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DEI Document - shares	6 Months Ended
DEI Document - shares	Jun. 30, 2012	Aug. 01, 2012
Entity Information [Line Items]
Entity Registrant Name	Energy Transfer Equity, L.P.
Entity Central Index Key	0001276187
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		279,955,608

Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2012	Dec. 31, 2011
ASSETS
Cash and cash equivalents	$ 217,160	$ 126,342
Marketable securities	11	1,229
Accounts receivable, net of allowance for doubtful accounts	709,670	680,491
Accounts receivable from related companies	34,296	100,406
Inventories	443,742	327,963
Exchanges receivable	59,969	21,307
Price risk management assets	46,171	15,802
Other current assets	172,755	181,904
Total current assets	1,683,774	1,455,444
PROPERTY, PLANT AND EQUIPMENT	23,751,846	16,529,339
ACCUMULATED DEPRECIATION	(1,843,981)	(1,970,777)
PROPERTY, PLANT AND EQUIPMENT, net	21,907,865	14,558,562
ADVANCES TO AND INVESTMENTS IN AFFILIATES	4,574,293	1,496,600
LONG-TERM PRICE RISK MANAGEMENT ASSETS	40,846	26,011
GOODWILL	3,458,809	2,038,975
INTANGIBLE ASSETS, net	971,341	1,072,291
OTHER NON-CURRENT ASSETS, net	476,294	248,910
Total assets	33,113,222	20,896,793
LIABILITIES AND EQUITY
Accounts payable	456,322	512,023
Accounts payable to related companies	2,434	33,208
Exchanges payable	133,301	17,957
Price risk management liabilities	47,252	90,053
Accrued and other current liabilities	1,081,333	763,912
Current maturities of long-term debt	113,921	424,160
Total current liabilities	1,834,563	1,841,313
LONG-TERM DEBT, less current maturities	17,959,464	10,946,864
PREFERRED UNITS	319,860	322,910
Deferred Income Taxes	1,936,150	217,244
LONG-TERM PRICE RISK MANAGEMENT LIABILITIES	246,242	81,415
OTHER NON-CURRENT LIABILITIES	312,712	26,958
COMMITMENTS AND CONTINGENCIES
PREFERRED UNITS OF SUBSIDIARY	72,370	71,144
EQUITY:
General Partner	71	321
Limited Partners:
Common Unitholders	2,297,473	52,485
Accumulated other comprehensive income	1,309	678
Total partners' capital	2,298,853	53,484
Noncontrolling interest	8,133,008	7,335,461
Total equity	10,431,861	7,388,945
Total liabilities and equity	$ 33,113,222	$ 20,896,793

Balance Sheet Paranthetical (Parentheticals) - USD ($) $ in Thousands	Jun. 30, 2012	Dec. 31, 2011
Allowance for Doubtful Accounts Receivable, Current	$ 2,815	$ 8,841

Consolidated Statements Of Operations $ in Thousands	3 Months Ended		6 Months Ended
Consolidated Statements Of Operations $ in Thousands	Jun. 30, 2012 USD ($) $ / Units shares	Jun. 30, 2011 USD ($) $ / Units shares	Jun. 30, 2012 USD ($) $ / Units shares	Jun. 30, 2011 USD ($) $ / Units shares
REVENUES:
Natural gas sales	$ 635,597	$ 815,469	$ 1,140,207	$ 1,524,793
NGL sales	598,969	412,872	1,131,268	688,024
Gathering, transportation and other fees	600,806	456,797	1,101,768	869,053
Retail propane sales	11,637	220,296	87,082	748,762
Other	129,305	69,472	205,120	133,394
Total revenues	1,976,314	1,974,906	3,665,445	3,964,026
COSTS AND EXPENSES:
Cost of products sold	992,356	1,264,152	2,014,556	2,465,578
Operating expenses	260,517	222,717	435,422	443,413
Depreciation and amortization	221,767	148,530	382,968	287,786
Selling, general and administrative	122,950	78,946	271,212	142,445
Total costs and expenses	1,597,590	1,714,345	3,104,158	3,339,222
OPERATING INCOME	378,724	260,561	561,287	624,804
OTHER INCOME (EXPENSE):
Interest expense, net of interest capitalized	(281,255)	(181,517)	(494,585)	(349,446)
Bridge loan related fees	0	0	(62,241)	0
Equity in earnings of affiliates	22,463	28,819	97,695	54,260
Gain on deconsolidation of Propane Business	765	0	1,056,709	0
Losses on disposal of assets	(1,402)	(681)	(2,462)	(2,435)
Losses on extinguishments of debt	(7,821)	0	(122,844)	0
Gains (losses) on non-hedged interest rate derivatives	(44,668)	1,883	(17,178)	3,403
Other, net	17,891	2,811	31,197	(9,715)
INCOME BEFORE INCOME TAX EXPENSE	84,697	111,876	1,047,578	320,871
Income tax expense	10,175	5,224	11,754	15,127
NET INCOME	74,522	106,652	1,035,824	305,744
LESS: NET INCOME ATTRIBUTABLE TO NONCONTROLLING INTEREST	21,024	40,367	815,904	150,819
NET INCOME ATTRIBUTABLE TO PARTNERS	53,498	66,285	219,920	154,925
GENERAL PARTNER'S INTEREST IN NET INCOME	132	205	638	479
LIMITED PARTNERS' INTEREST IN NET INCOME	$ 53,366	$ 66,080	$ 219,282	$ 154,446
BASIC NET INCOME PER LIMITED PARTNER UNIT \| $ / Units	0.19	0.30	0.87	0.69
BASIC AVERAGE NUMBER OF UNITS OUTSTANDING \| shares	279,955,578	222,972,708	253,343,028	222,963,741
DILUTED NET INCOME PER LIMITED PARTNER UNIT \| $ / Units	0.19	0.30	0.86	0.69
DILUTED AVERAGE NUMBER OF UNITS OUTSTANDING \| shares	279,955,578	222,972,708	253,343,028	222,963,741

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Statement of Income and Comprehensive Income [Abstract]
Net income	$ 74,522	$ 106,652	$ 1,035,824	$ 305,744
Other comprehensive income (loss), net of tax:
Reclassification to earnings of gains and losses on derivative instruments accounted for as cash flow hedges	(7,879)	123	(7,814)	(13,416)
Change in value of derivative instruments accounted for as cash flow hedges	(501)	3,829	21,148	(7,009)
Change in value of available-for-sale securities	0	(643)	(114)	(35)
Change in other comprehensive income from equity investments	(22,208)	0	(22,208)	0
Other comprehensive income (loss), net of tax, total	(30,588)	3,309	(8,988)	(20,460)
Comprehensive income	43,934	109,961	1,026,836	285,284
Less: Comprehensive income attributable to noncontrolling interest	(4,303)	43,250	806,285	135,513
Comprehensive income attributable to partners	$ 48,237	$ 66,711	$ 220,551	$ 149,771

Consolidated Statement Of Equity - 6 months ended Jun. 30, 2012 - USD ($) $ in Thousands	Total	General Partner [Member]	Common Unitholders [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]
Balance at Dec. 31, 2011	$ 7,388,945	$ 321	$ 52,485	$ 678	$ 7,335,461
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Distributions to partners	(315,196)	(865)	(314,331)	0	0
Distributions to noncontrolling interest	(446,896)	0	0	0	(446,896)
Units issued in Southern Union Merger	2,354,490	0	2,354,490	0	0
Subsidiary units issued for cash	390,401	(21)	(13,918)	0	404,340
Subsidiary units issued in acquisition certain acquisitions	7,000	0	0	0	7,000
Non-cash compensation expense, net of units tendered by employees for tax withholdings	23,489	0	328	0	23,161
Capital Contributions from Noncontrolling Interest	9,834	0	0	0	9,834
Other, net	(7,042)	(2)	(863)	0	(6,177)
Other comprehensive loss (loss), net of tax	(8,988)	0	0	631	(9,619)
Net income	1,035,824	638	219,282	0	815,904
Balance at Jun. 30, 2012	$ 10,431,861	$ 71	$ 2,297,473	$ 1,309	$ 8,133,008

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES:
Net income	$ 1,035,824	$ 305,744
Reconciliation of net income to net cash provided by operating activities:
Depreciation and amortization	382,968	287,786
Deferred Income Taxes	3,921	30
Gain on curtailment of other postretirement benefit plans	(15,332)	0
Amortization of finance costs charged to interest	5,569	9,577
Bridge loan related fees	62,241	0
Non-cash compensation expense	23,736	23,085
Gain on deconsolidation of Propane Business	(1,056,709)	0
Losses on disposal of assets	2,462	2,435
Losses on extinguishments of debt	122,844	0
Distributions in excess of equity in earnings of affiliates, net	2,978	29,875
Other non-cash	5,863	18,604
Changes in operating assets and liabilities, net of effects of acquisitions and deconsolidation	(151,918)	21,201
Net cash provided by operating activities	424,447	698,337
CASH FLOWS FROM INVESTING ACTIVITIES:
Cash paid for acquisitions, net of cash received	(10,317)	(1,948,612)
Capital expenditures (excluding allowance for equity funds used during construction)	(1,293,903)	(794,151)
Contributions in aid of construction costs	12,056	13,967
Distributions from (advances to) affiliates, net	56,288	(22,668)
Proceeds from the sale of assets	33,676	6,925
Cash proceeds from contribution and sale of propane operations	1,442,536	0
Other	(1,997)	0
Net cash used in investing activities	(2,733,249)	(2,744,539)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings	5,964,419	5,202,535
Repayments of long-term debt	(3,101,014)	(3,420,348)
Subsidiary equity offering, net of issue costs	390,401	974,104
Distributions to partners	(315,196)	(246,016)
Debt issuance costs	(98,038)	(22,198)
Distributions to noncontrolling interests	(446,896)	(376,440)
Capital Contributions from Noncontrolling Interest	9,834	0
Other, net	(3,890)	(3,228)
Net cash provided by financing activities	2,399,620	2,108,409
INCREASE IN CASH AND CASH EQUIVALENTS	90,818	62,207
CASH AND CASH EQUIVALENTS, beginning of period	126,342	86,264
CASH AND CASH EQUIVALENTS, end of period	217,160	148,471
Southern Union Merger [Member]
CASH FLOWS FROM INVESTING ACTIVITIES:
Cash paid for acquisitions, net of cash received	$ (2,971,588)	$ 0

Operations And Organization

6 Months Ended

Jun. 30, 2012

Operations And Organization [Abstract]

Operations And Organization

OPERATIONS AND ORGANIZATION:

Business Operations

Unless the context requires otherwise, references to “we,” “us,” “our,” the “Partnership” and “ETE” mean Energy Transfer Equity, L.P. and its consolidated subsidiaries, which include ETP, ETP GP, ETP LLC, Regency, Regency GP, Regency LLC, and Southern Union. References to the “Parent Company” mean Energy Transfer Equity, L.P. on a stand-alone basis.

At June 30, 2012, our equity interests in ETP and Regency consisted of:



	General Partner Interest (as a % of total partnership interest)		IDRs		Common Units	Limited Partner Ownership (as a % and net of any treasury units)
ETP	1.5	%	100	%	52,476,059	23	%
Regency	1.6	%	100	%	26,266,791	15	%

On March 26, 2012, we acquired all of the outstanding shares of Southern Union for approximately $3.01 billion in cash and approximately 57.0 million ETE Common Units. See Note 3 for more information regarding the Southern Union Merger.

The unaudited consolidated financial statements of ETE presented herein for the three and six month periods ended June 30, 2012 and 2011 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”);


•	our wholly-owned subsidiary, Southern Union (see description of its operations below under “Business Operations”); and


•	ETP’s, Regency’s and Southern Union’s wholly-owned subsidiaries and our wholly-owned subsidiaries that own the general partner and IDR interests in ETP and Regency.

Our unaudited consolidated financial statements include the results of operations of Southern Union from March 26, 2012, the date we acquired Southern Union, through June 30, 2012.

Business Operations

The Parent Company’s principal sources of cash flow have historically derived from its direct and indirect investments in the limited partner and general partner interests in ETP and Regency. Effective with the acquisition of Southern Union, the Parent Company also generates cash flows through its wholly-owned subsidiary, Southern Union. The Parent Company’s primary cash requirements are for general and administrative expenses, debt service requirements and distributions to its partners and holders of the Preferred Units. Parent Company-only assets are not available to satisfy the debts and other obligations of ETE’s subsidiaries. In order to understand the financial condition of the Parent Company on a stand-alone basis, see Note 21 for stand-alone financial information apart from that of the consolidated partnership information included herein.

The following is a brief description of our operating entities:

•

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, a joint venture that owns and operates NGL storage, fractionation and transportation assets in Texas, Louisiana and Mississippi. Concurrent with the Parent Company's acquisition of Southern Union, ETP acquired a 50% interest in Citrus, which owns FGT (see Note 3).

•

Regency is a publicly traded partnership engaged in the gathering and processing, contract compression, treating and transportation of natural gas and the transportation, fractionation and storage of 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, Bone Spring, Avalon and Marcellus shales, as well as the Permian Delaware basin and the mid-continent region. Its assets are located in Texas, Louisiana, Arkansas, Pennsylvania, California, Mississippi, Alabama, West Virginia and the mid-continent region of the United States, which includes Kansas, Colorado and Oklahoma. Regency also holds a 30% interest in Lone Star.

•

Southern Union is engaged primarily in the transportation, storage, gathering, processing and distribution of natural gas. Southern Union owns and operates interstate pipeline that transports natural gas from the Gulf of Mexico, South Texas and the Panhandle regions of Texas and Oklahoma to major U.S. markets in the Midwest and Great Lakes regions. It owns and operates a LNG import terminal located on Louisiana's Gulf Coast. Through SUGS, it owns natural gas and NGL pipelines, cryogenic plants, treating plants and is engaged in connecting producing wells of exploration and production companies to its gathering system, treating natural gas to remove impurities to meet pipeline quality specifications, processing natural gas for the removal of NGLs and redelivering natural gas and NGLs to a variety of markets in West Texas and New Mexico. Southern Union also has regulated utility operations in Missouri and Massachusetts.

See Note 20 for discussion regarding our reportable segments.

Preparation of Interim Financial Statements

The accompanying consolidated balance sheet as of December 31, 2011, which has been derived from audited financial statements, and the unaudited interim consolidated financial statements and notes thereto of the Partnership as of June 30, 2012 and for the three and six months ended June 30, 2012 and 2011, have been prepared in accordance with 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 June 30, 2012, and the Partnership’s results of operations and cash flows for the three and six months ended June 30, 2012 and 2011. 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, 2011, as filed with the SEC on February 22, 2012.

Certain prior period amounts have been reclassified to conform to the 2012 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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+ Details

Estimates and Significant Accounting Policies	6 Months Ended
Estimates and Significant Accounting Policies	Jun. 30, 2012
Estimates Disclosure [Abstract]
Estimates	ESTIMATES AND SIGNIFICANT ACCOUNTING POLICIES: 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 values and results could differ from those estimates. Significant Accounting Policies As a result of the Southern Union Merger on March 26, 2012, the following significant accounting policies have been added to our significant accounting policies described in our Form 10-K for the year ended December 31, 2011. Pensions and Other Postretirement Benefit Plans Employers are required to recognize in their balance sheets the overfunded or underfunded status of defined benefit pension and other postretirement plans, measured as the difference between the fair value of the plan assets and the benefit obligation (the projected benefit obligation for pension plans and the accumulated postretirement benefit obligation for other postretirement plans). Each overfunded plan is recognized as an asset and each underfunded plan is recognized as a liability. Employers must recognize the change in the funded status of the plan in the year in which the change occurs through Accumulated other comprehensive income in equity. See Note 14 for further information regarding pensions and other postretirement benefit plans. Revenue Recognition for Southern Union's Natural Gas Distribution Operations In Southern Union's natural gas distribution operations, natural gas utility customers are billed on a monthly-cycle basis. The related cost of natural gas and revenue taxes are matched with cycle-billed revenues through utilization of purchased natural gas adjustment provisions in tariffs approved by the regulatory agencies having jurisdiction. Revenues from natural gas delivered but not yet billed are accrued, along with the related natural gas purchase costs and revenue-related taxes.

Acquisitions

6 Months Ended

Jun. 30, 2012

Acquisitions and Dispositions [Abstract]

Acquisitions

ACQUISITIONS:

Southern Union Merger

On March 26, 2012, Sigma Acquisition Corporation, a Delaware corporation and a wholly-owned subsidiary of ETE, completed its acquisition of Southern Union. Southern Union is the surviving entity in the merger and operates as a wholly-owned subsidiary of ETE. The assets acquired as a result of this merger significantly expand our existing geographic footprint of natural gas pipeline and natural gas transportation capacity and into natural gas utilities distribution, and are complementary to the assets owned and operated by our other entities.

Under the terms of the merger agreement, Southern Union stockholders were able to elect to exchange each outstanding share of Southern Union common stock for $44.25 in cash or 1.00 ETE Common Unit, with no more than 60% of the aggregate merger consideration payable in cash and no more than 50% of the merger consideration payable in ETE Common Units. Based on the final results of the merger consideration, elections were as follows:


•	approximately 54% of outstanding Southern Union shares, or 67,985,929 shares, received cash for total cash consideration of $3.01 billion; and


•	approximately 46% of outstanding Southern Union shares, or 56,981,860 shares, received ETE Common Units valued at $2.35 billion at the time of the merger.

Effective with the closing of the transaction, Southern Union's common stock is no longer publicly traded.

Citrus Merger

In connection with the Southern Union Merger on March 26, 2012, ETP completed its acquisition of CrossCountry, a subsidiary of Southern Union which owns an indirect 50% interest in Citrus, the owner of FGT. The total merger consideration was approximately $2.0 billion, consisting of approximately $1.9 billion in cash and approximately 2.25 million ETP Common Units. See Note 4 for more information regarding ETP's equity method investment in Citrus.

In connection with the Citrus Merger, we relinquished our rights to an aggregate $220 million of IDRs from ETP that we would otherwise be entitled to receive over 16 consecutive quarters following the closing of the merger.

Pursuant to the merger agreement, we also granted ETP a right of first offer with respect to any disposition by us or SUGS, a subsidiary of Southern Union that owns and operates a natural gas gathering and processing system serving the Permian Basin in West Texas and New Mexico.

Summary of Assets Acquired and Liabilities Assumed

We accounted for the Southern Union Merger using the acquisition method of accounting, which requires, among other things, that assets acquired and liabilities assumed be recognized on the balance sheet at their fair values as of the acquisition date. Our consolidated balance sheet presented as of June 30, 2012 reflects the preliminary purchase price allocations based on available information. Certain amounts included in the preliminary purchase price allocation as of June 30, 2012 have been changed from amounts reflected as of March 31, 2012 based on management's review of the valuation. Management is continuing to review the valuation and expects to be substantially complete with the purchase price allocation in the third quarter of 2012.

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



Total current assets	$	561,038
Property, plant and equipment (useful lives of 25 - 30 years)	6,958,768
Goodwill	2,030,273
Intangible assets (weighted average useful life of 17.5 years)	55,000
Investments in unconsolidated affiliates	2,022,784
Other assets	162,576
	11,790,439

Long-term debt obligations, including current portion	3,778,706
Deferred income taxes	1,698,352
Other liabilities	950,511
	6,427,569
Total consideration	5,362,870
Cash received	36,792
Total consideration, net of cash received	$	5,326,078

Goodwill was allocated by reportable business segment as $1.17 billion to the Southern Union Transportation and Storage segment; $598.3 million to the Southern Union Gathering and Processing segment; $251.8 million to the Southern Union Distribution segment; and $10.8 million to Corporate and other.

Other liabilities assumed include approximately $46.0 million of AROs, which are primarily related to owned natural gas storage wells and offshore lines and platforms. At the end of the useful life of these underlying assets, Southern Union is legally or contractually required to abandon in place or remove the asset. An ARO is required to be recorded when a legal obligation to retire an asset exists and such obligation can be reasonably estimated. Although a number of other onshore assets in Southern Union's system are subject to agreements that give rise to an ARO upon the discontinued use of the assets, AROs were not recorded because these assets have an indeterminate removal or abandonment date given the expected continued use of the assets with proper maintenance or replacement. As of June 30, 2012 AROs assumed as a result of the Southern Union Merger were approximately $46.5 million.

Pro Forma Results of Operations

The following unaudited pro forma consolidated results of operations for the three and six months ended June 30, 2012 and 2011 are presented as if the Southern Union Merger had been completed on January 1, 2011. Actual results for the three months ended June 30, 2012 include Southern Union for the entire period; however, pro forma amounts shown below reflect adjustments for certain acquisition-related costs recognized during the period.



	Three Months Ended June 30,				Six Months Ended June 30,
	2012		2011		2012		2011
Revenues	$	1,976,314	$	2,606,513	$	4,299,094	$	5,342,455
Net income	84,983		127,798		1,173,075		348,925
Net income attributable to partners	63,959		80,646		354,977		184,536
Basic net income per Limited Partner unit	$	0.23	$	0.29	$	1.26	$	0.66
Diluted net income per Limited Partner unit	$	0.23	$	0.29	$	1.26	$	0.66

The pro forma consolidated results of operations include adjustments to:

•include the results of Southern Union 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 transactions;

•adjust for one-time expenses; and

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

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

Southern Union's revenue included in our consolidated statement of operations was approximately $472.5 million and $512.2 million for the three months ended June 30, 2012 and since the acquisition date to June 30, 2012, respectively. Southern Union's net income and net loss included in our consolidated statement of operations were approximately $11.7 million and $26.8 million for the three months ended June 30, 2012 and since the acquisition date to June 30, 2012, respectively.

Expenses Related to the Southern Union Merger

As a result of the acquisition, we recognized $8.3 million of merger-related costs during the three months ended June 30, 2012 and $38.2 million during the six months ended June 30, 2012.

Pending Sunoco Merger

On April 30, 2012, ETP announced that it had entered into a definitive merger agreement whereby ETP will acquire Sunoco in exchange for ETP Common Units and cash. Under the terms of the merger agreement, Sunoco shareholders would receive, for each Sunoco common share, either $50.00 in cash, 1.0490 ETP Common Units or a combination of $25.00 in cash and 0.5245 of an ETP Common Unit. The cash and unit elections, however, will be subject to proration to ensure that the total amount of cash paid and the total number of ETP Common Units issued in the merger to Sunoco shareholders as a whole are equal to the total amount of cash and number of ETP Common Units that would have been paid and issued if all Sunoco shareholders received the standard mix of consideration. Upon closing, Sunoco shareholders are expected to own approximately 20% of ETP's outstanding limited partner units. This transaction is expected to close in the third or fourth quarter of 2012, subject to approval of Sunoco's shareholders and customary regulatory approvals.

Sunoco owns the general partner interest of Sunoco Logistics, consisting of a 2% general partner interest, 100% of the IDRs, and 32.4% of the outstanding common units of Sunoco Logistics. Sunoco also generates cash flow from a portfolio of retail outlets for the sale of gasoline and middle distillates in the east coast, midwest and southeast areas of the United States. Sunoco Logistics is a publicly traded limited partnership that owns and operates a logistics business consisting of a geographically diverse portfolio of complementary pipeline, terminalling and crude oil acquisition and marketing assets.

Pending Holdco Transaction

On June 15, 2012, ETE and ETP entered into a transaction agreement pursuant to which, immediately following and subject to the closing of the Sunoco merger, (i) ETE will contribute its interest in Southern Union into an ETP-controlled entity in exchange for a 60% equity interest in the new entity, to be called Holdco and (ii) ETP will contribute its interest in Sunoco to Holdco and will retain a 40% equity interest in Holdco (the "Holdco Transaction"). Prior to the contribution of Sunoco to Holdco, Sunoco will contribute its interests in Sunoco Logistics to ETP in exchange for 50,706,000 ETP Class F Units representing limited partner interest in ETP ("ETP Class F Units") plus an additional number of ETP Class F Units determined based upon the amount of cash contributed to ETP by Sunoco at the closing of the merger, as calculated in accordance with the merger agreement. The ETP Class F Units will be entitled to 35% of the quarterly cash distributions generated by ETP and its subsidiaries other than Holdco, subject to a maximum cash distribution of $3.75 per ETP Class F Unit per year. Pursuant to a stockholders agreement between ETE and ETP, ETP will control Holdco. Consequently, ETP expects to consolidate Holdco (including Sunoco and Southern Union) in its consolidated financial statements subsequent to consummation of the Holdco Transaction.

Under the terms of the Holdco Transaction agreement, we will relinquish an aggregate of $210 million of IDRs over 12 consecutive quarters following the closing of the Holdco 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
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-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.

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-Name Accounting Standards Codification
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+ Details

Investments in Affiliates

6 Months Ended

Jun. 30, 2012

INVESTMENTS IN AFFILIATES [Abstract]

Investments in and Advances to Affiliates

INVESTMENTS IN AFFILIATES:

Citrus Corp.

ETP acquired a 50% interest in Citrus, which owns 100% of FGT on March 26, 2012. A subsidiary of Kinder Morgan, Inc. owns the remaining 50% interest in Citrus. In exchange for the interest in Citrus, Southern Union received $1.9 billion in cash and $105 million of ETP Common Units. ETP initially recorded its investment in Citrus at $2.0 billion, which exceeded its proportionate share of Citrus' equity by $1.03 billion, all of which is treated as equity method goodwill due to the application of regulatory accounting.

AmeriGas Partners, L.P.

On January 12, 2012, ETP contributed its Propane Business to AmeriGas in exchange for approximately $1.46 billion in cash and approximately 29.6 million AmeriGas Common Units valued at $1.12 billion at the time of the contribution. In addition, AmeriGas assumed approximately $71 million of existing debt of the Propane Business. ETP recognized a gain on deconsolidation of $1.06 billion and recorded equity in losses of $36.4 million and equity in earnings of $3.1 million related to AmeriGas for the three and six months ended June 30, 2012, respectively.

ETP's investment in AmeriGas initially reflected $630.0 million in excess of the proportionate share of AmeriGas' limited partners' capital. Of this excess fair value, $288.6 million is being amortized over a weighted average period of 14 years and $341.4 million is being treated as equity method goodwill and non-amortizable intangible assets.

We have not reflected the Propane operations as discontinued operations as ETP will have a continuing involvement in this business as a result of the investment in AmeriGas.

In June 2012, we sold the remainder of our retail propane operations, consisting of our cylinder exchange business, to a third party. In connection with the contribution agreement with AmeriGas, certain excess sales proceeds from the sale of the cylinder exchange business were remitted to AmeriGas, and we received net proceeds of approximately $43.0 million.

Midcontinent Express Pipeline LLC

Regency owns a 50% interest in MEP, which owns approximately 500 miles of natural gas pipelines that extend from Southeast Oklahoma, across Northeast Texas, Northern Louisiana and Central Mississippi to an interconnect with the Transcontinental natural gas pipeline system in Butler, Alabama.

RIGS Haynesville Partnership Co.

Regency owns a 49.99% interest in HPC, which, through its ownership of the RIGS, delivers natural gas from Northwest Louisiana to downstream pipelines and markets through a 450-mile intrastate pipeline system.

Fayetteville Express Pipeline LLC

ETP owns a 50% interest in the FEP, which owns an approximately 185-mile natural gas pipeline that originates in Conway County, Arkansas, continues eastward through White County, Arkansas and terminates at an interconnect with Trunkline Gas Company in Panola County, Mississippi.

Summarized Financial Information

The following tables present aggregated selected income statement data for our unconsolidated affiliates, including AmeriGas, Citrus, FEP, HPC and MEP (on a 100% basis for all periods presented).



	Three Months Ended June 30,				Six Months Ended June 30,
	2012		2011		2012		2011
Revenue	$	1,045,245	$	809,430	$	2,411,123	$	1,964,584
Operating income	220,202		208,911		534,284		494,618
Net income	49,512		93,282		266,743		328,570

In addition to the equity method investments described above, ETP, Regency and Southern Union each have other insignificant equity method investments.

Cash And Cash Equivalents

6 Months Ended

Jun. 30, 2012

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.

Non-cash investing and financing activities are as follows:



	Six Months Ended June 30,
	2012			2011
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures	$	484,936		$	106,047
Accrued advances to affiliates	$	3,844		$	—
Gain (loss) from subsidiary common unit transactions	$	(13,939	)	$	92,074
AmeriGas limited partner interest received in Propane Contribution (see Note 4)	$	1,123,003		$	—
NON-CASH FINANCING ACTIVITIES:
Issuance of common units in connection with Southern Union Merger (see Note 3)	$	2,354,490		$	—
Subsidiary issuances of common units in connection with acquisitions	$	112,000		$	—

Inventories (Notes)

6 Months Ended

Jun. 30, 2012

Inventory, Net [Abstract]

Inventories

INVENTORIES:

Inventories consisted of the following:



	June 30, 2012		December 31, 2011
Natural gas and NGLs, excluding propane	$	305,279	$	146,132
Propane	—		86,958
Appliances, parts and fittings and other	138,463		94,873
Total inventories	$	443,742	$	327,963

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	6 Months Ended
Goodwill And Intangible Assets	Jun. 30, 2012
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	GOODWILL: A net increase in goodwill of $1.42 billion was recorded during the six months ended June 30, 2012, which includes goodwill of $2.03 billion recorded as a result of the Southern Union Merger partially offset by a decrease of $605.6 million as a result of ETP's contribution of its Propane Business to AmeriGas. The goodwill recorded as a result of the Southern Union Merger was primarily due to expected commercial and operational synergies and is subject to change based on final purchase price allocations. None of the goodwill recorded as a result of this transaction is deductible for tax purposes. See Note 3 for further discussion of Southern Union Merger.

- 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

6 Months Ended

Jun. 30, 2012

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.

We have marketable securities, commodity derivatives, interest rate derivatives, the Preferred Units and embedded derivatives in 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 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 as the primary input, the LIBOR curve, is based on quotes from an active exchange of Eurodollar futures for the same period as the future interest swap settlements, and we 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.

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 June 30, 2012 was $19.33 billion and $18.07 billion, respectively. As of December 31, 2011, the aggregate fair value and carrying amount of our consolidated debt obligations was $12.21 billion and $11.37 billion, respectively. The fair value of our consolidated debt obligations is a Level 2 valuation based on the observable inputs used for similar liabilities.

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 June 30, 2012 and December 31, 2011 based on inputs used to derive their fair values:



	Fair Value Measurements at June 30, 2012
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Marketable securities	$	11		$	11		$	—		$	—
Interest rate derivatives	50,543			—			50,543			—
Commodity derivatives:
Condensate — Forward Swaps	3,974			—			3,974			—
Natural Gas:
Basis Swaps IFERC/NYMEX	53,966			53,966			—			—
Swing Swaps IFERC	5,589			1,390			4,199			—
Fixed Swaps/Futures	81,517			63,572			17,945			—
Options — Puts	3,688			—			3,688			—
Forward Physical Contracts	976			—			976			—
NGLs:
Swaps	7,681			—			7,681			—
Options — Puts	1,523			—			1,523			—
Power:
Forwards	42,504			6,196			36,308			—
Options — Puts	135			135			—			—
Total commodity derivatives	201,553			125,259			76,294			—
Total Assets	$	252,107		$	125,270		$	126,837		$	—
Liabilities:
Interest rate derivatives	$	(233,447	)	$	—		$	(233,447	)	$	—
Preferred Units	(319,860		)	—			—			(319,860		)
Embedded derivatives in the Regency Preferred Units	(30,644		)	—			—			(30,644		)
Natural Gas:
Basis Swaps IFERC/NYMEX	(73,804		)	(73,804		)	—			—
Swing Swaps IFERC	(7,504		)	(2,668		)	(4,836		)	—
Fixed Swaps/Futures	(81,314		)	(61,002		)	(20,312		)	—
Options — Calls	(1		)	—			(1		)	—
Options — Puts	(55		)	—			(55		)	—
Forward Physical Contracts	(386		)	—			(386		)	—
Power:
Forwards	(41,444		)	(776		)	(40,668		)	—
Total commodity derivatives	(204,508		)	(138,250		)	(66,258		)	—
Total Liabilities	$	(788,459	)	$	(138,250	)	$	(299,705	)	$	(350,504	)



	Fair Value Measurements at December 31, 2011
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Marketable securities	$	1,229		$	1,229		$	—		$	—
Interest rate derivatives	36,301			—			36,301			—
Commodity derivatives:
Condensate — Forward Swaps	538			—			538			—
Natural Gas:
Basis Swaps IFERC/NYMEX	62,924			62,924			—			—
Swing Swaps IFERC	15,002			1,687			13,315			—
Fixed Swaps/Futures	218,479			214,572			3,907			—
Options — Puts	6,435			—			6,435			—
Forward Physical Contracts	699			—			699			—
NGLs:
Swaps	94			—			94			—
Options — Puts	309			—			309			—
Propane — Forwards/Swaps	9			—			9			—
Total commodity derivatives	304,489			279,183			25,306			—
Total Assets	$	342,019		$	280,412		$	61,607		$	—
Liabilities:
Interest rate derivatives	$	(117,490	)	$	—		$	(117,490	)	$	—
Preferred Units	(322,910		)	—			—			(322,910		)
Embedded derivatives in the Regency Preferred Units	(39,049		)	—			—			(39,049		)
Commodity derivatives:
Condensate — Forward Swaps	(1,567		)	—			(1,567		)	—
Natural Gas:
Basis Swaps IFERC/NYMEX	(82,290		)	(82,290		)	—			—
Swing Swaps IFERC	(16,074		)	(3,061		)	(13,013		)	—
Fixed Swaps/Futures	(148,111		)	(148,111		)	—			—
Options — Calls	(12		)	—			(12		)	—
Forward Physical Contracts	(712		)	—			(712		)	—
NGLs — Swaps	(8,561		)	—			(8,561		)	—
Propane — Forwards/Swaps	(4,131		)	—			(4,131		)	—
Total commodity derivatives	(261,458		)	(233,462		)	(27,996		)	—
Total Liabilities	$	(740,907	)	$	(233,462	)	$	(145,486	)	$	(361,959	)

The following table presents the material unobservable inputs used to estimate the fair value of the Preferred Units and the embedded derivatives in Regency's Preferred Units:



	Unobservable Input	June 30, 2012
Preferred Units	Assumed Yield	7.23	%
Embedded derivatives in the Regency Preferred Units	Credit Spread	6.83	%
	Volatility	18.02	%

Changes in the remaining term of the Preferred Units, U.S. Treasury yields and valuations in related instruments would cause a change in the yield to value the Preferred Units. Changes in Regency's cost of equity and U. S. Treasury yields would cause a change in the credit spread used to value the embedded derivatives in the Regency Preferred Units. Changes in Regency's historical unit price volatility would cause a change in the volatility used to value the embedded derivatives.

The following table presents a reconciliation of the beginning and ending balances for our Level 3 financial instruments measured at fair value on a recurring basis using significant unobservable inputs for the six months ended June 30, 2012. There were no transfers between the fair value hierarchy levels during the six months ended June 30, 2012 or 2011.



Balance, December 31, 2011	$	(361,959	)
Net unrealized gain included in other income (expense)	11,455
Balance, June 30, 2012	$	(350,504	)

- 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

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-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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-SubTopic 10
-Section 50
-Paragraph 28
-URI http://asc.fasb.org/extlink&oid=6957238&loc=d3e14064-108612

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-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
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-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=6957238&loc=d3e14172-108612

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-Publisher FASB
-Name Accounting Standards Codification
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+ Details

Net Income Per Limited Partner Unit

6 Months Ended

Jun. 30, 2012

Earnings Per Share [Abstract]

Net Income Per Limited Partner Unit

NET INCOME PER LIMITED PARTNER UNIT:

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



	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
Basic Net Income per Limited Partner Unit:
Limited Partners’ interest in net income	$	53,366		$	66,080		$	219,282		$	154,446
Weighted average Limited Partner units	279,955,578			222,972,708			253,343,028			222,963,741
Basic net income per Limited Partner unit	$	0.19		$	0.30		$	0.87		$	0.69
Diluted Net Income per Limited Partner Unit:
Limited Partners’ interest in net income	$	53,366		$	66,080		$	219,282		$	154,446
Dilutive effect of equity-based compensation of subsidiaries	(107		)	(132		)	(1,249		)	(402		)
Diluted net income available to Limited Partners	$	53,259		$	65,948		$	218,033		$	154,044
Weighted average Limited Partner units	279,955,578			222,972,708			253,343,028			222,963,741
Diluted net income per Limited Partner unit	$	0.19		$	0.30		$	0.86		$	0.69

The calculation above for the three and six months ended June 30, 2012 for diluted net income 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 11.

Debt Obligations

6 Months Ended

Jun. 30, 2012

Debt Obligations [Abstract]

Debt Obligations

DEBT OBLIGATIONS:

Our debt obligations consisted of the following:



	June 30, 2012			December 31, 2011
Parent Company Indebtedness:
ETE Senior Notes, due October 15, 2020	$	1,800,000		$	1,800,000
ETE Senior Secured Term Loan, due March 26, 2017	2,000,000			—
ETE Senior Secured Revolving Credit Facility	10,000			71,500
Subsidiary Indebtedness:
ETP Senior Notes (aggregated)	7,800,000			6,550,000
Transwestern Senior Unsecured Notes (aggregated)	870,000			870,000
HOLP Senior Secured Notes (aggregated)	—			71,314
Regency Senior Notes (aggregated)	1,262,500			1,350,000
Southern Union Senior Notes:
7.6% Senior Notes due February 1, 2024	359,765			—
8.25% Senior Notes due November 14, 2029	300,000			—
7.24% to 9.44% First Mortgage Bonds due February 15, 2020 to December 15, 2027	19,500			—
7.2% Junior Subordinated Notes due November 1, 2066	600,000			—
Notes Payable	7,465			—
Panhandle:
6.05% Senior Notes due August 15, 2013	250,000			—
6.2% Senior Notes due November 1, 2017	300,000			—
7.0% Senior Notes due June 15, 2018	400,000			—
8.125% Senior Notes due June 1, 2019	150,000			—
7.0% Senior Notes due July 15, 2029	66,305			—
Term Loan due February 23, 2015	455,000			—
Revolving Credit Facilities:
ETP Revolving Credit Facility	493,449			314,438
Regency Revolving Credit Facility	515,000			332,000
Southern Union Revolving Credit Facility	235,000			—
Other Long-Term Debt	22,022			10,434
Unamortized discounts, net	(55,963		)	(10,309		)
Fair value adjustments related to interest rate swaps	213,342			11,647
	18,073,385			11,371,024
Current maturities	(113,921		)	(424,160		)
	$	17,959,464		$	10,946,864

The following table reflects future maturities of long-term debt for each of the next five years and thereafter. These amounts exclude $157.4 million in net unamortized premiums and fair value adjustments related to interest rate swaps:



2012 (remainder)	$	111,410
2013	604,951
2014	900,045
2015	765,308
2016	1,476,516
Thereafter	14,057,776
Total	$	17,916,006

ETE Senior Secured Term Loan

We used the net proceeds from our Senior Secured Term Loan, along with proceeds received from ETP in the Citrus Merger, to fund the cash portion of the Southern Union Merger and pay related fees and expenses, including existing borrowings under our revolving credit facility and for general partnership purposes.

Borrowings bear interest at either the Eurodollar rate plus an applicable margin or the alternative base rate plus an applicable margin. The alternative base rate used to calculate interest on base rate loans will be calculated using the greater of a prime rate, a federal funds effective rate plus 0.50%, and an adjusted one-month LIBOR rate plus 1.00%. The applicable margins are 3.0% for Eurodollar loans and from 2.0% for base rate loans. The effective interest rate on the amount outstanding as of June 30, 2012 was 3.75%.

Southern Union Junior Subordinated Notes

Southern Union has interest rate swap agreements that effectively fix the interest rate applicable to the floating rate on $525.0 million of the $600.0 million Junior Subordinated Notes due 2066. The interest rate on the remaining notes is a variable rate based upon the three-month LIBOR rate plus 3.0175%. The balance of the variable rate portion of the Junior Subordinated Notes was $75.0 million at an effective interest rate of 3.48% at June 30, 2012.

Panhandle Term Loans

In February 2012, Southern Union refinanced LNG Holdings' $455.0 million term loan due March 2012 with an unsecured three-year term loan facility due February 2015, with LNG Holdings as borrower and PEPL and Trunkline LNG as guarantors and a floating interest rate tied to LIBOR plus a margin based on the rating of PEPL's senior unsecured debt. The effective interest rate of PEPL's term loan was 1.87% at June 30, 2012.

Bridge Term Loan Facility

Upon obtaining permanent financing for the Southern Union Merger in March 2012, we terminated the 364-day Bridge Term Loan Facility. For the six months ended June 30, 2012, bridge loan related fees reflects the recognition of $62.2 million of commitment fees upon termination of the facility.

ETP Senior Notes

In January 2012 ETP completed a public offering of $1.00 billion aggregate principal amount of 5.20% Senior Notes due February 1, 2022 and $1.00 billion aggregate principal amount of 6.50% Senior Notes due February 1, 2042 and used the net proceeds of $1.98 billion from the offering to fund the cash portion of the purchase price of the Citrus Merger 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.

In January 2012 ETP announced a tender offer for approximately $750.0 million aggregate principal amount of specified series of the ETP Senior Notes. The tender offer consisted of two separate offers: an Any and All Offer and a Maximum Tender Offer. The senior notes described below were repurchased under the offers for a total cost of $885.9 million and a loss on extinguishment of debt of $115.0 million was recorded during the six months ended June 30, 2012.

In the Any and All Offer ETP offered to purchase any and all of its 5.65% Senior Notes due August 1, 2012, at a fixed price. Pursuant to the Any and All Offer, ETP purchased $292 million aggregate principal amount of its 5.65% Senior Notes due August 1, 2012.

In the Maximum Tender Offer ETP offered to purchase certain series of outstanding ETP Senior Notes at a fixed spread over the index rate. Pursuant to the Maximum Tender Offer, on February 7, 2012, ETP purchased $200 million aggregate principal amount of its 9.7% Senior Notes due March 15, 2019, $200 million aggregate principal amount of its 9.0% Senior Notes due April 15, 2019 and $58.1 million aggregate principal amount of its 8.5% Senior Notes due April 15, 2014.

Regency Senior Notes

In May 2012, Regency exercised its option to redeem 35%, or $87.5 million, of its outstanding senior notes due 2016 at a price of 109.375%.

Revolving Credit Facilities

Parent Company Credit Facility

As of June 30, 2012, we had $10.0 million outstanding borrowings under the Parent Company Credit Facility and the amount available for future borrowings was $190.0 million. The weighted average interest rate on the total amount outstanding as of June 30, 2012 was 3.74%.

ETP Credit Facility

As of June 30, 2012, ETP had a balance of $493.4 million outstanding under the ETP Credit Facility, and the amount available for future borrowings was $1.98 billion after taking into account letters of credit of $30.3 million. The weighted average interest rate on the total amount outstanding as of June 30, 2012 was 1.74%.

Regency Credit Facility

As of June 30, 2012, there was a balance outstanding under the Regency Credit Facility of $515.0 million in revolving credit loans and approximately $9.0 million in letters of credit. The total amount available under the Regency Credit Facility, as of June 30, 2012, which is reduced by any letters of credit, was approximately $376.0 million. The weighted average interest rate on the total amount outstanding as of June 30, 2012 was 2.88%.

Southern Union Credit Facilities

The Southern Union Credit Facility provides for a $700 million revolving credit facility which matures on May 20, 2016. Borrowings on the Southern Union Credit Facility are available for working capital, other general company purposes and letter of credit requirements. The interest rate and commitment fee under the Southern Union Credit Facility are calculated using a pricing grid, which is based on the credit ratings for Southern Union's senior unsecured notes. The annualized interest rate for the Southern Union Credit Facility was 1.87% as of June 30, 2012.

Covenants Related to Our Credit Agreements

Covenants Related to Southern Union

Southern Union is not party to any lending agreement that would accelerate the maturity date of any obligation due to a failure to maintain any specific credit rating, nor would a reduction in any credit rating, by itself, cause an event of default under any of Southern Union’s lending agreements. Covenants exist in certain of the Southern Union’s debt agreements that require Southern Union to maintain a certain level of net worth, to meet certain debt to total capitalization ratios and to meet certain ratios of earnings before depreciation, interest and taxes to cash interest expense. A failure by Southern Union to satisfy any such covenant would give rise to an event of default under the associated debt, which could become immediately due and payable if Southern Union did not cure such default within any permitted cure period or if Southern Union did not obtain amendments, consents or waivers from its lenders with respect to such covenants.

Southern Union’s restrictive covenants include restrictions on debt levels, restrictions on liens securing debt and guarantees, restrictions on mergers and on the sales of assets, capitalization requirements, dividend restrictions, cross default and cross-acceleration and prepayment of debt provisions. A breach of any of these covenants could result in acceleration of Southern Union’s debt and other financial obligations and that of its subsidiaries. Under the current credit agreements, the significant debt covenants and cross defaults are as follows:


•	Under the Southern Union Credit Facility, the consolidated debt to total capitalization ratio, as defined therein, cannot exceed 65%;


•	Under the Southern Union Credit Facility, Southern Union must maintain an earnings before interest, tax, depreciation and amortization interest coverage ratio of at least 2.00 times;


•	Under Southern Union’s First Mortgage Bond indentures for the Fall River Gas division of New England Gas Company, Southern Union’s consolidated debt to total capitalization ratio, as defined therein, cannot exceed 70% at the end of any calendar quarter; and


•	All of Southern Union’s major borrowing agreements contain cross-defaults if Southern Union defaults on an agreement involving at least $10 million of principal.

In addition to the above restrictions and default provisions, Southern Union and/or its subsidiaries are subject to a number of additional restrictions and covenants. These restrictions and covenants include limitations on additional debt at some of its subsidiaries; limitations on the use of proceeds from borrowing at some of its subsidiaries; limitations, in some cases, on transactions with its affiliates; limitations on the incurrence of liens; potential limitations on the abilities of some of its subsidiaries to declare and pay dividends and potential limitations on some of its subsidiaries to participate in Southern Union’s cash management program; and limitations on Southern Union’s ability to prepay debt.

Compliance with Our Covenants

We were in compliance with all requirements, tests, limitations, and covenants related to our respective credit agreements as of June 30, 2012.

- 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	6 Months Ended
Redeemable Preferred Units	Jun. 30, 2012
Temporary Equity Disclosure [Abstract]
Redeemable Preferred Units [Text Block]	REDEEMABLE PREFERRED UNITS: ETE Preferred Units The Parent Company has outstanding 3,000,000 Series A Convertible Preferred Units to an affiliate of GE Energy Financial Services, Inc. having an aggregate liquidation preference of $300.0 million. These units are reflected as a non-current liability in our consolidated balance sheets. 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 had 4,371,586 Regency Preferred Units outstanding at June 30, 2012, which were convertible into 4,645,229 Regency Common Units. If outstanding on September 2, 2029, the Regency Preferred Units are mandatorily redeemable for $80.0 million plus all accrued but unpaid distributions thereon. Holders of the Regency Preferred Units receive fixed quarterly cash distributions of $0.445 per unit. Holders can elect to convert Regency Preferred Units to Regency Common Units at any time in accordance with Regency’s Partnership Agreement.

Equity

6 Months Ended

Jun. 30, 2012

Partners' Capital Notes [Abstract]

Equity

EQUITY:

ETE Common Units Issued

The change in ETE Common Units during the six months ended June 30, 2012 was as follows:



	Number of Units
Outstanding at December 31, 2011	222,972,708
Issuance of restricted units under equity incentive plan	740
Issuance of common units in connection with Southern Union Merger (See Note 3)	56,982,160
Outstanding at June 30, 2012	279,955,608

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 six months ended June 30, 2012, we recognized decreases in partners’ capital of $13.9 million.

Sales of Common Units by ETP

On July 3, 2012, ETP issued 15,525,000 ETP Common Units representing limited partner interests at $44.57 per ETP Common Unit in a public offering. Proceeds, net of commissions, of approximately $671.1 million from the offering 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.

During the six months ended June 30, 2012, ETP received proceeds from units issued pursuant to an Equity Distribution Agreement with Credit Suisse Securities (USA) LLC of $76.7 million, net of commissions, which were used for general partnership purposes. No ETP Common Units remain available to be issued under the ETP Equity Distribution Agreement as of June 30, 2012.

For the six months ended June 30, 2012, distributions of approximately $16.8 million were reinvested under its DRIP resulting in the issuance of 379,258 ETP Common Units. As of June 30, 2012, a total of 5,017,063 ETP Common Units remain available to be issued under this registration statement.

ETP issued approximately 2.25 million ETP Common Units to Southern Union as a portion of consideration in the Citrus Merger. See Note 3 for additional discussion.

Sale of Common Units by Regency

In March 2012, Regency issued 12,650,000 Regency Common Units through a public offering. The net proceeds of approximately $296.8 million were used to repay borrowings outstanding under the Regency Credit Facility and were used to redeem 35% in aggregate principal amount of its outstanding Senior Notes due 2016 and pay related premium expenses and interest.

On June 19, 2012, Regency entered into an Equity Distribution Agreement with Citi under which Regency may offer and sell Regency Common Units, having an aggregate offering price of up to $200 million from time to time through Citi, as sales agent for Regency. Sales of these units, if any, made under the Regency Equity Distribution Agreement will be made by means of ordinary brokers’ transactions on the New York Stock Exchange at market prices, in block transactions, or as otherwise agreed upon by Regency and Citi. Under the terms of this agreement, Regency may also sell Regency Common Units to Citi as principal for its own account at a price agreed upon at the time of sale. Any sale of Regency Common Units to Citi as principal would be pursuant to the terms of a separate agreement between the Partnership and Citi. Regency intends to use the net proceeds from the sale of these units for general partnership purposes. As of June 30, 2012, Regency has not issued any Regency Common Units pursuant to this agreement.

Parent Company Quarterly Distributions of Available Cash

Following are distributions declared and/or paid by us subsequent to December 31, 2011:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2011	February 7, 2012	February 17, 2012	$	0.625
March 31, 2012	May 4, 2012	May 18, 2012	0.625
June 30, 2012	August 6, 2012	August 17, 2012	0.625

ETP Quarterly Distributions of Available Cash

Following are distributions declared and/or paid by ETP subsequent to December 31, 2011:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2011	February 7, 2012	February 14, 2012	$	0.89375
March 31, 2012	May 4, 2012	May 15, 2012	0.89375
June 30, 2012	August 6, 2012	August 14, 2012	0.89375

Regency Quarterly Distributions of Available Cash

Following are distributions declared and/or paid by Regency subsequent to December 31, 2011:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2011	February 6, 2012	February 13, 2012	$	0.46
March 31, 2012	May 7, 2012	May 14, 2012	0.46
June 30, 2012	August 6, 2012	August 14, 2012	0.46

Accumulated Other Comprehensive Income

The following table presents the components of AOCI, net of tax:



	June 30, 2012			December 31, 2011
Net gains on commodity related hedges	$	15,030		$	1,696
Unrealized gains on available-for-sale securities	—			114
Equity investments, net	(22,208		)	—
Subtotal	(7,178		)	1,810
Amounts attributable to noncontrolling interest	8,487			(1,132		)
Total AOCI included in partners’ capital, net of tax	$	1,309		$	678

- 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	6 Months Ended
Unit-Based Compensation Plans	Jun. 30, 2012
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, DERs, common unit appreciation rights, and other unit-based awards. ETE Long-Term Incentive Plan During the six months ended June 30, 2012, no awards were granted to ETE employees. As of June 30, 2012 a total of 76,172 unit awards remain unvested, including the new awards granted to ETE directors during the period. We expect to recognize a total of $0.9 million in compensation expense over a weighted average period of 1.7 years related to unvested awards. ETP Unit-Based Compensation Plans During the six months ended June 30, 2012, ETP employees were granted a total of 62,917 unvested awards with five-year service vesting requirements, and directors were granted a total of 4,400 unvested awards with three-year service vesting requirements. The weighted average grant-date fair value of these awards was 46.99 per unit. As of June 30, 2012 a total of 2,369,652 unit awards remain unvested, including the new awards granted during the period. ETP expects to recognize a total of $61.8 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 There was no Regency Common Unit Option activity for the six months ended June 30, 2012. The aggregate intrinsic value and weighted average contractual term in years as of June 30, 2012 for the outstanding and exercisable common unit options was $0.3 million and 3.9 years, respectively. During the six months ended June 30, 2011, Regency received $0.7 million in proceeds from the exercise of unit options. Phantom Units During the six months ended June 30, 2012, Regency employees and directors were granted 7,250 Regency phantom units with three-year service vesting requirements. As of June 30, 2012, a total of 991,206 Regency Phantom Units remain unvested, with a weighted average grant date fair value of $24.59. Regency expects to recognize a total of $17.8 million in compensation expense over a weighted average period of 3.8 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

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-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

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
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-URI http://asc.fasb.org/extlink&oid=6418621&loc=d3e17540-113929

+ Details

Benefits

6 Months Ended

Jun. 30, 2012

BENEFITS [Abstract]

Postemployment Benefits Disclosure [Text Block]

BENEFITS:

Southern Union has pension plans that cover substantially all of its distribution operations' employees. Normal retirement age is 65, but certain plan provisions allow for earlier retirement. Pension benefits are calculated under formulas principally based on average earnings and length of service for salaried and non-union employees and average earnings and length of service or negotiated non-wage based formulas for union employees.

Southern Union has other postretirement plans that cover most of its employees. The health care plans generally provide for cost sharing between Southern Union and its retirees in the form of retiree contributions, deductibles, coinsurance, and a fixed cost cap on the amount Southern Union pays annually to provide future retiree health care coverage under certain of these plans.

Pension and other postretirement benefit liabilities are accrued on an actuarial basis during the years an employee provides services. The following table contains information at the acquisition date (March 26, 2012) about the obligations and funded status of Southern Union’s pension and other postretirement plans on a combined basis:



	Pension Benefits			Other Postretirement Benefits
Benefit obligation	$	227,548		$	140,651
Fair value of plan assets	$	143,979		$	118,784
Amount underfunded	$	(83,569	)	$	(21,867	)
Amounts recognized in our consolidated balance sheet related to Southern Union's pension and other postretirement plans consist of:
Non-current assets	$	—		$	6,062
Current liabilities	—			(133		)
Non-current liabilities	(83,569		)	(27,796		)
	$	(83,569	)	$	(21,867	)

The following table summarizes information at the acquisition date (March 26, 2012) for plans with an accumulated benefit obligation in excess of the plan assets:



	Pension Benefits		Other Postretirement Benefits
Projected benefit obligation	$	227,548	N/A
Accumulated benefit obligation	213,614		$	110,314
Fair value of plan assets	143,979		82,385

Assumptions

The following table includes weighted average assumptions used in determining benefit obligations as of the acquisition date (March 26, 2012):



	Pension Benefits		Other Postretirement Benefits
Discount rate	4.10	%	4.10	%
Rate of compensation increase	3.03	%	N/A

The assumed health care cost trend rates used to measure the expected cost of benefits covered by Southern Union's other postretirement benefit plans as of the acquisition date (March 26, 2012) are shown in the table below:



Health care cost trend rate assumed for next year	9.00	%
Rate to which the cost trend is assumed to decline (the ultimate trend rate)	4.85	%
Year that the rate reaches the ultimate trend rate	2020

Defined Contribution Plan

Employees of Southern Union and its subsidiaries participate in a company-sponsored defined contribution savings plan that is substantially similar to the 401(k) savings plan that covers the employees of ETE, ETP and Regency.

Income Taxes

6 Months Ended

Jun. 30, 2012

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 June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
Current expense (benefit):
Federal	$	(41	)	$	561		$	(60	)	$	5,663
State	4,153			5,439			7,889			9,435
Total	4,112			6,000			7,829			15,098
Deferred expense (benefit):
Federal	6,347			(747		)	(2,218		)	(559		)
State	(284		)	(29		)	6,143			588
Total	6,063			(776		)	3,925			29
Total income tax expense	$	10,175		$	5,224		$	11,754		$	15,127

Our effective tax rate has historically differed from the statutory rate due primarily to Partnership earnings that are not subject to federal and state income taxes at the Partnership level. The acquisition of Southern Union on March 26, 2012 increased our overall effective rate, because Southern Union is subject to federal and state income taxes.

In connection with the Southern Union Merger, we recorded a net deferred tax liability of approximately $1.70 billion, which was primarily related to property, plant and equipment. Southern Union has deferred tax net operating loss carry forwards of approximately $67.0 million as of June 30, 2012, of which $17.0 million and $50.0 million expire in 2030 and 2031, respectively. Southern Union currently anticipates a federal net operating loss of approximately $150 million for 2012.

As of June 30, 2012, Southern Union has unrecognized tax benefits for capitalization policies and state filing positions of $2.3 million and $17.1 million, respectively, which relate to tax positions taken by Southern Union or its subsidiaries prior to our acquisition on March 26, 2012.

- 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
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-Section 50
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Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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-Publisher FASB
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+ Details

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities

6 Months Ended

Jun. 30, 2012

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities [Abstract]

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities

REGULATORY MATTERS, COMMITMENTS, CONTINGENCIES AND ENVIRONMENTAL LIABILITIES:

Regulatory Matters

Southern Union and its Subsidiaries

Sea Robin Pipeline, a subsidiary of Southern Union, is recovering Hurricane Ike-related costs not otherwise recovered from insurance proceeds or from other third parties, as well as applicable carrying charges, through a rate surcharge approved by the FERC. As of June 30, 2012, our consolidated balance sheet reflects approximately $40.8 million of costs to be recovered by Sea Robin Pipeline in future periods via the surcharge.

The FERC is currently conducting an audit of PEPL, a subsidiary of Southern Union, to evaluate its compliance with the Uniform System of Accounts as prescribed by the FERC, annual and quarterly financial reporting to the FERC, reservation charge crediting policy and record retention. The audit is related to the period from January 1, 2010 to present and is expected to take approximately one year to complete.

Contingent Residual Support Agreement — AmeriGas

AmeriGas Finance LLC, a wholly owned subsidiary of AmeriGas, issued $550.0 million in aggregate principal amount of 6.75% senior notes due 2020 and $1.00 billion in aggregate principal amount of 7.00% senior notes due 2022. AmeriGas borrowed $1.50 billion of the proceeds of the Senior Notes issuance from Finance Company through an intercompany borrowing having maturity dates and repayment terms that mirror those of the Senior Notes.

In connection with the Propane Contribution, ETP entered into a CRSA with AmeriGas, AmeriGas Finance LLC, AmeriGas Finance Corp. and UGI Corp., pursuant to which ETP will provide contingent, residual support of the Supported Debt, as defined in the CRSA.

Commitments

In the normal course of our business, our operating entities 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. We believe that the terms of these agreements are commercially reasonable and will not have a material adverse effect on our financial position or results of operations.

We have certain non-cancelable leases for property and equipment, which require fixed monthly rental payments and expire at various dates through 2029. Rental expense under these operating leases has been included in operating expenses in the accompanying statements of operations and totaled approximately $11.7 million and $7.8 million for the three months ended June 30, 2012 and 2011, respectively, and $18.5 million and $13.2 million for the six months ended June 30, 2012 and 2011, respectively.

Future minimum lease commitments for such leases are:



Years Ending December 31:
2012 (remainder)	$	18,595
2013	38,341
2014	33,295
2015	31,683
2016	30,820
Thereafter	216,143

Certain of our subsidiaries' joint venture agreements require that they 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 NGLs 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 June 30, 2012 and December 31, 2011, accruals of approximately $10.1 million and $18.2 million, respectively, were reflected on our consolidated 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. Furthermore, 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 June 30, 2012 or December 31, 2011 consolidated balance sheets for contingencies and current litigation, other than amounts disclosed herein. Following is a discussion or our legal proceedings:

Will Price. Will Price, an individual, filed actions in the U.S. District Court for the District of Kansas for damages against a number of companies, including Panhandle, alleging mis-measurement of natural gas volumes and Btu content, resulting in lower royalties to mineral interest owners. On September 19, 2009, the Court denied plaintiffs’ request for class certification. Plaintiffs have filed a motion for reconsideration, which the Court denied on March 31, 2010. Panhandle believes that its measurement practices conformed to the terms of its FERC natural gas tariffs, which were filed with and approved by the FERC. As a result, Southern Union believes that it has meritorious defenses to the Will Price lawsuit (including FERC-related affirmative defenses, such as the filed rate/tariff doctrine, the primary/exclusive jurisdiction of the FERC, and the defense that Panhandle complied with the terms of its tariffs). In the event that Plaintiffs refuse Panhandle’s pending request for voluntary dismissal, Panhandle will continue to vigorously defend the case. Southern Union believes it has no liability associated with this proceeding.

Attorney General of the Commonwealth of Massachusetts v New England Gas Company. On July 7, 2011, the Massachusetts Attorney General filed a regulatory complaint with the MDPU against New England Gas Company with respect to certain environmental cost recoveries. The Attorney General is seeking a refund to New England Gas Company customers for alleged “excessive and imprudently incurred costs” related to legal fees associated with Southern Union’s environmental response activities. In the complaint, the Attorney General requests that the MDPU initiate an investigation into the New England Gas Company’s collection and reconciliation of recoverable environmental costs including: (i) the prudence of any and all legal fees, totaling $18.5 million, that were charged by the Kasowitz, Benson, Torres & Friedman firm and passed through the recovery mechanism since 2005, the year when a partner in the firm, Southern Union’s Vice Chairman, President and COO, joined Southern Union’s management team; (ii) the prudence of any and all legal fees that were charged by the Bishop, London & Dodds firm and passed through the recovery mechanism since 2005, the period during which a member of the firm served as Southern Union’s Chief Ethics Officer; and (iii) the propriety and allocation of certain legal fees charged that were passed through the recovery mechanism that the Attorney General contends only would qualify for a lesser, 50%, level of recovery. Southern Union has filed its answer denying the allegations and moved to dismiss the complaint, in part on a theory of collateral estoppel. The Attorney General’s motion to be reimbursed for expert and consultant costs by Southern Union of up to $150,000 was granted. The hearing officer has stayed discovery until resolution of a separate matter concerning the applicability of attorney-client privilege to legal billing invoices. Southern Union believes it has complied with all applicable requirements regarding its filings for cost recovery and has not recorded any accrued liability; however, Southern Union will continue to assess its potential exposure for such cost recoveries as the matter progresses.

Air Quality Control. SUGS is currently negotiating settlements to certain enforcement actions by the NMED and the TCEQ.

Compliance Orders from the New Mexico Environmental Department. SUGS has been in discussions with the New Mexico Environmental Department concerning allegations of violations of New Mexico air regulations related to the Jal #3 and Jal #4 facilities. The New Mexico Environmental Department has issued amended compliance orders and proposed penalties for alleged violations at Jal #4 in the amount of $0.5 million and at Jal #3 in the amount of $5.5 million. Hearings on the compliance orders were delayed until September 2012 to allow the parties to pursue substantive settlement discussions. SUGS has meritorious defenses to the New Mexico Environmental Department claims and can offer significant mitigating factors to the claimed violations. SUGS has recorded an accrued liability and will continue to assess its potential exposure to the allegations as the matter progresses.

FGT Phase VIII Expansion. FGT Phase VIII Expansion project was placed in-service on April 1, 2011, at an approximate cost of $2.5 billion, including capitalized equity and debt costs. To date, FGT has entered into long-term firm transportation service agreements with shippers for 25-year terms accounting for approximately 74% of the available expansion capacity.

In 2011, CrossCountry and Citrus' other stockholder each made sponsor contributions of $37 million in the form of loans to Citrus, net of repayments. The contributions are related to the costs of FGT's Phase VIII Expansion project. In conjunction with anticipated sponsor contributions, Citrus has entered into a promissory note in favor of each stockholder for up to $150 million. The promissory notes have a final maturity date of March 31, 2014, with no principal payments required prior to the maturity date, and bear an interest rate equal to a one-month Eurodollar rate plus a credit spread of 1.5%. Amounts may be redrawn periodically under the notes to temporarily fund capital expenditures, debt retirements, or other working capital needs.

FGT Pipeline Relocation Costs. The FDOT/FTE has various turnpike/State Road 91 widening projects that have impacted or may, over time, impact one or more of FGT's mainline pipelines located in FDOT/FTE rights-of-way. Several FDOT/FTE projects are the subject of litigation in Broward County, Florida. On January 27, 2011, a jury awarded FGT $82.7 million and rejected all damage claims by the FDOT/FTE. On May 2, 2011, the judge issued an order entitling FGT to an easement of 15 feet on either side of its pipelines and 75 feet of temporary work space. The judge further ruled that FGT is entitled to approximately $8 million in interest. In addition to ruling on other aspects of the easement, he ruled that pavement could not be placed directly over FGT's pipeline without the consent of FGT although FGT would be required to relocate the pipeline if it did not provide such consent. While FGT would seek reimbursement of any costs associated with relocation of its pipeline in connection with an FDOT project, FGT may not be successful in obtaining such reimbursement and, as such, could be required to bear the cost of such relocation. In any such instance, FGT would seek recovery of the reimbursement costs in rates. The judge also denied all other pending post-trial motions. The FDOT/FTE filed a notice of appeal on July 12, 2011. Briefing to the Florida Fourth District Court of Appeals is complete. The Florida Fourth District Court of Appeals granted a request by the FDOT to expedite the appeal. Oral argument was held March 7, 2012. Amounts ultimately received would primarily reduce FGT's property, plant and equipment costs.

Litigation Relating to the Southern Union Merger

On June 21, 2011, a putative class action lawsuit captioned Jaroslawicz v. Southern Union Company, et al., Cause No. 2011-37091, was filed in the 333rd Judicial District Court of Harris County, Texas. Also on June 21, 2011, another putative class action lawsuit captioned Magda v. Southern Union Company, et al., Cause No. 2011-37134, was filed in the 11th Judicial District Court of Harris County, Texas. The petitions named as defendants the members of the Southern Union Board of Directors ("Southern Union Board"), as well as Southern Union and ETE. The petitions, which were also amended on June 28, 2011 and August 19, 2011, alleged that the Southern Union Board breached their fiduciary duties to Southern Union's stockholders in connection with the merger transaction with ETE and that Southern Union and ETE aided and abetted those alleged breaches. The petitions further alleged that the Southern Union Merger involved an unfair price and an inadequate sales process, that Southern Union's directors entered into the transaction to benefit themselves personally, including though consulting and noncompete agreements and that defendants have failed to disclose all material information related to the Southern Union Merger to Southern Union stockholders. The petition sought injunctive relief, including an injunction of the Southern Union Merger, and an award of attorneys' and other fees and costs, in addition to other relief. The two Texas cases have been consolidated with the following style: In re: Southern Union Company; Cause No. 2011-37091, in the 333rd Judicial District Court of Harris County, Texas. On October 21, 2011, the court denied ETE's October 13, 2011, motion to stay the Texas proceeding in favor of cases pending in the Delaware Court of Chancery (described below).

On June 27, 2011, a putative class action lawsuit captioned Southeastern Pennsylvania Transportation Authority, et al. v. Southern Union Company, et al., C.A. No. 6615-CS, was filed in the Delaware Court of Chancery. Additionally, on June 29 and 30, 2011, putative class action lawsuits captioned KBC Asset Management NV v. Southern Union Company, et al., C.A. No. 6622-CS, and LBBW Asset Management Investment GmbH v. Southern Union Company, et al., C.A. No. 6627-CS, respectively were filed in the Delaware Court of Chancery. Also, on July 6, 2011, a putative class action lawsuit captioned Memo v. Southern Union Company, et al., C.A. No. 6639-CS, was filed in the Delaware Court of Chancery. Each complaint named as defendants the members of the Southern Union Board, Southern Union, and ETE. The plaintiffs alleged that the Southern Union directors breached their fiduciary duties to Southern Union's stockholders in connection with the merger transaction with ETE and further claimed that ETE aided and abetted those alleged breaches. The complaints further alleged that the Southern Union Merger involves an unfair price and an inadequate sales process, that Southern Union's directors entered into the transactions to benefit themselves personally, including through consulting and noncompete agreements, and that the Southern Union Board should deem a competing proposal made by The Williams Companies, Inc. ("Williams") to be superior. The complaints sought compensatory damages, injunctive relief, including an injunction of the Southern Union Merger, and an award of attorneys' and other fees and costs, in addition to other relief.

On August 25, 2011, a consolidated amended complaint was filed in the Southeastern Pennsylvania Transportation Authority, KBC Asset Management NV, and LBBW Asset Management Investment GmbH actions pending in the Delaware Court of Chancery naming the same defendants as the original complaints in those actions and alleging that the Southern Union directors breached their fiduciary duties to Southern Union's stockholders in connection with the merger transactions with ETE, that ETE aided and abetted those alleged breaches of fiduciary duty, and that the provisions in Section 5.4 of the Second Amended Merger Agreement relating to Southern Union's ability to accept a superior proposal is invalid under Delaware law. The amended complaint alleges that the Southern Union Merger involves an unfair price and an inadequate sales process, that Southern Union's directors entered into the Merger to benefit themselves personally, including through consulting and noncompete agreements, and that the defendants have failed to disclose all material information related to the Merger to Southern Union stockholders. The consolidated amended complaint sought injunctive relief, including an injunction of the Southern Union Merger and an award of attorneys' and other fees and costs, in addition to other relief.

The four Delaware Court of Chancery cases have been consolidated with the following style: In re Southern Union Co. Shareholder Litigation, C.A. No. 6615-CS, in the Delaware Court of Chancery.

On November 9, 2011, the attorneys for the plaintiffs in the aforementioned Texas and Delaware actions stated that they did not intend to pursue their efforts to enjoin the Southern Union Merger. Plaintiffs have indicated that they intend to pursue a claim for damages. A trial has not yet been scheduled in any of these matters. Discovery for the damages claim is in its preliminary stages.

On July 25, 2012, the plaintiffs in the Delaware action filed a notice with the Delaware Court of Chancery to voluntarily dismiss all claims without prejudice. In the notice, the plaintiffs stated their claims were being dismissed to avoid duplicative litigation and indicated their intent to join the Texas case before the District Court of Harris County, Texas, 333rd Judicial District.

ETE has not recorded an accrued liability, believes the allegations of all the foregoing actions related to the Southern Union Merger lack merit, and intends to contest them vigorously.

W. J. Garrett Trust. On November 28, 2011, W.J. Garrett Trust filed a lawsuit in Texas state court derivatively and on behalf of ETP unitholders. This lawsuit is W.J. Garrett Trust, et al. v. Bill W. Byrne, Paul E. Glaske, Kelcy L. Warren, David R. Albin, Michael K. Grimm, Ted Collins, Jr., Ray C. Davis, Marshall S. McCrea III, K. Rick Turner, ETE, Southern Union, ETP GP, ETP LLC and ETP, case number 2011-71702, in the 157th Judicial District Court of Harris County, Texas. Plaintiff alleges a variety of causes of action challenging the Citrus Acquisition and ETP's divesture of its Propane Business to AmeriGas (the “Propane Transactions”). Specifically, plaintiff alleges that the Propane Transactions involved an unfair price and alleges several deficiencies in the process by which the named directors and officers are conducting the Propane Transactions. Additionally, plaintiff alleges that: (i) the named directors and officers breached their fiduciary duties and their contractual duties in connection with the Propane Transactions; (ii) the named entities aided and abetted these breaches of the directors' and officers' fiduciary and contractual duties; (iii) Southern Union and ETE tortiously interfered with ETP's partnership agreement; and (iv) the defendants conspired to breach fiduciary and contractual duties. Plaintiff also seeks a declaration that the defendant breached their fiduciary and contractual duties.

On January 30, 2012, defendants filed a motion to stay discovery and special exceptions challenging the sufficiency of plaintiff's claims. On March 5, 2012, Judge Reece Rondon of the 234th Judicial District Court of Harris County, Texas (the state court judge originally assigned the case) heard oral argument on defendants' motions. Immediately following the hearing, Judge Rondon recused himself and transferred the case to Judge Randy Wilson of the 157th Judicial District Court of Harris County, Texas. On April 3, 2012, Judge Wilson heard oral argument on defendants' motions and the parties are awaiting ruling from the court on the motions.

El Paso. CrossCountry, the Southern Union subsidiary that indirectly owns a 50% interest in Citrus, filed a petition in the Delaware Court of Chancery seeking a declaratory judgment against El Paso, the owner of the other 50% interest of Citrus, that the Citrus Merger did not breach El Paso's rights under a joint venture agreement related to Citrus. This petition was filed by CrossCountry following an exchange of letters between CrossCountry, El Paso and Southern Union in which El Paso stated that it believed the Citrus Merger violated the provisions of the joint venture agreement. Subsequently, El Paso filed a petition asserting a counterclaim action against CrossCountry, ETP and ETE based on its claim that the Citrus Merger violated El Paso's right of first refusal and, in such petition, El Paso sought a rescission of the Citrus Merger or, alternatively, damages.

On April 18, 2012, the parties to the declaratory judgment action and related counterclaim action entered into a joint stipulation pursuant to which El Paso agreed that the Citrus Merger did not breach the joint venture agreement and that El Paso was not entitled to rescission or damages with respect to the Citrus Merger. On April 20, 2012, the Delaware court granted an order approving the joint stipulation and, as a result, all litigation with respect to the Citrus Merger has been terminated.

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, there can be no assurance 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, will not 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 subsidiaries have 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 our subsidiaries' liability in proportion to other parties, improvements in cleanup technologies and the extent to which environmental laws and regulations may change in the future.

The EPA's Spill Prevention, Control and Countermeasures program regulations were recently modified and impose additional requirements on many of our facilities. We expect 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 we believe such costs will not have a material adverse effect on our financial position, results of operations or cash flows.

On August 20, 2010, the EPA published new regulations under the CAA to control emissions of hazardous air pollutants from existing stationary reciprocal internal combustion engines. The rule will require some of our subsidiaries 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, we would not expect that the cost to comply with the rule's requirements will have a material adverse effect on our 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 some of our subsidiaries to undertake significant expenditures, including expenditures for purchasing, installing, monitoring and maintaining emissions control equipment, if equipment is replaced or existing facilities are expanded in the future. At this point, we are not able to predict the cost to comply with the rule’s requirements, because the rule applies only to changes our subsidiaries might make in the future.

On April 17, 2012 the EPA issued the Oil and Natural Gas Sector New Source Performance Standards and National Emission Standards for Hazardous Air Pollutants. The standards revise the new source performance standards for volatile organic compounds from leaking components at onshore natural gas processing plants and new source performance standards for sulfur dioxide emissions from natural gas processing plants. The EPA also established standards for certain oil and gas operations not covered by the existing standards. In addition to the operations covered by the existing standards, the newly established standards regulate volatile organic compound emissions from gas wells, centrifugal compressors, reciprocating compressors, pneumatic controllers and storage vessels. ETP is reviewing the new standards to determine the impact on its operations.

Our subsidiaries' pipeline operations are subject to regulation by the DOT under the 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. Integrity testing and assessment of all of these assets will continue, and the potential exists that results of such testing and assessment could cause our subsidiaries to incur future capital and operating expenditures for repairs or upgrades deemed necessary to ensure the continued safe and reliable operation of pipelines; however, no estimate can be made at this time of the likely range of such expenditures.

Environmental Remediation

Our subsidiaries are responsible for environmental remediation at certain sites, including the following:


•	Certain of our interstate pipelines conduct soil and groundwater remediation related to contamination from past uses of PCBs. PCB assessments are ongoing and, in some cases, our subsidiaries could potentially be held responsible for contamination caused by other parties.


•	Certain gathering and processing systems are responsible for soil and groundwater remediation related to releases of hydrocarbons.


•	Southern Union's distribution operations are responsible for soil and groundwater remediation at certain sites related to MGPs and may also be responsible for the removal of old MGP structures.

To the extent estimable, expected remediation costs are included in the amounts recorded for environmental matters in our consolidated balance sheets. In some circumstances, future costs cannot be reasonably estimated because remediation activities are undertaken as claims are made by customers and former customers. To the extent that an environmental remediation obligation is recorded by a subsidiary that applies regulatory accounting policies, amounts that are expected to be recoverable through tariffs or rates are recorded as regulatory assets on our consolidated balance sheets.

The table below reflects the amounts of accrued liabilities recorded in our consolidated balance sheets related to environmental matters that are considered to be probable and reasonably estimable. Except for matters discussed above, we do not have any material environmental matters assessed as reasonably possible that would require disclosure in our consolidated financial statements.



	June 30, 2012		December 31, 2011
Current	$	4,205	$	3,861
Non-current	35,121		9,990
Total environmental liabilities	$	39,326	$	13,851

- 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)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 450
-SubTopic 20
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6952336&loc=d3e14435-108349

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 460
-SubTopic 10
-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
-URI http://asc.fasb.org/extlink&oid=6394976&loc=d3e25287-109308

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-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

6 Months Ended

Jun. 30, 2012

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 commodity 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 operating entity.

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). ETP 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 our consolidated statements of operations.

ETP's trading activities include the use of financial commodity derivatives to take advantage of market opportunities. These trading activities are a complement to ETP's transportation and storage operations and are netted in cost of products sold in our consolidated statements of operations. Additionally, ETP also has trading activities related to power in its "All Other" operations which are also netted in costs of products sold. As a result of ETP's trading activities and the use of derivative financial instruments in ETP's transportation and storage operations, the degree of earnings volatility that can occur may be significant, favorably or unfavorably, from period to period. ETP attempts to manage this volatility through (i) the use of daily position and profit and loss reports provided to its risk oversight committee, which includes members of senior management, and (ii) the limits and authorizations set forth in ETP's commodity risk management policy.

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 against 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. To the extent that financial contracts are not tied to physical delivery volumes, ETP may engage in offsetting financial contracts to balance its positions. To the extent open commodity positions exist, fluctuating commodity prices can impact its financial position and results of operations, either favorably or unfavorably.

Prior to the deconsolidation of the Propane Business, ETP also used propane futures contracts to fix the purchase price related to certain fixed price sales contracts and to secure the purchase price of its propane inventory for a percentage of the anticipated sales by its cylinder exchange business.

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



	June 30, 2012			December 31, 2011
	Notional Volume		Maturity	Notional Volume		Maturity
Mark-to-Market Derivatives
(Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX⁽¹⁾	7,650,000		2012-2013	(151,260,000	)	2012-2013
Power (Thousand Megawatt):
Forwards	4,800		2012-2013	—		—
Options — Puts	36,800		2012	—		—
(Non-Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX	(55,272,500	)	2012-2013	(61,420,000	)	2012-2013
Swing Swaps IFERC	(19,825,000	)	2012-2013	92,370,000		2012-2013
Fixed Swaps/Futures	1,062,500		2012-2014	797,500		2012
Forward Physical Contracts	(20,481,365	)	2012	(10,672,028	)	2012
Options — Puts	500,000		2012	—		—
Propane (Gallons):
Forwards/Swaps	—		—	38,766,000		2012-2013
Fair Value Hedging Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX	(25,707,500	)	2012-2013	(28,752,500	)	2012
Fixed Swaps/Futures	(51,790,000	)	2012-2013	(45,822,500	)	2012
Hedged Item — Inventory	51,790,000		2012-2013	45,822,500		2012
Cash Flow Hedging Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX	(12,850,000	)	2012-2013	—		—
Fixed Swaps/Futures	(31,100,000	)	2012-2013	—		—
Options — Puts	1,800,000		2012	3,600,000		2012
Options — Calls	(1,800,000	)	2012	(3,600,000	)	2012

⁽¹⁾ Includes aggregate amounts for open positions related to Houston Ship Channel, Waha Hub, NGPL TexOk, West Louisiana Zone and Henry Hub locations.

We expect gains of $9.7 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.

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 effected by the inherent volatility of these commodities, which could adversely effect 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 GP have established comprehensive risk management policies and procedures to monitor and manage these market risks. Regency GP is responsible for delegation of transaction authority levels, and the Audit and Risk Committee of Regency GP is responsible for the overall management of credit risk and commodity price risk, including monitoring exposure limits. Regency GP’s Audit and Risk 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 11) 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 effect its cash flows.

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



	June 30, 2012		December 31, 2011
	Notional Volume	Maturity	Notional Volume	Maturity
Mark-to-Market Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Fixed Swaps/Futures	5,297,000	2012-2014	—	—
Propane (Gallons):
Forwards/Swaps	7,770,000	2012-2013	—	—
Natural Gas Liquids (Barrels):
Forwards/Swaps	277,000	2012-2013	—	—
Options — Puts	110,000	2012	110,000	2012
WTI Crude Oil (Barrels):
Forwards/Swaps	344,000	2012-2014	—	—
Cash Flow Hedging Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Fixed Swaps/Futures	—	—	2,198,000	2012
Propane (Gallons):
Forwards/Swaps	—	—	11,802,000	2012-2013
Natural Gas Liquids (Barrels):
Forwards/Swaps	—	—	533,000	2012-2013
WTI Crude Oil (Barrels):
Forwards/Swaps	—	—	350,000	2012-2014

On January 1, 2012, Regency de-designated all of its swap contracts and has accounted for these contracts using mark-to-market accounting. As of June 30, 2012, Regency had $1.1 million in net hedging losses in AOCI which will be amortized to earnings over the next 1.75 years, of which $0.8 million will be reclassified into earnings over the next 12 months.

Southern Union

Southern Union is exposed to certain risks in its ongoing business operations. Natural gas and NGL price swaps and NGL processing spread swaps are the principal derivative instruments used by Southern Union to manage commodity price risk associated with purchases and/or sales of natural gas and/or NGL, although other commodity derivative contracts may also be used from time to time.

Southern Union primarily enters into natural gas and NGL price swaps and NGL processing spread swaps to manage its exposure to changes in margin on forecasted sales of equity natural gas and NGL volumes resulting from movements in market commodity prices.

Southern Union enters into natural gas commodity financial instruments to manage the exposure to changes in the cost of natural gas passed through to utility customers that result from movements in market commodity prices. The cost of the derivative instruments and settlement of the respective obligations are recovered from utility customers through the purchased natural gas adjustment clause as authorized by the applicable regulatory authority and therefore do not impact earnings.

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



	June 30, 2012
	Notional Volume	Maturity
Mark-to-Market Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Fixed Swaps/Futures	19,750,000	2012-2014
Cash Flow Hedging Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Fixed Swaps/Futures	15,557,500	2012-2013
Natural Gas Liquids (Barrels):
Fixed Swaps/Futures	2,760,000	2012

We expect net after-tax gains of $17.1 million related to Southern Union’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. To maintain a cost effective capital structure, we borrow funds using a mix of fixed rate debt and floating rate debt. We also manage our interest rate exposures by utilizing interest rate swaps to achieve a desired mix of fixed and floating rate debt. We also utilize forward starting interest rate swaps to lock in the rate on a portion of anticipated debt issuances. Southern Union also uses treasury rate locks to manage interest rate risk associated with long term borrowings. The following is a summary of interest rate swaps outstanding as of June 30, 2012 and December 31, 2011, none of which were designated as hedges for accounting purposes:

Notional Amount

Outstanding

Entity

Term

Type⁽¹⁾

June 30,
2012

December 31, 2011

ETE

March 2017

Pay a fixed rate of 1.25% and receive a floating rate

500,000

—

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

ETP

July 2013 ⁽²⁾

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

400,000

300,000

ETP

July 2014 ⁽²⁾

Forward starting to pay a fixed rate of 4.26% and receive a floating rate

400,000

—

ETP

July 2018

Pay a floating rate plus a spread of 4.17% and receive a fixed rate of 6.70%

600,000

500,000

Regency

April 2012

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

—

250,000

Southern Union

November 2016

Pay a fixed rate of 2.913% and receive a floating rate

75,000

N/A

Southern Union

November 2021

Pay a fixed rate of 3.746% and receive a floating rate

450,000

N/A

(1)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.

As of June 30, 2012, Southern Union had no outstanding treasury rate locks; however, certain of its treasury rate locks that settled in prior periods are associated with interest payments on outstanding long-term debt. These treasury rate locks are accounted for as cash flow hedges, with the effective portion of their settled value recorded in AOCI and reclassified into interest expense in the same periods during which the related interest payments on long-term debt impact earnings.

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 or multiple counterparties.

Our counterparties consist primarily of petrochemical companies and other industrial, small to major oil and gas producers, midstream and power generation 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 nonperformance.

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 the consolidated balance sheets. ETP had net deposits with counterparties of $45.3 million and $66.2 million as of June 30, 2012 and December 31, 2011, respectively.

Regency is exposed to credit risk from its derivative counterparties. Regency does not require collateral from these counterparties as it deals primarily with financial institutions when entering into financial derivatives, and enters into master netting agreements that allow for netting of swap contract receivables and payables in the event of default by either party.

Certain of Southern Union’s derivative instruments contain provisions that require Southern Union’s debt to be maintained at an investment grade credit rating from each of the major credit rating agencies. If Southern Union’s debt were to fall below investment grade, Southern Union would be in violation of these provisions, and the counterparties to the derivative instruments could potentially require Southern Union to post collateral for certain of the derivative instruments. The aggregate fair value of Southern Union's derivative instruments with credit-risk-related contingent features that are in a net liability position at June 30, 2012 was $10.0 million.

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 June 30, 2012 and December 31, 2011:



	Fair Value of Derivative Instruments
	Asset Derivatives				Liability Derivatives
	June 30, 2012		December 31, 2011		June 30, 2012			December 31, 2011
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	12,911	$	77,197	$	(6,698	)	$	(819	)
Commodity derivatives	14,890		4,539		(2,146		)	(10,128		)
	27,801		81,736		(8,844		)	(10,947		)
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	$	123,426	$	227,337	$	(139,666	)	$	(251,268	)
Commodity derivatives	53,548		1,017		(59,220		)	(4,844		)
Interest rate derivatives	50,543		36,301		(233,447		)	(117,490		)
Embedded derivatives in Regency Preferred Units	—		—		(30,644		)	(39,049		)
	227,517		264,655		(462,977		)	(412,651		)
Total derivatives	$	255,318	$	346,391	$	(471,821	)	$	(423,598	)

The commodity derivatives (margin deposits) are recorded in other current assets on our consolidated balance sheets. The remainder of the non-exchange traded financial derivative instruments are recorded at fair value as price risk management assets or price risk management liabilities and are 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 June 30,					Six Months Ended June 30,
	2012			2011		2012		2011
Derivatives in cash flow hedging relationships:
Commodity derivatives	$	(17,038	)	$	3,769	$	5,177	$	(7,123	)
Interest rate derivatives	19,709			—		19,709		—
Total	$	2,671		$	3,769	$	24,886	$	(7,123	)



	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 June 30,					Six Months Ended June 30,
		2012		2011			2012		2011
Derivatives in cash flow hedging relationships:
Commodity derivatives	Cost of products sold	$	12,152	$	(2,148	)	$	15,587	$	12,954
Total		$	12,152	$	(2,148	)	$	15,587	$	12,954



	Location of Gain/(Loss) Reclassified from AOCI into Income (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Ineffective Portion
		Three Months Ended June 30,					Six Months Ended June 30,
		2012			2011		2012		2011
Derivatives in cash flow hedging relationships:
Commodity derivatives	Cost of products sold	$	(1	)	$	96	$	46	$	189
Total		$	(1	)	$	96	$	46	$	189



	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 June 30,				Six Months Ended June 30,
		2012		2011		2012		2011
Derivatives in fair value hedging relationships (including hedged item):
Commodity derivatives	Cost of products sold	$	31,671	$	15,874	$	18,833	$	22,291
Total		$	31,671	$	15,874	$	18,833	$	22,291



	Location of Gain/(Loss) Recognized in Income on Derivatives	Amount of Gain/(Loss) Recognized in Income on Derivatives
		Three Months Ended June 30,						Six Months Ended June 30,
		2012			2011			2012			2011
Derivatives not designated as hedging instruments:
Commodity derivatives — Trading	Cost of products sold	$	(709	)	$	—		$	(11,295	)	$	—
Commodity derivatives — Non-Trading	Cost of products sold	12,575			(11,427		)	12,112			(4,989		)
Interest rate derivatives	Gains (losses) on non-hedged interest rate derivatives	(44,668		)	1,883			(17,178		)	3,403
Embedded derivatives	Other income	7,909			2,950			8,405			5,525
Total		$	(24,893	)	$	(6,594	)	$	(7,956	)	$	3,939

- 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.

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 133
-Paragraph 44
-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 815
-SubTopic 30
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6887037&loc=d3e80784-113994

Reference 4: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-Name Accounting Standards Codification
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+ Details

Related Party Transactions	6 Months Ended
Related Party Transactions	Jun. 30, 2012
Related Party Transactions [Abstract]
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 six months ended June 30, 2012, the Parent Company received $4.3 million and $8.6 million in service fees, respectively, from Regency related to these services and $4.2 million and $8.1 million for the three and six months ended June 30, 2011, respectively. For the three and six months ended June 30, 2012, the Parent Company paid $4.5 million and $8.9 million in service fees, respectively, to ETP related to these services and other services for ETE's benefit and $3.5 million and $8.4 million for the three and six months ended June 30, 2011, respectively. The service fees received from Regency for the three and six months ended June 30, 2012 reflect the reimbursement of various general and administrative services of $1.8 million and $3.6 million, respectively, for expenses incurred by ETP on behalf of Regency and $0.8 million and $3.1 million for the three and six months ended June 30, 2011, respectively. Under a master services agreement with HPC, Regency operates HPC, providing all employees and services for its operation and management. The related party general administrative expenses reimbursed to Regency were $5.1 million and $9.3 million for the three and six months ended June 30, 2012 and $4.2 million and $8.4 million for the three and six months ended June 30, 2011, respectively.

- 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
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+ Details

Other Information

6 Months Ended

Jun. 30, 2012

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:



	June 30, 2012		December 31, 2011
Deposits paid to vendors	$	87,663	$	66,231
Prepaid expenses and other	85,092		115,673
Total other current assets	$	172,755	$	181,904

Other Non-Current Assets, net

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



	June 30, 2012		December 31, 2011
Unamortized financing costs (3 to 30 years)	$	153,110	$	132,375
Regulatory assets	220,180		88,993
Other	103,004		27,542
Total other non-current assets, net	$	476,294	$	248,910

Accrued and Other Current Liabilities

Accrued and other current liabilities consisted of the following:



	June 30, 2012		December 31, 2011
Interest payable	$	278,980	$	204,182
Customer advances and deposits	38,253		100,525
Accrued capital expenditures	472,409		228,877
Accrued wages and benefits	53,618		80,205
Taxes payable other than income taxes	127,937		79,331
Income taxes payable	8,882		14,781
Other	101,254		56,011
Total accrued and other current liabilities	$	1,081,333	$	763,912

Reportable Segments

6 Months Ended

Jun. 30, 2012

Reportable Segments [Abstract]

Reportable Segments

REPORTABLE SEGMENTS:

Our financial statements reflect five reportable segments as follows:

•

Investment in ETP — 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, a joint venture that owns and operates NGL storage, fractionation and transportation assets in Texas, Louisiana and Mississippi. Concurrent with the Parent Company's acquisition of Southern Union, ETP acquired a 50% interest in Citrus, which owns FGT (see Note 3).

•

Investment in Regency — Regency is a publicly traded partnership engaged in the gathering and processing, contract compression, treating and transportation of natural gas and the transportation, fractionation and storage of 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, Bone Spring, Avalon and Marcellus shales, as well as the Permian Delaware basin and the mid-continent region. Its assets are located in Texas, Louisiana, Arkansas, Pennsylvania, California, Mississippi, Alabama, West Virginia and the mid-continent region of the United States, which includes Kansas, Colorado and Oklahoma. Regency also holds a 30% interest in Lone Star.

•

Southern Union Transportation and Storage — We own the Transportation and Storage segment through our wholly-owned subsidiary, Southern Union. The Transportation and Storage segment is primarily engaged in the interstate transportation and storage of natural gas and also provides LNG terminalling and regasification services. Its operations expand from the Gulf Coast region throughout the Midwest and Great Lakes regions.

•

Southern Union Gathering and Processing — We own the Gathering and Processing segment through our wholly-owned subsidiary, Southern Union. The Gathering and Processing segment is primarily engaged in connecting wells of natural gas producers to its gathering system, treating natural gas to remove impurities to meet pipeline quality specifications, processing natural gas for the removal of NGL, and redelivering natural gas and NGL to a variety of markets. Its operations are located in West Texas and Southeast New Mexico.


•	Southern Union Distribution — We own the Distribution segment through our wholly-owned subsidiary, Southern Union. The Distribution segment is primarily engaged in the local distribution of natural gas in Missouri and Massachusetts.

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.

We previously reported net income as a measure of segment performance. We have revised certain reports provided to our chief operating decision maker to assess the performance of our business to reflect Segment Adjusted EBITDA. We define Segment Adjusted EBITDA as earnings before interest, taxes, depreciation, amortization and other non-cash items, such as non-cash compensation expense, gains and losses on disposals of assets, the allowance for equity funds used during construction, unrealized gains and losses on commodity risk management activities, non-cash impairment charges, and other non-operating income or expense items. Unrealized gains and losses on commodity risk management activities includes unrealized gains and losses on commodity derivatives and inventory fair value adjustments (excluding lower of cost or market adjustments). Segment Adjusted EBITDA reflects amounts for less than wholly owned subsidiaries and unconsolidated affiliates based on proportionate ownership. Based on the change in our segment performance measure, we have recast the presentation of our segment results for the prior years to be consistent with the current year presentation.

Related party transactions between our reportable segments 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 financial information by reportable segment. The amounts reflected as “Corporate and Other” include the Parent Company activity and the goodwill and property and plant and equipment fair value adjustments recorded as a result of the 2004 reverse acquisition of Heritage Propane Partners, L.P.



	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
Segment Adjusted EBITDA:
Investment in ETP	$	466,350		$	388,135		$	1,002,412		$	859,434
Investment in Regency	115,272			103,456			249,321			195,193
Southern Union Transportation and Storage	115,919			—			82,644			—
Southern Union Gathering and Processing	22,362			—			10,859			—
Southern Union Distribution	23,314			—			13,446			—
Corporate and Other	(15,273		)	(12,392		)	(50,124		)	(16,074		)
Total	727,944			479,199			1,308,558			1,038,553
Depreciation and amortization	(221,767		)	(148,530		)	(382,968		)	(287,786		)
Interest expense, net of interest capitalized	(281,255		)	(181,517		)	(494,585		)	(349,446		)
Bridge loan related fees	—			—			(62,241		)	—
Gain on deconsolidation of Propane Business	765			—			1,056,709			—
Gains (losses) on non-hedged interest rate derivatives	(44,668		)	1,883			(17,178		)	3,403
Non-cash unit-based compensation expense	(11,581		)	(11,699		)	(23,736		)	(23,085		)
Unrealized gains (losses) on commodity risk management activities	36,514			1,365			(46,997		)	12,747
Losses on disposal of assets	(1,402		)	(681		)	(2,462		)	(2,435		)
Losses on extinguishments of debt	(7,821		)	—			(122,844		)	—
Gain on curtailment of other postretirement benefit plans	—			—			15,332			—
Proportionate share of unconsolidated affiliates' interest, depreciation, amortization, non-cash compensation expense, loss on extinguishment of debt and taxes	(118,232		)	(29,300		)	(184,092		)	(57,421		)
Other, net	6,200			1,156			4,082			(13,659		)
Income before income tax expense	$	84,697		$	111,876		$	1,047,578		$	320,871



	June 30, 2012			December 31, 2011
Total assets:
Investment in ETP	$	17,859,419		$	15,518,616
Investment in Regency	5,832,562			5,567,856
Southern Union Transportation and Storage	5,755,369			—
Southern Union Gathering and Processing	2,805,884			—
Southern Union Distribution	1,245,794			—
Corporate and Other	424,152			470,086
Adjustments and Eliminations	(809,958		)	(659,765		)
Total	$	33,113,222		$	20,896,793



	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
Revenues:
Investment in ETP:
Revenues from external customers	$	1,228,503		$	1,616,748		$	2,529,993		$	3,292,795
Intersegment revenues	11,811			11,347			16,181			22,877
	1,240,314			1,628,095			2,546,174			3,315,672
Investment in Regency:
Revenues from external customers	309,479			354,816			663,391			670,375
Intersegment revenues	2,497			1,682			6,484			3,375
	311,976			356,498			669,875			673,750
Southern Union Transportation and Storage:
Revenues from external customers	183,765			—			197,241			—
Intersegment revenues	1,451			—			1,451			—
	185,216			—			198,692			—
Southern Union Gathering and Processing:
Revenues from external customers	195,499			—			214,735			—
Intersegment revenues	1,977			—			2,098			—
	197,476			—			216,833			—
Southern Union Distribution:
Revenues from external customers	86,220			—			94,505			—
Intersegment revenues	—			—			—			—
	86,220			—			94,505			—
Corporate and Other:
Revenues from external customers	3,558			—			2,152			—
Intersegment revenues	—			—			—			—
	3,558			—			2,152			—
Adjustments and Eliminations:
Revenues from external customers	(30,710		)	3,342			(36,572		)	856
Intersegment revenues	(17,736		)	(13,029		)	(26,214		)	(26,252		)
Total revenues	$	1,976,314		$	1,974,906		$	3,665,445		$	3,964,026

The following tables provide revenues, grouped by similar products and services, for our investments in ETP and Regency. These amounts include intersegment revenues for transactions between ETP, Regency and Southern Union.

Investment in ETP



	Three Months Ended June 30,				Six Months Ended June 30,
	2012		2011		2012		2011
Intrastate Transportation and Storage	$	452,237	$	643,653	$	899,033	$	1,232,331
Interstate Transportation	126,900		104,850		255,176		209,951
Midstream	460,077		513,584		914,176		926,779
NGL Transportation and Services	147,851		93,686		302,119		93,686
Retail Propane and Other Retail Propane Related	12,966		243,973		92,972		801,188
All Other	40,283		28,349		82,698		51,737
Total revenues	1,240,314		1,628,095		2,546,174		3,315,672
Less: Intersegment revenues	11,811		11,347		16,181		22,877
Revenues from external customers	$	1,228,503	$	1,616,748	$	2,529,993	$	3,292,795

Investment in Regency



	Three Months Ended June 30,				Six Months Ended June 30,
	2012		2011		2012		2011
Gathering and Processing	$	263,100	$	303,203	$	570,267	$	569,175
Contract Compression	36,237		38,072		73,438		76,508
Contract Treating	7,388		10,842		16,523		19,275
Corporate and Others	5,251		4,381		9,647		8,792
Total revenues	311,976		356,498		669,875		673,750
Less: Intersegment revenues	2,497		1,682		6,484		3,375
Revenues from external customers	$	309,479	$	354,816	$	663,391	$	670,375

- 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.

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+ Details

Supplemental Financial Statement Information

6 Months Ended

Jun. 30, 2012

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)



	June 30, 2012		December 31, 2011
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	2,729	$	18,460
Accounts receivable from related companies	4,084		1,456
Note receivable from affiliate	167,315		—
Other current assets	303		714
Total current assets	174,431		20,630
ADVANCES TO AND INVESTMENTS IN AFFILIATES	6,216,728		2,225,572
INTANGIBLES	20,874		—
GOODWILL	9,006		—
OTHER NON-CURRENT ASSETS, net	61,618		49,906
Total assets	$	6,482,657	$	2,296,108
LIABILITIES AND PARTNERS' CAPITAL
CURRENT LIABILITIES:
Accounts payable	$	846	$	174
Accounts payable to related companies	2,812		12,334
Interest payable	47,677		34,753
Price risk management liabilities	3,853		—
Accrued and other current liabilities	1,701		953
Current maturities of long-term debt	4,971		—
Total current liabilities	61,860		48,214
LONG-TERM DEBT, less current maturities	3,788,829		1,871,500
SERIES A CONVERTIBLE PREFERRED UNITS	319,860		322,910
OTHER NON-CURRENT LIABILITIES	13,255		—
COMMITMENTS AND CONTINGENCIES
PARTNERS' CAPITAL:
General Partner	71		321
Limited Partners	2,297,473		52,485
Accumulated other comprehensive income	1,309		678
Total partners’ capital	2,298,853		53,484
Total liabilities and partners' capital	$	6,482,657	$	2,296,108

STATEMENTS OF OPERATIONS

(unaudited)



	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES	$	(10,368	)	$	(12,037	)	$	(41,443	)	$	(13,879	)
OTHER INCOME (EXPENSE):
Interest expense, net of interest capitalized	(63,687		)	(40,587		)	(106,274		)	(81,526		)
Bridge loan related fees	—			—			(62,241		)	—
Loss on non-hedged derivatives	(8,700		)	—			(9,097		)	—
Equity in earnings of affiliates	127,370			120,626			434,057			267,268
Other, net	8,861			(1,653		)	4,960			(16,812		)
INCOME BEFORE INCOME TAXES	53,476			66,349			219,962			155,051
Income tax expense	(22		)	64			42			126
NET INCOME	53,498			66,285			219,920			154,925
GENERAL PARTNER’S INTEREST IN NET INCOME	132			205			638			479
LIMITED PARTNERS’ INTEREST IN NET INCOME	$	53,366		$	66,080		$	219,282		$	154,446

STATEMENTS OF CASH FLOWS

(unaudited)



	Six Months Ended June 30,
	2012			2011
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	$	203,062		$	233,152
CASH FLOWS FROM INVESTING ACTIVITIES:
Cash paid for acquisitions	(1,113,377		)	—
Contributions to affiliate	(445,000		)	—
Note receivable from affiliate	(221,217		)	—
Payments received on note receivable from affiliate	55,000			—
Net cash used in investing activities	(1,724,594		)	—
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings	2,005,000			20,000
Principal payments on debt	(106,500		)	(20,000		)
Distributions to partners	(315,196		)	(246,016		)
Debt issuance costs	(77,503		)	—
Net cash provided by (used in) financing activities	1,505,801			(246,016		)
DECREASE IN CASH AND CASH EQUIVALENTS	(15,731		)	(12,864		)
CASH AND CASH EQUIVALENTS, beginning of period	18,460			27,247
CASH AND CASH EQUIVALENTS, end of period	$	2,729		$	14,383

- 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 and Significant Accounting Policies (Policy)	6 Months Ended
Estimates and Significant Accounting Policies (Policy)	Jun. 30, 2012
Estimates Disclosure [Abstract]
Estimates	ESTIMATES AND SIGNIFICANT ACCOUNTING POLICIES: 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 values and results could differ from those estimates. Significant Accounting Policies As a result of the Southern Union Merger on March 26, 2012, the following significant accounting policies have been added to our significant accounting policies described in our Form 10-K for the year ended December 31, 2011. Pensions and Other Postretirement Benefit Plans Employers are required to recognize in their balance sheets the overfunded or underfunded status of defined benefit pension and other postretirement plans, measured as the difference between the fair value of the plan assets and the benefit obligation (the projected benefit obligation for pension plans and the accumulated postretirement benefit obligation for other postretirement plans). Each overfunded plan is recognized as an asset and each underfunded plan is recognized as a liability. Employers must recognize the change in the funded status of the plan in the year in which the change occurs through Accumulated other comprehensive income in equity. See Note 14 for further information regarding pensions and other postretirement benefit plans. Revenue Recognition for Southern Union's Natural Gas Distribution Operations In Southern Union's natural gas distribution operations, natural gas utility customers are billed on a monthly-cycle basis. The related cost of natural gas and revenue taxes are matched with cycle-billed revenues through utilization of purchased natural gas adjustment provisions in tariffs approved by the regulatory agencies having jurisdiction. Revenues from natural gas delivered but not yet billed are accrued, along with the related natural gas purchase costs and revenue-related taxes.

Operations And Organization (Tables)

6 Months Ended

Jun. 30, 2012

Operations And Organization [Abstract]

Schedule Of Equity Interests

At June 30, 2012, our equity interests in ETP and Regency consisted of:



	General Partner Interest (as a % of total partnership interest)		IDRs		Common Units	Limited Partner Ownership (as a % and net of any treasury units)
ETP	1.5	%	100	%	52,476,059	23	%
Regency	1.6	%	100	%	26,266,791	15	%

Acquisitions (Tables)

6 Months Ended

Jun. 30, 2012

Acquisitions and Dispositions [Abstract]

Schedule Of Assets Acquired And Liabilities Assumed In Acquisition

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



Total current assets	$	561,038
Property, plant and equipment (useful lives of 25 - 30 years)	6,958,768
Goodwill	2,030,273
Intangible assets (weighted average useful life of 17.5 years)	55,000
Investments in unconsolidated affiliates	2,022,784
Other assets	162,576
	11,790,439

Long-term debt obligations, including current portion	3,778,706
Deferred income taxes	1,698,352
Other liabilities	950,511
	6,427,569
Total consideration	5,362,870
Cash received	36,792
Total consideration, net of cash received	$	5,326,078

Pro Forma Results Of Operations



	Three Months Ended June 30,				Six Months Ended June 30,
	2012		2011		2012		2011
Revenues	$	1,976,314	$	2,606,513	$	4,299,094	$	5,342,455
Net income	84,983		127,798		1,173,075		348,925
Net income attributable to partners	63,959		80,646		354,977		184,536
Basic net income per Limited Partner unit	$	0.23	$	0.29	$	1.26	$	0.66
Diluted net income per Limited Partner unit	$	0.23	$	0.29	$	1.26	$	0.66

- 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

Investments in Affiliates (Tables)

6 Months Ended

Jun. 30, 2012

INVESTMENTS IN AFFILIATES [Abstract]

Investments in and Advances to Affiliates, Schedule of Investments [Text Block]

The following tables present aggregated selected income statement data for our unconsolidated affiliates, including AmeriGas, Citrus, FEP, HPC and MEP (on a 100% basis for all periods presented).



	Three Months Ended June 30,				Six Months Ended June 30,
	2012		2011		2012		2011
Revenue	$	1,045,245	$	809,430	$	2,411,123	$	1,964,584
Operating income	220,202		208,911		534,284		494,618
Net income	49,512		93,282		266,743		328,570

Cash And Cash Equivalents (Tables)

6 Months Ended

Jun. 30, 2012

Supplemental Cash Flow Information [Abstract]

Schedule Of Non-Cash Investing and Non-Cash Financing Activities

Non-cash investing and financing activities are as follows:



	Six Months Ended June 30,
	2012			2011
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures	$	484,936		$	106,047
Accrued advances to affiliates	$	3,844		$	—
Gain (loss) from subsidiary common unit transactions	$	(13,939	)	$	92,074
AmeriGas limited partner interest received in Propane Contribution (see Note 4)	$	1,123,003		$	—
NON-CASH FINANCING ACTIVITIES:
Issuance of common units in connection with Southern Union Merger (see Note 3)	$	2,354,490		$	—
Subsidiary issuances of common units in connection with acquisitions	$	112,000		$	—

Inventories (Tables)

6 Months Ended

Jun. 30, 2012

Inventory, Net [Abstract]

Schedule Of Inventory

Inventories consisted of the following:



	June 30, 2012		December 31, 2011
Natural gas and NGLs, excluding propane	$	305,279	$	146,132
Propane	—		86,958
Appliances, parts and fittings and other	138,463		94,873
Total inventories	$	443,742	$	327,963

Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2012

Fair Value Measurements [Abstract]

Fair Value Of Financial Assets And Liabilities Measured On Recurring Basis



	Fair Value Measurements at June 30, 2012
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Marketable securities	$	11		$	11		$	—		$	—
Interest rate derivatives	50,543			—			50,543			—
Commodity derivatives:
Condensate — Forward Swaps	3,974			—			3,974			—
Natural Gas:
Basis Swaps IFERC/NYMEX	53,966			53,966			—			—
Swing Swaps IFERC	5,589			1,390			4,199			—
Fixed Swaps/Futures	81,517			63,572			17,945			—
Options — Puts	3,688			—			3,688			—
Forward Physical Contracts	976			—			976			—
NGLs:
Swaps	7,681			—			7,681			—
Options — Puts	1,523			—			1,523			—
Power:
Forwards	42,504			6,196			36,308			—
Options — Puts	135			135			—			—
Total commodity derivatives	201,553			125,259			76,294			—
Total Assets	$	252,107		$	125,270		$	126,837		$	—
Liabilities:
Interest rate derivatives	$	(233,447	)	$	—		$	(233,447	)	$	—
Preferred Units	(319,860		)	—			—			(319,860		)
Embedded derivatives in the Regency Preferred Units	(30,644		)	—			—			(30,644		)
Natural Gas:
Basis Swaps IFERC/NYMEX	(73,804		)	(73,804		)	—			—
Swing Swaps IFERC	(7,504		)	(2,668		)	(4,836		)	—
Fixed Swaps/Futures	(81,314		)	(61,002		)	(20,312		)	—
Options — Calls	(1		)	—			(1		)	—
Options — Puts	(55		)	—			(55		)	—
Forward Physical Contracts	(386		)	—			(386		)	—
Power:
Forwards	(41,444		)	(776		)	(40,668		)	—
Total commodity derivatives	(204,508		)	(138,250		)	(66,258		)	—
Total Liabilities	$	(788,459	)	$	(138,250	)	$	(299,705	)	$	(350,504	)



	Fair Value Measurements at December 31, 2011
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Marketable securities	$	1,229		$	1,229		$	—		$	—
Interest rate derivatives	36,301			—			36,301			—
Commodity derivatives:
Condensate — Forward Swaps	538			—			538			—
Natural Gas:
Basis Swaps IFERC/NYMEX	62,924			62,924			—			—
Swing Swaps IFERC	15,002			1,687			13,315			—
Fixed Swaps/Futures	218,479			214,572			3,907			—
Options — Puts	6,435			—			6,435			—
Forward Physical Contracts	699			—			699			—
NGLs:
Swaps	94			—			94			—
Options — Puts	309			—			309			—
Propane — Forwards/Swaps	9			—			9			—
Total commodity derivatives	304,489			279,183			25,306			—
Total Assets	$	342,019		$	280,412		$	61,607		$	—
Liabilities:
Interest rate derivatives	$	(117,490	)	$	—		$	(117,490	)	$	—
Preferred Units	(322,910		)	—			—			(322,910		)
Embedded derivatives in the Regency Preferred Units	(39,049		)	—			—			(39,049		)
Commodity derivatives:
Condensate — Forward Swaps	(1,567		)	—			(1,567		)	—
Natural Gas:
Basis Swaps IFERC/NYMEX	(82,290		)	(82,290		)	—			—
Swing Swaps IFERC	(16,074		)	(3,061		)	(13,013		)	—
Fixed Swaps/Futures	(148,111		)	(148,111		)	—			—
Options — Calls	(12		)	—			(12		)	—
Forward Physical Contracts	(712		)	—			(712		)	—
NGLs — Swaps	(8,561		)	—			(8,561		)	—
Propane — Forwards/Swaps	(4,131		)	—			(4,131		)	—
Total commodity derivatives	(261,458		)	(233,462		)	(27,996		)	—
Total Liabilities	$	(740,907	)	$	(233,462	)	$	(145,486	)	$	(361,959	)

Unobservable Inputs of Fair Value Level 3 Liabilities [Table Text Block]

The following table presents the material unobservable inputs used to estimate the fair value of the Preferred Units and the embedded derivatives in Regency's Preferred Units:



	Unobservable Input	June 30, 2012
Preferred Units	Assumed Yield	7.23	%
Embedded derivatives in the Regency Preferred Units	Credit Spread	6.83	%
	Volatility	18.02	%

Reconciliation For Liabilities Measured At Fair Value On A Recurring Basis



Balance, December 31, 2011	$	(361,959	)
Net unrealized gain included in other income (expense)	11,455
Balance, June 30, 2012	$	(350,504	)

- 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

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 820
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6925170&loc=d3e19279-110258

Reference 8: 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 Per Limited Partner Unit (Tables)

6 Months Ended

Jun. 30, 2012

Earnings Per Share [Abstract]

Reconciliation Of Net Income And Weighted Average Units

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



	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
Basic Net Income per Limited Partner Unit:
Limited Partners’ interest in net income	$	53,366		$	66,080		$	219,282		$	154,446
Weighted average Limited Partner units	279,955,578			222,972,708			253,343,028			222,963,741
Basic net income per Limited Partner unit	$	0.19		$	0.30		$	0.87		$	0.69
Diluted Net Income per Limited Partner Unit:
Limited Partners’ interest in net income	$	53,366		$	66,080		$	219,282		$	154,446
Dilutive effect of equity-based compensation of subsidiaries	(107		)	(132		)	(1,249		)	(402		)
Diluted net income available to Limited Partners	$	53,259		$	65,948		$	218,033		$	154,044
Weighted average Limited Partner units	279,955,578			222,972,708			253,343,028			222,963,741
Diluted net income per Limited Partner unit	$	0.19		$	0.30		$	0.86		$	0.69

Debt Obligations Schedule of Debt Obligations (Tables)

6 Months Ended

Jun. 30, 2012

Debt Instrument [Line Items]

Schedule of Long-term Debt Instruments

Our debt obligations consisted of the following:



	June 30, 2012			December 31, 2011
Parent Company Indebtedness:
ETE Senior Notes, due October 15, 2020	$	1,800,000		$	1,800,000
ETE Senior Secured Term Loan, due March 26, 2017	2,000,000			—
ETE Senior Secured Revolving Credit Facility	10,000			71,500
Subsidiary Indebtedness:
ETP Senior Notes (aggregated)	7,800,000			6,550,000
Transwestern Senior Unsecured Notes (aggregated)	870,000			870,000
HOLP Senior Secured Notes (aggregated)	—			71,314
Regency Senior Notes (aggregated)	1,262,500			1,350,000
Southern Union Senior Notes:
7.6% Senior Notes due February 1, 2024	359,765			—
8.25% Senior Notes due November 14, 2029	300,000			—
7.24% to 9.44% First Mortgage Bonds due February 15, 2020 to December 15, 2027	19,500			—
7.2% Junior Subordinated Notes due November 1, 2066	600,000			—
Notes Payable	7,465			—
Panhandle:
6.05% Senior Notes due August 15, 2013	250,000			—
6.2% Senior Notes due November 1, 2017	300,000			—
7.0% Senior Notes due June 15, 2018	400,000			—
8.125% Senior Notes due June 1, 2019	150,000			—
7.0% Senior Notes due July 15, 2029	66,305			—
Term Loan due February 23, 2015	455,000			—
Revolving Credit Facilities:
ETP Revolving Credit Facility	493,449			314,438
Regency Revolving Credit Facility	515,000			332,000
Southern Union Revolving Credit Facility	235,000			—
Other Long-Term Debt	22,022			10,434
Unamortized discounts, net	(55,963		)	(10,309		)
Fair value adjustments related to interest rate swaps	213,342			11,647
	18,073,385			11,371,024
Current maturities	(113,921		)	(424,160		)
	$	17,959,464		$	10,946,864

- Definition

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph 22
-Article 5

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
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+ Details

Debt Obligations Schedule of Maturities of Long Term Debt Obligations (Tables)

6 Months Ended

Jun. 30, 2012

Debt Instrument [Line Items]

Schedule of Maturities of Long-term Debt



2012 (remainder)	$	111,410
2013	604,951
2014	900,045
2015	765,308
2016	1,476,516
Thereafter	14,057,776
Total	$	17,916,006

Equity (Tables)

6 Months Ended

Jun. 30, 2012

Change In ETE Common Units

The change in ETE Common Units during the six months ended June 30, 2012 was as follows:



	Number of Units
Outstanding at December 31, 2011	222,972,708
Issuance of restricted units under equity incentive plan	740
Issuance of common units in connection with Southern Union Merger (See Note 3)	56,982,160
Outstanding at June 30, 2012	279,955,608

Accumulated Other Comprehensive Income

The following table presents the components of AOCI, net of tax:



	June 30, 2012			December 31, 2011
Net gains on commodity related hedges	$	15,030		$	1,696
Unrealized gains on available-for-sale securities	—			114
Equity investments, net	(22,208		)	—
Subtotal	(7,178		)	1,810
Amounts attributable to noncontrolling interest	8,487			(1,132		)
Total AOCI included in partners’ capital, net of tax	$	1,309		$	678

Parent Company [Member]

Quarterly Distributions Of Available Cash

Following are distributions declared and/or paid by us subsequent to December 31, 2011:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2011	February 7, 2012	February 17, 2012	$	0.625
March 31, 2012	May 4, 2012	May 18, 2012	0.625
June 30, 2012	August 6, 2012	August 17, 2012	0.625

ETP [Member]

Quarterly Distributions Of Available Cash

Following are distributions declared and/or paid by ETP subsequent to December 31, 2011:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2011	February 7, 2012	February 14, 2012	$	0.89375
March 31, 2012	May 4, 2012	May 15, 2012	0.89375
June 30, 2012	August 6, 2012	August 14, 2012	0.89375

Regency [Member]

Quarterly Distributions Of Available Cash

Following are distributions declared and/or paid by Regency subsequent to December 31, 2011:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2011	February 6, 2012	February 13, 2012	$	0.46
March 31, 2012	May 7, 2012	May 14, 2012	0.46
June 30, 2012	August 6, 2012	August 14, 2012	0.46

- 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
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-Name Accounting Standards Codification
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-Paragraph 1
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-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
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-Name Accounting Standards Codification
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-Topic 220
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-URI http://asc.fasb.org/extlink&oid=6920043&loc=d3e689-108580

+ Details

Benefits (Tables)

Mar. 31, 2012

Defined Benefit Plan Disclosure [Line Items]

Schedule of Defined Benefit Plans Disclosures

The following table contains information at the acquisition date (March 26, 2012) about the obligations and funded status of Southern Union’s pension and other postretirement plans on a combined basis:



	Pension Benefits			Other Postretirement Benefits
Benefit obligation	$	227,548		$	140,651
Fair value of plan assets	$	143,979		$	118,784
Amount underfunded	$	(83,569	)	$	(21,867	)
Amounts recognized in our consolidated balance sheet related to Southern Union's pension and other postretirement plans consist of:
Non-current assets	$	—		$	6,062
Current liabilities	—			(133		)
Non-current liabilities	(83,569		)	(27,796		)
	$	(83,569	)	$	(21,867	)

Schedule of Accumulated Benefit Obligations in Excess of Fair Value of Plan Assets

The following table summarizes information at the acquisition date (March 26, 2012) for plans with an accumulated benefit obligation in excess of the plan assets:



	Pension Benefits		Other Postretirement Benefits
Projected benefit obligation	$	227,548	N/A
Accumulated benefit obligation	213,614		$	110,314
Fair value of plan assets	143,979		82,385

Benfit obligations assumptions table

The following table includes weighted average assumptions used in determining benefit obligations as of the acquisition date (March 26, 2012):



	Pension Benefits		Other Postretirement Benefits
Discount rate	4.10	%	4.10	%
Rate of compensation increase	3.03	%	N/A

Schedule of Health Care Cost Trend Rates



Health care cost trend rate assumed for next year	9.00	%
Rate to which the cost trend is assumed to decline (the ultimate trend rate)	4.85	%
Year that the rate reaches the ultimate trend rate	2020

- Definition

Tabular disclosure of one or more of the entity's defined benefit pension plans or one or more other defined benefit postretirement plans, separately for pension plans and other postretirement benefit plans including the entity's schedule of fair value of plan assets for defined benefit or other postretirement plans.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5, 6, 7
-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 158
-Paragraph 4, 7, 16, 20, 21
-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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Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 132R
-Paragraph 5
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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.

+ Details

Income Taxes (Tables)

6 Months Ended

Jun. 30, 2012

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 June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
Current expense (benefit):
Federal	$	(41	)	$	561		$	(60	)	$	5,663
State	4,153			5,439			7,889			9,435
Total	4,112			6,000			7,829			15,098
Deferred expense (benefit):
Federal	6,347			(747		)	(2,218		)	(559		)
State	(284		)	(29		)	6,143			588
Total	6,063			(776		)	3,925			29
Total income tax expense	$	10,175		$	5,224		$	11,754		$	15,127

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Future Lease Commitments (Tables)

6 Months Ended

Jun. 30, 2012

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities [Abstract]

Schedule of Future Minimum Rental Payments for Operating Leases

Future minimum lease commitments for such leases are:



Years Ending December 31:
2012 (remainder)	$	18,595
2013	38,341
2014	33,295
2015	31,683
2016	30,820
Thereafter	216,143

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Acrrued Environmental Liabilities (Tables)

6 Months Ended

Jun. 30, 2012

Environmental Exit Cost [Line Items]

Environmental Exit Costs by Cost



	June 30, 2012		December 31, 2011
Current	$	4,205	$	3,861
Non-current	35,121		9,990
Total environmental liabilities	$	39,326	$	13,851

Price Risk Management Assets And Liabilities (Tables)

6 Months Ended

Jun. 30, 2012

Interest Rate Swaps Outstanding

The following is a summary of interest rate swaps outstanding as of June 30, 2012 and December 31, 2011, none of which were designated as hedges for accounting purposes:

Notional Amount

Outstanding

Entity

Term

Type⁽¹⁾

June 30,
2012

December 31, 2011

ETE

March 2017

Pay a fixed rate of 1.25% and receive a floating rate

500,000

—

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

ETP

July 2013 ⁽²⁾

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

400,000

300,000

ETP

July 2014 ⁽²⁾

Forward starting to pay a fixed rate of 4.26% and receive a floating rate

400,000

—

ETP

July 2018

Pay a floating rate plus a spread of 4.17% and receive a fixed rate of 6.70%

600,000

500,000

Regency

April 2012

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

—

250,000

Southern Union

November 2016

Pay a fixed rate of 2.913% and receive a floating rate

75,000

N/A

Southern Union

November 2021

Pay a fixed rate of 3.746% and receive a floating rate

450,000

N/A

(1)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 June 30, 2012 and December 31, 2011:



	Fair Value of Derivative Instruments
	Asset Derivatives				Liability Derivatives
	June 30, 2012		December 31, 2011		June 30, 2012			December 31, 2011
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	12,911	$	77,197	$	(6,698	)	$	(819	)
Commodity derivatives	14,890		4,539		(2,146		)	(10,128		)
	27,801		81,736		(8,844		)	(10,947		)
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	$	123,426	$	227,337	$	(139,666	)	$	(251,268	)
Commodity derivatives	53,548		1,017		(59,220		)	(4,844		)
Interest rate derivatives	50,543		36,301		(233,447		)	(117,490		)
Embedded derivatives in Regency Preferred Units	—		—		(30,644		)	(39,049		)
	227,517		264,655		(462,977		)	(412,651		)
Total derivatives	$	255,318	$	346,391	$	(471,821	)	$	(423,598	)

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 June 30,					Six Months Ended June 30,
	2012			2011		2012		2011
Derivatives in cash flow hedging relationships:
Commodity derivatives	$	(17,038	)	$	3,769	$	5,177	$	(7,123	)
Interest rate derivatives	19,709			—		19,709		—
Total	$	2,671		$	3,769	$	24,886	$	(7,123	)

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 June 30,					Six Months Ended June 30,
		2012		2011			2012		2011
Derivatives in cash flow hedging relationships:
Commodity derivatives	Cost of products sold	$	12,152	$	(2,148	)	$	15,587	$	12,954
Total		$	12,152	$	(2,148	)	$	15,587	$	12,954



	Location of Gain/(Loss) Reclassified from AOCI into Income (Ineffective Portion)	Amount of Gain/(Loss) Recognized in Income on Ineffective Portion
		Three Months Ended June 30,					Six Months Ended June 30,
		2012			2011		2012		2011
Derivatives in cash flow hedging relationships:
Commodity derivatives	Cost of products sold	$	(1	)	$	96	$	46	$	189
Total		$	(1	)	$	96	$	46	$	189



	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 June 30,				Six Months Ended June 30,
		2012		2011		2012		2011
Derivatives in fair value hedging relationships (including hedged item):
Commodity derivatives	Cost of products sold	$	31,671	$	15,874	$	18,833	$	22,291
Total		$	31,671	$	15,874	$	18,833	$	22,291



	Location of Gain/(Loss) Recognized in Income on Derivatives	Amount of Gain/(Loss) Recognized in Income on Derivatives
		Three Months Ended June 30,						Six Months Ended June 30,
		2012			2011			2012			2011
Derivatives not designated as hedging instruments:
Commodity derivatives — Trading	Cost of products sold	$	(709	)	$	—		$	(11,295	)	$	—
Commodity derivatives — Non-Trading	Cost of products sold	12,575			(11,427		)	12,112			(4,989		)
Interest rate derivatives	Gains (losses) on non-hedged interest rate derivatives	(44,668		)	1,883			(17,178		)	3,403
Embedded derivatives	Other income	7,909			2,950			8,405			5,525
Total		$	(24,893	)	$	(6,594	)	$	(7,956	)	$	3,939

ETP [Member]

Outstanding Commodity-Related Derivatives

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



	June 30, 2012			December 31, 2011
	Notional Volume		Maturity	Notional Volume		Maturity
Mark-to-Market Derivatives
(Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX⁽¹⁾	7,650,000		2012-2013	(151,260,000	)	2012-2013
Power (Thousand Megawatt):
Forwards	4,800		2012-2013	—		—
Options — Puts	36,800		2012	—		—
(Non-Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX	(55,272,500	)	2012-2013	(61,420,000	)	2012-2013
Swing Swaps IFERC	(19,825,000	)	2012-2013	92,370,000		2012-2013
Fixed Swaps/Futures	1,062,500		2012-2014	797,500		2012
Forward Physical Contracts	(20,481,365	)	2012	(10,672,028	)	2012
Options — Puts	500,000		2012	—		—
Propane (Gallons):
Forwards/Swaps	—		—	38,766,000		2012-2013
Fair Value Hedging Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX	(25,707,500	)	2012-2013	(28,752,500	)	2012
Fixed Swaps/Futures	(51,790,000	)	2012-2013	(45,822,500	)	2012
Hedged Item — Inventory	51,790,000		2012-2013	45,822,500		2012
Cash Flow Hedging Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX	(12,850,000	)	2012-2013	—		—
Fixed Swaps/Futures	(31,100,000	)	2012-2013	—		—
Options — Puts	1,800,000		2012	3,600,000		2012
Options — Calls	(1,800,000	)	2012	(3,600,000	)	2012

⁽¹⁾ Includes aggregate amounts for open positions related to Houston Ship Channel, Waha Hub, NGPL TexOk, West Louisiana Zone and Henry Hub locations.

Regency [Member]

Outstanding Commodity-Related Derivatives

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



	June 30, 2012		December 31, 2011
	Notional Volume	Maturity	Notional Volume	Maturity
Mark-to-Market Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Fixed Swaps/Futures	5,297,000	2012-2014	—	—
Propane (Gallons):
Forwards/Swaps	7,770,000	2012-2013	—	—
Natural Gas Liquids (Barrels):
Forwards/Swaps	277,000	2012-2013	—	—
Options — Puts	110,000	2012	110,000	2012
WTI Crude Oil (Barrels):
Forwards/Swaps	344,000	2012-2014	—	—
Cash Flow Hedging Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Fixed Swaps/Futures	—	—	2,198,000	2012
Propane (Gallons):
Forwards/Swaps	—	—	11,802,000	2012-2013
Natural Gas Liquids (Barrels):
Forwards/Swaps	—	—	533,000	2012-2013
WTI Crude Oil (Barrels):
Forwards/Swaps	—	—	350,000	2012-2014

Southern Union [Member]

Outstanding Commodity-Related Derivatives

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



	June 30, 2012
	Notional Volume	Maturity
Mark-to-Market Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Fixed Swaps/Futures	19,750,000	2012-2014
Cash Flow Hedging Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Fixed Swaps/Futures	15,557,500	2012-2013
Natural Gas Liquids (Barrels):
Fixed Swaps/Futures	2,760,000	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
-Section 50
-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
-Section 50
-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
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n)(2))
-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 815
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6935481&loc=d3e41638-113959

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1B
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5580258-113959

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6935481&loc=SL5579240-113959

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=6935481&loc=d3e41641-113959

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 2
-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
-SubTopic 25
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6886632&loc=d3e76258-113986

+ Details

Other Information (Tables)

6 Months Ended

Jun. 30, 2012

Other Information [Abstract]

Other Current Assets

Other current assets consisted of the following:



	June 30, 2012		December 31, 2011
Deposits paid to vendors	$	87,663	$	66,231
Prepaid expenses and other	85,092		115,673
Total other current assets	$	172,755	$	181,904

Other Non-Current Assets, net

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



	June 30, 2012		December 31, 2011
Unamortized financing costs (3 to 30 years)	$	153,110	$	132,375
Regulatory assets	220,180		88,993
Other	103,004		27,542
Total other non-current assets, net	$	476,294	$	248,910

Accrued And Other Current Liabilities

Accrued and other current liabilities consisted of the following:



	June 30, 2012		December 31, 2011
Interest payable	$	278,980	$	204,182
Customer advances and deposits	38,253		100,525
Accrued capital expenditures	472,409		228,877
Accrued wages and benefits	53,618		80,205
Taxes payable other than income taxes	127,937		79,331
Income taxes payable	8,882		14,781
Other	101,254		56,011
Total accrued and other current liabilities	$	1,081,333	$	763,912

Reportable Segments (Tables)

6 Months Ended

Jun. 30, 2012

Operating Segments [Member]

Financial Information By Segment



	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
Segment Adjusted EBITDA:
Investment in ETP	$	466,350		$	388,135		$	1,002,412		$	859,434
Investment in Regency	115,272			103,456			249,321			195,193
Southern Union Transportation and Storage	115,919			—			82,644			—
Southern Union Gathering and Processing	22,362			—			10,859			—
Southern Union Distribution	23,314			—			13,446			—
Corporate and Other	(15,273		)	(12,392		)	(50,124		)	(16,074		)
Total	727,944			479,199			1,308,558			1,038,553
Depreciation and amortization	(221,767		)	(148,530		)	(382,968		)	(287,786		)
Interest expense, net of interest capitalized	(281,255		)	(181,517		)	(494,585		)	(349,446		)
Bridge loan related fees	—			—			(62,241		)	—
Gain on deconsolidation of Propane Business	765			—			1,056,709			—
Gains (losses) on non-hedged interest rate derivatives	(44,668		)	1,883			(17,178		)	3,403
Non-cash unit-based compensation expense	(11,581		)	(11,699		)	(23,736		)	(23,085		)
Unrealized gains (losses) on commodity risk management activities	36,514			1,365			(46,997		)	12,747
Losses on disposal of assets	(1,402		)	(681		)	(2,462		)	(2,435		)
Losses on extinguishments of debt	(7,821		)	—			(122,844		)	—
Gain on curtailment of other postretirement benefit plans	—			—			15,332			—
Proportionate share of unconsolidated affiliates' interest, depreciation, amortization, non-cash compensation expense, loss on extinguishment of debt and taxes	(118,232		)	(29,300		)	(184,092		)	(57,421		)
Other, net	6,200			1,156			4,082			(13,659		)
Income before income tax expense	$	84,697		$	111,876		$	1,047,578		$	320,871

Investment In ETP [Member]

Investment in ETP



	Three Months Ended June 30,				Six Months Ended June 30,
	2012		2011		2012		2011
Intrastate Transportation and Storage	$	452,237	$	643,653	$	899,033	$	1,232,331
Interstate Transportation	126,900		104,850		255,176		209,951
Midstream	460,077		513,584		914,176		926,779
NGL Transportation and Services	147,851		93,686		302,119		93,686
Retail Propane and Other Retail Propane Related	12,966		243,973		92,972		801,188
All Other	40,283		28,349		82,698		51,737
Total revenues	1,240,314		1,628,095		2,546,174		3,315,672
Less: Intersegment revenues	11,811		11,347		16,181		22,877
Revenues from external customers	$	1,228,503	$	1,616,748	$	2,529,993	$	3,292,795

Investment In Regency [Member]

Investment in Regency



	Three Months Ended June 30,				Six Months Ended June 30,
	2012		2011		2012		2011
Gathering and Processing	$	263,100	$	303,203	$	570,267	$	569,175
Contract Compression	36,237		38,072		73,438		76,508
Contract Treating	7,388		10,842		16,523		19,275
Corporate and Others	5,251		4,381		9,647		8,792
Total revenues	311,976		356,498		669,875		673,750
Less: Intersegment revenues	2,497		1,682		6,484		3,375
Revenues from external customers	$	309,479	$	354,816	$	663,391	$	670,375

Assets Segments [Member]

Financial Information By Segment



	June 30, 2012			December 31, 2011
Total assets:
Investment in ETP	$	17,859,419		$	15,518,616
Investment in Regency	5,832,562			5,567,856
Southern Union Transportation and Storage	5,755,369			—
Southern Union Gathering and Processing	2,805,884			—
Southern Union Distribution	1,245,794			—
Corporate and Other	424,152			470,086
Adjustments and Eliminations	(809,958		)	(659,765		)
Total	$	33,113,222		$	20,896,793

Sales Revenue, Segment [Member]

Financial Information By Segment



	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
Revenues:
Investment in ETP:
Revenues from external customers	$	1,228,503		$	1,616,748		$	2,529,993		$	3,292,795
Intersegment revenues	11,811			11,347			16,181			22,877
	1,240,314			1,628,095			2,546,174			3,315,672
Investment in Regency:
Revenues from external customers	309,479			354,816			663,391			670,375
Intersegment revenues	2,497			1,682			6,484			3,375
	311,976			356,498			669,875			673,750
Southern Union Transportation and Storage:
Revenues from external customers	183,765			—			197,241			—
Intersegment revenues	1,451			—			1,451			—
	185,216			—			198,692			—
Southern Union Gathering and Processing:
Revenues from external customers	195,499			—			214,735			—
Intersegment revenues	1,977			—			2,098			—
	197,476			—			216,833			—
Southern Union Distribution:
Revenues from external customers	86,220			—			94,505			—
Intersegment revenues	—			—			—			—
	86,220			—			94,505			—
Corporate and Other:
Revenues from external customers	3,558			—			2,152			—
Intersegment revenues	—			—			—			—
	3,558			—			2,152			—
Adjustments and Eliminations:
Revenues from external customers	(30,710		)	3,342			(36,572		)	856
Intersegment revenues	(17,736		)	(13,029		)	(26,214		)	(26,252		)
Total revenues	$	1,976,314		$	1,974,906		$	3,665,445		$	3,964,026

- 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)

6 Months Ended

Jun. 30, 2012

Schedule Of Balance Sheets

BALANCE SHEETS

(unaudited)



	June 30, 2012		December 31, 2011
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	2,729	$	18,460
Accounts receivable from related companies	4,084		1,456
Note receivable from affiliate	167,315		—
Other current assets	303		714
Total current assets	174,431		20,630
ADVANCES TO AND INVESTMENTS IN AFFILIATES	6,216,728		2,225,572
INTANGIBLES	20,874		—
GOODWILL	9,006		—
OTHER NON-CURRENT ASSETS, net	61,618		49,906
Total assets	$	6,482,657	$	2,296,108
LIABILITIES AND PARTNERS' CAPITAL
CURRENT LIABILITIES:
Accounts payable	$	846	$	174
Accounts payable to related companies	2,812		12,334
Interest payable	47,677		34,753
Price risk management liabilities	3,853		—
Accrued and other current liabilities	1,701		953
Current maturities of long-term debt	4,971		—
Total current liabilities	61,860		48,214
LONG-TERM DEBT, less current maturities	3,788,829		1,871,500
SERIES A CONVERTIBLE PREFERRED UNITS	319,860		322,910
OTHER NON-CURRENT LIABILITIES	13,255		—
COMMITMENTS AND CONTINGENCIES
PARTNERS' CAPITAL:
General Partner	71		321
Limited Partners	2,297,473		52,485
Accumulated other comprehensive income	1,309		678
Total partners’ capital	2,298,853		53,484
Total liabilities and partners' capital	$	6,482,657	$	2,296,108

Schedule Of Statements Of Operations

STATEMENTS OF OPERATIONS

(unaudited)



	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES	$	(10,368	)	$	(12,037	)	$	(41,443	)	$	(13,879	)
OTHER INCOME (EXPENSE):
Interest expense, net of interest capitalized	(63,687		)	(40,587		)	(106,274		)	(81,526		)
Bridge loan related fees	—			—			(62,241		)	—
Loss on non-hedged derivatives	(8,700		)	—			(9,097		)	—
Equity in earnings of affiliates	127,370			120,626			434,057			267,268
Other, net	8,861			(1,653		)	4,960			(16,812		)
INCOME BEFORE INCOME TAXES	53,476			66,349			219,962			155,051
Income tax expense	(22		)	64			42			126
NET INCOME	53,498			66,285			219,920			154,925
GENERAL PARTNER’S INTEREST IN NET INCOME	132			205			638			479
LIMITED PARTNERS’ INTEREST IN NET INCOME	$	53,366		$	66,080		$	219,282		$	154,446

Parent Company [Member]

Schedule Of Statements Of Cash Flows

STATEMENTS OF CASH FLOWS

(unaudited)



	Six Months Ended June 30,
	2012			2011
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	$	203,062		$	233,152
CASH FLOWS FROM INVESTING ACTIVITIES:
Cash paid for acquisitions	(1,113,377		)	—
Contributions to affiliate	(445,000		)	—
Note receivable from affiliate	(221,217		)	—
Payments received on note receivable from affiliate	55,000			—
Net cash used in investing activities	(1,724,594		)	—
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings	2,005,000			20,000
Principal payments on debt	(106,500		)	(20,000		)
Distributions to partners	(315,196		)	(246,016		)
Debt issuance costs	(77,503		)	—
Net cash provided by (used in) financing activities	1,505,801			(246,016		)
DECREASE IN CASH AND CASH EQUIVALENTS	(15,731		)	(12,864		)
CASH AND CASH EQUIVALENTS, beginning of period	18,460			27,247
CASH AND CASH EQUIVALENTS, end of period	$	2,729		$	14,383

Operations And Organization (Narrative) (Details) - USD ($) shares in Thousands, $ in Millions		6 Months Ended
	Mar. 31, 2012	Jun. 30, 2012	Mar. 26, 2012
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares		57,000
Citrus Corp [Member]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares		2,250
Regency [Member] \| Lone Star L.L.C. [Member]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners		30.00%
ETP [Member] \| Lone Star L.L.C. [Member]
Percentage interest in joint venture		70.00%
Southern Union Merger [Member]
Significant Acquisitions and Disposals, Date of Transaction for Acquisition or Disposal	Mar. 26, 2012
Business Acquisition, Cost of Acquired Entity, Cash Paid			$ 3,010
Citrus Merger [Member]
Business Acquisition, Cost of Acquired Entity, Cash Paid		$ 1,900
Interest ownership		50.00%

Operations And Organization (Schedule Of Equity Interests) (Details)	Jun. 30, 2012 shares
Incentive Distribution Rights	100.00%
ETP [Member]
General Partner Interest	1.50%
Incentive Distribution Rights	100.00%
Common Units	52,476,059
Percent of total equity ownership of a subsidiary	23.00%
Regency [Member]
General Partner Interest	1.60%
Incentive Distribution Rights	100.00%
Common Units	26,266,791
Percent of total equity ownership of a subsidiary	15.00%

Acquisitions (Narrative) (Details)		3 Months Ended		6 Months Ended
Acquisitions (Narrative) (Details)	Mar. 31, 2012 USD ($)	Jun. 30, 2012 USD ($) shares	Jun. 30, 2011 USD ($)	Jun. 30, 2012 USD ($) shares	Jun. 30, 2011 USD ($)	Mar. 26, 2012 USD ($) shares quarters
Revenues		$ 1,976,314,000	$ 1,974,906,000	$ 3,665,445,000	$ 3,964,026,000
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares \| shares				57,000,000
Net Income (Loss) Attributable to Parent		$ 53,498,000	66,285,000	$ 219,920,000	154,925,000
Citrus Corp [Member]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares \| shares				2,250,000
Citrus Merger [Member]
Interest ownership		50.00%		50.00%
Business Acquisition, Cost of Acquired Entity, Cash Paid		$ 1,900,000,000		$ 1,900,000,000
Business Acquisition, Cost of Acquired Entity, Purchase Price		2,000,000,000		2,000,000,000
Citrus Merger [Member] \| ETP [Member]
Incentive distributions to relinquish						$ 220,000,000
Number of periods of incentive distributions to be relinquished in future periods contingent upon closing of proposed transaction. \| quarters						16
Southern Union Merger [Member]
Revenues		472,500,000		512,200,000
Asset Retirement Obligation		46,500,000		46,500,000		$ 46,000,000
Percent of Outstanding Shares Exchanged for Equity						46.00%
Significant Acquisitions and Disposals, Date of Transaction for Acquisition or Disposal	Mar. 26, 2012
Business Acquisition, Cost of Acquired Entity, Cash Paid						$ 3,010,000,000
Business Acquisition, Cost of Acquired Entity, Purchase Price						5,362,870,000
Cash paid in exchange of each share						$ 44.25
Number of share received in exchange of each share \| shares						1.00
Percentage of maximum cash consideration in total consideration						60.00%
Percent of Outstanding Shares Exchanged for Cash						54.00%
Stock Issued During Period, Value, Acquisitions	$ 2,350,000,000
Net Income (Loss) Attributable to Parent		11,700,000		(26,800,000)
Business Combination, Acquisition Related Costs		8,300,000		38,200,000
Southern Union Merger [Member] \| Maximum [Member]
Percentage of Fluctuation In Common Units Allowed						50.00%
Southern Union Merger [Member] \| Units Acquired for Cash [Member]
Business Acquisition Units Acquired \| shares						67,985,929
Southern Union Merger [Member] \| Units Acquired for Equity [Member]
Business Acquisition Units Acquired \| shares						56,981,860
Sunoco Merger [Member]
Cash paid in exchange of each share		$ 50.00		$ 50.00
Number of share received in exchange of each share \| shares		1.0490		1.0490
Sunoco Ownership of ETP Common Units		20.00%		20.00%
Holdco Transaction [Member]
Relinquishment Of Rights Of Incentive Distributions		$ 210,000,000
Southern Union - Transportation and Storage [Member]
Goodwill, Acquired During Period				$ 1,170,000,000
Revenues		185,216,000	0	198,692,000	0
Southern Union - Gathering and Processing [Member]
Goodwill, Acquired During Period				598,300,000
Revenues		197,476,000	0	216,833,000	0
Southern Union - Distribution [Member]
Goodwill, Acquired During Period				251,800,000
Revenues		$ 86,220,000	$ 0	94,505,000	$ 0
Corporate And Other [Member]
Goodwill, Acquired During Period				$ 10,800,000

Acquisitions (Schedule Of Assets Acquired And Liabilities Assumed) (Details) - Southern Union Merger [Member] $ in Thousands	Mar. 26, 2012 USD ($)
Total current assets	$ 561,038
Property, Plant and Equipment	6,958,768
Goodwill	2,030,273
Intangible assets	55,000
Investments in unconsolidated affiliates	2,022,784
Other noncurrent assets	162,576
Total	11,790,439
Long-term debt obligations	3,778,706
Deferred income taxes	1,698,352
Other liabilities	950,511
Total	6,427,569
Total consideration	5,362,870
Cash received	36,792
Total consideration, net of cash received	$ 5,326,078

Acquisitions (Pro Forma Results Of Operations) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Mar. 31, 2011	Jun. 30, 2012	Jun. 30, 2011
Significant Acquisitions [Line Items]
Revenues			$ 4,299,094	$ 5,342,455
Net income			1,173,075	348,925
Net income attributable to partners			$ 354,977	$ 184,536
Basic net income per Limited Partner unit			$ 1.26	$ 0.66
Diluted net income per Limited Partner unit			$ 1.26	$ 0.66
Southern Union Merger [Member]
Significant Acquisitions [Line Items]
Revenues	$ 1,976,314	$ 2,606,513
Net income	84,983	127,798
Net income attributable to partners	$ 63,959	$ 80,646
Basic net income per Limited Partner unit	$ 0.23	$ 0.29
Diluted net income per Limited Partner unit	$ 0.23	$ 0.29

- 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

Acquisitions Sunoco Merger Narrative (Details)	3 Months Ended
Acquisitions Sunoco Merger Narrative (Details)	Jun. 30, 2012 USD ($) shares $ / shares
Business Acquisition [Line Items]
Equity interest in Holdco	60.00%
Class F Units to be Issued in Holdco Transaction \| shares	50,706,000
Class F Unit Distribution Rate	35.00%
Maximum Class F Distribution per Unit \| $ / shares	$ 3.75
Portion of incentive distribution rights of a subsidiary that are owned by the Parent Company directly or indirectly.	100.00%
Sunoco Merger [Member]
Business Acquisition [Line Items]
Percent of total equity ownership of a subsidiary	32.40%
Sunoco Ownership of ETP Common Units	20.00%
Cash Paid In Exchange Of Each Share \| $	$ 50.00
Number Of Share Received In Exchange Of Each Share \| shares	1.0490
General Partner Interest	2.00%
Holdco Transaction [Member]
Business Acquisition [Line Items]
Relinquishment Of Rights Of Incentive Distributions \| $	$ 210,000,000
50% Election [Member] \| Sunoco Merger [Member]
Business Acquisition [Line Items]
Cash Paid In Exchange Of Each Share \| $	$ 25.00
Number Of Share Received In Exchange Of Each Share \| shares	0.52
ETP [Member]
Business Acquisition [Line Items]
Percent of total equity ownership of a subsidiary	23.00%
Equity interest in Holdco	40.00%
General Partner Interest	1.50%
Portion of incentive distribution rights of a subsidiary that are owned by the Parent Company directly or indirectly.	100.00%

Acquisitions Acquisition Paranthetical (Details)	6 Months Ended
Acquisitions Acquisition Paranthetical (Details)	Jun. 30, 2012 years
Paranthetical [Abstract]
Property, Plant and Equipment, Useful Life, Minimum	25
Property, Plant and Equipment, Useful Life, Maximum	30
Acquired Finite-lived Intangible Asset, Weighted Average Useful Life	17.5

Investments in Affiliates (Details) $ in Thousands, shares in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2012 USD ($) years	Jun. 30, 2011 USD ($)	Jun. 30, 2012 USD ($) years	Jun. 30, 2011 USD ($)	Jan. 12, 2012 shares
Noncash or Part Noncash Divestiture, Amount of Consideration Received			$ 1,123,003	$ 0
Gain on deconsolidation of Propane Business	$ 765	$ 0	1,056,709	0
Equity in earnings of affiliates	$ 22,463	$ 28,819	$ 97,695	$ 54,260
FEP [Member]
Interest ownership	50.00%		50.00%
MEP [Member]
Interest ownership	50.00%		50.00%
RIGS Haynesville Partnership Co. [Member]
Interest ownership	49.99%		49.99%
Citrus Merger [Member]
Interest ownership	50.00%		50.00%
Business Acquisition, Cost of Acquired Entity, Purchase Price	$ 2,000,000		$ 2,000,000
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	1,030,000		1,030,000
Business Acquisition, Cost of Acquired Entity, Cash Paid	1,900,000		1,900,000
Business Acquisition, Cost of Acquired Entity, Equity Interests Issued and Issuable	105,000		$ 105,000
Citrus Merger [Member] \| Florida Gas Transmission Pipeline System [Member]
Percentage ownership operating facility			100.00%
ETP [Member]
Proceeds from Divestiture of Businesses			$ 1,460,000
Units received in contribution \| shares					29.6
AmeriGas limited partner interest received in exchange for contribution of Propane Business			1,120,000
Noncash or Part Noncash Divestiture, Amount of Consideration Received			71,000
Gain on deconsolidation of Propane Business			1,060,000
Equity in earnings of affiliates	(36,400)		(3,100)
AmeriGas [Member]
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	630,000		630,000
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity, Amortizable Amount	$ 288,600		$ 288,600
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity, Weighted Average Amortization (years) \| years	14		14
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity, Equity Method Goodwill	$ 341,400		$ 341,400
Propane Cylinder Exchange Business [Member] \| ETP [Member]
Proceeds from Divestiture of Businesses			$ 43,000

Investments in Affiliates Schedule of Equity Method Investments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Schedule of Equity Method Investments [Line Items]
Revenue	$ 1,045,245	$ 809,430	$ 2,411,123	$ 1,964,584
Operating Income	220,202	208,911	534,284	494,618
Net Income	$ 49,512	$ 93,282	$ 266,743	$ 328,570

- Definition

The amount of net income (loss) reported by an equity method investment of the entity.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 159
-Paragraph 18
-Subparagraph f
-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 Principles Board Opinion (APB)
-Number 18
-Paragraph 20
-Subparagraph 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 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph bb
-Article 1

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph w
-Article 1

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Article 4
-Section 08
-Paragraph g
-Subparagraph 1, 2

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 28
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=6957238&loc=d3e14064-108612

Reference 7: 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.(g))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 323
-SubTopic 10
-Section 50
-Paragraph 3
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=6382943&loc=d3e33918-111571

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 323
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6382943&loc=d3e33912-111571

+ Details

Cash And Cash Equivalents (Schedule Of Non-Cash Investing & Financing Activities) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011
Accrued capital expenditures	$ 484,936	$ 106,047
Accrued advances to affiliates	3,844	0
Gain (loss) from subsidiary common unit transactions	(13,939)	92,074
AmeriGas limited partner interest received in Propane Contribution	1,123,003	0
Issuance of common units in connection with Southern Union Merger	2,354,490	0
Subsidiary issuances of common units in connection with acquisition	7,000
ETP [Member]
AmeriGas limited partner interest received in Propane Contribution	71,000
Subsidiary issuances of common units in connection with acquisition	$ 112,000	$ 0

Inventories (Details) - USD ($) $ in Thousands	Jun. 30, 2012	Dec. 31, 2011
Inventory, Net [Abstract]
Natural gas and NGLs, excluding propane	$ 305,279	$ 146,132
Propane	0	86,958
Appliances, parts and fittings and other	138,463	94,873
Total inventories	$ 443,742	$ 327,963

Goodwill And Intangible Assets (Narrative) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2012	Mar. 26, 2012
Net increase in goodwill	$ 1,419,800
Goodwill, Written off Related to Sale of Business Unit	$ 605,600
Southern Union Merger [Member]
Goodwill		$ 2,030,273

Fair Value Measurements (Narrative) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2012	Dec. 31, 2011
Fair Value Measurements [Abstract]
Debt obligations, fair value	$ 19,330,000	$ 12,210,000
Debt obligations, carrying amount	18,073,385	$ 11,371,024
Transfers between the fair value hierarchy levels, Net	$ 0

Fair Value Measurements (Fair Value Of Financial Assets And Liabilities Measured On Recurring Basis) (Details) - USD ($) $ in Thousands	Jun. 30, 2012	Dec. 31, 2011
Marketable securities, Asset Fair Value	$ 11	$ 1,229
Series A Convertible Preferred Units, Liability Fair Value	(319,860)	(322,910)
Fair Value, Measurements, Recurring [Member]
Marketable securities, Asset Fair Value	11	1,229
Interest rate derivatives, Asset Fair Value	50,543	36,301
Commodity derivatives, Asset Fair Value	201,553	304,489
Total Assets	252,107	342,019
Interest rate derivatives, Liability Fair Value	(233,447)	(117,490)
Series A Convertible Preferred Units, Liability Fair Value	(319,860)	(322,910)
Embedded derivatives in the Regency Preferred Units, Liability Fair Value	(30,644)	(39,049)
Commodity derivatives, Liability Fair Value	(204,508)	(261,458)
Total Liabilities	(788,459)	(740,907)
Fair Value, Measurements, Recurring [Member] \| Level 1 [Member]
Marketable securities, Asset Fair Value	11	1,229
Interest rate derivatives, Asset Fair Value	0	0
Commodity derivatives, Asset Fair Value	125,259	279,183
Total Assets	125,270	280,412
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	(138,250)	(233,462)
Total Liabilities	(138,250)	(233,462)
Fair Value, Measurements, Recurring [Member] \| Level 2 [Member]
Marketable securities, Asset Fair Value	0	0
Interest rate derivatives, Asset Fair Value	50,543	36,301
Commodity derivatives, Asset Fair Value	76,294	25,306
Total Assets	126,837	61,607
Interest rate derivatives, Liability Fair Value	(233,447)	(117,490)
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	(66,258)	(27,996)
Total Liabilities	(299,705)	(145,486)
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	(319,860)	(322,910)
Embedded derivatives in the Regency Preferred Units, Liability Fair Value	(30,644)	(39,049)
Commodity derivatives, Liability Fair Value	0	0
Total Liabilities	(350,504)	(361,959)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Condensate Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	3,974	(538)
Commodity derivatives, Liability Fair Value		(1,567)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Basis Swaps IFERC/NYMEX [Member]
Commodity derivatives, Asset Fair Value	53,966	62,924
Commodity derivatives, Liability Fair Value	(73,804)	(82,290)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Swing Swaps IFERC [Member]
Commodity derivatives, Asset Fair Value	5,589	15,002
Commodity derivatives, Liability Fair Value	(7,504)	(16,074)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Fixed Swaps/Futures [Member]
Commodity derivatives, Asset Fair Value	81,517	218,479
Commodity derivatives, Liability Fair Value	(81,314)	(148,111)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Call Option [Member]
Commodity derivatives, Liability Fair Value	(1)	(12)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Options - Puts [Member]
Commodity derivatives, Asset Fair Value	3,688	6,435
Commodity derivatives, Liability Fair Value	(55)	(712)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Forward Physical Swaps [Member]
Commodity derivatives, Asset Fair Value	976	699
Commodity derivatives, Liability Fair Value	(386)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| NGLs - Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	7,681	94
Commodity derivatives, Liability Fair Value		(8,561)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Ngls Options Puts [Member]
Commodity derivatives, Asset Fair Value	1,523	309
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Propane Forward Swaps [Member]
Commodity derivatives, Asset Fair Value		9
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Power - Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	42,504
Commodity derivatives, Liability Fair Value	41,444
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Power - Options - Puts [Member]
Commodity derivatives, Asset Fair Value	135
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| WTI Crude Oil [Member]
Commodity derivatives, Liability Fair Value		(4,131)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Condensate 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] \| Basis Swaps IFERC/NYMEX [Member]
Commodity derivatives, Asset Fair Value	53,966	62,924
Commodity derivatives, Liability Fair Value	(73,804)	(82,290)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Swing Swaps IFERC [Member]
Commodity derivatives, Asset Fair Value	1,390	1,687
Commodity derivatives, Liability Fair Value	(2,668)	(3,061)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Fixed Swaps/Futures [Member]
Commodity derivatives, Asset Fair Value	63,572	214,572
Commodity derivatives, Liability Fair Value	(61,002)	(148,111)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Call Option [Member]
Commodity derivatives, Liability Fair Value	0	0
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
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Forward Physical 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] \| NGLs - 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] \| Ngls Options Puts [Member]
Commodity derivatives, Asset 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
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Power - Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	6,196
Commodity derivatives, Liability Fair Value	776
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| Power - Options - Puts [Member]
Commodity derivatives, Asset Fair Value	135
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 1 [Member] \| WTI Crude Oil [Member]
Commodity derivatives, Liability Fair Value		0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Condensate Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	3,974	(538)
Commodity derivatives, Liability Fair Value		(1,567)
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	4,199	13,315
Commodity derivatives, Liability Fair Value	(4,836)	(13,013)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Fixed Swaps/Futures [Member]
Commodity derivatives, Asset Fair Value	17,945	3,907
Commodity derivatives, Liability Fair Value	(20,312)	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Call Option [Member]
Commodity derivatives, Liability Fair Value	(1)	(12)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Options - Puts [Member]
Commodity derivatives, Asset Fair Value	3,688	6,435
Commodity derivatives, Liability Fair Value	(55)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Forward Physical Swaps [Member]
Commodity derivatives, Asset Fair Value	976	699
Commodity derivatives, Liability Fair Value	386	712
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| NGLs - Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	7,681	94
Commodity derivatives, Liability Fair Value		(8,561)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Ngls Options Puts [Member]
Commodity derivatives, Asset Fair Value	1,523	309
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Propane Forward Swaps [Member]
Commodity derivatives, Asset Fair Value		9
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Power - Forward Swaps [Member]
Commodity derivatives, Asset Fair Value	36,308
Commodity derivatives, Liability Fair Value	40,668
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| Power - Options - Puts [Member]
Commodity derivatives, Asset Fair Value	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 2 [Member] \| WTI Crude Oil [Member]
Commodity derivatives, Liability Fair Value		(4,131)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| Condensate 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] \| 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] \| Call Option [Member]
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
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| Forward Physical 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] \| NGLs - 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] \| Ngls Options Puts [Member]
Commodity derivatives, Asset 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
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| Power - Forward 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] \| Power - Options - Puts [Member]
Commodity derivatives, Asset Fair Value	$ 0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives [Member] \| Level 3 [Member] \| WTI Crude Oil [Member]
Commodity derivatives, Liability Fair Value		$ 0

Fair Value Measurements Unobservable Inputs of Fair Value Level 3 Liabilities (Details)	Jun. 30, 2012
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Preferred Units Assumed Yeild	7.23%
Embedded derivatives in the Regency Preferred Units, credit spread	6.83%
Embedded derivatives in the Regency Preferred Units, volatility	18.02%

Fair Value Measurements (Reconciliation For Liabilities Measured At Fair Value On A Recurring Basis) (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2012 USD ($)
Fair Value Measurements [Abstract]
Balance, December 31, 2011	$ (361,959)
Net unrealized gains included in other income (expense)	11,455
Balance, June 30, 2012	$ (350,504)

Net Income Per Limited Partner Unit (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012 USD ($) $ / Units shares	Jun. 30, 2011 USD ($) $ / Units shares	Jun. 30, 2012 USD ($) $ / Units shares	Jun. 30, 2011 USD ($) $ / Units shares
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Limited Partners' interest in net income	$ 53,366	$ 66,080	$ 219,282	$ 154,446
Weighted average Limited Partner units \| shares	279,955,578	222,972,708	253,343,028	222,963,741
Basic net income per Limited Partner unit \| $ / Units	0.19	0.30	0.87	0.69
Dilutive effect of equity-based compensation of subsidiaries	$ (107)	$ (132)	$ (1,249)	$ (402)
Diluted net income available to Limited Partners	$ 53,259	$ 65,948	$ 218,033	$ 154,044
Weighted average Limited Partner units \| shares	279,955,578	222,972,708	253,343,028	222,963,741
Diluted net income per Limited Partner unit \| $ / Units	0.19	0.30	0.86	0.69
Preferred units liquidation preference	$ 300,000		$ 300,000

- 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

Debt Obligations Schedule of Debt Obligations (Details) - USD ($) $ in Thousands	Jun. 30, 2012	Dec. 31, 2011
Debt Instrument [Line Items]
Other Long-term Debt	$ 22,022	$ 10,434
Debt Instrument, Unamortized Discount (Premium), Net	(55,963)	(10,309)
Fair Value Adjustment Related To Interest Rate Swaps	213,342	11,647
Long-term Debt	18,073,385	11,371,024
Current maturities of long-term debt	(113,921)	(424,160)
LONG-TERM DEBT, less current maturities	17,959,464	10,946,864
ETE Senior Secured Revolving Credit Facilities [Member]
Debt Instrument [Line Items]
Amount Outstanding	10,000
ETP [Member] \| Senior Notes [Member]
Debt Instrument [Line Items]
Senior Notes	7,800,000	6,550,000
ETP [Member] \| Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Amount Outstanding	493,400	314,400
Transwestern [Member] \| Senior Notes [Member]
Debt Instrument [Line Items]
Senior Notes	870,000	870,000
Holp [Member] \| Secured Debt [Member]
Debt Instrument [Line Items]
Senior Notes	0	71,314
Regency [Member] \| Senior Notes [Member]
Debt Instrument [Line Items]
Senior Notes	1,262,500	1,350,000
Regency [Member] \| Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Amount Outstanding	515,000	332,000
Southern Union [Member] \| Senior Notes 1 [Member]
Debt Instrument [Line Items]
Senior Notes	359,765	0
Southern Union [Member] \| Senior Notes 2 [Member]
Debt Instrument [Line Items]
Senior Notes	300,000	0
Southern Union [Member] \| First Mortgage Bonds 1 [Member]
Debt Instrument [Line Items]
Senior Notes	19,500	0
Southern Union [Member] \| Junior Subordinated Debt [Member]
Debt Instrument [Line Items]
Senior Notes	600,000	0
Southern Union [Member] \| Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Senior Notes	7,465	0
Southern Union [Member] \| Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Amount Outstanding	235,000	0
Panhandle [Member] \| Senior Notes 1 [Member]
Debt Instrument [Line Items]
Senior Notes	250,000	0
Panhandle [Member] \| Senior Notes 2 [Member]
Debt Instrument [Line Items]
Senior Notes	300,000	0
Panhandle [Member] \| Term Loan [Member]
Debt Instrument [Line Items]
Senior Notes	455,000	0
Panhandle [Member] \| Senior Notes 3 [Member]
Debt Instrument [Line Items]
Senior Notes	400,000	0
Panhandle [Member] \| Senior Notes 4 [Member]
Debt Instrument [Line Items]
Senior Notes	150,000	0
Panhandle [Member] \| Senior Notes 5 [Member]
Debt Instrument [Line Items]
Senior Notes	66,305	0
Parent Company [Member]
Debt Instrument [Line Items]
Current maturities of long-term debt	(4,971)	0
LONG-TERM DEBT, less current maturities	3,788,829	1,871,500
Parent Company [Member] \| Senior Notes 1 [Member]
Debt Instrument [Line Items]
Senior Notes	1,800,000	1,800,000
Parent Company [Member] \| ETE Senior Secured Term Loan [Member]
Debt Instrument [Line Items]
Senior Notes	$ 2,000,000	0
Parent Company [Member] \| ETE Senior Secured Revolving Credit Facilities [Member]
Debt Instrument [Line Items]
Amount Outstanding		$ 71,500

Debt Obligations Future Maturities of Debt (Details) $ in Thousands	Jun. 30, 2012 USD ($)
Extinguishment of Debt [Line Items]
2012 (remainder)	$ 111,410
2013	604,951
2014	900,045
2015	765,308
2016	1,476,516
Thereafter	14,057,776
Long-term Debt, Gross	$ 17,916,006

Debt Obligations (Parent Company) (Narrative) (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2012 USD ($)
Unamortized Discounts And Fair Value Adjustments	$ 157,400
ETE Senior Secured Term Loan [Member]
Debt Instrument, Interest Rate, Effective Percentage	3.75%
ETE Senior Secured Revolving Credit Facilities [Member]
Outstanding borrowings	$ 10,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 190,000
Weighted average interest rate on amount outstanding	3.74%
Federal Funds Effective Rate [Member] \| ETE Senior Secured Term Loan [Member]
Debt Instrument, Basis Spread on Variable Rate	0.50%
LIBOR [Member] \| ETE Senior Secured Term Loan [Member]
Debt Instrument, Basis Spread on Variable Rate	1.00%
Eurodollar Loans [Member] \| ETE Senior Secured Term Loan [Member]
Debt Instrument, Basis Spread on Variable Rate	3.00%
Base Rate Loans [Member] \| ETE Senior Secured Term Loan [Member]
Debt Instrument, Basis Spread on Variable Rate	2.00%
Bridge Loan [Member]
Write off of Deferred Debt Issuance Cost	$ 62,200

Debt Obligations (ETP Senior Notes)(Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Jan. 31, 2012	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Jan. 19, 2012
Extinguishment of Debt [Line Items]
Tender offer repurchase amount						$ 885,900
Losses on extinguishments of debt		$ (7,821)	$ 0	$ (122,844)	$ 0
Senior Notes Five Point Two Zero Percent Due Feb 1 2022 [Member] \| ETP Senior Notes [Member] \| Issuance of Debt [Member]
Extinguishment of Debt [Line Items]
Debt Instrument, Face Amount	$ 1,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.20%
Senior Notes Six Point Five Zero Due Feb 1 2042 [Member] \| ETP Senior Notes [Member] \| Issuance of Debt [Member]
Extinguishment of Debt [Line Items]
Debt Instrument, Face Amount	$ 1,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.50%
Senior Notes Six Point Five Zero Due Feb 1 2042 And Five Point Two Zero Due Feb 1 2022 [Member] \| ETP Senior Notes [Member] \| Issuance of Debt [Member]
Extinguishment of Debt [Line Items]
Proceeds from Debt, Net of Issuance Costs	$ 1,980,000
Any And All Offer [Member] \| Senior Notes 2 [Member] \| Tender Offer [Member]
Extinguishment of Debt [Line Items]
Aggregate Principal Amount Cash Tender Offer						292,000
Maximum Tender Offer [Member] \| Senior Notes 8 [Member] \| Tender Offer [Member]
Extinguishment of Debt [Line Items]
Aggregate Principal Amount Cash Tender Offer						200,000
Maximum Tender Offer [Member] \| Senior Notes 9 [Member] \| Tender Offer [Member]
Extinguishment of Debt [Line Items]
Aggregate Principal Amount Cash Tender Offer						200,000
Maximum Tender Offer [Member] \| Senior Notes 4 [Member] \| Tender Offer [Member]
Extinguishment of Debt [Line Items]
Aggregate Principal Amount Cash Tender Offer						$ 58,100
Maximum [Member] \| Tender Offer [Member]
Extinguishment of Debt [Line Items]
Aggregate Principal Amount Cash Tender Offer	$ 750,000
ETP [Domain]
Extinguishment of Debt [Line Items]
Losses on extinguishments of debt				$ (115,023)

Debt Obligations (Southern Union) (Narrative) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2012	Dec. 31, 2011
First Mortgage Bonds 1 [Member]
Debt to capitalization ratio maximum permitted	70.00%
Minimum Amount for Cross Default Swaps [Member]
Debt Covenant, Cross Default Feature, Minimum Amount	$ 10,000
Southern Union Credit Facility [Member]
Debt to capitalization ratio maximum permitted	65.00%
Maximum Consolidated EBITA To Consolidated Interest Expense	2.00
Southern Union [Member] \| Revolving Credit Facility [Member]
Line of Credit Facility, Current Borrowing Capacity	$ 700,000
Southern Union Credit Facility [Member]
Weighted average interest rate on amount outstanding	1.87%
Southern Union [Member] \| First Mortgage Bonds 1 [Member]
Senior Notes	$ 19,500	$ 0
Southern Union [Member] \| Junior Subordinated Debt [Member]
Debt Instrument, Interest Rate, Stated Percentage	7.20%
Debt instrument, maturity date	Nov. 01, 2066
Debt Instrument, Description of Variable Rate Basis	three-month LIBOR rate plus 3.0175%
Senior Notes	$ 600,000	0
Debt Instrument, Interest Rate, Effective Percentage	3.48%
Long-term Debt, Percentage Bearing Variable Interest, Amount	$ 525,000
Panhandle [Member] \| Term Loan [Member]
Senior Notes	$ 455,000	$ 0
Debt Instrument, Interest Rate, Effective Percentage	1.87%
Variable Rate Portion of Debt [Member] \| Southern Union [Member] \| Junior Subordinated Debt [Member]
Senior Notes	$ 75,000

Debt Obligations (ETP Credit Facility) (Narrative) (Details) - ETP Credit Facility [Member] $ in Millions	Jun. 30, 2012 USD ($)
Amount Outstanding	$ 493.4
Amount available for future borrowings	1,980.0
Letters of Credit Outstanding, Amount	$ 30.3
Weighted average interest rate on amount outstanding	1.74%

Debt Obligations (Regency Credit Facility) (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Losses on extinguishments of debt	$ (7,821)	$ 0	$ (122,844)	$ 0
Regency Credit Facility [Member]
Outstanding borrowings	515,000		515,000
Letters of Credit Outstanding, Amount	9,000		9,000
Amount available for future borrowings	$ 376,000		$ 376,000
Weighted average interest rate on amount outstanding	2.88%		2.88%

Debt Obligations Paranthetical (Details)	6 Months Ended
Debt Obligations Paranthetical (Details)	Jun. 30, 2012
Panhandle [Member] \| Senior Notes 1 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Aug. 15, 2013
Debt Instrument, Interest Rate, Stated Percentage	6.05%
Panhandle [Member] \| Senior Notes 2 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Nov. 01, 2017
Debt Instrument, Interest Rate, Stated Percentage	6.20%
Panhandle [Member] \| Senior Notes 3 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Jun. 15, 2018
Debt Instrument, Interest Rate, Stated Percentage	7.00%
Panhandle [Member] \| Senior Notes 4 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Jun. 01, 2019
Debt Instrument, Interest Rate, Stated Percentage	8.125%
Panhandle [Member] \| Senior Notes 5 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Jul. 15, 2029
Debt Instrument, Interest Rate, Stated Percentage	7.00%
Southern Union [Member] \| Senior Notes 1 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Feb. 01, 2024
Debt Instrument, Interest Rate, Stated Percentage	7.60%
Southern Union [Member] \| Senior Notes 2 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Nov. 14, 2029
Debt Instrument, Interest Rate, Stated Percentage	8.25%
Southern Union [Member] \| Junior Subordinated Debt [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Nov. 01, 2066
Debt Instrument, Interest Rate, Stated Percentage	7.20%
Minimum [Member] \| Southern Union [Member] \| First Mortgage Bonds 1 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Feb. 15, 2020
Debt Instrument, Interest Rate, Stated Percentage	7.24%
Maximum [Member] \| Southern Union [Member] \| First Mortgage Bonds 1 [Member]
Debt Instrument [Line Items]
Debt instrument, maturity date	Dec. 15, 2027
Debt Instrument, Interest Rate, Stated Percentage	9.44%

Debt Obligations Regency Senior Notes (Details) - Senior Notes 9 Point 375 Percent Due June 1 2016 [Member] - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2012	Jun. 30, 2012
Financial Instruments Subject to Mandatory Redemption by Settlement Terms [Line Items]
Redemption of Senior Notes		35.00%
Early Repayment of Senior Debt		$ 87.5
Offering Price for Debt Redemption Percentage	109.375%

Redeemable Preferred Units (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	6 Months Ended
	Jun. 30, 2012	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	4,645,229
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

+ References + Details

Equity (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011
Gain (Loss) on Sale of Previously Unissued Stock by Subsidiary	$ (13,939)	$ 92,074
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	57,000,000
Equity Distribution Agreement, maximum aggregate value of common units sold	$ 200,000
ETP [Domain]
Partners' Capital Account, Units, Sold in Public Offering	15,525,000
Price per Unit	$ 44.57
Partners' Capital Account, Public Sale of Units Net of Offering Costs	$ 671,100
Proceeds From Issuance Of Common Limited Partners Units Under Equity Distribution Agreement	76,700
ETP [Member] \| Distribution Reinvestment Plan [Member]
Value of units issued during period through DRIP	$ 16,800
Units issued during period through DRIP	379,258
DRIP Capacity	5,017,063
ETP [Member] \| Credit Suisse [Member]
Equity Distribution Agreement, remaining aggregate value to be sold	$ 0
Regency [Member]
Partners' Capital Account, Units, Sold in Public Offering	12,650,000
Proceeds from issuance of common units	$ 296,800
Citrus Corp [Member]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	2,250,000

Equity (Change In ETE Common Units) (Details)	6 Months Ended
Equity (Change In ETE Common Units) (Details)	Jun. 30, 2012 shares
Partners' Capital Notes [Abstract]
Outstanding, beginning of period	222,972,708
Issuance of restricted unis under equity incentive plan, units	740
Issuance of common units in connection with Southern Union Merger	57,000,000
Outstanding, end of period	279,955,608

Equity (Quarterly Distributions Of Available Cash) (Details) - $ / shares	3 Months Ended
	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011
Parent Company [Member]
Record Date	August 6, 2012	May 4, 2012	February 7, 2012
Payment Date	August 17, 2012	May 18, 2012	February 17, 2012
Distributions paid, rate per unit	$ 0.625	$ 0.625	$ 0.625
ETP [Member]
Record Date	August 6, 2012	May 4, 2012	February 7, 2012
Payment Date	August 14, 2012	May 15, 2012	February 14, 2012
Distributions paid, rate per unit	$ 0.89375	$ 0.89375	$ 0.89375
Regency [Member]
Record Date	August 6, 2012	May 7, 2012	February 6, 2012
Payment Date	August 14, 2012	May 14, 2012	February 13, 2012
Distributions paid, rate per unit	$ 0.460	$ 0.460	$ 0.460

Equity (Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2012	Dec. 31, 2011
Partners' Capital Notes [Abstract]
Unrealized gain (loss) on commodity contracts	$ 15,030	$ 1,696
Accumulated other comprehensive income (loss), available-for-sale securities adjustment, net of tax	0	114
AOCI attributable to equity method investments	(22,208)	0
Accumulated other comprehensive income loss net of tax before non controlling interest	(7,178)	1,810
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Noncontrolling Interest	(8,487)	1,132
Accumulated other comprehensive income (loss), net of tax	$ 1,309	$ 678

- 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 Thousands	6 Months Ended
	Jun. 30, 2012 USD ($) years $ / shares shares
ETE Long-Term Incentive Plan [Member]
Granted unvested awards	0
Remain unvested award	76,172
Unrecognized compensation expense \| $	$ 900
Weighted average period for recognition, years \| years	1.7
ETP Unit-Based Compensation Plans [Member]
Granted unvested awards	62,917
Vesting period (years)	5
Weighted average grant date fair value, per unit \| $ / shares	$ 46.99
Remain unvested award	2,369,652
Unrecognized compensation expense \| $	$ 61,800
Weighted average period for recognition, years \| years	1.7
ETP Unit-Based Compensation Plans [Member] \| Director [Member]
Granted unvested awards	4,400
Regency Common Unit Options [Member]
Granted awards	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value \| $	$ 300
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Remaining Contractual Term	3.9
Proceeds from Stock Options Exercised \| $	$ 700
Regency Phantom Units [Member]
Vesting period (years)	3
Weighted average grant date fair value per unit option \| $ / shares	$ 24.59
Remain unvested award	991,206
Granted awards	7,250
Unrecognized compensation expense \| $	$ 17,800
Weighted average period for recognition, years \| years	3.8

Benefits (Details) - USD ($) $ in Thousands	Mar. 31, 2012	Mar. 26, 2012
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	9.00%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	4.85%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate		2020
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate		4.10%
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation		$ 227,548
Defined Benefit Plan, Benefit Obligation		227,548
Defined Benefit Plan, Fair Value of Plan Assets		143,979
Defined Benefit Plan, Funded Status of Plan		(83,569)
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent		0
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities		0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent		(83,569)
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation		213,614
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets		$ 143,979
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase		3.03%
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate		4.10%
Defined Benefit Plan, Benefit Obligation		$ 140,651
Defined Benefit Plan, Fair Value of Plan Assets		118,784
Defined Benefit Plan, Funded Status of Plan		(21,867)
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent		6,062
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities		(133)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent		(27,796)
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation		110,314
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets		$ 82,385

Income Taxes (Components Of Federal And State Income Tax) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Income Taxes [Abstract]
Current expense, Federal	$ (41)	$ 561	$ (60)	$ 5,663
Current expense, State	4,153	5,439	7,889	9,435
Total current expense	4,112	6,000	7,829	15,098
Deferred expense, Federal	6,347	(747)	(2,218)	(559)
Deferred expense, State	(284)	(29)	6,143	588
Total deferred expense	6,063	(776)	3,925	29
Total income tax expense	$ 10,175	$ 5,224	$ 11,754	$ 15,127

- 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
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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
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-Name Accounting Standards Codification
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-SubTopic 10
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-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

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-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

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-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
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Reference 3: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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-Paragraph 1
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-Publisher FASB
-Name Accounting Standards Codification
-Glossary Deferred Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6510177

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-Name Accounting Standards Codification
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-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

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-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.

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-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
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-Paragraph 28
-Subparagraph (b)
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-Paragraph 1
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-Paragraph 1
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-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

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

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-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 109
-Paragraph 289
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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
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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.

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-Name Accounting Standards Codification
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-Paragraph 1
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-Publisher FASB
-Name Accounting Standards Codification
-Glossary Deferred Tax Expense (or Benefit)
-URI http://asc.fasb.org/extlink&oid=6510177

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

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-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
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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.

+ 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
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Reference 3: http://www.xbrl.org/2003/role/presentationRef
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-Name Statement of Financial Accounting Standard (FAS)
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-Name Accounting Standards Codification
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-Paragraph 1
-Subparagraph (SX 210.4-08.(h))
-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

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

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-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

Income Taxes Income Taxes Narrative (Details) - USD ($) $ in Thousands		12 Months Ended
	Mar. 31, 2012	Dec. 31, 2012	Jun. 30, 2012	Mar. 26, 2012
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards			$ 67,000
anticipated federal net operating gain (loss)		$ 150,000
Unrecognized Tax Benefits Capitalized			2,300
Unrecognized Tax Benefits State Filing Positions			17,100
Southern Union Merger [Member]
Operating Loss Carryforwards [Line Items]
Deferred income taxes				$ (1,698,352)
Significant Acquisitions and Disposals, Date of Transaction for Acquisition or Disposal	Mar. 26, 2012
Expiring in 2030 [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards			17,000
Expiring in 2031 [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards			$ 50,000

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities (Narrative) (Details) - USD ($)			3 Months Ended		6 Months Ended
	Jan. 12, 2012	Jul. 07, 2011	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011	Dec. 31, 2011
Surcharge recovery					$ 40,800,000
Maximum lease expiration year					2029
Operating leases rent expense			$ 11,700,000	$ 7,800,000	$ 18,500,000	$ 13,200,000
Total environmental liabilities			39,326,000		39,326,000		$ 13,851,000
Legal Fees		$ 18,500,000
AmeriGas [Member]
Proceeds from (Repayments of) Related Party Debt	$ 1,500,000,000
FGT [Member]
Estimated Cost			2,500,000,000		$ 2,500,000,000
Contracted Capacity					74.00%
Notes Receivable, Related Parties, Noncurrent			37,000,000		$ 37,000,000
Promissory Note with Unconsolidated Investment			$ 150,000,000		$ 150,000,000
Debt Instrument, Basis Spread on Variable Rate			1.50%		1.50%
Proceeds from Legal Settlements					$ 82,700,000
Interest Awarded					$ 8,000,000
Citrus [Member]
Interest ownership			50.00%		50.00%
Related To Deductibles [Member]
Accrual for loss contingency			$ 10,100,000		$ 10,100,000		$ 18,200,000
AmeriGas Finance LLC [Member] \| Sale [Member] \| Senior Notes Six Point Seven Five Due 2020 [Member]
Debt Instrument, Face Amount	$ 550,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.75%
AmeriGas Finance LLC [Member] \| Sale [Member] \| Senior Notes Seven Point Zero Due 2022 [Member]
Debt Instrument, Face Amount	$ 1,000,000,000
Debt Instrument, Interest Rate, Stated Percentage	7.00%
Attorney General of Commonwealth [Member]
Reimbursement Costs					150,000
Jal 3 Facility [Member]
Alleged Violations					500,000
Jal 4 Facility [Member]
Alleged Violations					$ 5,500,000

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Future Lease Commitments (Details) $ in Thousands	Jun. 30, 2012 USD ($)
Regulatory Matters, Commitments, Contingencies And Environmental Liabilities [Abstract]
2012 (remainder)	$ 18,595
2013	38,341
2014	33,295
2015	31,683
2016	30,820
Thereafter	$ 216,143

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Accrued Environmental Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2012	Dec. 31, 2011
Environmental Exit Cost [Line Items]
Current	$ 4,205	$ 3,861
Non-current	35,121	9,990
Total environmental liabilities	$ 39,326	$ 13,851

- Definition

Carrying value of the obligation (known or estimated) arising from requirements to perform activities to remediate one or more sites, payable in twelve months or in the next operating cycle if longer.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Statement of Financial Accounting Standard (FAS)
-Number 5
-Paragraph 9
-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 02
-Paragraph 20
-Article 5

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Statement of Position (SOP)
-Number 96-1
-Paragraph 161, 163
-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 450
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6952336&loc=d3e14326-108349

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
-SubTopic 30
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=6393242&loc=d3e13207-110859

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.20)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

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-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section 45
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6361293&loc=d3e6911-107765

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 410
-SubTopic 30
-Section 50
-Paragraph 10
-Subparagraph (d)(1)
-URI http://asc.fasb.org/extlink&oid=6393242&loc=d3e13237-110859

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher AICPA
-Name Accounting Research Bulletin (ARB)
-Number 43
-Chapter 3
-Section A
-Paragraph 8
-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

Price Risk Management Assets And Liabilities (Narrative) (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012 USD ($)	Jun. 30, 2011 USD ($)	Jun. 30, 2012 USD ($) years	Jun. 30, 2011 USD ($)	Dec. 31, 2011 USD ($)
Swap maturity term (years) \| years			10
Deposits with counterparties	$ 87,663		$ 87,663		$ 66,231
Unrealized gains (losses) on commodity derivatives	3,700	$ (15,700)	4,300	$ 2,100
Unrealized gains (losses) on commodity derivatives and related hedged inventory	(38,300)	$ (16,700)	(74,100)	$ 7,800
ETP [Member]
Expected gains (losses) related to derivatives to be reclassified into earnings over next year related to amounts currently reported an AOCI	9,700		9,700
Deposits with counterparties	45,329		45,329
Regency [Member]
Expected gains (losses) related to derivatives to be reclassified into earnings over next year related to amounts currently reported an AOCI	800		800
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	(1,100)		$ (1,100)
Amortization Period Of Deferred Gain Loss On Discontinuation Of Cash Flow Hedge			1.75
Southern Union [Member]
Expected gains (losses) related to derivatives to be reclassified into earnings over next year related to amounts currently reported an AOCI	17,100		$ 17,100
Derivative, Net Liability Position, Aggregate Fair Value	$ 10,000		$ 10,000

Price Risk Management Assets And Liabilities (Outstanding Commodity-Related Derivatives) (Details)

Jun. 30, 2012

bbl

gal

MMbtu

Dec. 31, 2011

bbl

gal

MMbtu

Mark-To-Market Derivatives [Member] | Natural Gas [Member] | Basis Swaps IFERC/NYMEX Trading (MMBtu) [Member] | ETP [Member]

Notional Volume

^[1]

7,650,000

(151,260,000)

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Natural Gas [Member] | Basis Swaps IFERC/NYMEX (MMBtu) [Member] | ETP [Member]

Notional Volume

(55,272,500)

(61,420,000)

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Natural Gas [Member] | Swing Swaps IFERC (MMBtu) [Member] | ETP [Member]

Notional Volume

(19,825,000)

92,370,000

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Natural Gas [Member] | Fixed Swaps/Futures (MMBtu) [Member] | ETP [Member]

Notional Volume

1,062,500

797,500

Maximum Term Of Commodity Derivatives

2013

2012

Minimum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Natural Gas [Member] | Fixed Swaps/Futures (MMBtu) [Member] | Regency [Member]

Notional Volume

5,297,000

Maximum Term Of Commodity Derivatives

2014

Minimum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Natural Gas [Member] | Fixed Swaps/Futures (MMBtu) [Member] | Southern Union [Member]

Notional Volume

19,750,000

Maximum Term Of Commodity Derivatives

2014

Minimum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Natural Gas [Member] | Forward Physical Contracts (MMBtu) [Member] | ETP [Member]

Notional Volume

(20,481,365)

(10,672,028)

Maximum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Natural Gas [Member] | Options - Puts (MMBtu) [Member] | ETP [Member]

Notional Volume

500,000

Maximum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Power - Forward Swaps [Member] | Forwards (Thousand Megawatt) [Member] | ETP [Member]

Notional Volume

4,800

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Power - Options - Puts [Member] | Options - Puts (Thousand Megawatt) [Member] | ETP [Member]

Notional Volume

36,800

Maximum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Propane [Member] | Forwards/Swaps (Gallons) [Member] | ETP [Member]

Notional Volume | gal

38,766,000

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Propane [Member] | Forwards/Swaps (Gallons) [Member] | Regency [Member]

Notional Volume | gal

7,770,000

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Natural Gas Liquids [Member] | Forwards/Swaps (Barrels) [Member] | Regency [Member]

Notional Volume | bbl

277,000

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | Natural Gas Liquids [Member] | Options Puts Barrels [Member] | Regency [Member]

Notional Volume | bbl

110,000

Maximum Term Of Commodity Derivatives

2012

Mark-To-Market Derivatives [Member] | WTI Crude Oil [Member] | Forwards/Swaps (Barrels) [Member] | Regency [Member]

Notional Volume | bbl

344,000

Maximum Term Of Commodity Derivatives

2014

Minimum Term Of Commodity Derivatives

2012

Fair Value Hedging Derivatives [Member] | Natural Gas [Member] | Basis Swaps IFERC/NYMEX (MMBtu) [Member] | ETP [Member]

Notional Volume

(25,707,500)

(28,752,500)

Maximum Term Of Commodity Derivatives

2013

2012

Minimum Term Of Commodity Derivatives

2012

Fair Value Hedging Derivatives [Member] | Natural Gas [Member] | Fixed Swaps/Futures (MMBtu) [Member] | ETP [Member]

Notional Volume

(51,790,000)

(45,822,500)

Maximum Term Of Commodity Derivatives

2013

2012

Minimum Term Of Commodity Derivatives

2012

Fair Value Hedging Derivatives [Member] | Natural Gas [Member] | Hedged Item - Inventory (MMBtu) [Member] | ETP [Member]

Notional Volume

51,790,000

45,822,500

Maximum Term Of Commodity Derivatives

2013

2012

Minimum Term Of Commodity Derivatives

2012

Cash Flow Hedging Derivatives [Member] | Natural Gas [Member] | Basis Swaps IFERC/NYMEX (MMBtu) [Member] | ETP [Member]

Notional Volume

(12,850,000)

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Cash Flow Hedging Derivatives [Member] | Natural Gas [Member] | Fixed Swaps/Futures (MMBtu) [Member] | ETP [Member]

Notional Volume

(31,100,000)

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Cash Flow Hedging Derivatives [Member] | Natural Gas [Member] | Fixed Swaps/Futures (MMBtu) [Member] | Regency [Member]

Notional Volume

2,198,000

Maximum Term Of Commodity Derivatives

2012

Cash Flow Hedging Derivatives [Member] | Natural Gas [Member] | Fixed Swaps/Futures (MMBtu) [Member] | Southern Union [Member]

Notional Volume

15,557,500

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Cash Flow Hedging Derivatives [Member] | Natural Gas [Member] | Options - Puts (MMBtu) [Member] | ETP [Member]

Notional Volume

1,800,000

3,600,000

Maximum Term Of Commodity Derivatives

2012

Cash Flow Hedging Derivatives [Member] | Natural Gas [Member] | Options - Calls (MMBtu) [Member] | ETP [Member]

Notional Volume

(1,800,000)

(3,600,000)

Maximum Term Of Commodity Derivatives

2012

Cash Flow Hedging Derivatives [Member] | Propane [Member] | Forwards/Swaps (Gallons) [Member] | Regency [Member]

Notional Volume | gal

11,802,000

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Cash Flow Hedging Derivatives [Member] | Natural Gas Liquids [Member] | Fixed Swaps/Futures (MMBtu) [Member] | Southern Union [Member]

Notional Volume

2,760,000

Maximum Term Of Commodity Derivatives

2012

Cash Flow Hedging Derivatives [Member] | Natural Gas Liquids [Member] | Forwards/Swaps (Barrels) [Member] | Regency [Member]

Notional Volume | bbl

533,000

Maximum Term Of Commodity Derivatives

2013

Minimum Term Of Commodity Derivatives

2012

Cash Flow Hedging Derivatives [Member] | WTI Crude Oil [Member] | Forwards/Swaps (Barrels) [Member] | Regency [Member]

Notional Volume | bbl

350,000

Maximum Term Of Commodity Derivatives

2014

Minimum Term Of Commodity Derivatives

2012

[1]	(1) Includes aggregate amounts for open positions related to Houston Ship Channel, Waha Hub, NGPL TexOk, West Louisiana Zone and Henry Hub locations.

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

3 Months Ended

6 Months Ended

Mar. 31, 2012

Jun. 30, 2012

Dec. 31, 2011

March 2017 [Member] | Parent Company [Member]

Notional Amount

$ 500,000

$ 0

Type

^[1]

Pay a fixed rate of 1.25% and receive a floating rate

May 2012 [Member] | ETP [Member]

Notional Amount

^[2]

$ 0

350,000

Type

^[1]

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

August 2012 [Member] | ETP [Member]

Notional Amount

^[2]

$ 0

500,000

Type

^[1]

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

July 2013 [Member] | ETP [Member]

Notional Amount

^[2]

$ 400,000

300,000

Type

^[1]

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

July 2014 [Member] | ETP [Member]

Notional Amount

^[2]

$ 400,000

Type

^[1]

Forward starting to pay a fixed rate of 4.26% and receive a floating rate

July 2018 [Member] | ETP [Member]

Notional Amount

$ 600,000

500,000

Type

^[1]

Pay a floating rate plus a spread of 4.17% and receive a fixed rate of 6.70%

April 2012 [Member] | Regency [Member]

Notional Amount

$ 0

$ 250,000

Type

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

November 2016 [Member] | Southern Union [Member]

Notional Amount

$ 75,000

Type

^[1]

Pay a fixed rate of 2.913% and receive a floating rate

November 2021 [Member] | Southern Union [Member]

Notional Amount

$ 450,000

Type

^[1]

Pay a fixed rate of 3.746% and receive a floating rate

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

Price Risk Management Assets And Liabilities (Fair Value Of Derivative Instruments) (Details) - USD ($) $ in Thousands	Jun. 30, 2012	Dec. 31, 2011
Total derivatives assets	$ 255,318	$ 346,391
Total derivatives liabilities	(471,821)	(423,598)
Designated as Hedging Instrument [Member]
Total derivatives assets	27,801	81,736
Total derivatives liabilities	(8,844)	(10,947)
Designated as Hedging Instrument [Member] \| Commodity Derivatives (Margin Deposits) [Member]
Total derivatives assets	12,911	77,197
Total derivatives liabilities	(6,698)	(819)
Designated as Hedging Instrument [Member] \| Commodity Derivatives [Member]
Total derivatives assets	14,890	4,539
Total derivatives liabilities	(2,146)	(10,128)
Not Designated as Hedging Instrument [Member]
Total derivatives assets	227,517	264,655
Total derivatives liabilities	(462,977)	(412,651)
Not Designated as Hedging Instrument [Member] \| Commodity Derivatives (Margin Deposits) [Member]
Total derivatives assets	123,426	227,337
Total derivatives liabilities	(139,666)	(251,268)
Not Designated as Hedging Instrument [Member] \| Commodity Derivatives [Member]
Total derivatives assets	53,548	1,017
Total derivatives liabilities	(59,220)	(4,844)
Not Designated as Hedging Instrument [Member] \| Interest Rate Derivatives [Member]
Total derivatives assets	50,543	36,301
Total derivatives liabilities	(233,447)	(117,490)
Not Designated as Hedging Instrument [Member] \| Embedded Derivatives [Member]
Total derivatives assets	0	0
Total derivatives liabilities	$ (30,644)	$ (39,049)

Price Risk Management Assets And Liabilities (Partnership's Derivative Assets And Liabilities Recognized OCI On Derivatives) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Change in Value Recognized in OCI on Derivatives (Effective Portion)	$ 2,671	$ 3,769	$ 24,886	$ (7,123)
Commodity Derivatives [Member]
Change in Value Recognized in OCI on Derivatives (Effective Portion)	(17,038)	3,769	5,177	(7,123)
Interest Rate Derivatives [Member]
Change in Value Recognized in OCI on Derivatives (Effective Portion)	$ 19,709	$ 0	$ 19,709	$ 0

Price Risk Management Assets And Liabilities (Partnership's Derivative Assets And Liabilities Amount Of Gain (Loss) Recognized) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Amount of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	$ 12,152	$ (2,148)	$ 15,587	$ 12,954
Amount of Gain/(Loss) Recognized in Income on Ineffective Portion	(1)	96	46	189
Amount of Gain/(Loss) Recognized in Income representing hedge ineffectiveness and amount excluded from the assessment of effectiveness	31,671	15,874	18,833	22,291
Amount of Gain/(Loss) Recognized in Income on Derivatives	(24,893)	(6,594)	(7,956)	3,939
Commodity Derivatives - Trading [Member] \| Cost of Products Sold [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	(709)	0	(11,295)	0
Commodity Derivatives [Member] \| Cost of Products Sold [Member]
Amount of Gain/(Loss) Reclassified from AOCI into Income (Effective Portion)	12,152	(2,148)	15,587	12,954
Amount of Gain/(Loss) Recognized in Income on Ineffective Portion	(1)	96	46	189
Amount of Gain/(Loss) Recognized in Income representing hedge ineffectiveness and amount excluded from the assessment of effectiveness	31,671	15,874	18,833	22,291
Amount of Gain/(Loss) Recognized in Income on Derivatives	12,575	(11,427)	12,112	(4,989)
Interest Rate Derivatives [Member] \| Losses On Non-Hedged Interest Rate Derivatives [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	(44,668)	1,883	(17,178)	3,403
Embedded Derivatives [Member] \| Other Income (Expenses) [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	$ 7,909	$ 2,950	$ 8,405	$ 5,525

Related Party Transactions (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
ETP [Member]
General and administrative services paid	$ 4.5	$ 3.5	$ 8.9	$ 8.4
General administrative expenses reimbursed	1.8	0.8	3.6	3.1
Regency [Member]
General and administrative revenues	4.3	4.2	8.6	8.1
HPC [Member]
General administrative expenses reimbursed	$ 5.1	$ 4.2	$ 9.3	$ 8.4

Other Information (Other Current Assets) (Details) - USD ($) $ in Thousands	Jun. 30, 2012	Dec. 31, 2011
Other Information [Abstract]
Deposits paid to vendors	$ 87,663	$ 66,231
Prepaid expenses and other	85,092	115,673
Total other current assets	$ 172,755	$ 181,904

Other Information (Other Non-Current Assets, net) (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2012 USD ($) years	Dec. 31, 2011 USD ($)
Unamortized financing costs (3 to 30 years)	$ 153,110	$ 132,375
Regulatory assets	220,180	88,993
Total non-current other assets, net	$ 476,294	248,910
Financing Costs [Member]
Financing cost, amortization period, maximum (years) \| years	30
Financing cost, amortization period, minimum (years) \| years	3
Other [Member]
Other	$ 103,004	$ 27,542

Other Information (Accrued And Other Current Liabilities) (Details) - USD ($) $ in Thousands	Jun. 30, 2012	Dec. 31, 2011
Other Information [Abstract]
Interest payable	$ 278,980	$ 204,182
Customer advances and deposits	38,253	100,525
Accrued capital expenditures	472,409	228,877
Accrued wages and benefits	53,618	80,205
Taxes payable other than income taxes	127,937	79,331
Income taxes payable	8,882	14,781
Other	101,254	56,011
Total accrued and other current liabilities	$ 1,081,333	$ 763,912

- 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 Narrative (Detail) (Details)	Jun. 30, 2012
Lone Star L.L.C. [Member] \| ETP [Member]
Subsidiary Interest in Joint Venture	70.00%
Lone Star L.L.C. [Member] \| Regency [Member]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	30.00%
Citrus Merger [Member]
Interest ownership	50.00%

Reportable Segments (Assets Segments)(Details) - USD ($) $ in Thousands	Jun. 30, 2012	Dec. 31, 2011
Assets	$ 33,113,222	$ 20,896,793
Investment In ETP [Member]
Assets	17,859,419	15,518,616
Investment In Regency [Member]
Assets	5,832,562	5,567,856
Southern Union - Transportation and Storage [Member]
Assets	5,755,369	0
Southern Union - Gathering and Processing [Member]
Assets	2,805,884	0
Southern Union - Distribution [Member]
Assets	1,245,794	0
Corporate And Other [Member]
Assets	424,152	470,086
Adjustments And Eliminations [Member]
Assets	$ (809,958)	$ (659,765)

Reportable Segments Revenues (External and Intersegment) by Investments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Revenues	$ 1,976,314	$ 1,974,906	$ 3,665,445	$ 3,964,026
ETP [Member]
Revenue from External Customers	1,228,503	1,616,748	2,529,993	3,292,795
Intersegment Revenues	11,811	11,347	16,181	22,877
Revenues	1,240,314	1,628,095	2,546,174	3,315,672
Regency [Member]
Revenue from External Customers	309,479	354,816	663,391	670,375
Intersegment Revenues	2,497	1,682	6,484	3,375
Revenues	311,976	356,498	669,875	673,750
Southern Union - Transportation and Storage [Member]
Revenue from External Customers	183,765	0	197,241	0
Intersegment Revenues	1,451	0	1,451	0
Revenues	185,216	0	198,692	0
Southern Union - Gathering and Processing [Member]
Revenue from External Customers	195,499	0	214,735	0
Intersegment Revenues	1,977	0	2,098	0
Revenues	197,476	0	216,833	0
Southern Union - Distribution [Member]
Revenue from External Customers	86,220	0	94,505	0
Intersegment Revenues	0	0	0	0
Revenues	86,220	0	94,505	0
Corporate And Others [Member]
Revenue from External Customers	3,558	0	2,152	0
Intersegment Revenues	0	0	0	0
Revenues	3,558	0	2,152	0
Corporate Elimination [Member]
Revenue from External Customers	(30,710)	3,342	(36,572)	856
Intersegment Elimination [Member]
Segment Reporting Information Eliminations Of Revenues	$ (17,736)	$ (13,029)	$ (26,214)	$ (26,252)

Reportable Segments Revenues from External Customers by Segment (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Revenues	$ 1,976,314	$ 1,974,906	$ 3,665,445	$ 3,964,026
ETP [Member]
Revenues	1,240,314	1,628,095	2,546,174	3,315,672
Segment Reporting Information, Intersegment Revenue	11,811	11,347	16,181	22,877
Revenue from External Customers	1,228,503	1,616,748	2,529,993	3,292,795
Regency [Member]
Revenues	311,976	356,498	669,875	673,750
Segment Reporting Information, Intersegment Revenue	2,497	1,682	6,484	3,375
Revenue from External Customers	309,479	354,816	663,391	670,375
Intrastate Transportation And Storage [Member] \| ETP [Member]
Revenues	452,237	643,653	899,033	1,232,331
Interstate Transportation [Member] \| ETP [Member]
Revenues	126,900	104,850	255,176	209,951
Midstream [Member] \| ETP [Member]
Revenues	460,077	513,584	914,176	926,779
NGL Transportation And Services [Member] \| ETP [Member]
Revenues	147,851	93,686	302,119	93,686
Retail Propane And Other Retail Propane Related [Member] \| ETP [Member]
Revenues	12,966	243,973	92,972	801,188
All Other [Member] \| ETP [Member]
Revenues	40,283	28,349	82,698	51,737
Gathering And Processing [Member] \| Regency [Member]
Revenues	263,100	303,203	570,267	569,175
Contract Compression [Member] \| Regency [Member]
Revenues	36,237	38,072	73,438	76,508
Contract Treating [Member] \| Regency [Member]
Revenues	7,388	10,842	16,523	19,275
Corporate And Others [Member] \| Regency [Member]
Revenues	$ 5,251	$ 4,381	$ 9,647	$ 8,792

Reportable Segments Operatine Segments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
Segment Reporting Information [Line Items]
Adjusted EBITDA	$ 727,944	$ 479,199	$ 1,308,558	$ 1,038,553
Depreciation and amortization	(221,767)	(148,530)	(382,968)	(287,786)
Interest Expense	(281,255)	(181,517)	(494,585)	(349,446)
Bridge loan related fees	0	0	(62,241)	0
Gain on deconsolidation of Propane Business	765	0	1,056,709	0
Gains (losses) on non-hedged interest rate derivatives	(44,668)	1,883	(17,178)	3,403
Non-cash compensation expense	11,581	11,699	23,736	23,085
Unrealized Gain (Loss) on Derivatives	36,514	1,365	(46,997)	12,747
Losses on disposal of assets	(1,402)	(681)	(2,462)	(2,435)
Losses on extinguishments of debt	(7,821)	0	(122,844)	0
Gain on curtailment of other postretirement benefit plans	0	0	(15,332)	0
Proportionate share of unconsolidated affiliates' interest, depreciation and allowance for equity funds used during construction	(118,232)	(29,300)	(184,092)	(57,421)
Other	6,200	1,156	4,082	(13,659)
Income before income tax expense	84,697	111,876	1,047,578	320,871
ETP [Domain]
Segment Reporting Information [Line Items]
Adjusted EBITDA	466,350	388,135	1,002,412	859,434
Regency [Domain]
Segment Reporting Information [Line Items]
Adjusted EBITDA	115,272	103,456	249,321	195,193
Southern Union - Transportation and Storage [Member]
Segment Reporting Information [Line Items]
Adjusted EBITDA	115,919	0	82,644	0
Southern Union - Gathering and Processing [Member]
Segment Reporting Information [Line Items]
Adjusted EBITDA	22,362	0	10,859	0
Southern Union - Distribution [Member]
Segment Reporting Information [Line Items]
Adjusted EBITDA	23,314	0	13,446	0
Corporate And Other [Member]
Segment Reporting Information [Line Items]
Adjusted EBITDA	$ (15,273)	$ (12,392)	$ (50,124)	$ (16,074)

Supplemental Financial Statement Information (Schedule Of Balance Sheets) (Details) - USD ($) $ in Thousands	Jun. 30, 2012	Dec. 31, 2011	Jun. 30, 2011	Dec. 31, 2010
Cash and cash equivalents	$ 217,160	$ 126,342	$ 148,471	$ 86,264
Accounts receivable from related companies	34,296	100,406
Other current assets	172,755	181,904
Total current assets	1,683,774	1,455,444
ADVANCES TO AND INVESTMENTS IN AFFILIATES	4,574,293	1,496,600
LONG-TERM PRICE RISK MANAGEMENT ASSETS	40,846	26,011
GOODWILL	3,458,809	2,038,975
OTHER NON-CURRENT ASSETS, net	476,294	248,910
Total assets	33,113,222	20,896,793
Accounts payable	456,322	512,023
Accounts payable to related companies	2,434	33,208
Interest Payable, Current	278,980	204,182
Accrued and other current liabilities	1,081,333	763,912
Current maturities of long-term debt	113,921	424,160
Total current liabilities	1,834,563	1,841,313
LONG-TERM DEBT, less current maturities	17,959,464	10,946,864
SERIES A CONVERTIBLE PREFERRED UNITS	72,370	71,144
OTHER NON-CURRENT LIABILITIES	312,712	26,958
LONG-TERM PRICE RISK MANAGEMENT LIABILITIES	246,242	81,415
COMMITMENTS AND CONTINGENCIES
General Partner	71	321
Limited Partners	2,297,473	52,485
Accumulated other comprehensive income	1,309	678
Total partners' capital	2,298,853	53,484
Total liabilities and equity	33,113,222	20,896,793
Parent Company [Member]
Cash and cash equivalents	2,729	18,460	$ 14,383	$ 27,247
Accounts receivable from related companies	4,084	1,456
Notes Receivable, Related Parties	167,315	0
Other current assets	303	714
Total current assets	174,431	20,630
ADVANCES TO AND INVESTMENTS IN AFFILIATES	6,216,728	2,225,572
LONG-TERM PRICE RISK MANAGEMENT ASSETS	20,874	0
GOODWILL	9,006	0
OTHER NON-CURRENT ASSETS, net	61,618	49,906
Total assets	6,482,657	2,296,108
Accounts payable	846	174
Accounts payable to related companies	2,812	12,334
Interest Payable, Current	47,677	34,753
Accrued and other current liabilities	1,701	953
Current maturities of long-term debt	4,971	0
Total current liabilities	61,860	48,214
LONG-TERM DEBT, less current maturities	3,788,829	1,871,500
SERIES A CONVERTIBLE PREFERRED UNITS	319,860	322,910
OTHER NON-CURRENT LIABILITIES	13,255	0
LONG-TERM PRICE RISK MANAGEMENT LIABILITIES	3,853	0
COMMITMENTS AND CONTINGENCIES
General Partner	71	321
Limited Partners	2,297,473	52,485
Accumulated other comprehensive income	1,309	678
Total partners' capital	2,298,853	53,484
Total liabilities and equity	$ 6,482,657	$ 2,296,108

Supplemental Financial Statement Information (Schedule Of Statements Of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Jun. 30, 2012	Jun. 30, 2011
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES	$ (122,950)	$ (78,946)	$ (271,212)	$ (142,445)
InterestExpense	281,255	181,517	494,585	349,446
Equity in earnings of affiliates	22,463	28,819	97,695	54,260
Gains (losses) on non-hedged interest rate derivatives	(44,668)	1,883	(17,178)	3,403
Other, net	17,891	2,811	31,197	(9,715)
Income tax expense	10,175	5,224	11,754	15,127
NET INCOME ATTRIBUTABLE TO PARTNERS	53,498	66,285	219,920	154,925
GENERAL PARTNER'S INTEREST IN NET INCOME	132	205	638	479
LIMITED PARTNERS' INTEREST IN NET INCOME	53,366	66,080	219,282	154,446
Parent Company [Member]
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES	(10,368)	(12,037)	(41,443)	(13,879)
InterestExpense	63,687	40,587	106,274	81,526
Write off of Deferred Debt Issuance Cost	0	0	(62,241)	0
Equity in earnings of affiliates	127,370	120,626	434,057	267,268
Gains (losses) on non-hedged interest rate derivatives	(8,700)	0	(9,097)	0
Other, net	8,861	(1,653)	4,960	(16,812)
INCOME BEFORE INCOME TAXES	53,476	66,349	219,962	155,051
Income tax expense	(22)	64	42	126
NET INCOME ATTRIBUTABLE TO PARTNERS	53,498	66,285	219,920	154,925
GENERAL PARTNER'S INTEREST IN NET INCOME	132	205	638	479
LIMITED PARTNERS' INTEREST IN NET INCOME	$ 53,366	$ 66,080	$ 219,282	$ 154,446

Supplemental Financial Statement Information (Schedule Of Statements Of Cash Flows) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2012	Jun. 30, 2011
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	$ 424,447	$ 698,337
Payments to Acquire Businesses, Net of Cash Acquired	10,317	1,948,612
Contributions to affiliate	56,288	(22,668)
Net Cash Provided by (Used in) Investing Activities	(2,733,249)	(2,744,539)
Proceeds from borrowings	5,964,419	5,202,535
Repayments of long-term debt	(3,101,014)	(3,420,348)
Distributions to partners	(315,196)	(246,016)
Debt issuance costs	(98,038)	(22,198)
Net cash provided by financing activities	2,399,620	2,108,409
INCREASE IN CASH AND CASH EQUIVALENTS	90,818	62,207
CASH AND CASH EQUIVALENTS, beginning of period	126,342	86,264
CASH AND CASH EQUIVALENTS, end of period	217,160	148,471
Parent Company [Member]
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	203,062	233,152
Payments to Acquire Businesses, Net of Cash Acquired	(1,113,377)	0
Contributions to affiliate	(445,000)	0
Repayments of Related Party Debt	(221,217)	0
Proceeds from Collection of Notes Receivable	55,000	0
Net Cash Provided by (Used in) Investing Activities	(1,724,594)	0
Proceeds from borrowings	2,005,000	20,000
Repayments of long-term debt	(106,500)	(20,000)
Distributions to partners	(315,196)	(246,016)
Debt issuance costs	(77,503)	0
Net cash provided by financing activities	1,505,801	(246,016)
INCREASE IN CASH AND CASH EQUIVALENTS	(15,731)	(12,864)
CASH AND CASH EQUIVALENTS, beginning of period	18,460	27,247
CASH AND CASH EQUIVALENTS, end of period	$ 2,729	$ 14,383