2010, the aggregate fair value and carrying amount of our consolidated debt obligations was $10.23 billion and $9.38 billion, respectively.

We have marketable securities, commodity derivatives, interest rate derivatives, the Preferred Units and embedded derivatives in the Preferred Units of a Subsidiary (the “Regency Preferred Units”) that are accounted for as assets and liabilities at fair value in our consolidated balance sheets. We determine the fair value of our assets and liabilities subject to fair value measurement by using the highest possible “level” of inputs. Level 1 inputs are observable quotes in an active market for identical assets and liabilities. We consider the valuation of marketable securities and commodity derivatives transacted through a clearing broker with a published price from the appropriate exchange as a Level 1 valuation. Level 2 inputs are inputs observable for similar assets and liabilities. We consider over-the-counter (“OTC”) commodity derivatives entered into directly with third parties as a Level 2 valuation since the values of these derivatives are quoted on an exchange for similar transactions. Additionally, we consider our options transacted through our clearing broker as having Level 2 inputs due to the level of activity of these contracts on the exchange in which they trade. We consider the valuation of our interest rate derivatives as Level 2 since we use a LIBOR curve based on quotes from an active exchange of Eurodollar futures for the same period as the future interest swap settlements and discount the future cash flows accordingly, including the effects of credit risk. Level 3 inputs are unobservable. Derivatives related to the Regency 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 value, and are considered Level 3. The fair value of the Preferred Units was based predominantly on an income approach model and is also considered Level 3.

The following tables summarize the fair value of our financial assets and liabilities measured and recorded at fair value on a recurring basis as of September 30, 2011 and December 31, 2010 based on inputs used to derive their fair values:



	Fair Value Measurements at September 30, 2011 Using
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Marketable securities	$	3,151		$	3,151		$	—		$	—
Interest rate derivatives	30,564			—			30,564			—
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	74,892			74,892			—			—
Swing Swaps IFERC	21,818			1,074			20,744			—
Fixed Swaps/Futures	73,076			70,112			2,964			—
Options — Puts	13,348			—			13,348			—
Forward Physical Swaps	738			—			738			—
NGLs — Forward Swaps	577			—			577			—
Propane — Forward Swaps	77			—			77			—
WTI Crude Oil	4,817			—			4,817			—
Total commodity derivatives	189,343			146,078			43,265			—
Total Assets	$	223,058		$	149,229		$	73,829		$	—
Liabilities:
Interest rate derivatives	$	(99,658	)	$	—		$	(99,658	)	$	—
Series A Convertible Preferred Units	(314,980		)	—			—			(314,980		)
Embedded derivatives in the Regency Preferred Units	(36,268		)	—			—			(36,268		)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(68,918		)	(68,918		)	—			—
Swing Swaps IFERC	(22,707		)	(1,988		)	(20,719		)	—
Fixed Swaps/Futures	(48,287		)	(48,133		)	(154		)	—
Options — Puts	(423		)	—			(423		)	—
Options — Calls	(122		)	—			(122		)	—
Forward Physical Swaps	(482		)	—			(482		)	—
NGLs — Forward Swaps	(11,722		)	—			(11,722		)	—
Propane — Forward Swaps	(2,086		)	—			(2,086		)	—
Total commodity derivatives	(154,747		)	(119,039		)	(35,708		)	—
Total Liabilities	$	(605,653	)	$	(119,039	)	$	(135,366	)	$	(351,248	)



	Fair Value Measurements at December 31, 2010 Using
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Marketable securities	$	2,032		$	2,032		$	—		$	—
Interest rate derivatives	20,790			—			20,790			—
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	15,756			15,756			—			—
Swing Swaps IFERC	1,682			1,562			120			—
Fixed Swaps/Futures	44,955			42,474			2,481			—
Options — Calls	75			—			75			—
Options — Puts	26,241			—			26,241			—
NGLs — Forward Swaps	192			—			192			—
Propane — Forward Swaps	6,864			—			6,864			—
Total commodity derivatives	95,765			59,792			35,973			—
Total Assets	$	118,587		$	61,824		$	56,763		$	—
Liabilities:
Interest rate derivatives	$	(20,922	)	$	—		$	(20,922	)	$	—
Series A Convertible Preferred Units	(317,600		)	—			—			(317,600		)
Embedded derivatives in the Regency Preferred Units	(57,023		)	—			—			(57,023		)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(17,372		)	(17,372		)	—			—
Swing Swaps IFERC	(3,768		)	(3,520		)	(248		)	—
Fixed Swaps/Futures	(42,252		)	(41,825		)	(427		)	—
Options — Calls	(2,643		)	—			(2,643		)	—
Options — Puts	(7		)	—			(7		)	—
NGLs — Forward Swaps	(10,684		)	—			(10,684		)	—
WTI Crude Oil	(3,581		)	—			(3,581		)	—
Total commodity derivatives	(80,307		)	(62,717		)	(17,590		)	—
Total Liabilities	$	(475,852	)	$	(62,717	)	$	(38,512	)	$	(374,623	)

The following table presents a reconciliation of the beginning and ending balances for liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3) for the nine months ended September 30, 2011. There were no transfers between the fair value hierarchy levels during the nine months ended September 30, 2011.



Balance, December 31, 2010	$	(374,623	)
Net unrealized gains included in other income (expense)	23,375
Balance, September 30, 2011	$	(351,248	)

- Definition

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 44A, 44B
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15C, 15D
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15A
-Subparagraph a-d
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 15B
-Subparagraph a, b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 3, 10, 14, 15
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 157
-Paragraph 32, 33, 34
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 159
-Paragraph 17-22, 27, 28
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19207-110258

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 21
-URI http://asc.fasb.org/extlink&oid=6947722&loc=d3e13537-108611

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-Publisher FASB
-Name Accounting Standards Codification
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-SubTopic 10
-Section 50
-Paragraph 28
-URI http://asc.fasb.org/extlink&oid=6957238&loc=d3e14064-108612

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=6947722&loc=d3e13433-108611

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=6957238&loc=d3e14172-108612

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 16
-URI http://asc.fasb.org/extlink&oid=6947722&loc=d3e13504-108611

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19296-110258

+ Details

Net Income (Loss) Per Limited Partner Unit

9 Months Ended

Sep. 30, 2011

Earnings Per Share [Abstract]

Net Income (Loss) Per Limited Partner Unit

NET INCOME (LOSS) PER LIMITED PARTNER UNIT:

A reconciliation of net income (loss) and weighted average units used in computing basic and diluted net income (loss) per unit is as follows:



	Three Months Ended September 30,					Nine Months Ended September 30,
	2011		2010			2011		2010
Basic Net Income (Loss) per Limited Partner Unit:
Limited Partners’ interest in net income (loss)	$	68,869	$	(15,289	)	$	223,315	$	116,346
Weighted average Limited Partner units	222,972,708		222,941,172			222,966,763		222,941,151
Basic net income (loss) per Limited Partner unit	$	0.31	$	(0.07	)	$	1.00	$	0.52
Diluted Net Income (Loss) per Limited Partner Unit:
Limited Partners’ interest in net income (loss)	$	68,869	$	(15,289	)	$	223,315	$	116,346
Dilutive effect of equity-based compensation of subsidiaries	167		—			525		158
Diluted net income (loss) available to Limited Partners	$	68,702	$	(15,289	)	$	222,790	$	116,188
Weighted average Limited Partner units	222,972,708		222,941,172			222,966,763		222,941,151
Diluted net income (loss) per Limited Partner unit	$	0.31	$	(0.07	)	$	1.00	$	0.52

Discontinued operations per unit has been omitted as the impact rounds to $0.00 per unit for all relevant periods presented.

The calculation above for the three and nine months ended September 30, 2011 for diluted net income (loss) per limited partner unit excludes the impact of any ETE Common Units that would be issued upon conversion of the Preferred Units, because inclusion would have been antidilutive. The Preferred Units have a liquidation preference of $300 million and are subject to mandatory conversion as discussed in Note 10.

Debt Obligations

9 Months Ended

Sep. 30, 2011

Debt Obligations [Abstract]

Debt Obligations

DEBT OBLIGATIONS:

Senior Notes

ETP Senior Notes

In May 2011, ETP completed a public offering of $800 million aggregate principal amount of 4.65% Senior Notes due June 1, 2021 and $700 million aggregate principal amount of 6.05% Senior Notes due June 1, 2041. ETP used the proceeds, net of commissions, of $1.48 billion to repay all of the borrowings outstanding under its revolving credit facility (the “ETP Credit Facility”), to fund capital expenditures related to pipeline construction projects and for general partnership purposes. ETP may redeem some or all of the notes at any time and from time to time pursuant to the terms of the indenture subject to the payment of a “make-whole” premium. Interest will be paid semi-annually.

Regency Senior Notes

In May 2011, Regency issued $500 million aggregate principal amount of 6.50% Senior Notes due July 15, 2021 (the “Regency 2021 Notes”). Regency used the proceeds, net of commissions, of approximately $491.3 million to repay borrowings outstanding under its revolving credit facility (the “Regency Credit Facility”). Regency capitalized $9.8 million in debt issuance costs that will be amortized to interest expense, net over the term of the Regency 2021 Notes. Interest will be paid semi-annually.

At any time prior to July 15, 2016, Regency may redeem some or all of the Regency 2021 Notes at a redemption price equal to 100% of the principal amount plus a “make-whole” premium, plus accrued and unpaid interest to the redemption date. At any time before July 15, 2014, Regency may redeem up to 35% of the aggregate principal amount of the Regency 2021 Notes then outstanding at a redemption price equal to 106.5% of the principal amount of the notes to be redeemed, plus accrued and unpaid interest to the redemption date.

Upon the occurrence of a change of control event, as defined in the indenture, followed by a rating decline within 90 days, each holder of the Regency 2021 Notes will be entitled to require Regency to purchase all or a portion of its notes at a purchase price of 101% plus accrued interest and liquidated damages, if any. Regency’s ability to purchase the notes upon a change of control will be limited by the terms of its debt agreements, including Regency’s revolving credit facility.

The Regency 2021 Notes contain various covenants that limit, among other things, Regency’s ability, and the ability of certain of its subsidiaries to:


•	incur additional indebtedness;


•	pay distributions on, or repurchase or redeem equity interests;


•	make certain investments;


•	incur liens;


•	enter into certain types of transactions with affiliates; and


•	sell assets, consolidate or merge with or into other companies.

Revolving Credit Facilities

Parent Company Credit Agreement

The Parent Company has a $200 million senior secured revolving credit facility (the “Parent Company Credit Agreement”) available through September 20, 2015. The Parent Company Credit Agreement is secured by all tangible or intangible assets of ETE and certain of its subsidiaries. As of September 30, 2011, there were no outstanding borrowings under the Parent Company Credit Agreement.

ETP Credit Facility

The ETP Credit Facility provides for $2 billion of revolving credit capacity that is expandable to $3 billion (subject to obtaining the approval of the administrative agent and securing lender commitments for the increased borrowing capacity). The ETP Credit Facility matures on July 20, 2012, unless ETP elects the option of one-year extensions (subject to the approval of each such extension by the lenders holding a majority of the aggregate lending commitments). As of September 30, 2011, ETP had a balance of $574.6 million outstanding under the ETP Credit Facility, and the amount available for future borrowings was $1.4 billion taking into account letters of credit of $24.3 million. The weighted average interest rate on the total amount outstanding as of September 30, 2011 was 0.80%.

On October 27, 2011, ETP amended and restated the ETP Credit Facility to, among other things, (i) allow for borrowings of up to $2.5 billion; (ii) extend the maturity date from July 20, 2012 to October 27, 2016 (which may be extended by one year with lender approval); (iii) allow for an increase in the size of the credit facility to $3.75 billion (subject to obtaining lender commitments for the additional borrowing capacity); and (iv) to adjust the interest rates and commitment fees to current market terms. Following this amendment and based on ETP's current ratings, the interest margin for LIBOR rate loans is 1.50% and the commitment fee for unused borrowing capacity is 0.25%.

Regency Credit Facility

The Regency Credit Facility has aggregate revolving commitments of $900 million that matures June 15, 2014. As of September 30, 2011, there was a balance outstanding under the Regency Credit Facility of $445 million in revolving credit loans and approximately $20 million in letters of credit. The total amount available under the Regency Credit Facility, as of September 30, 2011, which is reduced by any letters of credit, was approximately $435 million. The weighted average interest rate on the total amount outstanding as of September 30, 2011 was 3.03%.

Covenants Related to Our Credit Agreements

We, ETP and Regency are required to assess compliance quarterly and were in compliance with all requirements, tests, limitations, and covenants related to our respective credit agreements as of September 30, 2011.

- Definition

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

+ References + Details

Redeemable Preferred Units	9 Months Ended
Redeemable Preferred Units	Sep. 30, 2011
Temporary Equity Disclosure [Abstract]
Preferred Stock [Text Block]	REDEEMABLE PREFERRED UNITS: ETE Preferred Units In connection with the Regency Transactions completed in May 2010, ETE issued 3,000,000 Series A Convertible Preferred Units to an affiliate of GE Energy Financial Services, Inc. (“GE EFS”) having an aggregate liquidation preference of $300 million. These units are reflected as a non-current liability in our consolidated balance sheets as of September 30, 2011 and December 31, 2010. The Preferred Units are measured at fair value on a recurring basis. Changes in the estimated fair value of the ETE Preferred Units are recorded in other income (expense) on the consolidated statements of operations. Regency Preferred Units Regency has 4,371,586 Regency Preferred Units outstanding at September 30, 2011, which were convertible into 4,626,197 Regency Common Units. If outstanding on September 2, 2029, the Regency Preferred Units are mandatorily redeemable for $80 million plus all accrued but unpaid distributions thereon. Holders of the Regency Preferred Units receive fixed quarterly cash distributions of $0.445 per unit from Regency. Holders can elect to convert Regency Preferred Units to Regency Common Units at any time in accordance with Regency’s Partnership Agreement.

Equity

9 Months Ended

Sep. 30, 2011

Partners' Capital Notes [Abstract]

Equity

EQUITY:

ETE Common Units Issued

The change in ETE Common Units during the nine months ended September 30, 2011 was as follows:



	Number of Units
Outstanding at December 31, 2010	222,941,172
Issuance of restricted common units under equity incentive plan	31,536
Outstanding at September 30, 2011	222,972,708

Sales of Common Units by Subsidiaries

The Parent Company accounts for the difference between the carrying amount of its investments in ETP and Regency and the underlying book value arising from the issuance or redemption of units by ETP or Regency (excluding transactions with the Parent Company) as capital transactions.

As a result of ETP’s and Regency’s issuances of Common Units during the nine months ended September 30, 2011, we recognized increases in partners’ capital of $93.9 million.

Sales of Common Units by ETP

On April 1, 2011, ETP issued 14,202,500 Common Units through a public offering. The proceeds, net of commissions, of approximately $695.5 million were used to repay amounts outstanding under the ETP Credit Facility, to fund capital expenditures related to pipeline construction projects and for general partnership purposes.

ETP has an Equity Distribution Agreement with Credit Suisse Securities (USA) LLC (“Credit Suisse”) under which ETP may offer and sell from time to time through Credit Suisse, as its sales agent, ETP Common Units having an aggregate offering price of up to $200 million. During the nine months ended September 30, 2011, ETP received proceeds from units issued pursuant to this agreement of approximately $96.3 million, net of commissions, which were used for general partnership purposes. Approximately $77.5 million of ETP Common Units remain available to be issued under the Equity Distribution Agreement based on trades initiated through September 30, 2011.

In April 2011, ETP filed a registration statement with the SEC covering ETP’s Distribution Reinvestment Plan (the “DRIP”). The DRIP provides Unitholders of record and beneficial owners of ETP Common Units a voluntary means by which they can increase the number of ETP Common Units they own by reinvesting the quarterly cash distributions they would otherwise receive in the purchase of additional ETP Common Units. The registration statement covers the issuance of up to 5,750,000 ETP Common Units under the DRIP.

For the nine months ended September 30, 2011, distributions of approximately $7.6 million were reinvested under the DRIP resulting in the issuance of 175,863 Common Units.

Sales of Common Units by Regency

In October 2011, Regency issued 11,500,000 Regency Common Units through a public offering. The proceeds, net of commissions, of approximately $231.9 million were used to repay borrowings outstanding under the Regency Credit Facility.

In May 2011, Regency issued 8,500,001 Regency Common Units in a private placement. The net proceeds of $203.9 million were used to fund a portion of Regency’s 30% ownership interest in Lone Star, as discussed in Note 3.

Parent Company Quarterly Distributions of Available Cash

The Parent Company’s only cash-generating assets currently consist of distributions from ETP and Regency related to limited and general partnership interests, including IDRs. We currently have no independent operations outside of our interests in ETP and Regency.

Following are distributions declared and/or paid by us subsequent to December 31, 2010:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2010	February 7, 2011	February 18, 2011	$	0.540
March 31, 2011	May 6, 2011	May 19, 2011	0.560
June 30, 2011	August 5, 2011	August 19, 2011	0.625
September 30, 2011	November 4, 2011	November 18, 2011	0.625

ETP Quarterly Distributions of Available Cash

Following are distributions declared and/or paid by ETP subsequent to December 31, 2010:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2010	February 7, 2011	February 14, 2011	$	0.89375
March 31, 2011	May 6, 2011	May 16, 2011	0.89375
June 30, 2011	August 5, 2011	August 15, 2011	0.89375
September 30, 2011	November 4, 2011	November 14, 2011	0.89375

Regency Quarterly Distributions of Available Cash

Following are distributions declared and/or paid by Regency subsequent to December 31, 2010:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2010	February 7, 2011	February 14, 2011	$	0.445
March 31, 2011	May 6, 2011	May 13, 2011	0.445
June 30, 2011	August 5, 2011	August 12, 2011	0.450
September 30, 2011	November 7, 2011	November 14, 2011	0.455

Accumulated Other Comprehensive Income

The following table presents the components of accumulated other comprehensive income (“AOCI”), net of tax:



	September 30, 2011			December 31, 2010
Net gains on commodity related hedges	$	10,420		$	14,146
Unrealized gains (losses) on available-for-sale securities	(17		)	918
Subtotal	10,403			15,064
Amounts attributable to noncontrolling interest	(7,667		)	(10,266		)
Total AOCI included in partners’ capital, net of tax	$	2,736		$	4,798

- Definition

The entire disclosure for the formation, structure, control and ownership of the partnership. Disclosures related to accounts comprising partners' capital. Includes balances of general partners' capital account, limited partners' capital account, preferred partners' capital account and total partners' capital account and units outstanding; accumulated other comprehensive income; amount and nature of changes to amount of partner's capital and units outstanding by class, rights and privileges for each class of units; distribution policies and distributions paid by unit class; impact of and correction of an error in previously issued financial statements; limitations of partners' liability; redemption, conversion and distribution policies; and deferred compensation related to the issuance of units.

+ References + Details

Unit-Based Compensation Plans	9 Months Ended
Unit-Based Compensation Plans	Sep. 30, 2011
Share-based Compensation, Allocation and Classification in Financial Statements [Abstract]
Unit-Based Compensation Plans	UNIT-BASED COMPENSATION PLANS: We, ETP, and Regency have equity incentive plans for employees, officers and directors, which provide for various types of awards, including options to purchase common units, restricted units, phantom units, distribution equivalent rights (“DERs”), common unit appreciation rights, and other unit-based awards. ETE Long-Term Incentive Plan During the nine months ended September 30, 2011, ETE employees were granted a total of 30,000 unvested awards with five-year service vesting requirements. The weighted average grant-date fair value of these awards was $39.82 per unit. As of September 30, 2011 a total of 105,713 unit awards remain unvested, including the new awards granted during the period. We expect to recognize a total of $1.4 million in compensation expense over a weighted average period of 1.9 years related to unvested awards. ETP Unit-Based Compensation Plans During the nine months ended September 30, 2011, ETP employees were granted a total of 556,700 unvested awards with five-year service vesting requirements, and directors were granted a total of 2,580 unvested awards with three-year service vesting requirements. The weighted average grant-date fair value of these awards was $53.12 per unit. As of September 30, 2011 a total of 2,349,540 unit awards remain unvested, including the new awards granted during the period. ETP expects to recognize a total of $58.3 million in compensation expense over a weighted average period of 1.7 years related to unvested awards. Regency Unit-Based Compensation Plans Common Unit Options During the nine months ended September 30, 2011, no Regency Common Unit options were granted. As of September 30, 2011, a total of 156,850 Regency Common Unit options remain vested and exercisable, with a weighted average exercise price of $21.99 per Regency Common Unit option. Phantom Units During the nine months ended September 30, 2011, Regency employees and directors were granted 76,745 Regency phantom units with three-year service vesting requirements. As of September 30, 2011, a total of 713,225 Regency Phantom Units remain unvested, with a weighted average grant date fair value of $24.78. Regency expects to recognize a total of $12 million in compensation expense over a weighted average period of 4.0 years related to Regency’s unvested phantom units.

- Definition

The entire disclosure for compensation-related costs for equity-based compensation, which may include disclosure of policies, compensation plan details, allocation of equity compensation, incentive distributions, equity-based arrangements to obtain goods and services, deferred compensation arrangements, employee stock ownership plan details and employee stock purchase plan details.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 123R
-Paragraph 64, 65, A240
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Statement of Position (SOP)
-Number 93-6
-Paragraph 53
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 14

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 50
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6406099&loc=d3e25284-112666

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6415400&loc=d3e5047-113901

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
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-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6415400&loc=d3e5070-113901

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-Name Accounting Standards Codification
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-SubTopic 10
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-Topic 718
-SubTopic 40
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6418621&loc=d3e17540-113929

+ Details

Income Taxes

9 Months Ended

Sep. 30, 2011

Income Taxes [Abstract]

Income Taxes

INCOME TAXES:

The components of the federal and state income tax expense of our taxable subsidiaries are summarized as follows:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2011			2010			2011			2010
Current expense (benefit):
Federal	$	1,124		$	(3,182	)	$	6,787		$	(124	)
State	2,675			1,363			12,109			8,864
Total	3,799			(1,819		)	18,896			8,740
Deferred expense (benefit):
Federal	(41		)	3,286			(599		)	2,257
State	(468		)	626			120			360
Total	(509		)	3,912			(479		)	2,617
Total income tax expense	$	3,290		$	2,093		$	18,417		$	11,357

The effective tax rate differs from the statutory rate due primarily to Partnership earnings that are not subject to federal and state income taxes at the Partnership level.

- Definition

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 136, 172
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 43, 44, 45, 46, 47, 48, 49
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32718-109319

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 7: http://www.xbrl.org/2003/role/presentationRef
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-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32559-109319

+ Details

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities	9 Months Ended
	Sep. 30, 2011
Regulatory Matters, Commitments, Contingencies And Environmental Liabilities [Abstract]
Regulatory Matters, Commitments, Contingencies And Environmental Liabilities	REGULATORY MATTERS, COMMITMENTS, CONTINGENCIES AND ENVIRONMENTAL LIABILITIES: Regulatory Matter On September 29, 2006, the Transwestern Pipeline Company, LLC ("Transwestern") filed revised tariff sheets under Section 4(e) of the Natural Gas Act (“NGA”) proposing a general rate increase to be effective on November 1, 2006. In April 2007, the FERC approved a Stipulation and Agreement of Settlement that resolved the primary components of the rate case. Under the terms of the settlement, Transwestern was required to file a new general NGA Section 4 rate case no later than October 1, 2011. However, Transwestern sought and on September 2, 2011 was granted an extension of the filing date until December 1, 2011 to allow time for settlement discussions with shippers. On September 21, 2011, Transwestern filed a proposed settlement with the FERC, which was approved by the FERC on October 31, 2011. The settlement maintains the currently effective transportation and fuel tariff rates with the exception that it reduces certain San Juan Lateral fuel rates staggered over the three year period beginning in April 2012. The settlement also resolves certain non-rate matters and reflects a continuation of the accounting practices from the prior rate settlement. Under the settlement, Transwestern will be required to file a Section 4 rate case on October 1, 2014. Guarantee — Fayetteville Express Pipeline LLC Fayetteville Express Pipeline LLC (“FEP”), a joint venture entity in which ETP owns a 50% interest, had a credit agreement that provided for a $1.1 billion senior revolving credit facility (the “FEP Facility”). ETP guaranteed 50% of the obligations of FEP under the FEP Facility, with the remainder of FEP Facility obligations guaranteed by Kinder Morgan Energy Partners, L.P. (“KMP”). Amounts borrowed under the FEP Facility bear interest at a rate based on either a Eurodollar rate or Prime Rate. In July 2011, the FEP Facility was repaid with capital contributions from ETP and KMP totaling $390 million along with proceeds from a $600 million term loan credit facility maturing in July 2012 (which can be extended for one year at the option of FEP). Upon closing and funding of the term loan facility, the FEP Facility was terminated. FEP also entered into a $50 million revolving credit facility maturing in July 2015. FEP's indebtedness under its new credit facilities is not guaranteed by ETP or KMP. NGL Pipeline Regulation ETP and Regency have interests in NGL pipelines located in Texas. ETP and Regency believe that these pipelines do not provide interstate service and that they are thus not subject to the jurisdiction of the FERC under the Interstate Commerce Act (“ICA”) and the Energy Policy of 1992. Under the ICA, tariffs must be just and reasonable and not unduly discriminatory or confer any undue preference. We cannot guarantee that the jurisdictional status of ETP’s and Regency’s NGL facilities will remain unchanged; however, should they be found jurisdictional, the FERC’s rate-making methodologies may limit ETP’s and Regency’s ability to set rates based on their actual costs, may delay or limit the use of rates that reflect increased costs and may subject ETP and Regency to potentially burdensome and expensive operational, reporting and other requirements. Any of the foregoing could adversely affect our business, revenues and cash flow. Commitments In the normal course of our business, ETP and Regency purchase, process and sell natural gas pursuant to long-term contracts and enter into long-term transportation and storage agreements. Such contracts contain terms that are customary in the industry. ETP has also entered into several propane purchase and supply commitments, which are typically one year agreements with varying terms as to quantities, prices and expiration dates. ETP believes that the terms of these agreements are commercially reasonable and will not have a material adverse effect on its financial position or results of operations. ETP and Regency have certain non-cancelable leases for property and equipment, which require fixed monthly rental payments and expire at various dates through 2034. Rental expense under these operating leases has been included in operating expenses in the accompanying statements of operations and totaled approximately $7.3 million and $6 million for the three months ended September 30, 2011 and 2010, respectively. For the nine months ended September 30, 2011 and 2010, rental expense for operating leases totaled approximately $20.5 million and $17.7 million, respectively. ETP’s propane operations have an agreement with Enterprise Products Partners L.P. (together with its subsidiaries “Enterprise”) (see Note 16) to supply a portion of its propane requirements. The agreement will continue until 2015 and includes an option to extend the agreement for an additional year. In connection with the sale of ETP’s investment in M-P Energy in October 2007, ETP executed a propane purchase agreement for approximately 90 million gallons per year through 2015 at market prices plus a nominal fee. ETP’s and Regency’s joint venture agreements require that ETP and Regency fund their proportionate shares of capital contributions to their unconsolidated affiliates. Such capital contributions will depend upon their unconsolidated affiliates’ capital requirements, such as for funding capital projects or repayment of long-term obligations. Litigation and Contingencies We may, from time to time, be involved in litigation and claims arising out of our operations in the normal course of business. Natural gas and propane are flammable, combustible gases. Serious personal injury and significant property damage can arise in connection with their transportation, storage or use. In the ordinary course of business, we are sometimes threatened with or named as a defendant in various lawsuits seeking actual and punitive damages for product liability, personal injury and property damage. We maintain liability insurance with insurers in amounts and with coverage and deductibles management believes are reasonable and prudent, and which are generally accepted in the industry. However, there can be no assurance that the levels of insurance protection currently in effect will continue to be available at reasonable prices or that such levels will remain adequate to protect us from material expenses related to product liability, personal injury or property damage in the future. We or our subsidiaries are a party to various legal proceedings and/or regulatory proceedings incidental to our businesses. For each of these matters, we evaluate the merits of the case, our exposure to the matter, possible legal or settlement strategies, the likelihood of an unfavorable outcome and the availability of insurance coverage. If we determine that an unfavorable outcome of a particular matter is probable and can be estimated, we accrue the contingent obligation, as well as any expected insurance recoverable amounts related to the contingency. As of September 30, 2011 and December 31, 2010, accruals of approximately $13.3 million and $10.2 million, respectively, were reflected on our balance sheets related to these contingent obligations. As new information becomes available, our estimates may change. The impact of these changes may have a significant effect on our results of operations in a single period. The outcome of these matters cannot be predicted with certainty, and there can be no assurance that the outcome of a particular matter will not result in the payment of amounts that have not been accrued for the matter. Further, we may revise accrual amounts prior to the resolution of a particular contingency based on changes in facts and circumstances or in the expected outcome. No amounts have been recorded in our September 30, 2011 or December 31, 2010 consolidated balance sheets for contingencies and current litigation, other than amounts disclosed herein. Environmental Matters Our operations are subject to extensive federal, state and local environmental and safety laws and regulations that require expenditures to ensure compliance, including related to air emissions and wastewater discharges, at operating facilities and for remediation at current and former facilities as well as waste disposal sites. Although we believe our operations are in substantial compliance with applicable environmental laws and regulations, risks of additional costs and liabilities are inherent in the business of transporting, storing, gathering, treating, compressing, blending and processing natural gas, natural gas liquids and other products. As a result, there can be no assurance that significant costs and liabilities will not be incurred. Costs of planning, designing, constructing and operating pipelines, plants and other facilities must incorporate compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, the imposition of remedial obligations, the issuance of injunctions and the filing of federally authorized citizen suits. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies thereunder, and claims for damages to property or persons resulting from the operations, could result in substantial costs and liabilities. We are unable to estimate any losses or range of losses that could result from such developments. Furthermore, we may revise accrual amounts prior to resolution of a particular contingency based on changes in facts and circumstances or changes in the expected outcome. Our operations are also subject to the requirements of the federal Occupational Safety and Health Act (“OSHA”) and comparable state laws that regulate the protection of the health and safety of employees. In addition, OSHA’s hazardous communication standard requires that information be maintained about hazardous materials used or produced in our operations and that this information be provided to employees, state and local government authorities and citizens. We believe that our operations are in substantial compliance with the OSHA requirements, including general industry standards, record keeping requirements, and monitoring of occupational exposure to regulated substances. National Fire Protection Association Pamphlets No. 54 and No. 58, which establish rules and procedures governing the safe handling of propane, or comparable regulations, have been adopted as the industry standard in all of the states in which we operate. In some states, these laws are administered by state agencies, and in others, they are administered on a municipal level. With respect to the transportation of propane by truck, we are subject to regulations governing the transportation of hazardous materials under the Federal Motor Carrier Safety Act, administered by the U.S. Department of Transportation (“DOT”). We conduct ongoing training programs to help ensure that our operations are in compliance with applicable regulations. We believe that the procedures currently in effect at all of our facilities for the handling, storage and distribution of propane are consistent with industry standards and are in substantial compliance with applicable laws and regulations. ETP Environmental Matters ETP has adopted policies, practices and procedures in the areas of pollution control, product safety, occupational safety and health, and the handling, storage, use, and disposal of hazardous materials to prevent and minimize material environmental or other damage, and to limit the financial liability, which could result from such events. However, the risk of environmental or other damage is inherent in transporting, gathering, treating, compressing, blending and processing natural gas, natural gas liquids and other products, as it is with other entities engaged in similar businesses. Environmental exposures and liabilities are difficult to assess and estimate due to unknown factors such as the magnitude of possible contamination, the timing and extent of remediation, the determination of ETP’s liability in proportion to other parties, improvements in cleanup technologies and the extent to which environmental laws and regulations may change in the future. Although environmental costs may have a significant impact on the results of operations for any single period, ETP believes that such costs will not have a material adverse effect on its financial position. As of September 30, 2011 and December 31, 2010, accruals related to ETP on an undiscounted basis of $12.6 million and $13.8 million, respectively, were recorded in our consolidated balance sheets as accrued and other current liabilities and other non-current liabilities related to environmental matters. Based on information available at this time and reviews undertaken to identify potential exposure, ETP believes the amount reserved for environmental matters is adequate to cover the potential exposure for cleanup costs. Transwestern conducts soil and groundwater remediation at a number of its facilities. Some of the cleanup activities include remediation of several compressor sites on the Transwestern system for contamination by polychlorinated biphenyls (“PCBs”). The costs of this work are not eligible for recovery in rates. ETP’s total accrued future estimated cost of remediation activities expected to continue through 2025 is $7.9 million, which is included in the aggregate environmental accruals discussed above. Transwestern received approval from the FERC for the continuation of rate recovery of projected soil and groundwater remediation costs not related to PCBs for the term of its rate case settlement. Transwestern, as part of ongoing arrangements with customers, continues to incur costs associated with containing and removing potential PCBs. Future costs cannot be reasonably estimated because remediation activities are undertaken as claims are made by customers and former customers. However, such future costs are not expected to have a material impact on our financial position, results of operations or cash flows. The U.S. Environmental Protection Agency’s (the “EPA”) Spill Prevention, Control and Countermeasures program regulations were recently modified and impose additional requirements on many of ETP’s facilities. ETP expects to expend resources on tank integrity testing and any associated corrective actions as well as potential upgrades to containment structures to comply with the new rules. Costs associated with tank integrity testing and resulting corrective actions cannot be reasonably estimated at this time, but ETP believes such costs will not have a material adverse effect on its financial position, results of operations or cash flows. Petroleum-based contamination or environmental wastes are known to be located on or adjacent to six sites on which HOLP presently has, or formerly had, retail propane operations. These sites were evaluated at the time of their acquisition. In all cases, remediation operations have been or will be undertaken by others, and in all six cases, HOLP obtained indemnification rights for expenses associated with any remediation from the former owners or related entities. ETP has not been named as a potentially responsible party at any of these sites, and ETP believes that its operations have not contributed to the environmental issues at these sites. Accordingly, no amounts have been recorded in our September 30, 2011 or December 31, 2010 consolidated balance sheets. Based on information currently available to us, the presence of contamination and remediation activities at these sites are not expected to have a material adverse effect on our financial condition or results of operations. On August 20, 2010, the EPA published new regulations under the federal Clean Air Act ("CAA") to control emissions of hazardous air pollutants from existing stationary reciprocal internal combustion engines. The rule will require ETP to undertake certain expenditures and activities, likely including purchasing and installing emissions control equipment. In response to an industry group legal challenge to portions of the rule in the U.S. Court of Appeals for the D.C. Circuit and a Petition for Administrative Reconsideration to the EPA, on March 9, 2011, the EPA issued a new proposed rule and a direct final rule effective on May 9, 2011 to clarify compliance requirements related to operation and maintenance procedures for continuous parametric monitoring systems. If no further changes to the standard are made as a result of comments to the proposed rule, ETP would not expect that the cost to comply with the rule's requirements will have a material adverse effect on its financial condition or results of operations. Compliance with the final rule is required by October 2013. On June 29, 2011, the EPA finalized a rule under the CAA that revised the new source performance standards for manufacturers, owners and operators of new, modified and reconstructed stationary internal combustion engines. The rule became effective on August 29, 2011. The rule modifications may require ETP to undertake significant expenditures, including expenditures for purchasing, installing, monitoring and maintaining emissions control equipment, if it replaces equipment or expands existing facilities in the future. At this point, ETP is not able to predict the cost to comply with the rule’s requirements, because the rule applies only to changes ETP might make in the future. ETP’s pipeline operations are subject to regulation by the DOT under the Pipeline Hazardous Materials Safety Administration (“PHMSA”), pursuant to which the PHMSA has established requirements relating to the design, installation, testing, construction, operation, replacement and management of pipeline facilities. Moreover, the PHMSA, through the Office of Pipeline Safety, has promulgated a rule requiring pipeline operators to develop integrity management programs to comprehensively evaluate their pipelines, and take measures to protect pipeline segments located in what the rule refers to as “high consequence areas.” Activities under these integrity management programs involve the performance of internal pipeline inspections, pressure testing or other effective means to assess the integrity of these regulated pipeline segments, and the regulations require prompt action to address integrity issues raised by the assessment and analysis. For the three months ended September 30, 2011 and 2010, $4.2 million and $5.8 million, respectively, of capital costs and $3.9 million of operating and maintenance costs have been incurred for pipeline integrity testing. For the nine months ended September 30, 2011 and 2010, $9.7 million and $10.8 million, respectively, of capital costs and $9.8 million and $10.2 million, respectively, of operating and maintenance costs have been incurred for pipeline integrity testing. Integrity testing and assessment of all of these assets will continue, and the potential exists that results of such testing and assessment could cause ETP to incur even greater capital and operating expenditures for repairs or upgrades deemed necessary to ensure the continued safe and reliable operation of its pipelines; however, no estimate can be made at this time of the likely range of such expenditures.

- Definition

The entire disclosure for commitments and contingencies.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 14
-Paragraph 3
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 5
-Paragraph 9, 10, 11, 12
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.25)
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Reference 4: http://www.xbrl.org/2003/role/presentationRef
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-Topic 450
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Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6398077&loc=d3e12565-110249

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 440
-SubTopic 10
-Section 50
-Paragraph 2
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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-Topic 825
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6449706&loc=d3e16207-108621

+ Details

Price Risk Management Assets And Liabilities

9 Months Ended

Sep. 30, 2011

General Discussion of Derivative Instruments and Hedging Activities [Abstract]

Price Risk Management Assets And Liabilities

PRICE RISK MANAGEMENT ASSETS AND LIABILITIES:

Commodity Price Risk

We are exposed to market risks related to the volatility of natural gas, NGL and propane prices. To manage the impact of volatility from these prices, our subsidiaries utilize various exchange-traded and OTC commodity financial instrument contracts. These contracts consist primarily of futures, swaps and options and are recorded at fair value in our consolidated balance sheets. Following is a description of price risk management activities by segment as well as tables detailing the outstanding commodity-related derivatives as of September 30, 2011 and December 31, 2010 by segment.

Investment in ETP

ETP injects and holds natural gas in its Bammel storage facility to take advantage of contango markets (i.e., when the price of natural gas is higher in the future than the current spot price) and uses financial derivatives to hedge the natural gas held in connection with these arbitrage opportunities. At the inception of the hedge, ETP will lock in a margin by purchasing gas in the spot market or off peak season and entering into a financial contract to lock in the sale price. If ETP designates the related financial contract as a fair value hedge for accounting purposes, ETP will value the hedged natural gas inventory at current spot market prices along with the financial derivative it uses to hedge it. Changes in the spread between the forward natural gas prices designated as fair value hedges and the physical inventory spot price result in unrealized gains or losses until the underlying physical gas is withdrawn and the related designated derivatives are settled. Once the gas is withdrawn and the designated derivatives are settled, the previously unrealized gains or losses associated with these positions are realized. Unrealized margins represent the unrealized gains or losses from ETP’s derivative instruments using mark-to-market accounting, with changes in the fair value of its derivatives being recorded directly in earnings. These margins fluctuate based upon changes in the spreads between the physical spot price and forward natural gas prices. If the spread narrows between the physical and financial prices, ETP will record unrealized gains or lower unrealized losses. If the spread widens, ETP will record unrealized losses or lower unrealized gains. Typically, as ETP enters the winter months, the spread converges so that it recognizes in earnings the original locked-in spread through either mark-to-market adjustments or the physical withdrawal of natural gas.

ETP is also exposed to market risk on natural gas it retains for fees in its intrastate transportation and storage operations and operational gas sales in its interstate transportation operations. ETP uses financial derivatives to hedge the sales price of this gas, including futures, swaps and options. Certain contracts that qualify for hedge accounting are designated as cash flow hedges of the forecasted sale of natural gas. The change in value, to the extent the contracts are effective, remains in AOCI until the forecasted transaction occurs. When the forecasted transaction occurs, any gain or loss associated with the derivative is recorded in cost of products sold in the consolidated statements of operations.

Derivatives are utilized in ETP’s midstream operations in order to mitigate price volatility and manage fixed price exposure incurred from contractual obligations. ETP attempts to maintain balanced positions in its marketing activities to protect itself from the volatility in the energy commodities markets; however, net unbalanced positions can exist. Long-term physical contracts are tied to index prices. System gas, which is also tied to index prices, is expected to provide most of the gas required by its long-term physical contracts. When third-party gas is required to supply long-term contracts, a hedge is put in place to protect the margin on the contract. Financial contracts, which are not tied to physical delivery, are expected to be offset with financial contracts to balance ETP’s positions. To the extent open commodity positions exist, fluctuating commodity prices can impact its financial position and results of operations, either favorably or unfavorably.

ETP’s propane operations permit customers to guarantee the propane delivery price for the next heating season. As ETP executes fixed sales price contracts with its customers, it may enter into propane futures contracts to fix the purchase price related to these sales contracts, thereby locking in a gross profit margin. Additionally, ETP may use propane futures contracts to secure the purchase price of its propane inventory for a percentage of its anticipated propane sales.

The following table details ETP’s outstanding commodity-related derivatives:



	September 30, 2011			December 31, 2010
	Notional Volume		Maturity	Notional Volume		Maturity
Mark-to-Market Derivatives
Natural Gas:
Basis Swaps IFERC/NYMEX (MMBtu)	(39,952,500	)	2011-2013	(38,897,500	)	2011
Swing Swaps IFERC (MMBtu)	30,517,500		2011-2013	(19,720,000	)	2011
Fixed Swaps/Futures (MMBtu)	(15,517,500	)	2011-2012	(2,570,000	)	2011
Forward Physical Contracts (MMBtu)	12,324,054		2011-2012	—		—
Options — Calls (MMBtu)	—		—	(3,000,000	)	2011
Propane:
Forwards/Swaps (Gallons)	52,668,000		2011-2012	1,974,000		2011
Fair Value Hedging Derivatives
Natural Gas:
Basis Swaps IFERC/NYMEX (MMBtu)	(19,685,000	)	2011-2012	(28,050,000	)	2011
Fixed Swaps/Futures (MMBtu)	(29,837,500	)	2011-2012	(39,105,000	)	2011
Hedged Item — Inventory (MMBtu)	29,837,500		2011	39,105,000		2011
Cash Flow Hedging Derivatives
Natural Gas:
Fixed Swaps/Futures (MMBtu)	460,000		2011	(210,000	)	2011
Options — Puts (MMBtu)	9,390,000		2011-2012	26,760,000		2011-2012
Options — Calls (MMBtu)	(9,390,000	)	2011-2012	(26,760,000	)	2011-2012
Propane:
Forwards/Swaps (Gallons)	—		—	32,466,000		2011

We expect gains of $11.6 million related to ETP’s commodity derivatives to be reclassified into earnings over the next 12 months related to amounts currently reported in AOCI. The amount ultimately realized, however, will differ as commodity prices change and the underlying physical transaction occurs.

Investment in Regency

Regency 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 market forces. Regency’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. Regency 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, Regency 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 are prohibited under Regency’s policy.

Regency is exposed to market risks associated with commodity prices, counterparty credit, and interest rates. Regency’s management and the board of directors of Regency’s General Partner have established comprehensive risk management policies and procedures to monitor and manage these market risks. Regency’s General Partner is responsible for delegation of transaction authority levels, and the Risk Management Committee of Regency’s General Partner is responsible for the overall management of credit risk and commodity price risk, including monitoring exposure limits. Regency’s Risk Management Committee receives regular briefings on positions and exposures, credit exposures, and overall risk management in the context of market activities.

Regency’s Preferred Units (see Note 10) contain embedded derivatives which are required to be bifurcated and accounted for separately, such as the holders’ conversion option and Regency’s call option. These embedded derivatives are accounted for using mark-to-market accounting. Regency does not expect the embedded derivatives to affect its cash flows.

The following table details Regency’s outstanding commodity-related derivatives:



	September 30, 2011		December 31, 2010
	Notional Volume	Maturity	Notional Volume	Maturity
Cash Flow Hedging Derivatives
Natural Gas:
Fixed Swaps/Futures (MMBtu)	2,934,000	2012	3,830,000	2011
Propane:
Forwards/Swaps (Gallons)	15,204,000	2013	18,648,000	2011-2012
Natural Gas Liquids:
Forwards/Swaps (Barrels)	771,000	2013	1,212,110	2011-2012
WTI Crude Oil:
Forwards/Swaps (Barrels)	417,000	2014	373,655	2011-2012

We expect losses of $5.3 million related to Regency’s commodity derivatives to be reclassified into earnings over the next 12 months related to amounts currently reported in AOCI. The amount ultimately realized, however, will differ as commodity prices change and the underlying physical transaction occurs.

Interest Rate Risk

We are exposed to market risk for changes in interest rates. In order to maintain a cost effective capital structure, we borrow funds using a mix of fixed rate debt and variable rate debt. We manage our current interest rate exposure by utilizing interest rate swaps to achieve a desired mix of fixed and variable rate debt. We also utilize forward starting interest rate swaps to lock in the rate on a portion of anticipated debt issuances. The following is a summary of interest rate swaps outstanding as of September 30, 2011 and December 31, 2010, none of which were designated as hedges for accounting purposes:

Notional Amount

Outstanding

Entity

Term

Type⁽¹⁾

September 30, 2011

December 31, 2010

ETP

May 2012 ⁽²⁾

Forward starting to pay a fixed rate of 2.59% and receive a floating rate

350,000

—

ETP

August 2012⁽²⁾

Forward starting to pay a fixed rate of 3.51% and receive a floating rate

500,000

400,000

ETP

July 2013 ⁽²⁾

Forward starting to pay a fixed rate of 4.02% and receive a floating rate

300,000

—

ETP

July 2018

Pay a floating rate plus a spread of 4.01% and receive a fixed rate of 6.70%

500,000

Regency

April 2012

Pay a fixed rate of 1.325% and receive a floating rate

250,000

(1)As of September 30, 2011. Floating rates are based on 3-month LIBOR.


⁽²⁾	These forward starting swaps have a term of 10 years with a mandatory termination date the same as the effective date.

Credit Risk

We maintain credit policies with regard to our counterparties that we believe minimize our overall credit risk. These policies include an evaluation of potential counterparties’ financial condition (including credit ratings), collateral requirements under certain circumstances and the use of standardized agreements, which allow for netting of positive and negative exposures associated with a single counterparty.

Our counterparties consist primarily of petrochemical companies, other industrial, mid-size to major oil and gas companies and power companies. This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions. Currently, management does not anticipate a material adverse effect on our financial position or results of operations as a result of counterparty performance.

ETP utilizes master netting agreements and has maintenance margin deposits with certain counterparties in the OTC market and with clearing brokers. Payments on margin deposits are required when the value of a derivative exceeds its pre-established credit limit with the counterparty. Margin deposits are returned to ETP on the settlement date for non-exchange traded derivatives. ETP exchanges margin calls on a daily basis for exchange traded transactions. Since the margin calls are made daily with the exchange brokers, the fair value of the financial derivative instruments are deemed current and netted in deposits paid to vendors within other current assets in our consolidated balance sheets. ETP had net deposits with counterparties of $56.4 million and $52.2 million as of September 30, 2011 and December 31, 2010, respectively.

Regency is exposed to credit risk from its derivative counterparties. Although Regency does not require collateral from these counterparties, Regency 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.

For financial instruments, failure of a counterparty to perform on a contract could result in our inability to realize amounts that have been recorded on our consolidated balance sheets and recognized in net income or other comprehensive income.

Derivative Summary

The following table provides a balance sheet overview of consolidated derivative assets and liabilities as of September 30, 2011 and December 31, 2010:



	Fair Value of Derivative Instruments
	Asset Derivatives				Liability Derivatives
	September 30, 2011		December 31, 2010		September 30, 2011			December 31, 2010
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	43,337	$	35,031	$	(461	)	$	(6,631	)
Commodity derivatives	8,358		9,263		(11,876		)	(14,692		)
	51,695		44,294		(12,337		)	(21,323		)
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	$	146,589	$	64,940	$	(149,598	)	$	(72,729	)
Commodity derivatives	815		275		(2,568		)	—
Interest rate derivatives	30,564		20,790		(99,658		)	(20,922		)
Embedded derivatives in Regency Preferred Units	—		—		(36,268		)	(57,023		)
	177,968		86,005		(288,092		)	(150,674		)
Total derivatives	$	229,663	$	130,299	$	(300,429	)	$	(171,997	)

The commodity derivatives (margin deposits) are recorded in “Other current assets” on our consolidated balance sheets. The remainder of the derivatives are recorded in “Price risk management assets/liabilities.”

We disclose the non-exchange traded financial derivative instruments as price risk management assets and liabilities on our consolidated balance sheets at fair value with amounts classified as either current or long-term depending on the anticipated settlement date.

The following tables summarize the amounts recognized with respect to consolidated derivative financial instruments for the periods presented:



	Change in Value Recognized in OCI on Derivatives (Effective Portion)
	Three Months Ended September 30,					Nine Months Ended September 30,
	2011		2010			2011		2010
Derivatives in cash flow hedging relationships:
Commodity derivatives	$	16,414	$	36,035		$	9,291	$	60,992
Interest rate derivatives	—		(9,825		)	—		(29,980		)
Total	$	16,414	$	26,210		$	9,291	$	31,012



	Location of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	Amount of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)
		Three Months Ended September 30,						Nine Months Ended September 30,
		2011			2010			2011		2010
Derivatives in cash flow hedging relationships:
Commodity derivatives	Cost of products sold	$	(166	)	$	6,780		$	12,793	$	19,153
Interest rate derivatives	Interest expense, net	—			(70,812		)	—		(86,697		)
Total		$	(166	)	$	(64,032	)	$	12,793	$	(67,544	)



	Location of Gain/(Loss) Reclassified from AOCI into Income (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Ineffective Portion
		Three Months Ended September 30,					Nine Months Ended September 30,
		2011			2010		2011		2010
Derivatives in cash flow hedging relationships:
Commodity derivatives	Cost of products sold	$	(91	)	$	241	$	98	$	346
Total		$	(91	)	$	241	$	98	$	346



	Location of Gain/(Loss) Recognized in Income on Derivatives	Amount of Gain/ (Loss) Recognized in Income Representing Hedge Ineffectiveness and Amount Excluded from the Assessment of Effectiveness
		Three Months Ended September 30,					Nine Months Ended September 30,
		2011			2010		2011		2010
Derivatives in fair value hedging relationships (including hedged item):
Commodity derivatives	Cost of products sold	$	(3,559	)	$	9,968	$	18,732	$	9,001
Total		$	(3,559	)	$	9,968	$	18,732	$	9,001



	Location of Gain/(Loss) Recognized in Income on Derivatives	Amount of Gain/(Loss) Recognized in Income on Derivatives
		Three Months Ended September 30,						Nine Months Ended September 30,
		2011			2010			2011			2010
Derivatives not designated as hedging instruments:
Commodity derivatives	Cost of products sold	$	9,056		$	3,219		$	4,067		$	3,762
Interest rate derivatives	Losses on non-hedged interest rate derivatives	(68,496		)	(31,966		)	(65,093		)	(68,858		)
Embedded Derivatives	Other income (expenses)	15,230			7,321			20,755			3,715
Total		$	(44,210	)	$	(21,426	)	$	(40,271	)	$	(61,381	)

We recognized $0.7 million of unrealized gains and $0.8 million of unrealized losses on commodity derivatives not in fair value hedging relationships (including the ineffective portion of commodity derivatives in cash flow hedging relationships) for the three months ended September 30, 2011 and 2010, respectively. We recognized $2.8 million of unrealized gains and $49 million of unrealized losses on commodity derivatives not in fair value hedging relationships (including the ineffective portion of commodity derivatives in cash flow hedging relationships) for the nine months ended September 30, 2011 and 2010, respectively. In addition, for the three months ended September 30, 2011 and 2010, we recognized unrealized losses of $7.1 million and unrealized gains of $8.2 million, respectively, on commodity derivatives and related hedged inventory accounted for as fair value hedges. For the nine months ended September 30, 2011 and 2010, we recognized unrealized losses of $1.3 million and $35.3 million, respectively, on commodity derivatives and related hedged inventory accounted for as fair value hedges.

- Definition

The entire disclosure for the entity's entire derivative instruments and hedging activities. Describes an entity's risk management strategies, derivatives in hedging activities and non-hedging derivative instruments, the assets, obligations, liabilities, revenues and expenses arising therefrom, and the amounts of and methodologies and assumptions used in determining the amounts of such items.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 45
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

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-Publisher FASB
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+ Details

Related Party Transactions

9 Months Ended

Sep. 30, 2011

Related Party Transactions

RELATED PARTY TRANSACTIONS:

The Parent Company has agreements with subsidiaries to provide or receive various general and administrative services. For the three and nine months ended September 30, 2011, the Parent Company received $4.2 million and $12.4 million in management fees, respectively, from Regency related to these services, while for the three and nine months ended September 30, 2010, the Parent Company received $2.5 million and $3.3 million in management fees, respectively, from Regency related to these services. For the three and nine months ended September 30, 2011, the Parent Company paid $4.4 million and $12.7 million in management fees, respectively, to ETP related to these services, while for the three and nine months ended September 30, 2010, the Parent Company paid $2.6 million and $3.7 million in management fees, respectively, to ETP related to these services. The management fees received from Regency for the three and nine months ended September 30, 2011 reflect the reimbursement of various general and administrative services of $1.7 million and $4.9 million, respectively, for expenses incurred by ETP on behalf of Regency.

Enterprise and its subsidiaries currently hold a significant portion of our limited partner interest. As a result, Enterprise and its affiliates are considered related parties for financial reporting purposes.

ETP and Enterprise transport natural gas on each other’s pipelines, share operating expenses on jointly-owned pipelines and ETP sells natural gas to Enterprise. ETP’s propane operations purchase a portion of its propane requirements from Enterprise pursuant to an agreement that expires in 2015 and includes an option to extend the agreement for an additional year. Regency sells natural gas and NGLs to, and incurs NGL processing fees with Enterprise. The following table presents sales to and purchases from Enterprise:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2011		2010		2011		2010
ETP’s Natural Gas Operations:
Sales	$	164,339	$	126,992	$	462,359	$	402,238
Purchases	3,938		396		21,898		13,928
Regency’s Natural Gas Operations:
Sales	119,519		53,620		275,488		72,121
Purchases	2,094		1,890		5,092		2,312
ETP’s Propane Operations:
Sales	395		262		10,613		11,228
Purchases	86,673		58,642		328,830		276,821

As of September 30, 2011 and December 31, 2010, a subsidiary of ETP had forward mark-to-market derivatives for 52.7 million and 1.7 million gallons of propane at a fair value liability of $2.0 million and a fair value asset of $0.2 million, respectively, with Enterprise. In addition, as of December 31, 2010, a subsidiary of ETP had forward derivatives accounted for as cash flow hedges of 32.5 million gallons of propane at a fair value asset of $6.6 million with Enterprise. ETP's propane operations discontinued cash flow hedge accounting during the three months ended September 30, 2011; therefore, all of its forward derivatives are currently accounted for using mark-to-market accounting.

Under a master services agreement with RIGS Haynesville Partnership Co. (“HPC”), Regency operates and provides all employees and services for the operation and management of HPC. The related party general administrative expenses reimbursed to Regency were $4.2 million and $12.6 million for the three and nine months ended September 30, 2011. For the three months ended September 30, 2010 and the period from May 26, 2010 to September 30, 2010, the related party general administrative expenses reimbursed to Regency were $4.2 million and $5.6 million, respectively.

Regency’s contract compression operations provide contract compression services to HPC. HPC also provides transportation service to Regency. For the three and nine months ended September 30, 2011, Regency had revenue of $6.4 million and $19.4 million, respectively, and cost of sales of $2.9 million and $11 million, respectively, with HPC. For the three months ended September 30, 2010 and the period from May 26, 2010 to September 30, 2010, Regency had revenue of $5.6 million and $7.7 million, respectively, and cost of sales of $2.5 million and $4.3 million, respectively, with HPC.

The following table summarizes the related party balances on our consolidated balance sheets:



	September 30, 2011			December 31, 2010
Accounts receivable from related parties:
Enterprise:
ETP’s Natural Gas Operations	$	53,016		$	36,736
Regency’s Natural Gas Operations	31,285			25,539
ETP’s Propane Operations	222			2,327
Other	1,931			11,729
Total accounts receivable from related parties:	$	86,454		$	76,331
Accounts payable to related parties:
Enterprise:
ETP’s Natural Gas Operations	$	2,465		$	2,687
Regency’s Natural Gas Operations	1,199			1,323
ETP’s Propane Operations	19,632			22,985
Other	1,322			356
Total accounts payable to related parties:	$	24,618		$	27,351

ETP’s net imbalance (payable to) receivable from Enterprise	$	(89	)	$	1,360

Regency’s net imbalance receivable from Enterprise	$	1,464		$	753

- Definition

The entire disclosure for related party transactions, including the nature of the relationship(s), a description of the transactions, the amount of the transactions, the effects of any change in the method of establishing the terms of the transaction from the previous period, stated interest rate, expiration date, terms and manner of settlement per the agreement with the related party, and amounts due to or from related parties. If the entity and one or more other entities are under common ownership or management control and this control affects the operating results or financial position, disclosure includes the nature of the control relationship even if there are no transactions between the entities. Disclosure may also include the aggregate amount of current and deferred tax expense for each statement of earnings presented where the entity is a member of a group that files a consolidated tax return, the amount of any tax related balances due to or from affiliates as of the date of each statement of financial position presented, the principal provisions of the method by which the consolidated amount of current and deferred tax expense is allocated to the members of the group and the nature and effect of any changes in that method. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Article 4
-Section 08
-Paragraph k

Reference 2: http://www.xbrl.org/2003/role/presentationRef
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-Name Regulation S-X (SX)
-Number 210
-Article 3A
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Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 57
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+ Details

Other Information

9 Months Ended

Sep. 30, 2011

Other Information [Abstract]

Other Information

OTHER INFORMATION:

The tables below present additional detail for certain balance sheet captions.

Other Current Assets

Other current assets consisted of the following:



	September 30, 2011		December 31, 2010
Deposits paid to vendors	$	56,435	$	52,192
Prepaid expenses and other	87,143		57,167
Total other current assets	$	143,578	$	109,359

Other Non-Current Assets, net

Other non-current assets, net consisted of the following:



	September 30, 2011		December 31, 2010
Unamortized financing costs (3 to 30 years)	$	129,921	$	98,067
Regulatory assets	89,943		92,939
Other	27,839		34,575
Total non-current other assets, net	$	247,703	$	225,581

Accrued and Other Current Liabilities

Accrued and other current liabilities consisted of the following:



	September 30, 2011		December 31, 2010
Interest payable	$	247,600	$	191,466
Customer advances and deposits	126,066		111,448
Accrued capital expenditures	147,795		87,260
Accrued wages and benefits	72,117		76,592
Taxes payable other than income taxes	96,007		36,204
Income taxes payable	6,166		8,344
Other	98,909		56,374
Total accrued and other current liabilities	$	794,660	$	567,688

Reportable Segments

9 Months Ended

Sep. 30, 2011

Reportable Segments [Abstract]

Reportable Segments

REPORTABLE SEGMENTS:

Our reportable segments reflect two reportable segments, both of which conduct their business exclusively in the United States of America, as follows:

•Investment in ETP — Reflects the consolidated operations of ETP.

•Investment in Regency — Reflects the consolidated operations of Regency.

Each of the respective general partners of ETP and Regency has separate operating management and boards of directors. We control ETP and Regency through our ownership of their respective general partners. See further discussion of ETP and Regency’s operations in Note 1.

We evaluate the performance of our operating segments based on net income. The following tables present financial information by segment. The amounts reflected as “Corporate and Other” include the Parent Company activity and the goodwill and property, plant and equipment fair value adjustments recorded as a result of the 2004 reverse acquisition of Heritage Propane Partners, L.P.

Related party transactions between ETP and Regency are generally based on transactions made at market-related rates. Consolidated revenues and expenses reflect the elimination of all material intercompany transactions.

The following tables present the financial information by segment for the following periods:



	Investment in ETP		Investment in Regency			Corporate and Other			Adjustments and Eliminations			Total
Three months ended September 30, 2011:
Revenues from external customers	$	1,708,413	$	388,271		$	—		$	1,182		$	2,097,866
Intersegment revenues	6,903		1,996			—			(8,899		)	—
Income tax expense (benefit)	4,039		(89		)	(660		)	—			3,290
Net income (loss)	76,050		30,849			(36,915		)	(9,285		)	60,699
Three months ended September 30, 2010:
Revenues from external customers	$	1,290,644	$	295,094		$	—		$	2,069		$	1,587,807
Intersegment revenues	—		1,794			—			(1,794		)	—
Income tax expense (benefit)	1,993		450			(350		)	—			2,093
Net income (loss)	107,387		7,846			(120,059		)	—			(4,826		)
Nine months ended September 30, 2011:
Revenues from external customers	$	5,001,208	$	1,058,646		$	—		$	2,038		$	6,061,892
Intersegment revenues	29,780		5,371			—			(35,151		)	—
Income tax expense (benefit)	20,419		(19		)	(1,983		)	—			18,417
Net income (loss)	479,868		59,991			(155,743		)	(17,673		)	366,443
Nine months ended September 30, 2010:
Revenues from external customers	$	4,430,331	$	391,177		$	—		$	808		$	4,822,316
Intersegment revenues	—		2,691			—			(2,691		)	—
Income tax expense (benefit)	12,486		695			(1,824		)	—			11,357
Net income (loss)	390,341		2,951			(214,516		)	—			178,776



	September 30, 2011			December 31, 2010
Total assets:
Investment in ETP	$	15,078,048		$	12,149,992
Investment in Regency	5,525,739			4,770,204
Corporate and Other	480,342			469,221
Adjustments and Eliminations	(640,811		)	(10,687		)
Total	$	20,443,318		$	17,378,730

The following tables provide revenues, grouped by similar products and services, for both ETP and Regency. These amounts include transactions between ETP and Regency.

Investment in ETP



	Three Months Ended September 30,				Nine Months Ended September 30,
	2011		2010		2011		2010
Intrastate Transportation and Storage	$	617,244	$	529,507	$	1,849,575	$	1,662,037
Interstate Transportation	120,065		74,659		330,016		213,007
Midstream	565,246		458,381		1,492,025		1,484,211
NGL Transportation and Services	131,284		—		224,970		—
Retail Propane and Other Retail Propane Related	236,781		205,833		1,037,969		987,114
All Other	44,696		22,264		96,433		83,962
Total revenues	$	1,715,316	$	1,290,644	$	5,030,988	$	4,430,331

Investment in Regency



	Three Months Ended September 30,				Nine Months Ended September 30,
	2011		2010		2011		2010
Gathering and Processing	$	339,273	$	253,054	$	908,448	$	775,636
Joint Ventures	—		—		—		—
Contract Compression	36,024		36,172		112,532		107,197
Contract Treating	10,573		3,299		29,848		3,299
Corporate and Others	4,397		4,363		13,189		12,786
Total revenues	$	390,267	$	296,888	$	1,064,017	$	898,918

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 131
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9054-108599

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9031-108599

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8924-108599

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8538-108599

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8906-108599

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9038-108599

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 29
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8864-108599

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 33
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8971-108599

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
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-Paragraph 26
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8844-108599

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
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-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8380-108599

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8595-108599

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8933-108599

+ Details

Supplemental Financial Statement Information

9 Months Ended

Sep. 30, 2011

Supplemental Financial Statement Information

Supplemental Financial Statement Information

SUPPLEMENTAL FINANCIAL STATEMENT INFORMATION:

Following are the financial statements of the Parent Company, which are included to provide additional information with respect to the Parent Company’s financial position, results of operations and cash flows on a stand-alone basis:

BALANCE SHEETS

(unaudited)



	September 30, 2011		December 31, 2010
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	26,174	$	27,247
Accounts receivable from related companies	1,553		171
Other current assets	1,534		864
Total current assets	29,261		28,282
ADVANCES TO AND INVESTMENTS IN AFFILIATES	2,197,813		2,231,722
OTHER NON-CURRENT ASSETS, net	50,720		29,118
Total assets	$	2,277,794	$	2,289,122
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Accounts payable	$	502	$	—
Accounts payable to related companies	11,469		6,654
Accrued and other current liabilities	100,318		44,200
Total current liabilities	112,289		50,854
LONG-TERM DEBT, less current maturities	1,800,000		1,800,000
SERIES A CONVERTIBLE PREFERRED UNITS	314,980		317,600

COMMITMENTS AND CONTINGENCIES

EQUITY:
General Partner	306		520
Limited Partners	47,483		115,350
Accumulated other comprehensive income	2,736		4,798
Total partners’ capital	50,525		120,668
Total liabilities and equity	$	2,277,794	$	2,289,122

STATEMENTS OF OPERATIONS

(unaudited)



	Three Months Ended September 30,						Nine Months Ended September 30,
	2011			2010			2011			2010
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES	$	(11,667	)	$	(2,920	)	$	(25,546	)	$	(20,335	)
OTHER INCOME (EXPENSE):
Interest expense	(40,819		)	(89,484		)	(122,345		)	(126,400		)
Equity in earnings of affiliates	102,565			102,388			369,833			324,128
Losses on non-hedged interest rate derivatives	—			(18,211		)	—			(53,388		)
Other, net	19,068			(6,736		)	2,256			(6,949		)
INCOME (LOSS) BEFORE INCOME TAXES	69,147			(14,963		)	224,198			117,056
Income tax expense	64			374			190			349
NET INCOME (LOSS)	69,083			(15,337		)	224,008			116,707
GENERAL PARTNER’S INTEREST IN NET INCOME (LOSS)	214			(48		)	693			361
LIMITED PARTNERS’ INTEREST IN NET INCOME (LOSS)	$	68,869		$	(15,289	)	$	223,315		$	116,346

STATEMENTS OF CASH FLOWS

(unaudited)



	Nine Months Ended September 30,
	2011			2010
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	$	384,733		$	175,126
CASH FLOWS FROM INVESTING ACTIVITIES:
MEP Transaction	—			3,016
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings	20,000			1,850,245
Principal payments on debt	(20,000		)	(1,624,374		)
Distributions to partners	(385,806		)	(362,286		)
Debt issuance costs	—			(35,464		)
Net cash used in financing activities	(385,806		)	(171,879		)
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(1,073		)	6,263
CASH AND CASH EQUIVALENTS, beginning of period	27,247			62
CASH AND CASH EQUIVALENTS, end of period	$	26,174		$	6,325

- Definition

The entire disclosure for condensed financial information, including the financial position, cash flows, and the results of operations of the registrant (parent company) as of the same dates or for the same periods for which audited consolidated financial statements are being presented. Alternatively, the details of this disclosure can be reported by the specific parent company taxonomy elements, indicating the appropriate date and period contexts in an instance document.

+ References + Details

Estimates (Policy)	9 Months Ended
Estimates (Policy)	Sep. 30, 2011
Estimates Disclosure [Abstract]
Estimates	ESTIMATES: The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the accrual for and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The natural gas industry conducts its business by processing actual transactions at the end of the month following the month of delivery. Consequently, the most current month’s financial results for natural gas and NGL related operations are estimated using volume estimates and market prices. Any differences between estimated results and actual results are recognized in the following month’s financial statements. Management believes that the estimated operating results represent the actual results in all material respects. Some of the other significant estimates made by management include, but are not limited to, the timing of certain forecasted transactions that are hedged, the fair value of derivative instruments, useful lives for depreciation and amortization, purchase accounting allocations and subsequent realizability of intangible assets, fair value measurements used in the goodwill impairment test, market value of inventory, assets and liabilities resulting from the regulated ratemaking process, contingency reserves and environmental reserves. Actual results could differ from those estimates.

Operations And Organization (Tables)

9 Months Ended

Sep. 30, 2011

Operations And Organization [Abstract]

Schedule Of Equity Interests

At September 30, 2011, our equity interests consisted of:



	General Partner Interest (as a % of total partnership interest)		Incentive Distribution Rights (“IDRs”)		Common Units
ETP	1.6	%	100	%	50,226,967
Regency	1.9	%	100	%	26,266,791

Acquisitions and Divestitures (Tables)

9 Months Ended

Sep. 30, 2011

Acquisitions and Dispositions [Abstract]

Schedule Of Assets Acquired And Liabilities Assumed In LDH Acquisition

The following table summarizes the assets acquired and liabilities assumed recognized as of the acquisition date:



Total current assets	$	118,177
Property, plant and equipment⁽¹⁾	1,419,591
Goodwill	432,026
Intangible assets	81,000
Other assets	157
	2,050,951

Total current liabilities	74,964
Other long-term liabilities	438
	75,402
Total consideration	1,975,549
Cash received	31,231
Total consideration, net of cash received	$	1,944,318

(1)Property, plant and equipment (and estimated useful lives) consists of the following:



Land and improvements	$	30,759
Buildings and improvements (10 to 40 years)	3,123
Pipelines and equipment (20 to 65 years)	662,881
Natural gas liquids storage (40 years)	682,419
Linepack	704
Vehicles (3 to 20 years)	242
Furniture and fixtures (3 to 10 years)	49
Other (5 to 10 years)	8,526
Construction work-in-process	30,888
Property, plant and equipment	$	1,419,591

Schedule Of Components Of Property, Plant And Equipment Acquired

Property, plant and equipment (and estimated useful lives) consists of the following:



Land and improvements	$	30,759
Buildings and improvements (10 to 40 years)	3,123
Pipelines and equipment (20 to 65 years)	662,881
Natural gas liquids storage (40 years)	682,419
Linepack	704
Vehicles (3 to 20 years)	242
Furniture and fixtures (3 to 10 years)	49
Other (5 to 10 years)	8,526
Construction work-in-process	30,888
Property, plant and equipment	$	1,419,591

Pro Forma Results Of Operations



	Three Months Ended September 30,					Nine Months Ended September 30,
	2011		2010			2011		2010
Revenues	$	2,097,866	$	1,656,950		$	6,170,481	$	5,558,813
Net income (loss)	60,669		(10,114		)	358,230		203,747
Net income attributable to partners	69,083		(16,777		)	221,972		162,889
Basic net income (loss) per Limited Partner unit	$	0.31	$	(0.08	)	$	1.00	$	0.73
Diluted net income (loss) per Limited Partner unit	$	0.31	$	(0.08	)	$	1.00	$	0.73

- Definition

Tabular disclosure of pro forma results of operations for a material business acquisition or series of individually immaterial business acquisitions that are material in the aggregate.

+ References + Details

- Definition

Tabular disclosure of a material business combination completed during the period, including background, timing, and recognized assets and liabilities. This table does not include leveraged buyouts.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141
-Paragraph 51
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141
-Paragraph 52
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Paragraph 68
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 141R
-Appendix F
-Paragraph F4
-Subparagraph e

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6972119&loc=d3e1392-128463

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 805
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6972119&loc=d3e1486-128463

+ Details

Cash And Cash Equivalents (Tables)

9 Months Ended

Sep. 30, 2011

Supplemental Cash Flow Information [Abstract]

Schedule Of Net Changes In Operating Assets And Liabilities Included Cash Flows From Operating Activities

The net change in operating assets and liabilities (net of effects of acquisitions) included in cash flows from operating activities is comprised as follows:



	Nine Months Ended September 30,
	2011			2010
Accounts receivable	$	15,492		$	200,962
Accounts receivable from related companies	(8,401		)	(10,637		)
Inventories	50,096			113,790
Exchanges receivable	4,251			4,757
Other current assets	(15,992		)	21,250
Other non-current assets, net	7,406			8,538
Accounts payable	(26,696		)	(107,895		)
Accounts payable to related companies	(2,733		)	(5,741		)
Exchanges payable	(244		)	(8,340		)
Accrued and other current liabilities	165,277			52,127
Other non-current liabilities	1,244			(741		)
Price risk management assets and liabilities, net	44,476			162,734
Net change in operating assets and liabilities, net of effects of acquisitions	$	234,176		$	430,804

Schedule Of Non-Cash Investing Activities

Non-cash investing and financing activities are as follows:



	Nine Months Ended September 30,
	2011		2010
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures	$	154,378	$	83,834
Gain from subsidiary common unit transactions	$	93,941	$	343,714
NON-CASH FINANCING ACTIVITIES:
Subsidiary issuance of common units in connection with acquisition	$	3,000	$	—
Long-term debt assumed and non-compete agreement notes payable issued in acquisitions	$	4,166	$	1,240,481

Inventories (Tables)

9 Months Ended

Sep. 30, 2011

Inventory, Net [Abstract]

Schedule Of Inventory

Inventories consisted of the following:



	September 30, 2011		December 31, 2010
Natural gas and NGLs, excluding propane	$	120,798	$	170,179
Propane	75,085		76,341
Appliances, parts and fittings and other	132,958		119,864
Total inventories	$	328,841	$	366,384

Goodwill And Intangible Assets (Tables)

9 Months Ended

Sep. 30, 2011

Goodwill and Intangible Assets Disclosure [Abstract]

Components And Useful Lives Of Intangibles And Other Assets

Components and useful lives of intangible assets were as follows:



	September 30, 2011					December 31, 2010
	Gross Carrying Amount		Accumulated Amortization			Gross Carrying Amount		Accumulated Amortization
Amortizable intangible assets:
Customer relationships, contracts and agreements (3 to 46 years)	$	1,056,948	$	(122,257	)	$	971,657	$	(88,583	)
Trade names (20 years)	65,500		(4,367		)	65,500		(1,910		)
Noncompete agreements (3 to 15 years)	15,893		(7,900		)	21,165		(11,888		)
Patents (9 years)	750		(181		)	750		(118		)
Other (10 to 15 years)	1,320		(566		)	1,320		(492		)
Total amortizable intangible assets	1,140,411		(135,271		)	1,060,392		(102,991		)
Non-amortizable intangible assets:
Trademarks	78,828		—			77,445		—
Total intangible assets	$	1,219,239	$	(135,271	)	$	1,137,837	$	(102,991	)

Aggregate Amortization Expense Of Intangibles And Other Assets

Aggregate amortization expense of intangible assets was as follows:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2011		2010		2011		2010
Reported in depreciation and amortization	$	13,168	$	7,887	$	40,541	$	23,215

Estimated Aggregate Amortization Expense

Estimated aggregate amortization expense related to intangible assets for the next five years is as follows:



Years Ending December 31:
2012	$	53,989
2013	49,652
2014	48,531
2015	47,644
2016	46,864

Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2011

Fair Value Measurements [Abstract]

Fair Value Of Financial Assets And Liabilities Measured On Recurring Basis



	Fair Value Measurements at September 30, 2011 Using
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Marketable securities	$	3,151		$	3,151		$	—		$	—
Interest rate derivatives	30,564			—			30,564			—
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	74,892			74,892			—			—
Swing Swaps IFERC	21,818			1,074			20,744			—
Fixed Swaps/Futures	73,076			70,112			2,964			—
Options — Puts	13,348			—			13,348			—
Forward Physical Swaps	738			—			738			—
NGLs — Forward Swaps	577			—			577			—
Propane — Forward Swaps	77			—			77			—
WTI Crude Oil	4,817			—			4,817			—
Total commodity derivatives	189,343			146,078			43,265			—
Total Assets	$	223,058		$	149,229		$	73,829		$	—
Liabilities:
Interest rate derivatives	$	(99,658	)	$	—		$	(99,658	)	$	—
Series A Convertible Preferred Units	(314,980		)	—			—			(314,980		)
Embedded derivatives in the Regency Preferred Units	(36,268		)	—			—			(36,268		)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(68,918		)	(68,918		)	—			—
Swing Swaps IFERC	(22,707		)	(1,988		)	(20,719		)	—
Fixed Swaps/Futures	(48,287		)	(48,133		)	(154		)	—
Options — Puts	(423		)	—			(423		)	—
Options — Calls	(122		)	—			(122		)	—
Forward Physical Swaps	(482		)	—			(482		)	—
NGLs — Forward Swaps	(11,722		)	—			(11,722		)	—
Propane — Forward Swaps	(2,086		)	—			(2,086		)	—
Total commodity derivatives	(154,747		)	(119,039		)	(35,708		)	—
Total Liabilities	$	(605,653	)	$	(119,039	)	$	(135,366	)	$	(351,248	)



	Fair Value Measurements at December 31, 2010 Using
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Marketable securities	$	2,032		$	2,032		$	—		$	—
Interest rate derivatives	20,790			—			20,790			—
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	15,756			15,756			—			—
Swing Swaps IFERC	1,682			1,562			120			—
Fixed Swaps/Futures	44,955			42,474			2,481			—
Options — Calls	75			—			75			—
Options — Puts	26,241			—			26,241			—
NGLs — Forward Swaps	192			—			192			—
Propane — Forward Swaps	6,864			—			6,864			—
Total commodity derivatives	95,765			59,792			35,973			—
Total Assets	$	118,587		$	61,824		$	56,763		$	—
Liabilities:
Interest rate derivatives	$	(20,922	)	$	—		$	(20,922	)	$	—
Series A Convertible Preferred Units	(317,600		)	—			—			(317,600		)
Embedded derivatives in the Regency Preferred Units	(57,023		)	—			—			(57,023		)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(17,372		)	(17,372		)	—			—
Swing Swaps IFERC	(3,768		)	(3,520		)	(248		)	—
Fixed Swaps/Futures	(42,252		)	(41,825		)	(427		)	—
Options — Calls	(2,643		)	—			(2,643		)	—
Options — Puts	(7		)	—			(7		)	—
NGLs — Forward Swaps	(10,684		)	—			(10,684		)	—
WTI Crude Oil	(3,581		)	—			(3,581		)	—
Total commodity derivatives	(80,307		)	(62,717		)	(17,590		)	—
Total Liabilities	$	(475,852	)	$	(62,717	)	$	(38,512	)	$	(374,623	)

Reconciliation For Liabilities Measured At Fair Value On A Recurring Basis



Balance, December 31, 2010	$	(374,623	)
Net unrealized gains included in other income (expense)	23,375
Balance, September 30, 2011	$	(351,248	)

- Definition

Tabular disclosure of the fair value measurement of liabilities using significant unobservable inputs (Level 3), a reconciliation of the beginning and ending balances, separately presenting changes during the period attributable to the following: (1) total gains or losses for the period (realized and unrealized), segregating those gains or losses included in earnings (or changes in net assets), and gains or losses recognized in other comprehensive income and a description of where those gains or losses included in earnings (or changes in net assets) are reported in the statement of income (or activities); (2) purchases, sales, issuances, and settlements (each type disclosed separately); and (3) transfers in and transfers out of Level 3 (for example, transfers due to changes in the observability of significant inputs) by class of liability.

+ References + Details

- Definition

Tabular disclosure of the fair value measurement of assets and liabilities which includes [financial] instruments measured at fair value that are classified in stockholders' equity. Such assets and liabilities may be measured on a recurring or nonrecurring basis. The disclosures which may be required or desired include: (1) for assets and liabilities measured on a recurring basis, disclosure may include: (a) the fair value measurements at the reporting date; (b) the level within the fair value hierarchy in which the fair value measurements in their entirety fall, segregating fair value measurements using quoted prices in active markets for identical assets or liabilities (Level 1), significant other observable inputs (Level 2), and significant unobservable inputs (Level 3); (c) for fair value measurements using significant unobservable inputs (Level 3), a reconciliation of the beginning and ending balances, separately presenting changes during the period attributable to the following: (i) total gains or losses for the period (realized and unrealized), segregating those gains or losses included in earnings (or changes in net assets), and a description of where those gains or losses included in earnings (or changes in net assets) are reported in the statement of income (or activities); (ii) purchases, sales, issuances, and settlements (net); (iii) transfers in and transfers out of Level 3 (for example, transfers due to changes in the observability of significant inputs); (d) the amount of the total gains or losses for the period in subparagraph (c) (i) above included in earnings (or changes in net assets) that are attributable to the change in unrealized gains or losses relating to those assets and liabilities still held at the reporting date and a description of where those unrealized gains or losses are reported in the statement of income (or activities); (e) the valuation technique(s) used to measure fair value and a discussion of changes in valuation techniques, if any, during the period and (2) for assets and liabilities that are measured at fair value on a nonrecurring basis (for example, impaired assets) disclosure may include, in addition to (a) above: (a) the reasons for the fair value measurements recorded; (b) the same as (b) above; (c) for fair value measurements using significant unobservable inputs (Level 3), a description of the inputs and the information used to develop the inputs; and (d) the valuation technique(s) used to measure fair value and a discussion of changes, if any, in the valuation technique(s) used to measure similar assets and/or liabilities in prior periods. Where the quoted price in an active market for the identical liability is not available, the Level 1 input is the quoted price of an identical liability when traded as an asset.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 107
-Paragraph 10
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 157
-Paragraph 32
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 157
-Paragraph 33
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 157
-Paragraph 6
-Footnote 4
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19207-110258

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19190-110258

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-Publisher FASB
-Name Accounting Standards Codification
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-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19279-110258

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19296-110258

+ Details

Net Income (Loss) Per Limited Partner Unit (Tables)

9 Months Ended

Sep. 30, 2011

Earnings Per Share [Abstract]

Reconciliation Of Net Income (Loss) And Weighted Average Units

A reconciliation of net income (loss) and weighted average units used in computing basic and diluted net income (loss) per unit is as follows:



	Three Months Ended September 30,					Nine Months Ended September 30,
	2011		2010			2011		2010
Basic Net Income (Loss) per Limited Partner Unit:
Limited Partners’ interest in net income (loss)	$	68,869	$	(15,289	)	$	223,315	$	116,346
Weighted average Limited Partner units	222,972,708		222,941,172			222,966,763		222,941,151
Basic net income (loss) per Limited Partner unit	$	0.31	$	(0.07	)	$	1.00	$	0.52
Diluted Net Income (Loss) per Limited Partner Unit:
Limited Partners’ interest in net income (loss)	$	68,869	$	(15,289	)	$	223,315	$	116,346
Dilutive effect of equity-based compensation of subsidiaries	167		—			525		158
Diluted net income (loss) available to Limited Partners	$	68,702	$	(15,289	)	$	222,790	$	116,188
Weighted average Limited Partner units	222,972,708		222,941,172			222,966,763		222,941,151
Diluted net income (loss) per Limited Partner unit	$	0.31	$	(0.07	)	$	1.00	$	0.52

Equity (Tables)

9 Months Ended

Sep. 30, 2011

Change In ETE Common Units

The change in ETE Common Units during the nine months ended September 30, 2011 was as follows:



	Number of Units
Outstanding at December 31, 2010	222,941,172
Issuance of restricted common units under equity incentive plan	31,536
Outstanding at September 30, 2011	222,972,708

Accumulated Other Comprehensive Income (Loss)

The following table presents the components of accumulated other comprehensive income (“AOCI”), net of tax:



	September 30, 2011			December 31, 2010
Net gains on commodity related hedges	$	10,420		$	14,146
Unrealized gains (losses) on available-for-sale securities	(17		)	918
Subtotal	10,403			15,064
Amounts attributable to noncontrolling interest	(7,667		)	(10,266		)
Total AOCI included in partners’ capital, net of tax	$	2,736		$	4,798

Parent Company [Member]

Quarterly Distributions Of Available Cash

Following are distributions declared and/or paid by us subsequent to December 31, 2010:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2010	February 7, 2011	February 18, 2011	$	0.540
March 31, 2011	May 6, 2011	May 19, 2011	0.560
June 30, 2011	August 5, 2011	August 19, 2011	0.625
September 30, 2011	November 4, 2011	November 18, 2011	0.625

ETP [Member]

Quarterly Distributions Of Available Cash

Following are distributions declared and/or paid by ETP subsequent to December 31, 2010:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2010	February 7, 2011	February 14, 2011	$	0.89375
March 31, 2011	May 6, 2011	May 16, 2011	0.89375
June 30, 2011	August 5, 2011	August 15, 2011	0.89375
September 30, 2011	November 4, 2011	November 14, 2011	0.89375

Regency [Member]

Quarterly Distributions Of Available Cash

Following are distributions declared and/or paid by Regency subsequent to December 31, 2010:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2010	February 7, 2011	February 14, 2011	$	0.445
March 31, 2011	May 6, 2011	May 13, 2011	0.445
June 30, 2011	August 5, 2011	August 12, 2011	0.450
September 30, 2011	November 7, 2011	November 14, 2011	0.455

- Definition

The entire disclosure for comprehensive income. Includes, but is not limited to, the following: 1) the amount of income tax expense or benefit allocated to each component of other comprehensive income, including reclassification adjustments, 2) the reclassification adjustments for each classification of other comprehensive income and 3) the ending accumulated balances for each component of comprehensive income. Components of comprehensive income include: (1) foreign currency translation adjustments; (2) gains (losses) on foreign currency transactions that are designated as, and are effective as, economic hedges of a net investment in a foreign entity; (3) gains (losses) on intercompany foreign currency transactions that are of a long-term-investment nature, when the entities to the transaction are consolidated, combined, or accounted for by the equity method in the reporting enterprise's financial statements; (4) change in the market value of a futures contract that qualifies as a hedge of an asset reported at fair value; (5) unrealized holding gains (losses) on available-for-sale securities and that resulting from transfers of debt securities from the held-to-maturity category to the available-for-sale category; (6) a net loss recognized as an additional pension liability not yet recognized as net periodic pension cost; and (7) the net gain (loss) and net prior service cost or credit for pension plans and other postretirement benefit plans.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 130
-Paragraph 14-26
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e637-108580

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 14
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e681-108580

Reference 4: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
-URI http://asc.fasb.org/extlink&oid=6959260&loc=d3e187085-122770

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
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-URI http://asc.fasb.org/extlink&oid=6920433&loc=d3e998-108581

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Reclassification Adjustments
-URI http://asc.fasb.org/extlink&oid=6522872

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
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-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e716-108580

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e689-108580

+ Details

Income Taxes (Tables)

9 Months Ended

Sep. 30, 2011

Income Taxes [Abstract]

Components Of Federal And State Income Tax

The components of the federal and state income tax expense of our taxable subsidiaries are summarized as follows:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2011			2010			2011			2010
Current expense (benefit):
Federal	$	1,124		$	(3,182	)	$	6,787		$	(124	)
State	2,675			1,363			12,109			8,864
Total	3,799			(1,819		)	18,896			8,740
Deferred expense (benefit):
Federal	(41		)	3,286			(599		)	2,257
State	(468		)	626			120			360
Total	(509		)	3,912			(479		)	2,617
Total income tax expense	$	3,290		$	2,093		$	18,417		$	11,357

Price Risk Management Assets And Liabilities (Tables)

9 Months Ended

Sep. 30, 2011

Interest Rate Swaps Outstanding

The following is a summary of interest rate swaps outstanding as of September 30, 2011 and December 31, 2010, none of which were designated as hedges for accounting purposes:

Notional Amount

Outstanding

Entity

Term

Type⁽¹⁾

September 30, 2011

December 31, 2010

ETP

May 2012 ⁽²⁾

Forward starting to pay a fixed rate of 2.59% and receive a floating rate

350,000

—

ETP

August 2012⁽²⁾

Forward starting to pay a fixed rate of 3.51% and receive a floating rate

500,000

400,000

ETP

July 2013 ⁽²⁾

Forward starting to pay a fixed rate of 4.02% and receive a floating rate

300,000

—

ETP

July 2018

Pay a floating rate plus a spread of 4.01% and receive a fixed rate of 6.70%

500,000

Regency

April 2012

Pay a fixed rate of 1.325% and receive a floating rate

250,000

(1)As of September 30, 2011. Floating rates are based on 3-month LIBOR.


⁽²⁾	These forward starting swaps have a term of 10 years with a mandatory termination date the same as the effective date.

Fair Value Of Derivative Instruments

The following table provides a balance sheet overview of consolidated derivative assets and liabilities as of September 30, 2011 and December 31, 2010:



	Fair Value of Derivative Instruments
	Asset Derivatives				Liability Derivatives
	September 30, 2011		December 31, 2010		September 30, 2011			December 31, 2010
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	43,337	$	35,031	$	(461	)	$	(6,631	)
Commodity derivatives	8,358		9,263		(11,876		)	(14,692		)
	51,695		44,294		(12,337		)	(21,323		)
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	$	146,589	$	64,940	$	(149,598	)	$	(72,729	)
Commodity derivatives	815		275		(2,568		)	—
Interest rate derivatives	30,564		20,790		(99,658		)	(20,922		)
Embedded derivatives in Regency Preferred Units	—		—		(36,268		)	(57,023		)
	177,968		86,005		(288,092		)	(150,674		)
Total derivatives	$	229,663	$	130,299	$	(300,429	)	$	(171,997	)

Partnership's Derivative Assets And Liabilities Recognized OCI On Derivatives

The following tables summarize the amounts recognized with respect to consolidated derivative financial instruments for the periods presented:



	Change in Value Recognized in OCI on Derivatives (Effective Portion)
	Three Months Ended September 30,					Nine Months Ended September 30,
	2011		2010			2011		2010
Derivatives in cash flow hedging relationships:
Commodity derivatives	$	16,414	$	36,035		$	9,291	$	60,992
Interest rate derivatives	—		(9,825		)	—		(29,980		)
Total	$	16,414	$	26,210		$	9,291	$	31,012

Partnership's Derivative Assets And Liabilities Amount Of Gain (Loss) Recognized



	Location of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	Amount of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)
		Three Months Ended September 30,						Nine Months Ended September 30,
		2011			2010			2011		2010
Derivatives in cash flow hedging relationships:
Commodity derivatives	Cost of products sold	$	(166	)	$	6,780		$	12,793	$	19,153
Interest rate derivatives	Interest expense, net	—			(70,812		)	—		(86,697		)
Total		$	(166	)	$	(64,032	)	$	12,793	$	(67,544	)



	Location of Gain/(Loss) Reclassified from AOCI into Income (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Ineffective Portion
		Three Months Ended September 30,					Nine Months Ended September 30,
		2011			2010		2011		2010
Derivatives in cash flow hedging relationships:
Commodity derivatives	Cost of products sold	$	(91	)	$	241	$	98	$	346
Total		$	(91	)	$	241	$	98	$	346



	Location of Gain/(Loss) Recognized in Income on Derivatives	Amount of Gain/ (Loss) Recognized in Income Representing Hedge Ineffectiveness and Amount Excluded from the Assessment of Effectiveness
		Three Months Ended September 30,					Nine Months Ended September 30,
		2011			2010		2011		2010
Derivatives in fair value hedging relationships (including hedged item):
Commodity derivatives	Cost of products sold	$	(3,559	)	$	9,968	$	18,732	$	9,001
Total		$	(3,559	)	$	9,968	$	18,732	$	9,001



	Location of Gain/(Loss) Recognized in Income on Derivatives	Amount of Gain/(Loss) Recognized in Income on Derivatives
		Three Months Ended September 30,						Nine Months Ended September 30,
		2011			2010			2011			2010
Derivatives not designated as hedging instruments:
Commodity derivatives	Cost of products sold	$	9,056		$	3,219		$	4,067		$	3,762
Interest rate derivatives	Losses on non-hedged interest rate derivatives	(68,496		)	(31,966		)	(65,093		)	(68,858		)
Embedded Derivatives	Other income (expenses)	15,230			7,321			20,755			3,715
Total		$	(44,210	)	$	(21,426	)	$	(40,271	)	$	(61,381	)

ETP [Member]

Outstanding Commodity-Related Derivatives

The following table details ETP’s outstanding commodity-related derivatives:



	September 30, 2011			December 31, 2010
	Notional Volume		Maturity	Notional Volume		Maturity
Mark-to-Market Derivatives
Natural Gas:
Basis Swaps IFERC/NYMEX (MMBtu)	(39,952,500	)	2011-2013	(38,897,500	)	2011
Swing Swaps IFERC (MMBtu)	30,517,500		2011-2013	(19,720,000	)	2011
Fixed Swaps/Futures (MMBtu)	(15,517,500	)	2011-2012	(2,570,000	)	2011
Forward Physical Contracts (MMBtu)	12,324,054		2011-2012	—		—
Options — Calls (MMBtu)	—		—	(3,000,000	)	2011
Propane:
Forwards/Swaps (Gallons)	52,668,000		2011-2012	1,974,000		2011
Fair Value Hedging Derivatives
Natural Gas:
Basis Swaps IFERC/NYMEX (MMBtu)	(19,685,000	)	2011-2012	(28,050,000	)	2011
Fixed Swaps/Futures (MMBtu)	(29,837,500	)	2011-2012	(39,105,000	)	2011
Hedged Item — Inventory (MMBtu)	29,837,500		2011	39,105,000		2011
Cash Flow Hedging Derivatives
Natural Gas:
Fixed Swaps/Futures (MMBtu)	460,000		2011	(210,000	)	2011
Options — Puts (MMBtu)	9,390,000		2011-2012	26,760,000		2011-2012
Options — Calls (MMBtu)	(9,390,000	)	2011-2012	(26,760,000	)	2011-2012
Propane:
Forwards/Swaps (Gallons)	—		—	32,466,000		2011

Regency [Member]

Outstanding Commodity-Related Derivatives

The following table details Regency’s outstanding commodity-related derivatives:



	September 30, 2011		December 31, 2010
	Notional Volume	Maturity	Notional Volume	Maturity
Cash Flow Hedging Derivatives
Natural Gas:
Fixed Swaps/Futures (MMBtu)	2,934,000	2012	3,830,000	2011
Propane:
Forwards/Swaps (Gallons)	15,204,000	2013	18,648,000	2011-2012
Natural Gas Liquids:
Forwards/Swaps (Barrels)	771,000	2013	1,212,110	2011-2012
WTI Crude Oil:
Forwards/Swaps (Barrels)	417,000	2014	373,655	2011-2012

- Definition

Tabular disclosure of the location and amount of gains and losses reported in the statement of financial performance, or when applicable, the statement of financial position. For example, (a) gains and losses recognized in the income statement on derivative instruments designated and qualifying as hedging instruments in fair value hedges and related hedged items designated and qualifying in fair value hedges and (b) gains and losses initially recognized in other comprehensive income on derivative instruments designated and qualifying as cash flow hedges.

+ References + Details

- Definition

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5579245-113959

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5624163-113959

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
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-Paragraph 4C
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5624171-113959

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
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-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6935481&loc=d3e41678-113959

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
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-Paragraph 1
-Subparagraph (SX 210.4-08.(n)(2))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

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-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5580258-113959

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-Publisher FASB
-Name Accounting Standards Codification
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-Name Accounting Standards Codification
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-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=6935481&loc=d3e41620-113959

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6886632&loc=d3e76258-113986

+ Details

Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 2011

The following table presents sales to and purchases from Enterprise:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2011		2010		2011		2010
ETP’s Natural Gas Operations:
Sales	$	164,339	$	126,992	$	462,359	$	402,238
Purchases	3,938		396		21,898		13,928
Regency’s Natural Gas Operations:
Sales	119,519		53,620		275,488		72,121
Purchases	2,094		1,890		5,092		2,312
ETP’s Propane Operations:
Sales	395		262		10,613		11,228
Purchases	86,673		58,642		328,830		276,821

Related Party Receivables And Payables

The following table summarizes the related party balances on our consolidated balance sheets:



	September 30, 2011			December 31, 2010
Accounts receivable from related parties:
Enterprise:
ETP’s Natural Gas Operations	$	53,016		$	36,736
Regency’s Natural Gas Operations	31,285			25,539
ETP’s Propane Operations	222			2,327
Other	1,931			11,729
Total accounts receivable from related parties:	$	86,454		$	76,331
Accounts payable to related parties:
Enterprise:
ETP’s Natural Gas Operations	$	2,465		$	2,687
Regency’s Natural Gas Operations	1,199			1,323
ETP’s Propane Operations	19,632			22,985
Other	1,322			356
Total accounts payable to related parties:	$	24,618		$	27,351

ETP’s net imbalance (payable to) receivable from Enterprise	$	(89	)	$	1,360

Regency’s net imbalance receivable from Enterprise	$	1,464		$	753

Other Information (Tables)

9 Months Ended

Sep. 30, 2011

Other Information [Abstract]

Other Current Assets

Other current assets consisted of the following:



	September 30, 2011		December 31, 2010
Deposits paid to vendors	$	56,435	$	52,192
Prepaid expenses and other	87,143		57,167
Total other current assets	$	143,578	$	109,359

Other Non-Current Assets, net

Other non-current assets, net consisted of the following:



	September 30, 2011		December 31, 2010
Unamortized financing costs (3 to 30 years)	$	129,921	$	98,067
Regulatory assets	89,943		92,939
Other	27,839		34,575
Total non-current other assets, net	$	247,703	$	225,581

Accrued And Other Current Liabilities

Accrued and other current liabilities consisted of the following:



	September 30, 2011		December 31, 2010
Interest payable	$	247,600	$	191,466
Customer advances and deposits	126,066		111,448
Accrued capital expenditures	147,795		87,260
Accrued wages and benefits	72,117		76,592
Taxes payable other than income taxes	96,007		36,204
Income taxes payable	6,166		8,344
Other	98,909		56,374
Total accrued and other current liabilities	$	794,660	$	567,688

Reportable Segments (Tables)

9 Months Ended

Sep. 30, 2011

Operating Segments [Member]

Financial Information By Segment

The following tables present the financial information by segment for the following periods:



	Investment in ETP		Investment in Regency			Corporate and Other			Adjustments and Eliminations			Total
Three months ended September 30, 2011:
Revenues from external customers	$	1,708,413	$	388,271		$	—		$	1,182		$	2,097,866
Intersegment revenues	6,903		1,996			—			(8,899		)	—
Income tax expense (benefit)	4,039		(89		)	(660		)	—			3,290
Net income (loss)	76,050		30,849			(36,915		)	(9,285		)	60,699
Three months ended September 30, 2010:
Revenues from external customers	$	1,290,644	$	295,094		$	—		$	2,069		$	1,587,807
Intersegment revenues	—		1,794			—			(1,794		)	—
Income tax expense (benefit)	1,993		450			(350		)	—			2,093
Net income (loss)	107,387		7,846			(120,059		)	—			(4,826		)
Nine months ended September 30, 2011:
Revenues from external customers	$	5,001,208	$	1,058,646		$	—		$	2,038		$	6,061,892
Intersegment revenues	29,780		5,371			—			(35,151		)	—
Income tax expense (benefit)	20,419		(19		)	(1,983		)	—			18,417
Net income (loss)	479,868		59,991			(155,743		)	(17,673		)	366,443
Nine months ended September 30, 2010:
Revenues from external customers	$	4,430,331	$	391,177		$	—		$	808		$	4,822,316
Intersegment revenues	—		2,691			—			(2,691		)	—
Income tax expense (benefit)	12,486		695			(1,824		)	—			11,357
Net income (loss)	390,341		2,951			(214,516		)	—			178,776

Investment In ETP [Member]

Investment in ETP



	Three Months Ended September 30,				Nine Months Ended September 30,
	2011		2010		2011		2010
Intrastate Transportation and Storage	$	617,244	$	529,507	$	1,849,575	$	1,662,037
Interstate Transportation	120,065		74,659		330,016		213,007
Midstream	565,246		458,381		1,492,025		1,484,211
NGL Transportation and Services	131,284		—		224,970		—
Retail Propane and Other Retail Propane Related	236,781		205,833		1,037,969		987,114
All Other	44,696		22,264		96,433		83,962
Total revenues	$	1,715,316	$	1,290,644	$	5,030,988	$	4,430,331

Investment In Regency [Member]

Investment in Regency



	Three Months Ended September 30,				Nine Months Ended September 30,
	2011		2010		2011		2010
Gathering and Processing	$	339,273	$	253,054	$	908,448	$	775,636
Joint Ventures	—		—		—		—
Contract Compression	36,024		36,172		112,532		107,197
Contract Treating	10,573		3,299		29,848		3,299
Corporate and Others	4,397		4,363		13,189		12,786
Total revenues	$	390,267	$	296,888	$	1,064,017	$	898,918

Assets Segments [Member]

Financial Information By Segment



	September 30, 2011			December 31, 2010
Total assets:
Investment in ETP	$	15,078,048		$	12,149,992
Investment in Regency	5,525,739			4,770,204
Corporate and Other	480,342			469,221
Adjustments and Eliminations	(640,811		)	(10,687		)
Total	$	20,443,318		$	17,378,730

- Definition

Tabular disclosure of the profit or loss and total assets for each reportable segment. An entity discloses certain information on each reportable segment if the amounts (a) are included in the measure of segment profit or loss reviewed by the chief operating decision maker or (b) are otherwise regularly provided to the chief operating decision maker, even if not included in that measure of segment profit or loss.

+ References + Details

Supplemental Financial Statement Information (Tables)

9 Months Ended

Sep. 30, 2011

Schedule Of Balance Sheets

BALANCE SHEETS

(unaudited)



	September 30, 2011		December 31, 2010
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	26,174	$	27,247
Accounts receivable from related companies	1,553		171
Other current assets	1,534		864
Total current assets	29,261		28,282
ADVANCES TO AND INVESTMENTS IN AFFILIATES	2,197,813		2,231,722
OTHER NON-CURRENT ASSETS, net	50,720		29,118
Total assets	$	2,277,794	$	2,289,122
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Accounts payable	$	502	$	—
Accounts payable to related companies	11,469		6,654
Accrued and other current liabilities	100,318		44,200
Total current liabilities	112,289		50,854
LONG-TERM DEBT, less current maturities	1,800,000		1,800,000
SERIES A CONVERTIBLE PREFERRED UNITS	314,980		317,600

COMMITMENTS AND CONTINGENCIES

EQUITY:
General Partner	306		520
Limited Partners	47,483		115,350
Accumulated other comprehensive income	2,736		4,798
Total partners’ capital	50,525		120,668
Total liabilities and equity	$	2,277,794	$	2,289,122

Schedule Of Statements Of Operations

STATEMENTS OF OPERATIONS

(unaudited)



	Three Months Ended September 30,						Nine Months Ended September 30,
	2011			2010			2011			2010
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES	$	(11,667	)	$	(2,920	)	$	(25,546	)	$	(20,335	)
OTHER INCOME (EXPENSE):
Interest expense	(40,819		)	(89,484		)	(122,345		)	(126,400		)
Equity in earnings of affiliates	102,565			102,388			369,833			324,128
Losses on non-hedged interest rate derivatives	—			(18,211		)	—			(53,388		)
Other, net	19,068			(6,736		)	2,256			(6,949		)
INCOME (LOSS) BEFORE INCOME TAXES	69,147			(14,963		)	224,198			117,056
Income tax expense	64			374			190			349
NET INCOME (LOSS)	69,083			(15,337		)	224,008			116,707
GENERAL PARTNER’S INTEREST IN NET INCOME (LOSS)	214			(48		)	693			361
LIMITED PARTNERS’ INTEREST IN NET INCOME (LOSS)	$	68,869		$	(15,289	)	$	223,315		$	116,346

Schedule Of Statements Of Cash Flows

Non-cash investing and financing activities are as follows:



	Nine Months Ended September 30,
	2011		2010
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures	$	154,378	$	83,834
Gain from subsidiary common unit transactions	$	93,941	$	343,714
NON-CASH FINANCING ACTIVITIES:
Subsidiary issuance of common units in connection with acquisition	$	3,000	$	—
Long-term debt assumed and non-compete agreement notes payable issued in acquisitions	$	4,166	$	1,240,481

Parent Company [Member]

Schedule Of Statements Of Cash Flows

STATEMENTS OF CASH FLOWS

(unaudited)



	Nine Months Ended September 30,
	2011			2010
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	$	384,733		$	175,126
CASH FLOWS FROM INVESTING ACTIVITIES:
MEP Transaction	—			3,016
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings	20,000			1,850,245
Principal payments on debt	(20,000		)	(1,624,374		)
Distributions to partners	(385,806		)	(362,286		)
Debt issuance costs	—			(35,464		)
Net cash used in financing activities	(385,806		)	(171,879		)
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(1,073		)	6,263
CASH AND CASH EQUIVALENTS, beginning of period	27,247			62
CASH AND CASH EQUIVALENTS, end of period	$	26,174		$	6,325

Operations And Organization (Narrative) (Details) - Lone Star L.L.C. [Member]	Sep. 30, 2011
Regency [Member]
Equity method ownership, percentage	30.00%
ETP [Member]
Percentage interest in joint venture	70.00%

Operations And Organization (Schedule Of Equity Interests) (Details)	Sep. 30, 2011 shares
ETP [Member]
General Partner Interest	1.60%
Incentive Distribution Rights	100.00%
Common Units	50,226,967
Regency [Member]
General Partner Interest	1.90%
Incentive Distribution Rights	100.00%
Common Units	26,266,791

Acquisitions and Divestitures (Narrative) (Details) $ / shares in Units, $ in Thousands	1 Months Ended	3 Months Ended	9 Months Ended
	Sep. 30, 2011 USD ($)	Sep. 30, 2011 USD ($)	Sep. 30, 2011 USD ($) shares $ / shares	Oct. 17, 2011 USD ($)	Dec. 31, 2010
Cash paid in acquisition of LDH	$ 1,980,000	$ 1,980,000	$ 1,980,000
Acquisition of all outstanding shares of SUG, total transaction price	1,975,549	1,975,549	1,975,549
ETP [Member]
Incentive distributions to relinquish	$ 220,000	$ 220,000	$ 220,000
ETP's Propane Operations [Member] \| Sale [Member]
Cash paid in acquisition				$ 1,500,000
Acquisition of all outstanding shares of SUG, total transaction price				2,900,000
Business Acquisition, Equity Interest Issued or Issuable, Value Assigned				$ 1,320,000
Lone Star L.L.C. [Member] \| Regency [Member]
Interest ownership	30.00%	30.00%	30.00%
Cash paid in acquisition	$ 592,700	$ 592,700	$ 592,700
Lone Star L.L.C. [Member] \| ETP [Member]
Subsidiary Interest in Joint Venture	70.00%	70.00%	70.00%
Cash paid in acquisition	$ 1,380,000	$ 1,380,000	$ 1,380,000
SUG Merger [Member]
Acquisition of all outstanding shares of SUG, total transaction price	9,400,000	9,400,000	9,400,000
Proposed Business Combination, Cash Paid and Equity Issued	5,700,000	5,700,000	5,700,000
Amount of SUG debt assumed as part of acquisition price	$ 3,700,000	$ 3,700,000	$ 3,700,000
Cash paid in exchange of each share \| $ / shares			$ 44.25
Number of share received in exchange of each share \| shares			1.00
Percentage of maximum cash consideration in total consideration			60.00%
SUG Merger [Member] \| Minimum [Member]
Percentage of fluctuation in common unit			40.00%
SUG Merger [Member] \| Maximum [Member]
Percentage of fluctuation in common unit			50.00%
Citrus Corp [Member]
Equity method investment ownership percentage of pending acquisition	50.00%	50.00%	50.00%
Potential business acquisition cash payment	$ 1,900,000	$ 1,900,000	$ 1,900,000
Common units received due to business exchange	105,000	105,000	105,000
Purchase price	$ 2,000,000	2,000,000	$ 2,000,000
Florida Gas Transmission Pipeline System [Member]
Percentage ownership operating facility			100.00%
MEP [Member] \| Regency [Member]
Interest ownership					49.90%
Equity Method Investment, Additional Ownership Percentage Acquired	0.10%
Payments to Acquire Interest in Subsidiaries and Affiliates		$ 1,200

Acquisitions and Divestitures (Schedule Of Assets Acquired And Liabilities Assumed In LDH Acquisition) (Details)
$ in Thousands

Sep. 30, 2011

USD ($)

Acquisitions and Dispositions [Abstract]

Total current assets

$ 118,177

Property, plant, and equipment

1,419,591

^[1]

432,026

81,000

157

2,050,951

Total current liabilities

74,964

Other long-term liabilities

438

Total liabilities

75,402

Total consideration

1,975,549

Cash received

31,231

Total consideration, net of cash received

$ 1,944,318

[1]

Property, plant and equipment (and estimated useful lives) consists of the following:Land and improvements$30,759Buildings and improvements (10 to 40 years)3,123Pipelines and equipment (20 to 65 years)662,881Natural gas liquids storage (40 years)682,419Linepack704Vehicles (3 to 20 years)242Furniture and fixtures (3 to 10 years)49Other (5 to 10 years)8,526Construction work-in-process30,888Property, plant and equipment$1,419,591

Acquisitions and Divestitures (Schedule of Components Of Property, Plant And Equipment Acquired) (Details)
$ in Thousands

9 Months Ended

Sep. 30, 2011

USD ($)

years

Property, plant, and equipment | $

$ 1,419,591

^[1]

Land and improvements [Member]

Property, plant, and equipment | $

30,759

Buildings and improvements [Member]

Property, plant, and equipment | $

$ 3,123

Property, plant and equipment, useful life, maximum (years)

Property, plant and equipment, useful life, minimum (years)

Pipelines And Equipment [Member]

Property, plant, and equipment | $

$ 662,881

Property, plant and equipment, useful life, maximum (years)

Property, plant and equipment, useful life, minimum (years)

Natural Gas Liquid Storage [Member]

Property, plant, and equipment | $

$ 682,419

Property, plant and equipment, useful life, maximum (years)

Linepack [Member]

Property, plant, and equipment | $

$ 704

Vehicles [Member]

Property, plant, and equipment | $

$ 242

Property, plant and equipment, useful life, maximum (years)

Property, plant and equipment, useful life, minimum (years)

Furniture and Fixtures [Member]

Property, plant, and equipment | $

$ 49

Property, plant and equipment, useful life, maximum (years)

Property, plant and equipment, useful life, minimum (years)

Property, Plant and Equipment, Other Types [Member]

Property, plant, and equipment | $

$ 8,526

Property, plant and equipment, useful life, maximum (years)

Property, plant and equipment, useful life, minimum (years)

Construction Work-In-Process [Member]

Property, plant, and equipment | $

$ 30,888

[1]

Acquisitions and Divestitures (Pro Forma Results Of Operations) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Acquisitions and Dispositions [Abstract]
Revenues	$ 2,097,866	$ 1,656,950	$ 6,170,481	$ 5,558,813
Net income (loss)	60,669	(10,114)	358,230	203,747
Net income attributable to partners	$ 69,083	$ (16,777)	$ 221,972	$ 162,889
Basic net income (loss) per Limited Partner unit	$ 0.31	$ (0.08)	$ 1.00	$ 0.73
Diluted net income (loss) per Limited Partner unit	$ 0.31	$ (0.08)	$ 1.00	$ 0.73

- Definition

The pro forma basic net income per share for a period as if the business combination or combinations had been completed at the beginning of a period.

+ References + Details

- Definition

The pro forma diluted net income per share for a period as if the business combination or combinations had been completed at the beginning of a period.

+ References + Details

Cash And Cash Equivalents (Schedule Of Net Changes In Operating Assets And Liabilities Included Cash Flows From Operating Activities) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010
Supplemental Cash Flow Information [Abstract]
Accounts receivable	$ 15,492	$ 200,962
Accounts receivable from related companies	(8,401)	(10,637)
Inventories	50,096	113,790
Exchanges receivable	4,251	4,757
Other current assets	(15,992)	21,250
Other non-current assets, net	7,406	8,538
Accounts payable	(26,696)	(107,895)
Accounts payable to related companies	(2,733)	(5,741)
Exchanges payable	(244)	(8,340)
Accrued and other current liabilities	165,277	52,127
Other non-current liabilities	1,244	(741)
Price risk management assets and liabilities, net	44,476	162,734
Net change in operating assets and liabilities, net of effects of acquisitions	$ 234,176	$ 430,804

Cash And Cash Equivalents (Schedule Of Non-Cash Investing & Financing Activities) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010
Supplemental Cash Flow Information [Abstract]
Accrued capital expenditures	$ 154,378	$ 83,834
Gain from subsidiary common unit transactions	93,941	343,714
Subsidiary issuance of common units in connection with acquisition	3,000	0
Long-term debt assumed and non-compete agreement notes payable issued in acquisitions	$ 4,166	$ 1,240,481

Inventories (Details) - USD ($) $ in Thousands	Sep. 30, 2011	Dec. 31, 2010
Inventory, Net [Abstract]
Natural gas and NGLs, excluding propane	$ 120,798	$ 170,179
Propane	75,085	76,341
Appliances, parts and fittings and other	132,958	119,864
Total inventories	$ 328,841	$ 366,384

- Definition

Carrying amount as of the balance sheet date of products used directly or indirectly in the manufacturing or production process, which may or may not become part of the final product. May also include items used in the storage, presentation or transportation of physical goods.

+ References + Details

Goodwill And Intangible Assets (Narrative) (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2011 USD ($) years
Net increase in goodwill	$ 438,800
Intangible assets acquired	81,000
Customer Contracts [Member]
Intangible assets acquired	$ 81,000
Intangible assets, useful life, minimum (years) \| years	3
Intangible assets, useful life, maximum (years) \| years	15

Goodwill And Intangible Assets (Components And Useful Lives Of Intangible Assets) (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2011 USD ($) years	Dec. 31, 2010 USD ($)
Accumulated Amortization, Intangibles, Gross	$ 135,271	$ 102,991
Gross Carrying Amount, Amortizable intangible assets	1,140,411	1,060,392
Accumulated Amortization, Amortizable intangible assets	(135,271)	(102,991)
Gross Carrying Amount, Total intangible assets	1,219,239	1,137,837
Trademarks [Member]
Accumulated Amortization, Amortizable intangible assets	0	0
Gross Carrying Amount, Non-amortizable intangible assets	78,828	77,445
Customer Relationships, Contracts And Agreements [Member]
Gross Carrying Amount, Amortizable intangible assets	1,056,948	971,657
Accumulated Amortization, Amortizable intangible assets	$ (122,257)	(88,583)
Intangible assets, useful life, minimum (years) \| years	3
Intangible assets, useful life, maximum (years) \| years	46
Trade Names [Member]
Gross Carrying Amount, Amortizable intangible assets	$ 65,500	65,500
Accumulated Amortization, Amortizable intangible assets	$ (4,367)	(1,910)
Intangible assets, useful life (years) \| years	20
Noncompete Agreements [Member]
Gross Carrying Amount, Amortizable intangible assets	$ 15,893	21,165
Accumulated Amortization, Amortizable intangible assets	$ (7,900)	(11,888)
Intangible assets, useful life, minimum (years) \| years	3
Intangible assets, useful life, maximum (years) \| years	15
Patents [Member]
Gross Carrying Amount, Amortizable intangible assets	$ 750	750
Accumulated Amortization, Amortizable intangible assets	$ (181)	(118)
Intangible assets, useful life (years) \| years	9
Other [Member]
Gross Carrying Amount, Amortizable intangible assets	$ 1,320	1,320
Accumulated Amortization, Amortizable intangible assets	$ (566)	$ (492)
Intangible assets, useful life, minimum (years) \| years	10
Intangible assets, useful life, maximum (years) \| years	15

Goodwill And Intangible Assets (Aggregate Amortization Expense Of Intangible Assets) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Depreciation And Amortization [Member]
Aggregate amortization expenses	$ 13,168	$ 7,887	$ 40,541	$ 23,215

Goodwill And Intangible Assets (Estimated Aggregate Amortization Expense) (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2011 USD ($)
Goodwill and Intangible Assets Disclosure [Abstract]
2012	$ 53,989
2013	49,652
2014	48,531
2015	47,644
2016	$ 46,864

Fair Value Measurements (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2011	Dec. 31, 2010
Fair Value Measurements [Abstract]
Debt obligations fair value	$ 12,270	$ 10,230
Debt obligations, carrying amount	$ 11,680	$ 9,380

Fair Value Measurements (Fair Value Of Financial Assets And Liabilities Measured On Recurring Basis) (Details) - USD ($) $ in Thousands	Sep. 30, 2011	Dec. 31, 2010
Marketable securities, Asset Fair Value	$ 3,151	$ 2,032
Series A Convertible Preferred Units, Liability Fair Value	(314,980)	(317,600)
Fair Value, Measurements, Recurring [Member]
Marketable securities, Asset Fair Value	3,151	2,032
Interest rate derivatives, Asset Fair Value	30,564	20,790
Commodity derivatives, Asset Fair Value	189,343	95,765
Total Assets	223,058	118,587
Interest rate derivatives, Liability Fair Value	(99,658)	(20,922)
Series A Convertible Preferred Units, Liability Fair Value	(314,980)	(317,600)
Embedded derivatives in the Regency Preferred Units, Liability Fair Value	(36,268)	(57,023)
Commodity derivatives, Liability Fair Value	(154,747)	(80,307)
Total Liabilities	(605,653)	(475,852)
Fair Value, Measurements, Recurring [Member] \| Level 1 [Member]
Marketable securities, Asset Fair Value	3,151	2,032
Interest rate derivatives, Asset Fair Value	0	0
Commodity derivatives, Asset Fair Value	146,078	59,792
Total Assets	149,229	61,824
Interest rate derivatives, Liability Fair Value	0	0
Series A Convertible Preferred Units, Liability Fair Value	0	0
Embedded derivatives in the Regency Preferred Units, Liability Fair Value	0	0
Commodity derivatives, Liability Fair Value	(119,039)	(62,717)
Total Liabilities	(119,039)	(62,717)
Fair Value, Measurements, Recurring [Member] \| Level 2 [Member]
Marketable securities, Asset Fair Value	0	0
Interest rate derivatives, Asset Fair Value	30,564	20,790
Commodity derivatives, Asset Fair Value	43,265	35,973
Total Assets	73,829	56,763
Interest rate derivatives, Liability Fair Value	(99,658)	(20,922)
Series A Convertible Preferred Units, Liability Fair Value	0	0
Embedded derivatives in the Regency Preferred Units, Liability Fair Value	0	0
Commodity derivatives, Liability Fair Value	(35,708)	(17,590)
Total Liabilities	(135,366)	(38,512)
Fair Value, Measurements, Recurring [Member] \| Level 3 [Member]
Marketable securities, Asset Fair Value	0	0
Interest rate derivatives, Asset Fair Value	0	0
Commodity derivatives, Asset Fair Value	0	0
Total Assets	0	0
Interest rate derivatives, Liability Fair Value	0	0
Series A Convertible Preferred Units, Liability Fair Value	(314,980)	(317,600)
Embedded derivatives in the Regency Preferred Units, Liability Fair Value	(36,268)	(57,023)
Commodity derivatives, Liability Fair Value	0	0
Total Liabilities	(351,248)	(374,623)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Basis Swaps IFERC/NYMEX [Member]
Commodity derivatives, Asset Fair Value	74,892	15,756
Commodity derivatives, Liability Fair Value	(68,918)	(17,372)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Swing Swaps IFERC [Member]
Commodity derivatives, Asset Fair Value	21,818	1,682
Commodity derivatives, Liability Fair Value	(22,707)	(3,768)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Fixed Swaps/Futures [Member]
Commodity derivatives, Asset Fair Value	73,076	44,955
Commodity derivatives, Liability Fair Value	(48,287)	(42,252)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Options - Puts [Member]
Commodity derivatives, Asset Fair Value	13,348	26,241
Commodity derivatives, Liability Fair Value	(423)	(7)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Options - Calls [Member]
Commodity derivatives, Asset Fair Value		75
Commodity derivatives, Liability Fair Value	(122)	(2,643)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Forward Physical Swaps [Member]
Commodity derivatives, Asset Fair Value	738
Commodity derivatives, Liability Fair Value	(482)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| NGLs - Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	577	192
Commodity derivatives, Liability Fair Value	(11,722)	(10,684)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Propane Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	77	6,864
Commodity derivatives, Liability Fair Value	(2,086)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| WTI Crude Oil [Member]
Commodity derivatives, Asset Fair Value	4,817
Commodity derivatives, Liability Fair Value		(3,581)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Basis Swaps IFERC/NYMEX [Member]
Commodity derivatives, Asset Fair Value	74,892	15,756
Commodity derivatives, Liability Fair Value	(68,918)	(17,372)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Swing Swaps IFERC [Member]
Commodity derivatives, Asset Fair Value	1,074	1,562
Commodity derivatives, Liability Fair Value	(1,988)	(3,520)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Fixed Swaps/Futures [Member]
Commodity derivatives, Asset Fair Value	70,112	42,474
Commodity derivatives, Liability Fair Value	(48,133)	(41,825)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Options - Puts [Member]
Commodity derivatives, Asset Fair Value	0	0
Commodity derivatives, Liability Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Options - Calls [Member]
Commodity derivatives, Asset Fair Value		0
Commodity derivatives, Liability Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Forward Physical Swaps [Member]
Commodity derivatives, Asset Fair Value	0
Commodity derivatives, Liability Fair Value	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| NGLs - Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	0	0
Commodity derivatives, Liability Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Propane Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	0	0
Commodity derivatives, Liability Fair Value	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| WTI Crude Oil [Member]
Commodity derivatives, Asset Fair Value	0
Commodity derivatives, Liability Fair Value		0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Basis Swaps IFERC/NYMEX [Member]
Commodity derivatives, Asset Fair Value	0	0
Commodity derivatives, Liability Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Swing Swaps IFERC [Member]
Commodity derivatives, Asset Fair Value	20,744	120
Commodity derivatives, Liability Fair Value	(20,719)	(248)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Fixed Swaps/Futures [Member]
Commodity derivatives, Asset Fair Value	2,964	2,481
Commodity derivatives, Liability Fair Value	(154)	(427)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Options - Puts [Member]
Commodity derivatives, Asset Fair Value	13,348	26,241
Commodity derivatives, Liability Fair Value	(423)	(7)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Options - Calls [Member]
Commodity derivatives, Asset Fair Value		75
Commodity derivatives, Liability Fair Value	(122)	(2,643)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Forward Physical Swaps [Member]
Commodity derivatives, Asset Fair Value	738
Commodity derivatives, Liability Fair Value	(482)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| NGLs - Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	577	192
Commodity derivatives, Liability Fair Value	(11,722)	(10,684)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Propane Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	77	6,864
Commodity derivatives, Liability Fair Value	(2,086)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| WTI Crude Oil [Member]
Commodity derivatives, Asset Fair Value	4,817
Commodity derivatives, Liability Fair Value		(3,581)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| Basis Swaps IFERC/NYMEX [Member]
Commodity derivatives, Asset Fair Value	0	0
Commodity derivatives, Liability Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| Swing Swaps IFERC [Member]
Commodity derivatives, Asset Fair Value	0	0
Commodity derivatives, Liability Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| Fixed Swaps/Futures [Member]
Commodity derivatives, Asset Fair Value	0	0
Commodity derivatives, Liability Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| Options - Puts [Member]
Commodity derivatives, Asset Fair Value	0	0
Commodity derivatives, Liability Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| Options - Calls [Member]
Commodity derivatives, Asset Fair Value		0
Commodity derivatives, Liability Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| Forward Physical Swaps [Member]
Commodity derivatives, Asset Fair Value	0
Commodity derivatives, Liability Fair Value	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| NGLs - Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	0	0
Commodity derivatives, Liability Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| Propane Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	0	0
Commodity derivatives, Liability Fair Value	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| WTI Crude Oil [Member]
Commodity derivatives, Asset Fair Value	$ 0
Commodity derivatives, Liability Fair Value		$ 0

Fair Value Measurements (Reconciliation For Liabilities Measured At Fair Value On A Recurring Basis) (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2011 USD ($)
Fair Value Measurements [Abstract]
Beginning Balance	$ (374,623)
Net unrealized gains included in other income (expense)	23,375
Ending Balance	$ (351,248)

Net Income (Loss) Per Limited Partner Unit (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011 USD ($) $ / shares shares	Sep. 30, 2010 USD ($) $ / shares shares	Sep. 30, 2011 USD ($) $ / shares shares	Sep. 30, 2010 USD ($) $ / shares shares
Earnings Per Share [Abstract]
Limited Partners' interest in net income (loss)	$ 68,869	$ (15,289)	$ 223,315	$ 116,346
Weighted average Limited Partner units \| shares	222,972,708	222,941,172	222,966,763	222,941,151
Basic net income (loss) per Limited Partner unit \| $ / shares	0.31	(0.07)	1.00	0.52
Dilutive effect of equity-based compensation of subsidiaries	$ 167	$ 0	$ 525	$ 158
Diluted net income (loss) available to Limited Partners	$ 68,702	$ (15,289)	$ 222,790	$ 116,188
Weighted average Limited Partner units \| shares	222,972,708	222,941,172	222,966,763	222,941,151
Diluted net income (loss) per Limited Partner unit \| $ / shares	0.31	(0.07)	1.00	0.52
Discontinued operations impact per Limited Partner unit, omitted \| $ / shares	0.00	0.00	0.00	0.00
Preferred units liquidation preference	$ 300,000		$ 300,000

Debt Obligations (Senior Notes) (Narrative) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2011 USD ($) days
4.65% Senior Notes Due June 1, 2021 [Member] \| ETP Senior Notes [Member]
Aggregate principal amount of senior notes	$ 800.0
Senior notes interest rate	4.65%
Debt instrument, maturity date	Jun. 01, 2021
6.05% Senior Notes Due June 1, 2041 [Member] \| ETP Senior Notes [Member]
Aggregate principal amount of senior notes	$ 700.0
Senior notes interest rate	6.05%
Debt instrument, maturity date	Jun. 01, 2041
6.5% Senior Notes Due July 15, 2021 [Member] \| Regency Senior Notes [Member]
Aggregate principal amount of senior notes	$ 500.0
Proceeds from debt net of issuance costs	491.3
Issuance costs capitalized	$ 9.8
Senior notes interest rate	6.50%
Debt instrument, maturity date	Jul. 15, 2021
ETP Credit Facility [Member] \| ETP Senior Notes [Member]
Proceeds from debt net of issuance costs	$ 1,480.0
Redemption Before July 15, 2016 [Member] \| Regency 2021 Notes [Member] \| Regency Senior Notes [Member]
Optional purchase price for debt, percentage	100.00%
Redemption Before July 15, 2014 [Member] \| Regency 2021 Notes [Member] \| Regency Senior Notes [Member]
Offering price for debt redemption, percentage	106.50%
Portion of debt redeemable with equity offering proceeds	35.00%
In The Event Of Change Of Control With Rating Decline [Member] \| Regency 2021 Notes [Member] \| Regency Senior Notes [Member]
Optional purchase price for debt, percentage	101.00%
Number of days within which rating decline must occur \| days	90

Debt Obligations (Parent Company Credit Agreement) (Narrative) (Details) - Revolving Credit Facility [Member] - ETE Senior Secured Revolving Credit Facilities [Member] $ in Millions	Sep. 30, 2011 USD ($)
Revolving credit facility	$ 200
Parent Company [Member]
Outstanding borrowings	$ 0

Debt Obligations (ETP Credit Facility) (Narrative) (Details) - ETP Credit Facility [Member] - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2011	Oct. 27, 2011
Revolving credit facility	$ 2,000.0
Revolving credit facility, expandable limit	$ 3,000.0
Debt instrument, maturity date	Jul. 20, 2012
Amount Outstanding	$ 574.6
Amount available for future borrowings	1,400.0
Letters of Credit Outstanding, Amount	$ 24.3
Weighted average interest rate on amount outstanding	0.80%
Financing [Member]
Revolving credit facility		$ 2,500.0
Revolving credit facility, expandable limit		$ 3,750.0
Debt Instrument, Basis Spread on Variable Rate		1.50%
Commitment Fee on Unused Portion of Credit Facility		0.25%

Debt Obligations (Regency Credit Facility) (Narrative) (Details) - Regency Credit Facility [Member] $ in Millions	9 Months Ended
	Sep. 30, 2011 USD ($)
Revolving commitments	$ 900
Debt instrument, maturity date	Jun. 15, 2014
Outstanding borrowings	$ 445
Letters of Credit Outstanding, Amount	20
Amount available for future borrowings	$ 435
Weighted average interest rate on amount outstanding	3.03%

Redeemable Preferred Units (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2011	May 31, 2010
Aggregate liquidation preference	$ 300
ETE Preferred Units [Member]
Preferred units, issued		3,000,000
Aggregate liquidation preference		$ 300
Regency Preferred Units [Member]
Preferred units outstanding	4,371,586
Common units issued upon conversion	4,626,197
Subsidiary preferred unit mandatory redemption date	September 2, 2029
Mandatory redeemable price of units outstanding	$ 80
Quarterly cash distribution, per preferred unit	$ 0.445

- Definition

The aggregate liquidation preference (or restrictions) of stock classified as temporary equity that has a preference in involuntary liquidation considerably in excess of the par or stated value of the shares. The liquidation preference is the difference between the preference in liquidation and the par or stated values of the share. Temporary equity is a security with redemption features that are outside the control of the issuer, is not classified as an asset or liability in conformity with GAAP, and is not mandatorily redeemable. Includes any type of security that is redeemable at a fixed or determinable price or on a fixed or determinable date or dates, is redeemable at the option of the holder, or has conditions for redemption which are not solely within the control of the issuer. If convertible, the issuer does not control the actions or events necessary to issue the maximum number of shares that could be required to be delivered under the conversion option if the holder exercises the option to convert the stock to another class of equity. If the security is a warrant or a rights issue, the warrant or rights issue is considered to be temporary equity if the issuer cannot demonstrate that it would be able to deliver upon the exercise of the option by the holder in all cases. Includes stock with put option held by ESOP and stock redeemable by holder only in the event of a change in control of the issuer.

+ References + Details

Equity (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended		3 Months Ended	9 Months Ended
Equity (Narrative) (Details) - USD ($) $ in Thousands	Oct. 31, 2011	May 31, 2011	Jun. 30, 2011	Sep. 30, 2011	Sep. 30, 2010
Gain from subsidiary issuances of common units				$ 93,941	$ 343,714
ETP [Member]
Common units issued through public offering			14,202,500
Proceeds from issuance of common units			$ 695,500
Equity Distribution Agreement, maximum aggregate value of common units sold				$ 200,000
ETP [Member] \| Distribution Reinvestment Plan [Member]
Common units issued through public offering				5,750,000
Value of units issued during period through DRIP				$ 7,600
Units issued during period through DRIP				175,863
ETP [Member] \| Credit Suisse [Member]
Proceeds from issuance of common units				$ 96,300
Equity Distribution Agreement, remaining aggregate value to be sold				$ 77,500
Regency [Member]
Common units issued through public offering	11,500,000
Common units issued through private placement		8,500,001
Proceeds from issuance of common units	$ 231,900	$ 203,900
Lone Star L.L.C. [Member] \| Regency [Member]
Interest ownership				30.00%

Equity (Change In ETE Common Units) (Details)	9 Months Ended
Equity (Change In ETE Common Units) (Details)	Sep. 30, 2011 shares
Partners' Capital Notes [Abstract]
Outstanding, December 31, 2010	222,941,172
Issuance of restricted common units under equity incentive plans	31,536
Outstanding, September 30, 2011	222,972,708

Equity (Quarterly Distributions Of Available Cash) (Details) - $ / shares	3 Months Ended
	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010
Parent Company [Member]
Quarter Ended	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010
Record Date	November 4, 2011	August 5, 2011	May 6, 2011	February 7, 2011
Payment Date	November 18, 2011	August 19, 2011	May 19, 2011	February 18, 2011
Distributions paid, rate per unit		$ 0.625	$ 0.560	$ 0.540
Distributions declared, rate per unit	$ 0.625
ETP [Member]
Quarter Ended	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010
Record Date	November 4, 2011	August 5, 2011	May 6, 2011	February 7, 2011
Payment Date	November 14, 2011	August 15, 2011	May 16, 2011	February 14, 2011
Distributions paid, rate per unit		$ 0.89375	$ 0.89375	$ 0.89375
Distributions declared, rate per unit	$ 0.89375
Regency [Member]
Quarter Ended	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010
Record Date	November 7, 2011	August 5, 2011	May 6, 2011	February 7, 2011
Payment Date	November 14, 2011	August 12, 2011	May 13, 2011	February 14, 2011
Distributions paid, rate per unit		$ 0.450	$ 0.445	$ 0.445
Distributions declared, rate per unit	$ 0.455

Equity (Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2011	Dec. 31, 2010
Partners' Capital Notes [Abstract]
Net gains on commodity related hedges	$ 10,420	$ 14,146
Unrealized gains (losses) on available-for-sale securities	(17)	918
Subtotal	10,403	15,064
Amounts attributable to noncontrolling interest	(7,667)	(10,266)
Total AOCI included in partners' capital, net of tax	$ 2,736	$ 4,798

- Definition

Accumulated change in equity from transactions and other events and circumstances from non-owner sources, net of tax effect, at period end. Excludes Net Income (Loss), and accumulated changes in equity from transactions resulting from investments by owners and distributions to owners. Includes foreign currency translation items, certain pension adjustments, unrealized gains and losses on certain investments in debt and equity securities, other than temporary impairment (OTTI) losses related to factors other than credit losses on available-for-sale and held-to-maturity debt securities that an entity does not intend to sell and it is not more likely than not that the entity will be required to sell before recovery of the amortized cost basis, as well as changes in the fair value of derivatives related to the effective portion of a designated cash flow hedge.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Principles Board Opinion (APB)
-Number 12
-Paragraph 10
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 130
-Paragraph 14, 17, 26
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph 31
-Article 5

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 04
-Article 3

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e637-108580

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 14
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e681-108580

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 13
-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e653-108580

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Staff Position (FSP)
-Number FAS115-1/124-1
-Paragraph 15D
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

- Definition

This element represents Other Comprehensive Income or Loss, Net of Tax, for the period attributable to noncontrolling interest. Includes deferred gains or losses on qualifying hedges, unrealized holding gains or losses on available-for-sale securities, minimum pension liability, and cumulative translation adjustment.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 30
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 29
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 20
-URI http://asc.fasb.org/extlink&oid=6921628&loc=SL4569643-111683

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 19
-URI http://asc.fasb.org/extlink&oid=6921628&loc=SL4569616-111683

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 1A
-Subparagraph (c)(3)
-URI http://asc.fasb.org/extlink&oid=6921930&loc=SL4573702-111684

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 38
-Subparagraph c(3)
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Unit-Based Compensation Plans (Details) $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2011 USD ($) years $ / shares shares
ETE Long-Term Incentive Plan [Member]
Granted unvested awards	30,000
Vesting period (years)	5
Weighted average grant date fair value, per unit \| $ / shares	$ 39.82
Remain unvested award	105,713
Unrecognized compensation expense \| $	$ 1.4
Weighted average period for recognition, years \| years	1.9
ETP Unit-Based Compensation Plans [Member]
Granted unvested awards	556,700
Vesting period (years)	5
Weighted average grant date fair value, per unit \| $ / shares	$ 53.12
Remain unvested award	2,349,540
Unrecognized compensation expense \| $	$ 58.3
Weighted average period for recognition, years \| years	1.7
ETP Unit-Based Compensation Plans [Member] \| Director [Member]
Granted unvested awards	2,580
Vesting period (years)	3
Regency Common Unit Options [Member]
Weighted average exercise price per unit option \| $ / shares	$ 21.99
Remain vested and exercisable	156,850
Granted awards	0
Regency Phantom Units [Member]
Vesting period (years)	3
Weighted average grant date fair value per unit option \| $ / shares	$ 24.78
Remain unvested award	713,225
Unrecognized compensation expense \| $	$ 12.0
Weighted average period for recognition, years \| years	4.0
Regency Phantom Units [Member] \| Director [Member]
Granted awards	76,745

Income Taxes (Components Of Federal And State Income Tax) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Income Taxes [Abstract]
Current expense (benefit), Federal	$ 1,124	$ (3,182)	$ 6,787	$ (124)
Current expense (benefit), State	2,675	1,363	12,109	8,864
Total current expense (benefit)	3,799	(1,819)	18,896	8,740
Deferred expense (benefit), Federal	(41)	3,286	(599)	2,257
Deferred expense (benefit), State	(468)	626	120	360
Total deferred expense (benefit)	(509)	3,912	(479)	2,617
Total income tax expense	$ 3,290	$ 2,093	$ 18,417	$ 11,357

- Definition

The component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of enacted federal tax law to the domestic taxable Income or Loss from continuing operations.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 45
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 6
-Section I
-Paragraph Question 1-7

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Current Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6509736

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.7)
-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 289
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

- Definition

The component of income tax expense for the period representing amounts of income taxes paid or payable (or refundable) for the period for all income tax obligations as determined by applying the provisions of relevant enacted tax laws to relevant amounts of taxable Income or Loss from continuing operations.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 45
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Current Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6509736

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.7)
-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 289
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 6
-Section I
-Subsection 7

+ Details

- Definition

The component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of enacted state and local tax law to relevant amounts of taxable Income or Loss from continuing operations.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 45
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Current Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6509736

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.7)
-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 289
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 6
-Section I
-Subsection 7

+ Details

- Definition

The component of total income tax expense for the period comprised of the increase (decrease) during the period in the entity's domestic deferred tax assets and liabilities attributable to continuing operations as determined by applying the provisions of the federally enacted tax law.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 45
-Subparagraph b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.7)
-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Deferred Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6510177

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 6
-Section I
-Subsection 7

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 8, 16, 17, 289
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

- Definition

The component of income tax expense for the period representing the increase (decrease) in the entity's deferred tax assets and liabilities pertaining to continuing operations.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 95
-Paragraph 28
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 45
-Subparagraph b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 230
-SubTopic 10
-Section 45
-Paragraph 28
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=6943989&loc=d3e3602-108585

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.7)
-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Deferred Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6510177

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 289
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 6
-Section I
-Subsection 7

+ Details

- Definition

The component of total income tax expense for the period comprised of the increase (decrease) in the entity's state and local deferred tax assets and liabilities attributable to continuing operations as determined by applying the provisions of the applicable enacted tax laws.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 45
-Subparagraph b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.7)
-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Deferred Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6510177

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 6
-Section I
-Subsection 7

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 8, 16, 17, 289
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

- Definition

The sum of the current income tax expense or benefit and the deferred income tax expense or benefit pertaining to pretax Income or Loss from continuing operations; income tax expense or benefit may include interest and penalties on tax uncertainties based on the entity's accounting policy.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph h
-Article 4

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name FASB Interpretation (FIN)
-Number 48
-Paragraph 15, 16, 19
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 45, 46
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
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-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32672-109319

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 9
-Subparagraph (a),(b)
-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 45
-Paragraph 25
-URI http://asc.fasb.org/extlink&oid=6907571&loc=d3e32247-109318

+ Details

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities (Narrative) (Details) gal in Millions, $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Jul. 31, 2011 USD ($)	Sep. 30, 2011 USD ($)	Sep. 30, 2010 USD ($)	Sep. 30, 2011 USD ($) years gal sites	Sep. 30, 2010 USD ($)	Dec. 31, 2010 USD ($)
Capital contribution from joint venture interest holders	$ 390.0
Proceed from loan credit facility				$ 600.0
Typical length of purchase and supply agreements (in years) \| years				1
Maximum lease expiration year				2034
Operating leases rent expense		$ 7.3	$ 6.0	$ 20.5	$ 17.7
Purchases made under contract (gallons of propane) \| gal				90
Long-term purchase contract agreement, expiration date				2015
Sites where remediation operations are responsibility of third parties \| sites				6
Capital costs		4.2	5.8	$ 9.7	10.8
Operating and maintenance costs		3.9	$ 3.9	9.8	$ 10.2
ETP [Member]
Accrual for environmental loss contingencies		12.6		12.6		$ 13.8
FEP Facility [Member]
Revolving credit facility		1,100.0		$ 1,100.0
Debt instrument, maturity date				Jul. 01, 2012
July 2015 [Member]
Revolving credit facility		$ 50.0		$ 50.0
Debt instrument, maturity date				Jul. 01, 2015
ETP Guarantee [Member] \| FEP Facility [Member]
Interest ownership		50.00%		50.00%
Line of credit facility obligation rate				50.00%
Related To Deductibles [Member]
Accrual for loss contingency		$ 13.3		$ 13.3		10.2
Contingencies And Litigation Matters Other Than Accruals Related To Environmental Matters And Deductibles [Member]
Accrual for loss contingency		0.0		$ 0.0		0.0
Future Estimated Cost Of Remediation Activities [Member] \| Transwestern [Member] \| ETP [Member]
Year remediation activities expected to continue through				2025
Components of accrual for environmental loss contingencies		7.9		$ 7.9
Accrual For Six Sites [Member]
Components of accrual for environmental loss contingencies		$ 0.0		$ 0.0		$ 0.0

Price Risk Management Assets And Liabilities (Narrative) (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011 USD ($)	Sep. 30, 2010 USD ($)	Sep. 30, 2011 USD ($) years	Sep. 30, 2010 USD ($)	Dec. 31, 2010 USD ($)
Swap maturity term (years) \| years			10
Deposits with counterparties	$ 56,435		$ 56,435		$ 52,192
Unrealized gains (losses) on commodity derivatives	700	$ (800)	2,800	$ (49,000)
ETP [Member]
Expected gains (losses) related to commodity derivatives to be reclassified into earnings over next year related to amounts currently reported an AOCI	11,600		11,600
Regency [Member]
Expected gains (losses) related to commodity derivatives to be reclassified into earnings over next year related to amounts currently reported an AOCI	(5,300)		(5,300)
Commodity Derivatives [Member]
Unrealized gains (losses) on commodity derivatives and related hedged inventory	$ (7,100)	$ 8,200	$ (1,300)	$ (35,300)

Price Risk Management Assets And Liabilities (Interest Rate Swaps Outstanding) (Details) - Interest Rate Derivatives [Member] - USD ($)
$ in Thousands

9 Months Ended

Sep. 30, 2011

Dec. 31, 2010

May 2012 [Member] | ETP [Member]

Term

^[1]

May 2012

Notional Amount

$ 350,000

$ 0

Type

^[2]

Forward starting to pay a fixed rate of 2.59% and receive a floating rate

Interest rate swaps, fixed rate

2.59%

August 2012 [Member] | ETP [Member]

Term

^[1]

August 2012

Notional Amount

$ 500,000

400,000

Type

^[2]

Forward starting to pay a fixed rate of 3.51% and receive a floating rate

Interest rate swaps, fixed rate

3.51%

July 2013 [Member] | ETP [Member]

Term

^[1]

July 2013

Notional Amount

$ 300,000

Type

^[2]

Forward starting to pay a fixed rate of 4.02% and receive a floating rate

Interest rate swaps, fixed rate

4.02%

July 2018 [Member] | ETP [Member]

Term

July 2018

Notional Amount

$ 500,000

500,000

Type

^[2]

Pay a floating rate plus a spread of 4.01% and receive a fixed rate of 6.70%

Interest rate swaps, spread on floating rate

4.01%

Interest rate swaps, fixed rate

6.70%

April 2012 [Member] | Regency [Member]

Term

April 2012

Notional Amount

$ 250,000

Type

^[2]

Pay a fixed rate of 1.325% and receive a floating rate

Interest rate swaps, fixed rate

1.325%

[1]	These forward starting swaps have a term of 10 years with a mandatory termination date the same as the effective date.
[2]	As of September 30, 2011. Floating rates are based on 3-month LIBOR.

Price Risk Management Assets And Liabilities (Fair Value Of Derivative Instruments) (Details) - USD ($) $ in Thousands	Sep. 30, 2011	Dec. 31, 2010
Total derivatives assets	$ 229,663	$ 130,299
Total derivatives liabilities	(300,429)	(171,997)
Designated as Hedging Instrument [Member]
Total derivatives assets	51,695	44,294
Total derivatives liabilities	(12,337)	(21,323)
Designated as Hedging Instrument [Member] \| Commodity Derivatives (Margin Deposits) [Member]
Total derivatives assets	43,337	35,031
Total derivatives liabilities	(461)	(6,631)
Designated as Hedging Instrument [Member] \| Commodity Derivatives [Member]
Total derivatives assets	8,358	9,263
Total derivatives liabilities	(11,876)	(14,692)
Not Designated as Hedging Instrument [Member]
Total derivatives assets	177,968	86,005
Total derivatives liabilities	(288,092)	(150,674)
Not Designated as Hedging Instrument [Member] \| Commodity Derivatives (Margin Deposits) [Member]
Total derivatives assets	146,589	64,940
Total derivatives liabilities	(149,598)	(72,729)
Not Designated as Hedging Instrument [Member] \| Commodity Derivatives [Member]
Total derivatives assets	815	275
Total derivatives liabilities	(2,568)	0
Not Designated as Hedging Instrument [Member] \| Interest Rate Derivatives [Member]
Total derivatives assets	30,564	20,790
Total derivatives liabilities	(99,658)	(20,922)
Not Designated as Hedging Instrument [Member] \| Embedded Derivatives [Member]
Total derivatives assets	0	0
Total derivatives liabilities	$ (36,268)	$ (57,023)

Price Risk Management Assets And Liabilities (Partnership's Derivative Assets And Liabilities Recognized OCI On Derivatives) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Change in Value Recognized in OCI on Derivatives (Effective Portion)	$ 16,414	$ 26,210	$ 9,291	$ 31,012
Commodity Derivatives [Member]
Change in Value Recognized in OCI on Derivatives (Effective Portion)	16,414	36,035	9,291	60,992
Interest Rate Derivatives [Member]
Change in Value Recognized in OCI on Derivatives (Effective Portion)	$ 0	$ (9,825)	$ 0	$ (29,980)

Price Risk Management Assets And Liabilities (Partnership's Derivative Assets And Liabilities Amount Of Gain (Loss) Recognized) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Amount of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	$ (166)	$ (64,032)	$ 12,793	$ (67,544)
Amount of Gain/(Loss) Recognized in Income on Ineffective Portion	(91)	241	98	346
Amount of Gain/(Loss) Recognized in Income representing hedge ineffectiveness and amount excluded from the assessment of effectiveness	(3,559)	9,968	18,732	9,001
Amount of Gain/(Loss) Recognized in Income on Derivatives	(44,210)	(21,426)	(40,271)	(61,381)
Commodity Derivatives [Member] \| Cost of Products Sold [Member]
Amount of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	(166)	6,780	12,793	19,153
Amount of Gain/(Loss) Recognized in Income on Ineffective Portion	(91)	241	98	346
Amount of Gain/(Loss) Recognized in Income representing hedge ineffectiveness and amount excluded from the assessment of effectiveness	(3,559)	9,968	18,732	9,001
Amount of Gain/(Loss) Recognized in Income on Derivatives	9,056	3,219	4,067	3,762
Interest Rate Derivatives [Member] \| Interest Expense [Member]
Amount of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	0	(70,812)	0	(86,697)
Interest Rate Derivatives [Member] \| Losses On Non-Hedged Interest Rate Derivatives [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	(68,496)	(31,966)	(65,093)	(68,858)
Embedded Derivatives [Member] \| Other Income (Expenses) [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	$ 15,230	$ 7,321	$ 20,755	$ 3,715

Related Party Transactions (Narrative) (Details) gal in Millions, $ in Millions	3 Months Ended		4 Months Ended	9 Months Ended
	Sep. 30, 2011 USD ($) gal	Sep. 30, 2010 USD ($)	Sep. 30, 2010 USD ($)	Sep. 30, 2011 USD ($) gal	Sep. 30, 2010 USD ($)	Dec. 31, 2010 USD ($) gal
Long-term purchase contract agreement, expiration date				2015
ETP [Member]
General and administrative services paid	$ 4.4	$ 2.6		$ 12.7	$ 3.7
General administrative expenses reimbursed	1.7			4.9
Regency [Member]
General and administrative revenues	4.2	2.5		12.4	$ 3.3
ETP Subsidiary [Member] \| Enterprise [Member]
Fair value of mark-to-market derivative liabilities	2.0			2.0
Fair value of derivative assets						$ 0.2
Fair value of derivative assets accounted for as cash flow hedges						$ 6.6
HPC [Member]
General administrative expenses reimbursed		4.2	$ 5.6
HPC [Member] \| Regency [Member]
General administrative expenses reimbursed	4.2			12.6
Revenue	6.4	5.6	7.7	19.4
Cost of sales	$ 2.9	$ 2.5	$ 4.3	$ 11.0
Gallons Of Propane [Member] \| ETP Subsidiary [Member]
Forward Mark To Market Derivatives Outstanding \| gal	52.7			52.7		1.7
Gallons Of Propane [Member] \| ETP Subsidiary [Member] \| Enterprise [Member]
Forward derivatives accounted for as cash flow hedges \| gal						32.5

Related Party Transactions (Sales To And Purchase From Affiliates Of Enterprise) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
ETP's Natural Gas Operations [Member]
Sales	$ 164,339	$ 126,992	$ 462,359	$ 402,238
Purchases	3,938	396	21,898	13,928
Regency's Natural Gas Operations [Member]
Sales	119,519	53,620	275,488	72,121
Purchases	2,094	1,890	5,092	2,312
ETP's Propane Operations [Member]
Sales	395	262	10,613	11,228
Purchases	$ 86,673	$ 58,642	$ 328,830	$ 276,821

Related Party Transactions (Related Party Receivables And Payables) (Details) - USD ($) $ in Thousands	Sep. 30, 2011	Dec. 31, 2010
Accounts receivable from related parties	$ 86,454	$ 76,331
Accounts payable to related parties	24,618	27,351
ETP's Natural Gas Operations [Member]
Accounts receivable from related parties	53,016	36,736
Accounts payable to related parties	2,465	2,687
Regency's Natural Gas Operations [Member]
Accounts receivable from related parties	31,285	25,539
Accounts payable to related parties	1,199	1,323
ETP's Propane Operations [Member]
Accounts receivable from related parties	222	2,327
Accounts payable to related parties	19,632	22,985
Other Operations [Member]
Accounts receivable from related parties	1,931	11,729
Accounts payable to related parties	1,322	356
Enterprise [Member] \| ETP [Member]
Net imbalance (payable to) receivable from Enterprise	(89)	1,360
Enterprise [Member] \| Regency [Member]
Net imbalance (payable to) receivable from Enterprise	$ 1,464	$ 753

Other Information (Other Current Assets) (Details) - USD ($) $ in Thousands	Sep. 30, 2011	Dec. 31, 2010
Other Information [Abstract]
Deposits paid to vendors	$ 56,435	$ 52,192
Prepaid expenses and other	87,143	57,167
Total other current assets	$ 143,578	$ 109,359

Other Information (Other Non-Current Assets, net) (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2011 USD ($) years	Dec. 31, 2010 USD ($)
Unamortized financing costs (3 to 30 years)	$ 129,921	$ 98,067
Regulatory assets	89,943	92,939
Total non-current other assets, net	$ 247,703	225,581
Financing Costs [Member]
Financing cost, amortization period, maximum (years) \| years	30
Financing cost, amortization period, minimum (years) \| years	3
Other [Member]
Other	$ 27,839	$ 34,575

Other Information (Accrued And Other Current Liabilities) (Details) - USD ($) $ in Thousands	Sep. 30, 2011	Dec. 31, 2010
Other Information [Abstract]
Interest payable	$ 247,600	$ 191,466
Customer advances and deposits	126,066	111,448
Accrued capital expenditures	147,795	87,260
Accrued wages and benefits	72,117	76,592
Taxes payable other than income taxes	96,007	36,204
Income taxes payable	6,166	8,344
Other	98,909	56,374
Total accrued and other current liabilities	$ 794,660	$ 567,688

- Definition

Carrying value as of the balance sheet date of obligations incurred and payable for real and property taxes. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer).

+ References + Details

- Definition

Carrying value as of the balance sheet date of obligations, excluding pension and other postretirement benefits, incurred through that date and payable for perquisites provided to employees pertaining to services received from them. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer).

+ References + Details

- Definition

Carrying value as of the balance sheet date of [accrued] interest payable on all forms of debt, including trade payables, that has been incurred and is unpaid. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer).

+ References + Details

- Definition

Aggregate carrying amount, as of the balance sheet date, of obligations incurred and payable, pertaining to costs that are statutory in nature, are incurred on contractual obligations, or accumulate over time and for which invoices have not yet been received or will not be rendered and of liabilities not separately disclosed in the balance sheet. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer).

+ References + Details

Reportable Segments (Operating Segments) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Revenues from external customers	$ 2,097,866	$ 1,587,807	$ 6,061,892	$ 4,822,316
Intersegment revenues	0	0	0	0
Income tax expense (benefit)	3,290	2,093	18,417	11,357
Net income (loss)	60,699	(4,826)	366,443	178,776
Investment In ETP [Member]
Revenue from external customers	1,708,413	1,290,644	5,001,208	4,430,331
Intersegment revenues	6,903	0	29,780	0
Income tax expense (benefit)	4,039	1,993	20,419	12,486
Net income (loss)	76,050	107,387	479,868	390,341
Investment In Regency [Member]
Revenue from external customers	388,271	295,094	1,058,646	391,177
Intersegment revenues	1,996	1,794	5,371	2,691
Income tax expense (benefit)	(89)	450	(19)	695
Net income (loss)	30,849	7,846	59,991	2,951
Corporate And Other [Member]
Revenue from external customers	0	0	0	0
Intersegment revenues	0	0	0	0
Income tax expense (benefit)	(660)	(350)	(1,983)	(1,824)
Net income (loss)	(36,915)	(120,059)	(155,743)	(214,516)
Adjustments And Eliminations [Member]
Revenue from external customers	1,182	2,069	2,038	808
Intersegment revenues	(8,899)	(1,794)	(35,151)	(2,691)
Income tax expense (benefit)	0	0	0	0
Net income (loss)	$ (9,285)	$ 0	$ (17,673)	$ 0

- Definition

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 29
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 38
-Subparagraph a
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph A1, A4, A5
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 5
-Subparagraph b
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 55
-Paragraph 4K
-URI http://asc.fasb.org/extlink&oid=6922042&loc=SL4591552-111686

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 19
-URI http://asc.fasb.org/extlink&oid=6921628&loc=SL4569616-111683

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 55
-Paragraph 4J
-URI http://asc.fasb.org/extlink&oid=6922042&loc=SL4591551-111686

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 1A
-Subparagraph (a),(c)
-URI http://asc.fasb.org/extlink&oid=6921930&loc=SL4573702-111684

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 51
-Paragraph 38
-Subparagraph c(1)
-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Reportable Segments (Assets Segments)(Details) - USD ($) $ in Thousands	Sep. 30, 2011	Dec. 31, 2010
Assets	$ 20,443,318	$ 17,378,730
Investment In ETP [Member]
Assets	15,078,048	12,149,992
Investment In Regency [Member]
Assets	5,525,739	4,770,204
Corporate And Other [Member]
Assets	480,342	469,221
Adjustments And Eliminations [Member]
Assets	$ (640,811)	$ (10,687)

Reportable Segments (Revenues By Similar Products And Services) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Total revenues	$ 2,097,866	$ 1,587,807	$ 6,061,892	$ 4,822,316
ETP [Domain]
Total revenues	1,715,316	1,290,644	5,030,988	4,430,331
Regency [Domain]
Total revenues	390,267	296,888	1,064,017	898,918
Intrastate Transportation And Storage [Member] \| ETP [Domain]
Total revenues	617,244	529,507	1,849,575	1,662,037
Interstate Transportation [Member] \| ETP [Domain]
Total revenues	120,065	74,659	330,016	213,007
Midstream [Member] \| ETP [Domain]
Total revenues	565,246	458,381	1,492,025	1,484,211
NGL Transportation And Services [Member] \| ETP [Domain]
Total revenues	131,284	0	224,970	0
Retail Propane And Other Retail Propane Related [Member] \| ETP [Domain]
Total revenues	236,781	205,833	1,037,969	987,114
All Other [Member] \| ETP [Domain]
Total revenues	44,696	22,264	96,433	83,962
Gathering And Processing [Member] \| Regency [Domain]
Total revenues	339,273	253,054	908,448	775,636
Joint Ventures [Member] \| Regency [Domain]
Total revenues	0	0	0	0
Contract Compression [Member] \| Regency [Domain]
Total revenues	36,024	36,172	112,532	107,197
Contract Treating [Member] \| Regency [Domain]
Total revenues	10,573	3,299	29,848	3,299
Corporate And Others [Member] \| Regency [Domain]
Total revenues	$ 4,397	$ 4,363	$ 13,189	$ 12,786

Supplemental Financial Statement Information (Schedule Of Balance Sheets) (Details) - USD ($) $ in Thousands	Sep. 30, 2011	Dec. 31, 2010	Sep. 30, 2010	Dec. 31, 2009
Cash and cash equivalents	$ 167,715	$ 86,264	$ 88,113	$ 68,315
Accounts receivable from related companies	86,454	76,331
Other current assets	143,578	109,359
Total current assets	1,433,088	1,291,010
ADVANCES TO AND INVESTMENTS IN AFFILIATES	1,515,604	1,359,979
OTHER NON-CURRENT ASSETS, net	247,703	225,581
Total assets	20,443,318	17,378,730
Accounts payable	468,480	421,556
Accounts payable to related companies	24,618	27,351
Accrued and other current liabilities	794,660	567,688
Total current liabilities	1,804,250	1,081,075
LONG-TERM DEBT, less current maturities	11,252,745	9,346,067
SERIES A CONVERTIBLE PREFERRED UNITS	71,091	70,943
LONG-TERM PRICE RISK MANAGEMENT LIABILITIES	73,261	79,465
COMMITMENTS AND CONTINGENCIES
General Partner	306	520
Limited Partners	47,483	115,350
Accumulated other comprehensive income	2,736	4,798
Total partners' capital	50,525	120,668
Total liabilities and equity	20,443,318	17,378,730
Parent Company [Member]
Cash and cash equivalents	26,174	27,247	$ 6,325	$ 62
Accounts receivable from related companies	1,553	171
Other current assets	1,534	864
Total current assets	29,261	28,282
ADVANCES TO AND INVESTMENTS IN AFFILIATES	2,197,813	2,231,722
OTHER NON-CURRENT ASSETS, net	50,720	29,118
Total assets	2,277,794	2,289,122
Accounts payable	502	0
Accounts payable to related companies	11,469	6,654
Accrued and other current liabilities	100,318	44,200
Total current liabilities	112,289	50,854
LONG-TERM DEBT, less current maturities	1,800,000	1,800,000
SERIES A CONVERTIBLE PREFERRED UNITS	314,980	317,600
COMMITMENTS AND CONTINGENCIES
General Partner	306	520
Limited Partners	47,483	115,350
Accumulated other comprehensive income	2,736	4,798
Total partners' capital	50,525	120,668
Total liabilities and equity	$ 2,277,794	$ 2,289,122

Supplemental Financial Statement Information (Schedule Of Statements Of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES	$ (82,587)	$ (61,526)	$ (225,032)	$ (177,673)
InterestExpense	193,772	209,871	543,218	460,578
Equity in earnings of affiliates	28,374	22,349	82,634	40,723
Losses on non-hedged interest rate derivatives	(68,497)	(31,966)	(65,094)	(68,858)
Other, net	33,231	14,379	21,081	10,819
Income tax expense	3,290	2,093	18,417	11,357
NET INCOME (LOSS) ATTRIBUTABLE TO PARTNERS	69,083	(15,337)	224,008	116,707
GENERAL PARTNER'S INTEREST IN NET INCOME (LOSS)	214	(48)	693	361
LIMITED PARTNERS' INTEREST IN NET INCOME (LOSS)	68,869	(15,289)	223,315	116,346
Parent Company [Member]
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES	(11,667)	(2,920)	(25,546)	(20,335)
InterestExpense	40,819	89,484	122,345	126,400
Equity in earnings of affiliates	102,565	102,388	369,833	324,128
Losses on non-hedged interest rate derivatives	0	(18,211)	0	(53,388)
Other, net	19,068	(6,736)	2,256	(6,949)
INCOME (LOSS) BEFORE INCOME TAXES	69,147	(14,963)	224,198	117,056
Income tax expense	64	374	190	349
NET INCOME (LOSS) ATTRIBUTABLE TO PARTNERS	69,083	(15,337)	224,008	116,707
GENERAL PARTNER'S INTEREST IN NET INCOME (LOSS)	214	(48)	693	361
LIMITED PARTNERS' INTEREST IN NET INCOME (LOSS)	$ 68,869	$ (15,289)	$ 223,315	$ 116,346

Supplemental Financial Statement Information (Schedule Of Statements Of Cash Flows) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	$ 1,102,960	$ 927,683
Proceeds from borrowings	6,429,107	2,927,042
Principal payments on debt	(4,130,493)	(3,133,678)
Distributions to partners	(385,806)	(362,286)
Debt issuance costs	(22,217)	(35,612)
Net cash provided by financing activities	2,314,489	489,800
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	81,451	19,798
CASH AND CASH EQUIVALENTS, beginning of period	86,264	68,315
CASH AND CASH EQUIVALENTS, end of period	167,715	88,113
Parent Company [Member]
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	384,733	175,126
MEP Transaction	0	3,016
Proceeds from borrowings	20,000	1,850,245
Principal payments on debt	(20,000)	(1,624,374)
Distributions to partners	(385,806)	(362,286)
Debt issuance costs	0	(35,464)
Net cash provided by financing activities	(385,806)	(171,879)
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(1,073)	6,263
CASH AND CASH EQUIVALENTS, beginning of period	27,247	62
CASH AND CASH EQUIVALENTS, end of period	$ 26,174	$ 6,325

Price Risk Management Assets And Liabilities (Outstanding Commodity-Related Derivatives) (Details)	Sep. 30, 2011 bbl gal MMbtu	Dec. 31, 2010 bbl gal MMbtu
Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Basis Swaps IFERC/NYMEX (MMBtu) [Member] \| ETP [Member]
Notional Volume	(39,952,500)	(38,897,500)
Maturity		2011
Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Swing Swaps IFERC (MMBtu) [Member] \| ETP [Member]
Notional Volume	30,517,500	(19,720,000)
Maturity		2011
Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Fixed Swaps/Futures (MMBtu) [Member] \| ETP [Member]
Notional Volume	(15,517,500)	(2,570,000)
Maturity		2011
Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Forward Physical Contracts (MMBtu) [Member] \| ETP [Member]
Notional Volume	12,324,054	0
Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Options - Calls (MMBtu) [Member] \| ETP [Member]
Notional Volume	0	(3,000,000)
Maturity		2011
Mark-To-Market Derivatives [Member] \| Propane [Member] \| Forwards/Swaps (Gallons) [Member] \| ETP [Member]
Notional Volume \| gal	52,668,000	1,974,000
Maturity		2011
Fair Value Hedging Derivatives [Member] \| Natural Gas [Member] \| Basis Swaps IFERC/NYMEX (MMBtu) [Member] \| ETP [Member]
Notional Volume	(19,685,000)	(28,050,000)
Maturity		2011
Fair Value Hedging Derivatives [Member] \| Natural Gas [Member] \| Fixed Swaps/Futures (MMBtu) [Member] \| ETP [Member]
Notional Volume	(29,837,500)	(39,105,000)
Maturity		2011
Fair Value Hedging Derivatives [Member] \| Natural Gas [Member] \| Hedged Item - Inventory (MMBtu) [Member] \| ETP [Member]
Notional Volume	29,837,500	39,105,000
Maturity	2011	2011
Cash Flow Hedging Derivatives [Member] \| Natural Gas [Member] \| Fixed Swaps/Futures (MMBtu) [Member] \| ETP [Member]
Notional Volume	460,000	(210,000)
Maturity	2011	2011
Cash Flow Hedging Derivatives [Member] \| Natural Gas [Member] \| Fixed Swaps/Futures (MMBtu) [Member] \| Regency [Member]
Notional Volume	2,934,000	3,830,000
Maturity	2012	2011
Cash Flow Hedging Derivatives [Member] \| Natural Gas [Member] \| Options - Puts (MMBtu) [Member] \| ETP [Member]
Notional Volume	9,390,000	26,760,000
Cash Flow Hedging Derivatives [Member] \| Natural Gas [Member] \| Options - Calls (MMBtu) [Member] \| ETP [Member]
Notional Volume	(9,390,000)	(26,760,000)
Cash Flow Hedging Derivatives [Member] \| Propane [Member] \| Forwards/Swaps (Gallons) [Member] \| ETP [Member]
Notional Volume \| gal	0	32,466,000
Maturity		2011
Cash Flow Hedging Derivatives [Member] \| Propane [Member] \| Forwards/Swaps (Gallons) [Member] \| Regency [Member]
Notional Volume \| gal	15,204,000	18,648,000
Maturity	2013
Cash Flow Hedging Derivatives [Member] \| Natural Gas Liquids [Member] \| Forwards/Swaps (Barrels) [Member] \| Regency [Member]
Notional Volume \| bbl	771,000	1,212,110
Maturity	2013
Cash Flow Hedging Derivatives [Member] \| WTI Crude Oil [Member] \| Forwards/Swaps (Barrels) [Member] \| Regency [Member]
Notional Volume \| bbl	417,000	373,655
Maturity	2014
Maximum [Member] \| Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Basis Swaps IFERC/NYMEX (MMBtu) [Member] \| ETP [Member]
Maturity	2013
Maximum [Member] \| Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Swing Swaps IFERC (MMBtu) [Member] \| ETP [Member]
Maturity	2013
Maximum [Member] \| Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Fixed Swaps/Futures (MMBtu) [Member] \| ETP [Member]
Maturity	2012
Maximum [Member] \| Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Forward Physical Contracts (MMBtu) [Member] \| ETP [Member]
Maturity	2012
Maximum [Member] \| Mark-To-Market Derivatives [Member] \| Propane [Member] \| Forwards/Swaps (Gallons) [Member] \| ETP [Member]
Maturity	2012
Maximum [Member] \| Fair Value Hedging Derivatives [Member] \| Natural Gas [Member] \| Basis Swaps IFERC/NYMEX (MMBtu) [Member] \| ETP [Member]
Maturity	2012
Maximum [Member] \| Fair Value Hedging Derivatives [Member] \| Natural Gas [Member] \| Fixed Swaps/Futures (MMBtu) [Member] \| ETP [Member]
Maturity	2012
Maximum [Member] \| Cash Flow Hedging Derivatives [Member] \| Natural Gas [Member] \| Options - Puts (MMBtu) [Member] \| ETP [Member]
Maturity	2012	2012
Maximum [Member] \| Cash Flow Hedging Derivatives [Member] \| Natural Gas [Member] \| Options - Calls (MMBtu) [Member] \| ETP [Member]
Maturity	2012	2012
Maximum [Member] \| Cash Flow Hedging Derivatives [Member] \| Propane [Member] \| Forwards/Swaps (Gallons) [Member] \| Regency [Member]
Maturity		2012
Maximum [Member] \| Cash Flow Hedging Derivatives [Member] \| Natural Gas Liquids [Member] \| Forwards/Swaps (Barrels) [Member] \| Regency [Member]
Maturity		2012
Maximum [Member] \| Cash Flow Hedging Derivatives [Member] \| WTI Crude Oil [Member] \| Forwards/Swaps (Barrels) [Member] \| Regency [Member]
Maturity		2012
Minimum [Member] \| Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Basis Swaps IFERC/NYMEX (MMBtu) [Member] \| ETP [Member]
Maturity	2011
Minimum [Member] \| Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Swing Swaps IFERC (MMBtu) [Member] \| ETP [Member]
Maturity	2011
Minimum [Member] \| Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Fixed Swaps/Futures (MMBtu) [Member] \| ETP [Member]
Maturity	2011
Minimum [Member] \| Mark-To-Market Derivatives [Member] \| Natural Gas [Member] \| Forward Physical Contracts (MMBtu) [Member] \| ETP [Member]
Maturity	2011
Minimum [Member] \| Mark-To-Market Derivatives [Member] \| Propane [Member] \| Forwards/Swaps (Gallons) [Member] \| ETP [Member]
Maturity	2011
Minimum [Member] \| Fair Value Hedging Derivatives [Member] \| Natural Gas [Member] \| Basis Swaps IFERC/NYMEX (MMBtu) [Member] \| ETP [Member]
Maturity	2011
Minimum [Member] \| Fair Value Hedging Derivatives [Member] \| Natural Gas [Member] \| Fixed Swaps/Futures (MMBtu) [Member] \| ETP [Member]
Maturity	2011
Minimum [Member] \| Cash Flow Hedging Derivatives [Member] \| Natural Gas [Member] \| Options - Puts (MMBtu) [Member] \| ETP [Member]
Maturity	2011	2011
Minimum [Member] \| Cash Flow Hedging Derivatives [Member] \| Natural Gas [Member] \| Options - Calls (MMBtu) [Member] \| ETP [Member]
Maturity	2011	2011
Minimum [Member] \| Cash Flow Hedging Derivatives [Member] \| Propane [Member] \| Forwards/Swaps (Gallons) [Member] \| Regency [Member]
Maturity		2011
Minimum [Member] \| Cash Flow Hedging Derivatives [Member] \| Natural Gas Liquids [Member] \| Forwards/Swaps (Barrels) [Member] \| Regency [Member]
Maturity		2011
Minimum [Member] \| Cash Flow Hedging Derivatives [Member] \| WTI Crude Oil [Member] \| Forwards/Swaps (Barrels) [Member] \| Regency [Member]
Maturity		2011