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DEI Document - shares	3 Months Ended
DEI Document - shares	Mar. 31, 2016	Apr. 29, 2016
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	Mar. 31, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q1
Amendment Flag	false
Entity Common Stock, Shares Outstanding		1,044,791,157

Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
ASSETS
Cash and cash equivalents	$ 807	$ 606
Accounts receivable, net	2,412	2,400
Accounts receivable from related companies	96	119
Inventories	1,499	1,636
Derivative assets	27	46
Other current assets	743	603
Total current assets	5,584	5,410
Property, plant and equipment	56,873	54,979
Accumulated depreciation and depletion	(6,748)	(6,296)
Property, Plant and Equipment, Net	50,125	48,683
Advances to and investments in unconsolidated affiliates	3,442	3,462
Non-current derivative assets	16	0
Other non-current assets, net	731	730
Intangible assets, net	5,396	5,431
Goodwill	7,471	7,473
Total assets	72,765	71,189
LIABILITIES AND EQUITY
Accounts payable	2,399	2,274
Accounts payable to related companies	15	28
Derivative liabilities	74	69
Accrued and other current liabilities	2,273	2,408
Current maturities of long-term debt	930	131
Total current liabilities	5,691	4,910
Long-term debt, less current maturities	37,401	36,837
Deferred income taxes	5,256	4,590
Non-current derivative liabilities	213	137
Other non-current liabilities	1,117	1,069
Commitments and contingencies
Preferred units of subsidiary	33	33
Redeemable noncontrolling interests	15	15
EQUITY:
General Partner	(2)	(2)
Limited Partners:
Common Unitholders	(1,684)	(952)
Class D Units	0	22
Series A Convertible Preferred Units	0	0
Total partners’ capital	(1,686)	(932)
Noncontrolling interest	24,725	24,530
Total equity	23,039	23,598
Total liabilities and equity	$ 72,765	$ 71,189

Consolidated Statements Of Operations - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
REVENUES
Natural gas sales	$ 838	$ 1,035
NGL sales	940	981
Crude sales	1,209	2,208
Gathering, transportation and other fees	1,003	1,046
Refined product sales	2,539	3,656
Other	1,153	1,454
Total revenues	7,682	10,380
COSTS AND EXPENSES
Cost of products sold	5,622	8,487
Operating expenses	641	628
Depreciation, depletion and amortization	562	493
Selling, general and administrative	156	155
Total costs and expenses	6,981	9,763
OPERATING INCOME	701	617
OTHER INCOME (EXPENSE)
Interest expense, net	(427)	(371)
Equity in earnings of unconsolidated affiliates	61	57
Losses on interest rate derivatives	(70)	(77)
Other, net	16	7
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT)	281	233
Income tax expense (benefit)	(55)	12
INCOME FROM CONTINUING OPERATIONS	336	221
NET INCOME	336	221
Less: Net income (loss) attributable to noncontrolling interest	24	(63)
NET INCOME ATTRIBUTABLE TO PARTNERS	312	284
General Partner’s interest in net income	1	1
Class D Unitholder’s interest in net income	0	1
Limited Partners’ interest in net income	$ 311	$ 282
NET INCOME PER LIMITED PARTNER UNIT:
Basic	$ 0.30	$ 0.26
Diluted	$ 0.30	$ 0.26

Consolidated Statements Of Comprehensive Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Statement of Comprehensive Income [Abstract]
Net income	$ 336	$ 221
Other comprehensive income (loss), net of tax:
Change in value of derivative instruments accounted for as cash flow hedges	0	1
Change in value of available-for-sale securities	2	1
Actuarial gain (loss) relating to pension and other postretirement benefit plans	(9)	45
Foreign currency translation adjustments	(1)	(2)
Change in other comprehensive income from unconsolidated affiliates	(6)	(2)
Other comprehensive income (loss), net of tax	(14)	43
Comprehensive income	322	264
Less: Comprehensive income (loss) attributable to noncontrolling interest	10	(20)
Comprehensive income attributable to partners	$ 312	$ 284

Consolidated Statement Of Equity - USD ($) $ in Millions	Total	General Partner	Common Unitholders	Class D Units	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interest
Goodwill	$ 7,473
Balance, December 31, 2015 at Dec. 31, 2015	23,598	$ (2)	$ (952)	$ 22	$ 0	$ 24,530
Distributions to partners	(299)	(1)	(298)	0	0	0
Distributions to noncontrolling interest	(658)	0	0	0	0	(658)
Subsidiary units issued	664	0		0	0	676
Gain (Loss) on Sale of Previously Unissued Stock by Subsidiary	(12)		(12)
Non-cash compensation expense, net of units tendered by employees for tax withholdings	1	0	0	(22)	0	23
Capital contributions received from noncontrolling interest	132	0	0	0	0	132
Sunoco, Inc. retail business to Sunoco LP transaction	(739)	0	(739)	0	0	0
Other comprehensive income, net of tax	(14)	0	0	0	0	(14)
Other, net	18	0	6	0	0	12
Net income	336	1	311	0	0	24
Balance, March 31, 2016 at Mar. 31, 2016	23,039	$ (2)	$ (1,684)	$ 0	$ 0	$ 24,725
Goodwill	$ 7,471

Consolidated Statements Of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
OPERATING ACTIVITIES
Net income	$ 336	$ 221
Reconciliation of net income to net cash provided by operating activities:
Depreciation, depletion and amortization	562	493
Deferred income taxes	(46)	20
Amortization included in interest expense	(3)	(10)
Unit-based compensation expense	1	23
Losses on disposal of assets	3	0
Inventory valuation adjustments	13	34
Equity in earnings of unconsolidated affiliates	(61)	(57)
Distributions from unconsolidated affiliates	84	64
Other non-cash	6	(9)
Net change in operating assets and liabilities, net of effects of acquisition	90	(204)
Net cash provided by operating activities	985	575
INVESTING ACTIVITIES
Cash paid for acquisitions, net of cash received	(2)	(370)
Cash received for sale of noncontrolling interest	0	64
Cash paid for acquisition of a noncontrolling interest	0	(129)
Capital expenditures, excluding allowance for equity funds used during construction	(1,948)	(2,158)
Contributions in aid of construction costs	10	4
Contributions to unconsolidated affiliate	31	34
Distributions from unconsolidated affiliates in excess of cumulative earnings	21	33
Proceeds from the sale of assets	10	9
Change in restricted cash	1	0
Other	(1)	(4)
Net cash used in investing activities	(1,942)	(2,585)
FINANCING ACTIVITIES
Proceeds from borrowings	5,750	8,731
Repayments of long-term debt	(4,422)	(5,938)
Subsidiary units issued for cash	664	857
Distributions to partners	(299)	(244)
Debt issuance costs	(19)	(33)
Distributions to noncontrolling interest	(658)	(565)
Capital contributions received from noncontrolling interest	132	219
Other, net	10	(1)
Net cash provided by financing activities	1,158	3,026
Increase in cash and cash equivalents	201	1,016
Cash and cash equivalents, beginning of period	606	847
Cash and cash equivalents, end of period	$ 807	$ 1,863

Operations And Organization

3 Months Ended

Mar. 31, 2016

Operations And Organization [Abstract]

Operations And Organization

ORGANIZATION AND BASIS OF PRESENTATION

Organization

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

The consolidated financial statements of ETE presented herein include the results of operations of:


•	the Parent Company;


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


•	consolidated subsidiaries of our controlled subsidiaries and our wholly-owned subsidiaries that own general partner interests and IDR interests in ETP and Sunoco LP; and


•	our wholly-owned subsidiary, Lake Charles LNG.

Our subsidiaries also own varying undivided interests in certain pipelines. Ownership of these pipelines has been structured as an ownership of an undivided interest in assets, not as an ownership interest in a partnership, limited liability company, joint venture or other forms of entities. Each owner controls marketing and invoices separately, and each owner is responsible for any loss, damage or injury that may occur to their own customers. As a result, we apply proportionate consolidation for our interests in these entities.

Business Operations

The Parent Company’s principal sources of cash flow are derived from its direct and indirect investments in the limited partner and general partner interests in ETP and Sunoco LP and cash flows from the operations of Lake Charles LNG. The Parent Company’s primary cash requirements are for general and administrative expenses, debt service requirements and distributions to its partners. 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 14 for stand-alone financial information apart from that of the consolidated partnership information included herein.

Our financial statements reflect the following reportable business segments:


•	Investment in ETP, including the consolidated operations of ETP;


•	Investment in Sunoco LP, including the consolidated operations of Sunoco LP;


•	Investment in Lake Charles LNG, including the operations of Lake Charles LNG; and


•	Corporate and Other, including the following:


•	activities of the Parent Company; and


•	the goodwill and property, plant and equipment fair value adjustments recorded as a result of the 2004 reverse acquisition of Heritage Propane Partners, L.P.

Basis of Presentation

The unaudited financial information included in this Form 10-Q has been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2015. In the opinion of the Partnership’s management, such financial information reflects all adjustments necessary for a fair presentation of the financial position and the results of operations for such interim periods in accordance with GAAP. All intercompany items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.

Certain prior period amounts have been reclassified to conform to the 2016 presentation. These reclassifications had no impact on net income or total equity.

Use of Estimates

The unaudited consolidated financial statements have been prepared in conformity with GAAP, which includes the use of estimates and assumptions made by management that affect the reported amounts of assets, liabilities, revenues, expenses and disclosure of contingent assets and liabilities that exist at the date of the consolidated financial statements. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could be different from those estimates.

Subsidiary Common Unit Transactions

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

Recent Accounting Pronouncements

In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09”), which clarifies the principles for recognizing revenue based on the core principle that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. In August 2015, the FASB deferred the effective date of ASU 2014-09, which is now effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. Early adoption is permitted as of annual reporting periods beginning after December 15, 2016, including interim reporting periods within those annual periods. ASU 2014-09 can be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. In March 2016, the FASB issued Accounting Standards Update No. 2016-08 to clarify the implementation guidance on principal versus agent considerations. In April 2016, the FASB issued Accounting Standards Update No. 2016-10 to clarify guidance related to identifying performance obligations and licensing implementation guidance contained in the new revenue recognition standard. The Partnership is currently evaluating the impact, if any, that adopting this new accounting standard will have on our revenue recognition policies.

In February 2015, the FASB issued Accounting Standards Update No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis (“ASU 2015-02”), which changed the requirements for consolidations analysis. Under ASU 2015-02, reporting entities are required to evaluate whether they should consolidate certain legal entities. The Partnership adopted this standard on January 1, 2016, and the adoption did not impact the Partnership’s financial position or results of operations.

In February 2016, the FASB issued Accounting Standards Update No. 2016-02, Leases (Topic 842) (“ASU 2016-02”), which establishes the principles that lessees and lessors shall apply to report useful information to users of financial statements about the amount, timing, and uncertainty of cash flows arising from a lease. ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. Early adoption is permitted. The Partnership is currently evaluating the impact that it will have on the consolidated financial statements and related disclosures.

In March 2016, the FASB issued Accounting Standards Update No. 2016-09, Stock compensation (Topic 718) (“ASU 2016-09”). The objective of the update is to reduce complexity in accounting standards. The areas for simplification in this update involve several aspects of the accounting for employee share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. In addition, the amendments in this update eliminate the guidance in Topic 718 that was indefinitely deferred shortly after the issuance of FASB Statement No. 123 (revised 2004), Share-Based Payment. ASU 2016-09 is effective for fiscal years beginning after December 15, 2016, and interim periods within those annual periods. Early adoption is permitted. The Partnership is currently evaluating the impact that it will have on the consolidated financial statements and related disclosures.

Acquisitions	3 Months Ended
Acquisitions	Mar. 31, 2016
ACQUISITIONS AND DIVESTITURE [Abstract]
Acquisitions	ACQUISITION AND CONTRIBUTION TRANSACTIONS WMB Merger In September 2015, ETE, ETC and WMB entered into a merger agreement. The merger agreement provides that WMB will be merged with and into ETC, with ETC surviving the merger. ETC is a recently formed limited partnership that will elect to be treated as a corporation for federal income tax purposes and, upon closing of the merger, would own the managing member interest in our general partner and limited partner interests in ETE. At the time of the merger, each issued and outstanding share of WMB common stock will be exchanged for (i) $8.00 in cash and 1.5274 ETC common shares representing limited partner interests in ETC, (ii) 1.8716 ETC common shares, or (iii) $43.50 in cash. The closing of the transaction is subject to customary conditions, including the receipt of approval of the merger from WMB’s stockholders and all required regulatory approvals, including approval pursuant to the Hart-Scott-Rodino Antitrust Improvements Act of 1976. Subject to the satisfaction or waiver of these conditions, ETE and WMB anticipate that the transaction will be completed in the first half of 2016. If the closing of the merger were to have occurred as of the date of this Quarterly Report on Form 10-Q, Latham & Watkins LLP (“Latham”) would have been unable to deliver to ETC and WMB its tax opinion to the effect that the contribution of WMB’s assets and liabilities to ETE and ETE’s issuance of Class E units to ETC should qualify as an exchange to which Section 721(a) of the Internal Revenue Code applies (the “721 Opinion”). The receipt by ETC and WMB of the 721 Opinion is one of the conditions to the closing of the merger and ETE believes that there is a substantial risk that the condition will not be satisfied or waived by ETE and that the merger will not be consummated. If the closing condition relating to the 721 Opinion is not met or waived, and as a result the merger is not consummated, ETE expects to announce that in a press release and file a Current Report on Form 8-K with the SEC regarding the same. Please see “Management’s Discussion and Analysis of Financial Condition and Results of Operations-Recent Developments,” for additional discussion related to the 721 Opinion, the reasons why Latham has indicated it would not be able to deliver the 721 Opinion and the risks associated with the failure of the related closing condition. Sunoco Retail to Sunoco LP In March 2016, ETP contributed to Sunoco LP its remaining 68.42% interest in Sunoco, LLC and 100% interest in the legacy Sunoco, Inc. retail business for $2.23 billion. Sunoco LP paid $2.20 billion in cash, including a working capital adjustment, and issued 5.7 million Sunoco LP common units to Retail Holdings, a wholly-owned subsidiary of ETP. The transaction was effective January 1, 2016.

- 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).

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+ Details

Cash And Cash Equivalents

3 Months Ended

Mar. 31, 2016

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 by uninsured or in deposit accounts that exceed the Federal Deposit Insurance Corporation insurance limit.

Non-cash investing activities were as follows:



	Three Months Ended March 31,
	2016			2015
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures	$	829		$	658
Net losses from subsidiary common unit issuances	(12		)	—

Inventories (Notes)

3 Months Ended

Mar. 31, 2016

Inventory, Net [Abstract]

Inventories

INVENTORIES

Inventories consisted of the following:



	March 31, 2016		December 31, 2015
Natural gas and NGLs	$	331	$	415
Crude oil	453		424
Refined products	342		420
Other	373		377
Total inventories	$	1,499	$	1,636

We utilize commodity derivatives to manage price volatility associated with our natural gas inventory. Changes in fair value of designated hedged inventory are recorded in inventory on our consolidated balance sheets and cost of products sold in our consolidated statements of operations.

Fair Value Measurements

3 Months Ended

Mar. 31, 2016

Fair Value Measurements [Abstract]

Fair Value Measurements

FAIR VALUE MEASURES

Based on the estimated borrowing rates currently available to us and our subsidiaries for loans with similar terms and average maturities, the aggregate fair value and carrying amount of our consolidated debt obligations as of March 31, 2016 was $35.61 billion and $38.33 billion, respectively. As of December 31, 2015, the aggregate fair value and carrying amount of our consolidated debt obligations was $33.22 billion and $36.97 billion, respectively. The fair value of our consolidated debt obligations is a Level 2 valuation based on the observable inputs used for similar liabilities.

We have commodity derivatives, interest rate derivatives and embedded derivatives in the ETP 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. Level 3 inputs are unobservable. Derivatives related to the embedded derivatives in the 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. During the three months ended March 31, 2016, no transfers were made between any levels within the fair value hierarchy.

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 March 31, 2016 and December 31, 2015 based on inputs used to derive their fair values:



	Fair Value Measurements at March 31, 2016
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Interest rate derivatives	$	25		$	—		$	25		$	—
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	6			6			—			—
Swing Swaps IFERC	1			—			1			—
Fixed Swaps/Futures	67			67			—			—
Forward Physical Swaps	3			—			3			—
Power:
Forwards	22			—			22			—
Futures	1			1			—			—
Options — Calls	2			2			—			—
Natural Gas Liquids – Forwards/Swaps	34			34			—			—
Refined Products — Futures	6			6			—			—
Crude – Futures	12			12			—			—
Total commodity derivatives	154			128			26			—
Total assets	$	179		$	128		$	51		$	—
Liabilities:
Interest rate derivatives	$	(267	)	$	—		$	(267	)	$	—
Embedded derivatives in the ETP Preferred Units	(5		)	—			—			(5		)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(9		)	(9		)	—			—
Swing Swaps IFERC	(2		)	(1		)	(1		)	—
Fixed Swaps/Futures	(50		)	(50		)	—			—
Power:
Forwards	(26		)	—			(26		)	—
Futures	(1		)	(1		)	—			—
Natural Gas Liquids – Forwards/Swaps	(33		)	(33		)	—			—
Refined Products — Futures	(4		)	(4		)	—			—
Crude — Futures	(5		)	(5		)	—			—
Total commodity derivatives	(130		)	(103		)	(27		)	—
Total liabilities	$	(402	)	$	(103	)	$	(294	)	$	(5	)



	Fair Value Measurements at December 31, 2015
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Natural Gas:
Basis Swaps IFERC/NYMEX	16			16			—			—
Swing Swaps IFERC	10			2			8			—
Fixed Swaps/Futures	274			274			—			—
Forward Physical Contracts	4			—			4			—
Power:
Forwards	22			—			22			—
Futures	3			3			—			—
Options — Calls	1			1			—			—
Options — Puts	1			1			—			—
Natural Gas Liquids — Forwards/Swaps	99			99			—			—
Refined Products — Futures	15			15			—			—
Crude - Futures	9			9			—			—
Total commodity derivatives	454			420			34			—
Total assets	$	454		$	420		$	34		$	—
Liabilities:
Interest rate derivatives	$	(171	)	$	—		$	(171	)	$	—
Embedded derivatives in the ETP Preferred Units	(5		)	—			—			(5		)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(16		)	(16		)	—			—
Swing Swaps IFERC	(12		)	(2		)	(10		)	—
Fixed Swaps/Futures	(203		)	(203		)	—			—
Power:
Forwards	(22		)	—			(22		)	—
Futures	(2		)	(2		)	—			—
Options — Calls	(1		)	(1		)	—			—
Natural Gas Liquids — Forwards/Swaps	(89		)	(89		)	—			—
Refined Products — Futures	(6		)	(6		)	—			—
Crude - Futures	(5		)	(5		)	—			—
Total commodity derivatives	(356		)	(324		)	(32		)	—
Total liabilities	$	(532	)	$	(324	)	$	(203	)	$	(5	)

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 three months ended March 31, 2016.



Balance, December 31, 2015	$	(5	)
Net unrealized gains included in other income (expense)	—
Balance, March 31, 2016	$	(5	)

- 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 + Details

Net Income per Limited Partner Unit

3 Months Ended

Mar. 31, 2016

Earnings Per Share [Abstract]

Net Income Per Limited Partner Unit

NET INCOME PER LIMITED PARTNER UNIT

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



	Three Months Ended March 31,
	2016		2015
Net Income	$	336	$	221
Less: Income (loss) attributable to noncontrolling interest	24		(63		)
Net Income, net of noncontrolling interest	312		284
Less: General Partner’s interest in income	1		1
Less: Class D Unitholder’s interest in income	—		1
Income available to Limited Partners	$	311	$	282
Basic Income per Limited Partner Unit:
Weighted average limited partner units	1,044.8		1,077.6
Basic income per Limited Partner unit	$	0.30	$	0.26
Diluted Income per Limited Partner Unit:
Income available to Limited Partners	$	311	$	282
Dilutive effect of equity-based compensation of subsidiaries and distributions to Class D Unitholder	—		(1		)
Diluted income available to Limited Partners	$	311	$	281
Weighted average limited partner units	1,044.8		1,077.6
Dilutive effect of unconverted unit awards	—		1.4
Diluted weighted average limited partner units	1,044.8		1,079.0
Diluted income per Limited Partner unit	$	0.30	$	0.26

Debt Obligations	3 Months Ended
Debt Obligations	Mar. 31, 2016
Debt Obligations [Abstract]
Debt Obligations	DEBT OBLIGATIONS Parent Company Indebtedness The Parent Company’s indebtedness, including its senior notes, senior secured term loan and senior secured revolving credit facility, is secured by all of its and certain of its subsidiaries’ tangible and intangible assets. Revolving Credit Facility The Parent Company’s revolving credit facility has a capacity of $1.5 billion. As of March 31, 2016, there were $965 million outstanding borrowings under the Parent Company Credit Facility and the amount available for future borrowings was $535 million. Subsidiary Indebtedness Sunoco LP Term Loan and Senior Notes In March 2016, Sunoco LP entered into a term loan agreement which provides secured financing in an aggregate principal amount of up to $2.035 billion due 2019. The full amount was borrowed by Sunoco LP as of March 31, 2016. Amounts borrowed under the term loan bear interest at either LIBOR or base rate plus an applicable margin based on Sunoco LP’s election for each interest period. The proceeds were used to fund a portion of the ETP dropdown and to pay fees and expenses incurred in connection with the ETP dropdown and the term loan. In April 2016, Sunoco LP issued $800 million aggregate principal amount of 6.25% Senior Notes due 2021. The net proceeds of $789 million were used to repay a portion of the borrowings under its term loan facility. ETP Credit Facility The ETP Credit Facility allows for borrowings of up to $3.75 billion and expires in November 2019. The indebtedness under the ETP Credit Facility is unsecured, is not guaranteed by any of ETP’s subsidiaries and has equal rights to holders of ETP’s current and future unsecured debt. As of March 31, 2016, the ETP Credit Facility had $4 million of outstanding borrowings. Sunoco Logistics Credit Facilities Sunoco Logistics maintains a $2.5 billion unsecured revolving credit agreement (the “Sunoco Logistics Credit Facility”), which matures in March 2020. The Sunoco Logistics Credit Facility contains an accordion feature, under which the total aggregate commitment may be increased to $3.25 billion under certain conditions. As of March 31, 2016, the Sunoco Logistics Credit Facility had $942 million of outstanding borrowings. Sunoco LP Credit Facility Sunoco LP maintains a $1.5 billion revolving credit facility (the “Sunoco LP Credit Facility”), which expires in September 2019. The Sunoco LP Credit Facility can be increased from time to time upon Sunoco LP’s written request, subject to certain conditions, up to an additional $250 million. As of March 31, 2016, the Sunoco LP Credit Facility had $675 million of outstanding borrowings. Compliance with Our Covenants We and our subsidiaries were in compliance with all requirements, tests, limitations, and covenants related to our respective credit agreements as of March 31, 2016.

Equity

3 Months Ended

Mar. 31, 2016

Partners' Capital Notes [Abstract]

Equity


	EQUITY

ETE

The changes in ETE common units and Convertible Units during the three months ended March 31, 2016 were as follows:



	Number of Convertible Units	Number of Common Units
Outstanding at December 31, 2015	—	1,044.8
Issue Series A Convertible Preferred Units	329.3	—
Outstanding at March 31, 2016	329.3	1,044.8

Series A Convertible Preferred Units

On March 8, 2016, the Partnership completed a private offering of 329.3 million Series A Convertible Preferred Units representing limited partner interests in the Partnership (the “Convertible Units”) to certain common unitholders (“Electing Unitholders”) who elected to participate in a plan to forgo a portion of their future potential cash distributions on common units participating in the plan for a period of up to nine fiscal quarters, commencing with distributions for the fiscal quarter ended March 31, 2016, and reinvest those distributions in the Convertible Units. With respect to each quarter for which the declaration date and record date occurs prior to the closing of the merger, or earlier termination of the merger agreement (the “WMB End Date”), each participating common unit will receive the same cash distribution as all other ETE common units up to $0.11 per unit, which represents approximately 40% of the per unit distribution paid with respect to ETE common units for the quarter ended December 31, 2015 (the “Preferred Distribution Amount”), and the holder of such participating common unit will forgo all cash distributions in excess of that amount (other than (i) any non-cash distribution or (ii) any cash distribution that is materially and substantially greater, on a per unit basis, than ETE’s most recent regular quarterly distribution, as determined by the ETE general partner (such distributions in clauses (i) and (ii), “Extraordinary Distributions”)). With respect to each quarter for which the declaration date and record date occurs after the WMB End Date, each participating common unit will forgo all distributions for each such quarter (other than Extraordinary Distributions), and each Convertible Unit will receive the Preferred Distribution Amount payable in cash prior to any distribution on ETE common units (other than Extraordinary Distributions). At the end of the plan period, which is expected to be May 18, 2018, the Convertible Units are expected to automatically convert into common units based on the Conversion Value (as defined and described below) of the Convertible Units and a conversion rate of $6.56.

The conversion value of each Convertible Unit (the “Conversion Value”) on the closing date of the offering is zero. The Conversion Value will increase each quarter in an amount equal to $0.285, which is the per unit amount of the cash distribution paid with respect to ETE common units for the quarter ended December 31, 2015 (the “Conversion Value Cap”), less the cash distribution actually paid with respect to each Convertible Unit for such quarter (or, if prior to the WMB End Date, each participating common unit). Any cash distributions in excess of $0.285 per ETE common unit, and any Extraordinary Distributions, made with respect to any quarter during the plan period will be disregarded for purposes of calculating the Conversion Value. The Conversion Value will be reflected in the carrying amount of the Convertible Units until the conversion into common units at the end of the plan period.

ETE issued 329,299,267 Convertible Units to the Electing Unitholders at the closing of the offering, which represents the participation by common unitholders with respect to approximately 31.5% of ETE’s total outstanding common units. ETE’s Chairman, Kelcy L. Warren, participated in the Plan with respect to substantially all of his common units, which represent approximately 18% of ETE’s total outstanding common units, and was issued 187,313,942 Convertible Units. In addition, John McReynolds, a director of our general partner and President of our general partner; and Matthew S. Ramsey, a director of our general partner and the general partner of ETP and Sunoco LP and President of the general partner of ETP, participated in the Plan with respect to substantially all of their common units, and Marshall S. McCrea, III, a director of our general partner and the general partner of ETP and Sunoco Logistics and the Group Chief Operating Officer and Chief Commercial Officer of our general partner, participated in the Plan with respect to a substantial portion of his common units. The common units for which Messrs. McReynolds, Ramsey and McCrea elected to participate in the Plan collectively represent approximately 2.2% of ETE’s total outstanding common units. ETE issued 21,382,155 Convertible Units to Mr. McReynolds, 51,317 Convertible Units to Mr. Ramsey and 1,112,728 Convertible Units to Mr. McCrea. Mr. Ray Davis, who owns an 18.8% membership interest in our general partner, participated in the Plan with respect to substantially all of his ETE common units, which represents approximately 6.9% of ETE’s total outstanding common units, and was issued 72,042,486 Convertible Units. Other than Mr. Davis, no other Electing Unitholder owns a material amount of equity securities of ETE or its affiliates.

Repurchase Program

During the three months ended March 31, 2016, ETE did not repurchase any ETE common units under its current buyback program. As of March 31, 2016, $936 million remained available to repurchase under the current program.

Subsidiary Common Unit Transactions

The Parent Company accounts for the difference between the carrying amount of its investment in ETP and Sunoco LP and the underlying book value arising from the issuance or redemption of units by ETP and Sunoco LP (excluding transactions with the Parent Company) as capital transactions. As a result of these transactions during the three months ended March 31, 2016, we recognized decreases in partners’ capital of $12 million.

ETP Common Unit Transactions

During the three months ended March 31, 2016, ETP received proceeds of $324 million, net of $3 million commissions, from the issuance of common units pursuant to equity distribution agreements, which were used for general partnership purposes. As of March 31, 2016, approximately none of ETP’s common units were available to be issued under an equity distribution agreement.

During the three months ended March 31, 2016, distributions of $39 million were reinvested under ETP’s distribution reinvestment plan resulting in the issuance of 1.8 million common units. As of March 31, 2016, a total of 9.7 million common units remain available to be issued under the existing registration statement in connection with the distribution reinvestment plan.

Sunoco Logistics Common Unit Transactions

During the three months ended March 31, 2016, Sunoco Logistics received proceeds of $301 million, net of commissions of $3 million, from the issuance of Sunoco Logistics common units pursuant to equity distribution agreements, which were used for general partnership purposes.

Sunoco LP Common Unit Transactions

In January 2016, Sunoco LP issued 16.4 million Class C units representing limited partner interest consisting of (i) 5.2 million Class C Units issued by Sunoco LP to Aloha as consideration for the contribution by Aloha to an indirect wholly-owned subsidiary, and (ii) 11.2 million Class C Units that were issued by Sunoco LP to its indirect wholly-owned subsidiaries in exchange for all of the outstanding Class A Units held by such subsidiaries.

In March 2016, ETP contributed to Sunoco LP its remaining 68.42% interest in Sunoco, LLC and 100% interest in the legacy Sunoco, Inc. retail business for $2.23 billion. Sunoco LP paid $2.20 billion in cash, including a working capital adjustment, and issued 5.7 million Sunoco LP common units to Retail Holdings, a wholly-owned subsidiary of ETP.

On March 31, 2016, Sunoco LP sold 2.3 million of Sunoco LP’s common units in a private placement to the Partnership.

Parent Company Quarterly Distributions of Available Cash

Following are distributions declared and/or paid by us subsequent to December 31, 2015:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2015	February 4, 2016	February 19, 2016	$	0.2850
March 31, 2016	May 6, 2016	May 19, 2016	0.2850

ETP Quarterly Distributions of Available Cash

Following are distributions declared and/or paid by ETP subsequent to December 31, 2015:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2015	February 8, 2016	February 16, 2016	$	1.0550
March 31, 2016	May 6, 2016	May 16, 2016	1.0550

ETE has agreed to relinquish its right to the following amounts of incentive distributions in future periods, including distributions on ETP Class I Units.



	Total Year
2016 (remainder)	$	103
2017	128
2018	105
2019	95

Sunoco Logistics Quarterly Distributions of Available Cash

Following are distributions declared and/or paid by Sunoco Logistics subsequent to December 31, 2015:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2015	February 8, 2016	February 12, 2016	$	0.4790
March 31, 2016	May 9, 2016	May 13, 2016	0.4890

Sunoco LP Quarterly Distributions of Available Cash

Following are distributions declared and/or paid by Sunoco LP subsequent to December 31, 2015:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2015	February 5, 2016	February 16, 2016	$	0.8013
March 31, 2016	May 6, 2016	May 16, 2016	0.8173

Accumulated Other Comprehensive Income

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



	March 31, 2016			December 31, 2015
Available-for-sale securities	$	2		$	—
Foreign currency translation adjustment	(5		)	(4		)
Net loss on interest rate derivatives	(6		)	—
Actuarial loss related to pensions and other postretirement benefits	(1		)	8
Subtotal	(10		)	4
Amounts attributable to noncontrolling interest	10			(4		)
Total AOCI, net of tax	$	—		$	—

Income Taxes (Notes)	3 Months Ended
Income Taxes (Notes)	Mar. 31, 2016
Income Tax Disclosure [Abstract]
Income Tax Disclosure [Text Block]	INCOME TAXES For the three months ended March 31, 2016, the Partnership’s effective income tax rate decreased from the prior year primarily due to lower earnings among the Partnership’s consolidated corporate subsidiaries. The three months ended March 31, 2016 also reflected a benefit of $9 million of net state tax benefit attributable to statutory state rate changes resulting from the contribution by ETP to Sunoco LP of its remaining 68.42% interest in Sunoco, LLC and 100% interest in the legacy Sunoco, Inc. retail business.

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities

3 Months Ended

Mar. 31, 2016

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

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities

REGULATORY MATTERS, COMMITMENTS, CONTINGENCIES AND ENVIRONMENTAL LIABILITIES

Contingent Residual Support Agreement – AmeriGas

In connection with the closing of the contribution of its propane operations in January 2012, ETP agreed to provide contingent, residual support of $1.55 billion of intercompany borrowings made by AmeriGas and certain of its affiliates with maturities through 2022 from a finance subsidiary of AmeriGas that have maturity dates and repayment terms that mirror those of an equal principal amount of senior notes issued by this finance company subsidiary to third party purchasers.

ETP Retail Holdings Guarantee of Sunoco LP Notes

Retail Holdings has provided a guarantee of collection, but not of payment, to Sunoco LP with respect to (i) $800 million principal amount of 6.375% senior notes due 2023 issued by Sunoco LP, (ii) $800 million principal amount of 6.25% senior notes due 2021 issued by Sunoco LP and (iii) $2.035 billion of borrowings outstanding under Sunoco LP’s Term Loan.

NGL Pipeline Regulation

ETP has interests in NGL pipelines located in Texas and New Mexico. ETP commenced the interstate transportation of NGLs in 2013, which is subject to the jurisdiction of the FERC under the Interstate Commerce Act (“ICA”) and the Energy Policy Act of 1992. Under the ICA, tariff rates must be just and reasonable and not unduly discriminatory and pipelines may not confer any undue preference. The tariff rates established for interstate services were based on a negotiated agreement; however, the FERC’s rate-making methodologies may limit ETP’s ability to set rates based on our actual costs, may delay or limit the use of rates that reflect increased costs and may subject us to potentially burdensome and expensive operational, reporting and other requirements. Any of the foregoing could adversely affect ETP’s business, revenues and cash flow.

FERC Audit

In March 2016, the FERC commenced an audit of Trunkline for the period from January 1, 2013 to present to evaluate Trunkline’s compliance with the requirements of its FERC gas tariff, the accounting regulations of the Uniform System of Accounts as prescribed by the FERC, and the FERC’s annual reporting requirements.

Commitments

In the normal course of our business, we purchase, process and sell natural gas pursuant to long-term contracts and we 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 2058. The table below reflects rental expense under these operating leases included in operating expenses in the accompanying statements of operations, which include contingent rentals, and rental expense recovered through related sublease rental income:



	Three Months Ended March 31,
	2016			2015
Rental expense⁽¹⁾	$	51		$	52
Less: Sublease rental income	(7		)	(8		)
Rental expense, net	$	44		$	44


⁽¹⁾	Includes contingent rentals totaling $16 million and $4 million for the three months ended March 31, 2016 and 2015 respectively.

Certain of our subsidiaries’ joint venture agreements require that they fund their proportionate shares of capital contributions to their unconsolidated affiliates. Such 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 crude oil are flammable and combustible. 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.

MTBE Litigation

Sunoco, Inc., along with other refiners, manufacturers and sellers of gasoline, is a defendant in lawsuits alleging MTBE contamination of groundwater. The plaintiffs typically include water purveyors and municipalities responsible for supplying drinking water and governmental authorities. The plaintiffs primarily assert product liability claims and additional claims including nuisance, trespass, negligence, violation of environmental laws and deceptive business practices. The plaintiffs in all of the cases seek to recover compensatory damages, and in some cases also seek natural resource damages, injunctive relief, punitive damages and attorneys’ fees.

As of March 31, 2016, Sunoco, Inc. is a defendant in five cases, including cases initiated by the States of New Jersey, Vermont, Pennsylvania, and two others by the Commonwealth of Puerto Rico with the more recent Puerto Rico action being a companion case alleging damages for additional sites beyond those at issue in the initial Puerto Rico action. Four of these cases are venued in a multidistrict litigation proceeding in a New York federal court. The New Jersey, Puerto Rico, Vermont, and Pennsylvania cases assert natural resource damage claims.

Fact discovery has concluded with respect to an initial set of 19 sites each that will be the subject of the first trial phase in the New Jersey case and the initial Puerto Rico case. Insufficient information has been developed about the plaintiffs’ legal theories or the facts with respect to statewide natural resource damage claims to provide an analysis of the ultimate potential liability of Sunoco, Inc. in these matters. It is reasonably possible that a loss may be realized; however, we are unable to estimate the possible loss or range of loss in excess of amounts accrued. Management believes that an adverse determination with respect to one or more of the MTBE cases could have a significant impact on results of operations during the period in which any said adverse determination occurs, but does not believe that any such adverse determination would have a material adverse effect on the Partnership’s consolidated financial position.

Regency Merger Litigation

Following the January 26, 2015 announcement of the definitive merger agreement with Regency, purported Regency unitholders filed lawsuits in state and federal courts in Dallas, Texas and Delaware state court asserting claims relating to the proposed transaction. All Regency merger related lawsuits have been dismissed, though one lawsuit remains pending on appeal. On June 10, 2015, Adrian Dieckman (“Dieckman”), a purported Regency unitholder, filed a class action complaint on behalf of Regency’s common unitholders in the Court of Chancery of the State of Delaware. The lawsuit alleges that the transaction did not comply with the Regency partnership agreement because the conflicts committee was not properly formed. Defendants filed a motion to dismiss, and on March 29, 2016, the Delaware court granted Defendants’ motion and dismissed the lawsuit. On April 26, 2016, Plaintiff filed its Notice of Appeal to the Supreme Court of Delaware. This appeal is styled Adrian Dieckman v. Regency GP LP, et al., No. 208, 2016, in the Supreme Court of the State of Delaware.

Jamie Welch Litigation

On March 10, 2016, Jamie Welch (“Welch”) filed an original petition against ETE and LE GP in Texas state court in Dallas. Welch alleges that Defendants 1) breached their contractual obligation to deliver and convert Welch’s Class D units upon termination; 2) failed to deliver long term incentive shares awarded to Welch; 3) failed to pay Welch’s 2015 bonus; 4) breached their obligation to grant Welch an interest in the Lake Charles LNG project; and 5) breached their obligation to pay Welch his severance. Welch brings claims for breach of contract and quantum meruit. On April 12, 2016, Defendants removed Welch’s lawsuit from state court to federal court in Dallas pursuant to 28 U.S.C. §§ 1441 and 1446. On April 29, 2016, Welch filed an amended complaint and removed his claim for payment of severance benefits.

Enterprise Products Partners, L.P. and Enterprise Products Operating LLC Litigation

On January 27, 2014, a trial commenced between ETP against Enterprise Products Partners, L.P. and Enterprise Products Operating LLC (collectively, “Enterprise”) and Enbridge (US) Inc. Trial resulted in a verdict in favor of ETP against Enterprise that consisted of $319 million in compensatory damages and $595 million in disgorgement to ETP. The jury also found that ETP owed Enterprise approximately $1 million under a reimbursement agreement. On July 29, 2014, the trial court entered a final judgment in favor of ETP and awarded ETP $536 million, consisting of compensatory damages, disgorgement, and pre-judgment interest. The trial court also ordered that ETP shall be entitled to recover post-judgment interest and costs of court and that Enterprise is not entitled to any net recovery on its counterclaims. Enterprise has filed a notice of appeal with the Texas Court of Appeals, and briefing by Enterprise and ETP is complete. Oral argument was held on April 20, 2016. The Court of Appeals is taking the briefs under advisement. In accordance with GAAP, no amounts related to the original verdict or the July 29, 2014 final judgment will be recorded in our financial statements until the appeal process is completed.

Litigation Relating to the Williams Companies, Inc.

On April 6, 2016, The Williams Companies, Inc. (“Williams”) filed a complaint against ETE and LE GP in the Delaware Court of Chancery (the “Delaware Williams Litigation”). This lawsuit is styled The Williams Companies, Inc. v. Energy Transfer Equity, L.P., et al., C.A. No. 12168-VCG. Williams alleges that Defendants breached the merger agreement between Williams, ETE, and several of ETE’s affiliates (the “Merger Agreement”) by issuing ETE’s Series A Convertible Preferred Units (the “Convertible Units”). According to Williams, the issuance of Convertible Units (the “Issuance”) violates various contractual restrictions on ETE’s actions between the execution and closing of the merger. Williams seeks, among other things, to (a) rescind the Issuance and (b) invalidate an amendment to ETE’s partnership agreement that was adopted on March 8, 2016 as part of the Issuance.

The Delaware Court of Chancery held a hearing on Williams’ Motion to Expedite on April 14, 2016. The Court granted Williams’ Motion to Expedite but significantly limited discovery. Williams amended its complaint in the Delaware suit on April 19, 2016, but did not add any additional claims. The Court has set a permanent injunction hearing for June 15, 2016. Defendants intend to vigorously defend this lawsuit.

Williams also filed a petition against Mr. Warren in the District Court of Dallas County, Texas, on April 6, 2016 (the “Texas Williams Litigation”). This lawsuit is styled The Williams Companies, Inc. v. Kelcy Warren, C.A. No. DC-16-03941. Williams alleges that Mr. Warren tortiously interfered with the Merger Agreement through his involvement in the Issuance. Williams seeks, among other things, damages from Mr. Warren, who intends to vigorously defend this lawsuit.

On May 3, 2016, ETE and LE GP filed an answer and counterclaim in the Delaware Williams Litigation. The counterclaim asserts that Williams materially breached its obligations under the Merger Agreement by (a) blocking ETE’s attempts to complete a public offering of the Convertible Units, including, among other things, by declining to allow Williams’ independent registered public accounting firm to provide the auditor consent required to be included in the registration statement for a public offering and (b) bringing the Texas Williams Litigation against Mr. Warren in the District Court of Dallas County, Texas.

Litigation Relating to the WMB Merger

Between October 5, 2015, and December 24, 2015, purported Williams stockholders filed six putative class action lawsuits in the Delaware Court of Chancery challenging the merger. The suits are captioned Greenwald et al. v. The Williams Companies, Inc., et al., C.A. No. 11573-VCG; Ozaki v. Armstrong et al., C.A. No. 11574-VCG; Blystone v. The Williams Companies, Inc., et al., C.A. No. 11601-VCG; Glener et al. v. The Williams Companies, Inc., et al., C.A. No. 11606-VCG; Amaitis et al. v. Armstrong et al., C.A. No. 11809-VCG; and State-Boston Retirement System et al. v. Armstrong et al., C.A. No. 11844-VCG. The complaints assert various claims against the individual members of Williams’ board of directors; ETE, ETC, ETC GP, LE GP and ETE GP (the “ETE Defendants”); Williams; and others. On January 13, 2016, the Court consolidated these six actions into a new consolidated action captioned In re The Williams Companies, Inc. Merger Litigation, Consolidated C.A. No. 11844-VCG (the “Merger Litigation”). In its stipulated order, the Court dismissed without prejudice the ETE Defendants (among others) from the consolidated action.

On January 14, 2016, a purported Williams stockholder (“Bumgarner”) filed a putative class action lawsuit against Williams and ETE, captioned Bumgarner v. The Williams Companies, Inc., et al., Case No. 16-cv-26-GKF-FHM, in the United States District Court for the Northern District of Oklahoma. Bumgarner alleges that ETE and Williams have violated Section 14 of the Securities Exchange Act of 1934 (the “Exchange Act”) by making allegedly false statements concerning the merger. As relief, the complaint seeks an injunction against the proposed merger. On February 1, 2016, Bumgarner filed an amended complaint, making substantially the same allegations. On February 19, 2016, ETE and Williams moved to dismiss the amended complaint. Bumgarner moved for expedited discovery on April 21, 2016. On April 28, 2016, the Court granted the motion to dismiss and dismissed Bumgarner’s claims in their entirety with leave to amend. The Court also granted expedited proceedings with respect to any further proceedings.

On January 19, 2016, The City of Birmingham Retirement and Relief System (“CBRRS”), a purported shareholder of Williams, filed a putative class action lawsuit against the members of Williams’ board of directors, Williams, ETE, ETC, ETC GP, LE GP, and ETE GP challenging the merger and the disclosures made in connection with the merger. The lawsuit was styled City of Birmingham Retirement and Relief System v. Alan S. Armstrong, et al., C.A. No. 16-17-RGA, in the United States District Court for the District of Delaware. CBRRS alleged violations of Section 14(a) and 20(a) of the Exchange Act among other claims. CBRRS moved to expedite, and Defendants moved to dismiss the suit. The Court denied expedition. CBRRS voluntarily dismissed the suit on March 7, 2016.

Unitholder Litigation Relating to the Issuance

In April 2016, two purported ETE unitholders (the “Issuance Plaintiffs”) filed putative class action lawsuits against, Energy Transfer Equity, L.P. and LE GP, LLC, Kelcy Warren, John McReynolds, Marshall McCrea, Matthew Ramsey, Ted Collins, K. Rick Turner, William Williams, Ray Davis, and Richard Brannon in the Delaware Court of Chancery. These lawsuits have been consolidated as In re Energy Transfer Equity, L.P. Unitholder Litigation, Consolidated C.A. No. 12197-VCG, in the Court of Chancery of the State of Delaware. One of the Issuance Plaintiffs had initially filed an action to inspect the books and records of ETE on April 11, 2016 but voluntarily dismissed the books and records action on April 22, 2016.

The Issuance Plaintiffs allege that the Issuance breached various provisions of ETE’s limited partnership agreement. The Issuance Plaintiff seek, among other things, preliminary and permanent injunctive relief that (a) prevents ETE from making distributions to the Convertible Units and (b) invalidates an amendment to ETE’s partnership agreement that was adopted on March 8, 2016 as part of the issuance of Convertible Units.

One of the Issuance Plaintiffs moved for expedited proceedings. The Delaware Court of Chancery granted a Motion to Expedite filed by one of the Issuance Plaintiffs and stated that the injunction hearing should be held before any August 2016 distribution. Defendants intend to vigorously defend this consolidated lawsuit.

Other Litigation and Contingencies

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 March 31, 2016 and December 31, 2015, accruals of approximately $59 million and $40 million, respectively, were reflected on our balance sheets related to these contingent obligations. As new information becomes available, our estimates may change. The impact of these changes may have a significant effect on our results of operations in a single period.

The outcome of these matters cannot be predicted with certainty and there can be no assurance that the outcome of a particular matter will not result in the payment of amounts that have not been accrued for the matter. 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. Currently, we are not able to estimate possible losses or a range of possible losses in excess of amounts accrued.

No amounts have been recorded in our March 31, 2016 or December 31, 2015 consolidated balance sheets for contingencies and current litigation, other than amounts disclosed herein.

Attorney General of the Commonwealth of Massachusetts v. New England Gas Company.

On July 7, 2011, the Massachusetts Attorney General (“AG”) filed a regulatory complaint with the Massachusetts Department of Public Utilities (“MDPU”) against New England Gas Company with respect to certain environmental cost recoveries. The AG 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 AG 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 approximately $19 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, the Southern Union former Vice Chairman, President and Chief Operating Officer, 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 AG contends only 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 hearing officer has deferred consideration of Southern Union’s motion to dismiss. The AG’s motion to be reimbursed expert and consultant costs by Southern Union of up to $150,000 was granted. By tariff, these costs are recoverable through rates charged to New England Gas Company customers. The hearing officer previously stayed discovery pending resolution of a dispute concerning the applicability of attorney-client privilege to legal billing invoices. The MDPU issued an interlocutory order on June 24, 2013 that lifted the stay, and discovery has resumed. Panhandle (as successor to Southern Union) believes it has complied with all applicable requirements regarding its filings for cost recovery and has not recorded any accrued liability; however, Panhandle will continue to assess its potential exposure for such cost recoveries as the matter progresses.

Compliance Orders from the New Mexico Environmental Department

Regency received a Notice of Violation from the New Mexico Environmental Department on September 23, 2015 for allegations of violations of New Mexico air regulations related to Jal #3. The Partnership has accrued $250,000 related to the claims and will continue to assess its potential exposure to the allegations as the matter progresses.

Lone Star NGL Fractionators Notice of Enforcement

Lone Star NGL Fractionators received a Notice of Enforcement from the Texas Commission on Environmental Quality on August 28, 2015 for allegations of violations of Texas air regulations related to its Mont Belvieu Gas Plant. The Partnership has accrued $300,000 related to the claim. As of April 2016, the Agreed Order is in the approval process with the Texas Commission on Environmental Quality and includes a $21,000 penalty and a $21,000 Supplemental Environmental Project.

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. Contingent losses related to all significant known environmental matters have been accrued and/or separately disclosed. However, 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.

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 liability in proportion to other parties, improvements in cleanup technologies and the extent to which environmental laws and regulations may change in the future. Although environmental costs may have a significant impact on the results of operations for any single period, we believe that such costs will not have a material adverse effect on our financial position.

Based on information available at this time and reviews undertaken to identify potential exposure, we believe the amount reserved for environmental matters is adequate to cover the potential exposure for cleanup costs.

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.


•	Currently operating Sunoco, Inc. retail sites.


•	Legacy sites related to Sunoco, Inc., that are subject to environmental assessments include formerly owned terminals and other logistics assets, retail sites that Sunoco, Inc. no longer operates, closed and/or sold refineries and other formerly owned sites.

•

Sunoco, Inc. is potentially subject to joint and several liability for the costs of remediation at sites at which it has been identified as a potentially responsible party (“PRP”). As of March 31, 2016, Sunoco, Inc. had been named as a PRP at approximately 48 identified or potentially identifiable “Superfund” sites under federal and/or comparable state law. Sunoco, Inc. is usually one of a number of companies identified as a PRP at a site. Sunoco, Inc. has reviewed the nature and extent of its involvement at each site and other relevant circumstances and, based upon Sunoco, Inc.’s purported nexus to the sites, believes that its potential liability associated with such sites will not be significant.

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. Currently, we are not able to estimate possible losses or a range of possible losses in excess of amounts accrued. 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.



	March 31, 2016		December 31, 2015
Current	$	40	$	42
Non-current	293		326
Total environmental liabilities	$	333	$	368

In 2013, we established a wholly-owned captive insurance company to bear certain risks associated with environmental obligations related to certain sites that are no longer operating. The premiums paid to the captive insurance company include estimates for environmental claims that have been incurred but not reported, based on an actuarially determined fully developed claims expense estimate. In such cases, we accrue losses attributable to unasserted claims based on the discounted estimates that are used to develop the premiums paid to the captive insurance company.

During the three months ended March 31, 2016 and 2015, Sunoco, Inc. and Sunoco LP collectively recorded $8 million and $7 million, respectively, of expenditures related to environmental cleanup programs.

On December 2, 2010, Sunoco, Inc. entered an Asset Sale and Purchase Agreement to sell the Toledo Refinery to Toledo Refining Company LLC (TRC) wherein Sunoco, Inc. retained certain liabilities associated with the pre-Closing time period. On January 2, 2013, USEPA issued a Finding of Violation (FOV) to TRC and, on September 30, 2013, EPA issued an NOV/FOV to TRC alleging Clean Air Act violations. To date, EPA has not issued an FOV or NOV/FOV to Sunoco, Inc. directly but some of EPA’s claims relate to the time period that Sunoco, Inc. operated the refinery. Specifically, EPA has claimed that the refinery flares were not operated in a manner consistent with good air pollution control practice for minimizing emissions and/or in conformance with their design, and that Sunoco, Inc. submitted semi-annual compliance reports in 2010 and 2011 that failed to include all of the information required by the regulations. EPA has proposed penalties in excess of $200,000 to resolve the allegations and discussions continue between the parties. The timing or outcome of this matter cannot be reasonably determined at this time, however, we do not expect there to be a material impact to our results of operations, cash flows or financial position.

Our pipeline operations are subject to regulation by the U.S. Department of Transportation 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 us to incur future capital and operating expenditures for repairs or upgrades deemed necessary to ensure the continued safe and reliable operation of our pipelines; however, no estimate can be made at this time of the likely range of such expenditures.

In April 2016, the PHMSA issued a Notice of Probable Violation ("NOPV"), Proposed Civil Penalty and Proposed Compliance Order related to certain procedures carried out during construction of Sunoco Logistics’ Permian Express 2 pipeline system in Texas. The correspondence proposes penalties in excess of $0.1 million, and Sunoco Logistics is currently in discussions with PHMSA to resolve these matters. The timing or outcome of these matters cannot be reasonably determined at this time, however, Sunoco Logistics does not expect there to be a material impact to its results of operations, cash flows, or financial position.

Our operations are also subject to the requirements of the OSHA, and comparable state laws that regulate the protection of the health and safety of employees. In addition, OSHA’s hazardous communication standard requires that information be maintained about hazardous materials used or produced in our operations and that this information be provided to employees, state and local government authorities and citizens. We believe that our operations are in substantial compliance with the OSHA requirements, including general industry standards, record keeping requirements, and monitoring of occupational exposure to regulated substances.

Derivative Assets And Liabilities

3 Months Ended

Mar. 31, 2016

General Discussion of Derivative Instruments and Hedging Activities [Abstract]

Derivative Assets And Liabilities

DERIVATIVE 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.

We use futures and basis swaps, designated as fair value hedges, to hedge our natural gas inventory stored in our Bammel storage facility. At hedge inception, we lock in a margin by purchasing gas in the spot market or off peak season and entering into a financial contract. Changes in the spreads between the forward natural gas prices 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.

We use futures, swaps and options to hedge the sales price of natural gas we retain for fees in our intrastate transportation and storage segment and operational gas sales on our interstate transportation and storage segment. These contracts are not designated as hedges for accounting purposes.

We use NGL and crude derivative swap contracts to hedge forecasted sales of NGL and condensate equity volumes we retain for fees in our midstream segment whereby our subsidiaries generally gather and process natural gas on behalf of producers, sell the resulting residue gas and NGL volumes at market prices and remit to producers an agreed upon percentage of the proceeds based on an index price for the residue gas and NGL. These contracts are not designated as hedges for accounting purposes.

We use derivatives in our liquids transportation and services segment to manage our storage facilities and the purchase and sale of purity NGL. These contracts are not designated as hedges for accounting purposes.

Sunoco Logistics utilizes swaps, futures and other derivative instruments to mitigate the risk associated with market movements in the price of refined products and NGLs. These contracts are not designated as hedges for accounting purposes.

We use futures and swaps to achieve ratable pricing of crude oil purchases, to convert certain expected refined product sales to fixed or floating prices, to lock in margins for certain refined products and to lock in the price of a portion of natural gas purchases or sales and transportation costs in our retail marketing segment. These contracts are not designated as hedges for accounting purposes.

We use financial commodity derivatives to take advantage of market opportunities in our trading activities which complement our transportation and storage segment’s operations and are netted in cost of products sold in our consolidated statements of operations. We also have trading and marketing activities related to power and natural gas in our all other segment which are also netted in cost of products sold. As a result of our trading activities and the use of derivative financial instruments in our transportation and storage segment, the degree of earnings volatility that can occur may be significant, favorably or unfavorably, from period to period. We attempt to manage this volatility through the use of daily position and profit and loss reports provided to our risk oversight committee, which includes members of senior management, and the limits and authorizations set forth in our commodity risk management policy.

The following table details our outstanding commodity-related derivatives:



	March 31, 2016			December 31, 2015
	Notional Volume		Maturity	Notional Volume		Maturity
Mark-to-Market Derivatives
(Trading)
Natural Gas (MMBtu):
Fixed Swaps/Futures	1,712,500		2016-2017	(602,500	)	2016-2017
Basis Swaps IFERC/NYMEX ⁽¹⁾	63,825,000		2016-2017	(31,240,000	)	2016-2017
Power (Megawatt):
Forwards	(344,954	)	2016-2017	357,092		2016-2017
Futures	2,675,597		2016-2017	(109,791	)	2016
Options — Puts	(227,600	)	2016	260,534		2016
Options — Calls	1,011,600		2016	1,300,647		2016
Crude (Bbls):
Futures	(616,000	)	2016-2017	(591,000	)	2016-2017
Options — Puts	(300,000	)	2016	—		—
Options — Calls	300,000		2016	—		—
(Non-Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX	(9,175,000	)	2016-2017	(6,522,500	)	2016-2017
Swing Swaps IFERC	105,170,000		2016-2017	71,340,000		2016-2017
Fixed Swaps/Futures	(6,862,500	)	2016-2018	(14,380,000	)	2016-2018
Forward Physical Contracts	26,156,570		2016-2017	21,922,484		2016-2017
Natural Gas Liquid and Crude (Bbls) — Forwards/Swaps	(6,273,000	)	2016	(8,146,800	)	2016-2018
Refined Products (Bbls) — Futures	(2,846,000	)	2016-2017	(1,289,000	)	2016-2017
Corn (Bushels) — Futures	122,000		2016	1,185,000		2016
Fair Value Hedging Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX	(23,215,000	)	2016	(37,555,000	)	2016
Fixed Swaps/Futures	(23,215,000	)	2016	(37,555,000	)	2016
Hedged Item — Inventory	23,215,000		2016	37,555,000		2016


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

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.

The following table summarizes our interest rate swaps outstanding none of which were designated as hedges for accounting purposes:



		Notional Amount Outstanding
Term	Type⁽¹⁾	March 31, 2016		December 31, 2015
July 2016⁽²⁾	Forward-starting to pay a fixed rate of 3.80% and receive a floating rate	$	200	$	200
July 2017⁽³⁾	Forward-starting to pay a fixed rate of 3.84% and receive a floating rate	300		300
July 2018⁽³⁾	Forward-starting to pay a fixed rate of 4.00% and receive a floating rate	200		200
December 2018	Pay a floating rate based on a 3-month LIBOR and receive a fixed rate of 1.53%	1,200		1,200
March 2019	Pay a floating rate based on a 3-month LIBOR and receive a fixed rate of 1.42%	300		300
July 2019⁽³⁾	Forward-starting to pay a fixed rate of 3.25% and receive a floating rate	200		200


⁽¹⁾	Floating rates are based on 3-month LIBOR.


⁽²⁾	Represents the effective date. These forward-starting swaps have a term of 10 and 30 years with a mandatory termination date the same as the effective date.


⁽³⁾	Represents the effective date. These forward-starting swaps have terms of 30 years with a mandatory termination date the same as the effective date.

Credit Risk

Credit risk refers to the risk that a counterparty may default on its contractual obligations resulting in a loss to the Partnership. Credit policies have been approved and implemented to govern ETP’s portfolio of counterparties with the objective of mitigating credit losses. These policies establish guidelines, controls and limits to manage credit risk within approved tolerances by mandating an appropriate evaluation of the financial condition of existing and potential counterparties, monitoring agency credit ratings, and by implementing credit practices that limit exposure according to the risk profiles of the counterparties. Furthermore, ETP may at times require collateral under certain circumstances to mitigate credit risk as necessary. ETP also implements the use of industry standard commercial agreements which allow for the netting of positive and negative exposures associated with transactions executed under a single commercial agreement. Additionally, ETP utilizes master netting agreements to offset credit exposure across multiple commercial agreements with a single counterparty or affiliated group of counterparties.

ETP’s counterparties consist of a diverse portfolio of customers across the energy industry, including petrochemical companies, commercial and industrials, oil and gas producers, motor fuel distributors, municipalities, utilities and midstream companies. ETP’s overall exposure may be affected positively or negatively by macroeconomic factors or regulatory changes that could impact its counterparties to one extent or another. Currently, management does not anticipate a material adverse effect in our financial position or results of operations as a consequence of counterparty non-performance.

ETP has maintenance margin deposits with certain counterparties in the OTC market, primarily independent system operators, and with clearing brokers. Payments on margin deposits are required when the value of a derivative exceeds our pre-established credit limit with the counterparty. Margin deposits are returned to ETP on or about the settlement date for non-exchange traded derivatives, and 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.

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 summary of our derivative assets and liabilities:



	Fair Value of Derivative Instruments
	Asset Derivatives				Liability Derivatives
	March 31, 2016		December 31, 2015		March 31, 2016			December 31, 2015
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	4	$	38	$	—		$	(3	)
	4		38		—			(3		)
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	$	115	$	353	$	(98	)	$	(306	)
Commodity derivatives	35		63		(32		)	(47		)
Interest rate derivatives	25		—		(267		)	(171		)
Embedded derivatives in the ETP Preferred Units	—		—		(5		)	(5		)
	175		416		(402		)	(529		)
Total derivatives	$	179	$	454	$	(402	)	$	(532	)

The following table presents the fair value of our recognized derivative assets and liabilities on a gross basis and amounts offset on the consolidated balance sheets that are subject to enforceable master netting arrangements or similar arrangements:



		Asset Derivatives						Liability Derivatives
	Balance Sheet Location	March 31, 2016			December 31, 2015			March 31, 2016			December 31, 2015
Derivatives without offsetting agreements	Derivative assets (liabilities)	$	25		$	—		$	(272	)	$	(176	)
Derivatives in offsetting agreements:
OTC contracts	Derivative assets (liabilities)	35			63			(32		)	(47		)
Broker cleared derivative contracts	Other current assets	119			391			(98		)	(309		)
Total gross derivatives		179			454			(402		)	(532		)
Less offsetting agreements:
Counterparty netting	Derivative assets (liabilities)	(17		)	(17		)	17			17
Payments on margin deposit	Other current assets	(98		)	(309		)	98			309
Total net derivatives		$	64		$	128		$	(287	)	$	(206	)

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

The following tables summarize the amounts recognized with respect to our derivative financial instruments:



	Change in Value Recognized in OCI on Derivatives (Effective Portion)
	Three Months Ended March 31,
	2016		2015
Derivatives in cash flow hedging relationships:
Commodity derivatives	$	—	$	1
Total	$	—	$	1



	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
	Location of Gain/(Loss) Recognized in Income on Derivatives	Three Months Ended March 31,
		2016			2015
Derivatives in fair value hedging relationships (including hedged item):
Commodity derivatives	Cost of products sold	$	(4	)	$	(3	)
Total		$	(4	)	$	(3	)



	Location of Gain/(Loss) Recognized in Income on Derivatives	Amount of Gain/(Loss) Recognized in Income on Derivatives
	Location of Gain/(Loss) Recognized in Income on Derivatives	Three Months Ended March 31,
		2016			2015
Derivatives not designated as hedging instruments:
Commodity derivatives – Trading	Cost of products sold	$	(9	)	$	(2	)
Commodity derivatives – Non-trading	Cost of products sold	8			(8		)
Interest rate derivatives	Gains (losses) on interest rate derivatives	(70		)	(77		)
Embedded derivatives	Other, net	—			2
Total		$	(71	)	$	(85	)

- Definition

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

+ References

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-Paragraph 1
-Subparagraph (SX 210.4-08.(n))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

+ Details

Related Party Transactions	3 Months Ended
Related Party Transactions	Mar. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS The Parent Company has agreements with subsidiaries to provide or receive various management and general and administrative services. The Parent Company pays ETP to provide services on its behalf and on behalf of other subsidiaries of the Parent Company. The Parent Company receives management fees from certain of its subsidiaries, which include the reimbursement of various general and administrative services for expenses incurred by ETP on behalf of those subsidiaries. All such amounts have been eliminated in our consolidated financial statements. In the ordinary course of business, our subsidiaries have related party transactions between each other which are generally based on transactions made at market-related rates. Our consolidated revenues and expenses reflect the elimination of all material intercompany transactions. In addition, ETE recorded sales with affiliates of $81 million and $76 million during the three ended March 31, 2016 and 2015, respectively.

- Definition

The entire disclosure for related party transactions. 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 + Details

Reportable Segments

3 Months Ended

Mar. 31, 2016

Segment Reporting [Abstract]

Reportable Segments

REPORTABLE SEGMENTS

Our financial statements reflect the following reportable business segments:

•Investment in ETP, including the consolidated operations of ETP;

•Investment in Sunoco LP, including the consolidated operations of Sunoco LP;


•	Investment in Lake Charles LNG, including the operations of Lake Charles LNG; and


•	Corporate and Other, including the following:


•	activities of the Parent Company; and


•	the goodwill and property, plant and equipment fair value adjustments recorded as a result of the 2004 reverse acquisition of Heritage Propane Partners, L.P.

ETP completed its acquisition of Regency in April 2015; therefore, the Investment in ETP segment amounts have been retrospectively adjusted to reflect Regency for the periods presented.

The Investment in Sunoco LP segment reflects the results of Sunoco LP and the legacy Sunoco, Inc. retail business for the periods presented. ETE’s consolidated results reflect the elimination of Sunoco, LLC, Susser and the legacy Sunoco, Inc. retail business for the periods during which those entities were included in the consolidated results of both ETP and Sunoco LP. In addition, subsequent to July 2015, ETP holds an equity method investment in Sunoco, LLC, and a continuing investment in Sunoco LP the equity in earnings from which is also eliminated in ETE’s consolidated financial statements.

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

We define Segment Adjusted EBITDA as earnings before interest, taxes, depreciation, depletion, 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, losses on extinguishments of debt, gain on deconsolidation and other non-operating income or expense items. Unrealized gains and losses on commodity risk management activities include 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 unconsolidated affiliates based on the Partnership’s proportionate ownership and amounts for less than wholly owned subsidiaries based on 100% of the subsidiaries’ results of operations. Based on the change in our reportable segments we have recast the presentation of our segment results for the prior years to be consistent with the current year presentation.

The following tables present financial information by segment:



	Three Months Ended March 31,
	2016			2015
Segment Adjusted EBITDA:
Investment in ETP	$	1,412		$	1,366
Investment in Sunoco LP	159			128
Investment in Lake Charles LNG	44			49
Corporate and Other	(37		)	(23		)
Adjustments and Eliminations	—			(125		)
Total	1,578			1,395
Depreciation, depletion and amortization	(562		)	(493		)
Interest expense, net	(427		)	(371		)
Losses on interest rate derivatives	(70		)	(77		)
Non-cash unit-based compensation expense	(1		)	(23		)
Unrealized losses on commodity risk management activities	(60		)	(75		)
Inventory valuation adjustments	(13		)	(34		)
Equity in earnings of unconsolidated affiliates	61			57
Adjusted EBITDA related to unconsolidated affiliates	(219		)	(146		)
Other, net	(6		)	—
Income before income tax expense	$	281		$	233



	March 31, 2016			December 31, 2015
Assets:
Investment in ETP	$	64,315		$	65,173
Investment in Sunoco LP	8,803			8,842
Investment in Lake Charles LNG	1,405			1,369
Corporate and Other	656			638
Adjustments and Eliminations	(2,414		)	(4,833		)
Total assets	$	72,765		$	71,189



	Three Months Ended March 31,
	2016			2015
Revenues:
Investment in ETP:
Revenues from external customers	$	4,434		$	10,326
Intersegment revenues	47			—
	4,481			10,326
Investment in Sunoco LP:
Revenues from external customers	3,199			4,342
Intersegment revenues	3			—
	3,202			4,342
Investment in Lake Charles LNG:
Revenues from external customers	49			54

Adjustments and Eliminations	(50		)	(4,342		)
Total revenues	$	7,682		$	10,380

The following tables provide revenues, grouped by similar products and services, for our reportable segments. These amounts include intersegment revenues for transactions between ETP, Sunoco LP and Lake Charles LNG.

Investment in ETP



	Three Months Ended March 31,
	2016		2015
Intrastate Transportation and Storage	$	446	$	541
Interstate Transportation and Storage	254		271
Midstream	527		749
Liquids Transportation and Services	829		812
Investment in Sunoco Logistics	1,729		2,526
Retail Marketing	—		4,782
All Other	696		645
Total revenues	4,481		10,326
Less: Intersegment revenues	47		—
Revenues from external customers	$	4,434	$	10,326

Investment in Sunoco LP



	Three Months Ended March 31,
	2016		2015
Retail operations	$	1,675	$	1,888
Wholesale operations	1,527		2,454
Total revenues	3,202		4,342
Less: Intersegment revenues	3		—
Revenues from external customers	$	3,199	$	4,342

Investment in Lake Charles LNG

Lake Charles LNG’s revenues for all periods presented were related to LNG terminalling.

- 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 Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 34
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8981-108599

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e9038-108599

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 33
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8971-108599

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8595-108599

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8380-108599

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8933-108599

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 26
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8844-108599

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 35
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8984-108599

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e9031-108599

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e9054-108599

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
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-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8538-108599

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
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-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8864-108599

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8924-108599

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=51669610&loc=d3e8906-108599

+ Details

Supplemental Financial Statement Information

3 Months Ended

Mar. 31, 2016

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)



	March 31, 2016			December 31, 2015
ASSETS
Current assets:
Cash and cash equivalents	$	8		$	1
Accounts receivable from related companies	37			34
Other current assets	1			—
Total current assets	46			35
Property, plant and equipment, net	27			20
Advances to and investments in unconsolidated affiliates	5,106			5,764
Intangible assets, net	5			6
Goodwill	9			9
Other non-current assets, net	10			10
Total assets	$	5,203		$	5,844
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accounts payable to related companies	$	44		$	111
Interest payable	85			66
Accrued and other current liabilities	6			1
Total current liabilities	135			178
Long-term debt, less current maturities	6,439			6,332
Note payable to affiliate	315			265
Other non-current liabilities	—			1
Commitments and contingencies
Partners’ capital:
General Partner	(2		)	(2		)
Limited Partners:
Common Unitholders	(1,684		)	(952		)
Class D Units	—			22
Series A Convertible Preferred Units	—			—
Total partners’ capital	(1,686		)	(932		)
Total liabilities and partners’ capital	$	5,203		$	5,844

STATEMENTS OF OPERATIONS

(unaudited)



	Three Months Ended March 31,
	2016			2015
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES⁽¹⁾	$	(37	)	$	(28	)
OTHER INCOME (EXPENSE):
Interest expense, net	(81		)	(61		)
Equity in earnings of unconsolidated affiliates	430			373
Other, net	—			1
INCOME BEFORE INCOME TAXES	312			285
Income tax benefit	—			1
NET INCOME	312			284
General Partner’s interest in net income	1			1
Class D Unitholder’s interest in net income	—			1
Limited Partners’ interest in net income	$	311		$	282


⁽¹⁾	Includes management fees paid by ETE to ETP.

STATEMENTS OF CASH FLOWS

(unaudited)



	Three Months Ended March 31,
	2016			2015
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	$	223		$	198
CASH FLOWS FROM INVESTING ACTIVITIES:
Cash paid for Bakken Pipeline Transaction	—			(817		)
Contributions to unconsolidated affiliate	(65		)	—
Capital expenditures	(7		)	(5		)
Net cash used in investing activities	(72		)	(822		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings	105			1,692
Principal payments on debt	—			(865		)
Proceeds from affiliate	50			54
Distributions to partners	(299		)	(244		)
Debt issuance costs	—			(11		)
Net cash provided by (used in) financing activities	(144		)	626
INCREASE IN CASH AND CASH EQUIVALENTS	7			2
CASH AND CASH EQUIVALENTS, beginning of period	1			2
CASH AND CASH EQUIVALENTS, end of period	$	8		$	4

Operations And Organization Accounting policy (Policies)	3 Months Ended
	Mar. 31, 2016
Accounting Policies [Abstract]
Consolidation, Subsidiary Stock Issuances, Policy [Policy Text Block]	Subsidiary Common Unit Transactions The Parent Company accounts for the difference between the carrying amount of its investments in ETP and Sunoco LP and the underlying book value arising from the issuance or redemption of units by ETP or Sunoco LP (excluding transactions with the Parent Company) as capital transactions.
Use of Estimates, Policy [Policy Text Block]	Use of Estimates The unaudited consolidated financial statements have been prepared in conformity with GAAP, which includes the use of estimates and assumptions made by management that affect the reported amounts of assets, liabilities, revenues, expenses and disclosure of contingent assets and liabilities that exist at the date of the consolidated financial statements. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could be different from those estimates.
New Accounting Pronouncements, Policy [Policy Text Block]	Recent Accounting Pronouncements In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU 2014-09”), which clarifies the principles for recognizing revenue based on the core principle that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. In August 2015, the FASB deferred the effective date of ASU 2014-09, which is now effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. Early adoption is permitted as of annual reporting periods beginning after December 15, 2016, including interim reporting periods within those annual periods. ASU 2014-09 can be adopted either retrospectively to each prior reporting period presented or as a cumulative-effect adjustment as of the date of adoption. In March 2016, the FASB issued Accounting Standards Update No. 2016-08 to clarify the implementation guidance on principal versus agent considerations. In April 2016, the FASB issued Accounting Standards Update No. 2016-10 to clarify guidance related to identifying performance obligations and licensing implementation guidance contained in the new revenue recognition standard. The Partnership is currently evaluating the impact, if any, that adopting this new accounting standard will have on our revenue recognition policies. In February 2015, the FASB issued Accounting Standards Update No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis (“ASU 2015-02”), which changed the requirements for consolidations analysis. Under ASU 2015-02, reporting entities are required to evaluate whether they should consolidate certain legal entities. The Partnership adopted this standard on January 1, 2016, and the adoption did not impact the Partnership’s financial position or results of operations. In February 2016, the FASB issued Accounting Standards Update No. 2016-02, Leases (Topic 842) (“ASU 2016-02”), which establishes the principles that lessees and lessors shall apply to report useful information to users of financial statements about the amount, timing, and uncertainty of cash flows arising from a lease. ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. Early adoption is permitted. The Partnership is currently evaluating the impact that it will have on the consolidated financial statements and related disclosures. In March 2016, the FASB issued Accounting Standards Update No. 2016-09, Stock compensation (Topic 718) (“ASU 2016-09”). The objective of the update is to reduce complexity in accounting standards. The areas for simplification in this update involve several aspects of the accounting for employee share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. In addition, the amendments in this update eliminate the guidance in Topic 718 that was indefinitely deferred shortly after the issuance of FASB Statement No. 123 (revised 2004), Share-Based Payment. ASU 2016-09 is effective for fiscal years beginning after December 15, 2016, and interim periods within those annual periods. Early adoption is permitted. The Partnership is currently evaluating the impact that it will have on the consolidated financial statements and related disclosures.
Excise Tax, Policy [Policy Text Block]

Cash And Cash Equivalents (Tables)

3 Months Ended

Mar. 31, 2016

Supplemental Cash Flow Information [Abstract]

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

Non-cash investing activities were as follows:



	Three Months Ended March 31,
	2016			2015
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures	$	829		$	658
Net losses from subsidiary common unit issuances	(12		)	—

Inventories (Tables)

3 Months Ended

Mar. 31, 2016

Inventory, Net [Abstract]

Schedule Of Inventory

Inventories consisted of the following:



	March 31, 2016		December 31, 2015
Natural gas and NGLs	$	331	$	415
Crude oil	453		424
Refined products	342		420
Other	373		377
Total inventories	$	1,499	$	1,636

Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2016

Fair Value Measurements [Abstract]

Fair Value Of Financial Assets And Liabilities Measured On Recurring Basis



	Fair Value Measurements at March 31, 2016
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Interest rate derivatives	$	25		$	—		$	25		$	—
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	6			6			—			—
Swing Swaps IFERC	1			—			1			—
Fixed Swaps/Futures	67			67			—			—
Forward Physical Swaps	3			—			3			—
Power:
Forwards	22			—			22			—
Futures	1			1			—			—
Options — Calls	2			2			—			—
Natural Gas Liquids – Forwards/Swaps	34			34			—			—
Refined Products — Futures	6			6			—			—
Crude – Futures	12			12			—			—
Total commodity derivatives	154			128			26			—
Total assets	$	179		$	128		$	51		$	—
Liabilities:
Interest rate derivatives	$	(267	)	$	—		$	(267	)	$	—
Embedded derivatives in the ETP Preferred Units	(5		)	—			—			(5		)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(9		)	(9		)	—			—
Swing Swaps IFERC	(2		)	(1		)	(1		)	—
Fixed Swaps/Futures	(50		)	(50		)	—			—
Power:
Forwards	(26		)	—			(26		)	—
Futures	(1		)	(1		)	—			—
Natural Gas Liquids – Forwards/Swaps	(33		)	(33		)	—			—
Refined Products — Futures	(4		)	(4		)	—			—
Crude — Futures	(5		)	(5		)	—			—
Total commodity derivatives	(130		)	(103		)	(27		)	—
Total liabilities	$	(402	)	$	(103	)	$	(294	)	$	(5	)



	Fair Value Measurements at December 31, 2015
	Fair Value Total			Level 1			Level 2			Level 3
Assets:
Natural Gas:
Basis Swaps IFERC/NYMEX	16			16			—			—
Swing Swaps IFERC	10			2			8			—
Fixed Swaps/Futures	274			274			—			—
Forward Physical Contracts	4			—			4			—
Power:
Forwards	22			—			22			—
Futures	3			3			—			—
Options — Calls	1			1			—			—
Options — Puts	1			1			—			—
Natural Gas Liquids — Forwards/Swaps	99			99			—			—
Refined Products — Futures	15			15			—			—
Crude - Futures	9			9			—			—
Total commodity derivatives	454			420			34			—
Total assets	$	454		$	420		$	34		$	—
Liabilities:
Interest rate derivatives	$	(171	)	$	—		$	(171	)	$	—
Embedded derivatives in the ETP Preferred Units	(5		)	—			—			(5		)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(16		)	(16		)	—			—
Swing Swaps IFERC	(12		)	(2		)	(10		)	—
Fixed Swaps/Futures	(203		)	(203		)	—			—
Power:
Forwards	(22		)	—			(22		)	—
Futures	(2		)	(2		)	—			—
Options — Calls	(1		)	(1		)	—			—
Natural Gas Liquids — Forwards/Swaps	(89		)	(89		)	—			—
Refined Products — Futures	(6		)	(6		)	—			—
Crude - Futures	(5		)	(5		)	—			—
Total commodity derivatives	(356		)	(324		)	(32		)	—
Total liabilities	$	(532	)	$	(324	)	$	(203	)	$	(5	)

Reconciliation For Liabilities Measured At Fair Value On A Recurring Basis



Balance, December 31, 2015	$	(5	)
Net unrealized gains included in other income (expense)	—
Balance, March 31, 2016	$	(5	)

Net Income per Limited Partner Unit (Tables)

3 Months Ended

Mar. 31, 2016

Earnings Per Share [Abstract]

Reconciliation Of Net Income And Weighted Average Units

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



	Three Months Ended March 31,
	2016		2015
Net Income	$	336	$	221
Less: Income (loss) attributable to noncontrolling interest	24		(63		)
Net Income, net of noncontrolling interest	312		284
Less: General Partner’s interest in income	1		1
Less: Class D Unitholder’s interest in income	—		1
Income available to Limited Partners	$	311	$	282
Basic Income per Limited Partner Unit:
Weighted average limited partner units	1,044.8		1,077.6
Basic income per Limited Partner unit	$	0.30	$	0.26
Diluted Income per Limited Partner Unit:
Income available to Limited Partners	$	311	$	282
Dilutive effect of equity-based compensation of subsidiaries and distributions to Class D Unitholder	—		(1		)
Diluted income available to Limited Partners	$	311	$	281
Weighted average limited partner units	1,044.8		1,077.6
Dilutive effect of unconverted unit awards	—		1.4
Diluted weighted average limited partner units	1,044.8		1,079.0
Diluted income per Limited Partner unit	$	0.30	$	0.26

Equity (Tables)

3 Months Ended

Mar. 31, 2016

Schedule of Net IDR Subsidies [Table Text Block]

ETE has agreed to relinquish its right to the following amounts of incentive distributions in future periods, including distributions on ETP Class I Units.



	Total Year
2016 (remainder)	$	103
2017	128
2018	105
2019	95

Change In ETE Common Units

The changes in ETE common units and Convertible Units during the three months ended March 31, 2016 were as follows:



	Number of Convertible Units	Number of Common Units
Outstanding at December 31, 2015	—	1,044.8
Issue Series A Convertible Preferred Units	329.3	—
Outstanding at March 31, 2016	329.3	1,044.8

Accumulated Other Comprehensive Income

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



	March 31, 2016			December 31, 2015
Available-for-sale securities	$	2		$	—
Foreign currency translation adjustment	(5		)	(4		)
Net loss on interest rate derivatives	(6		)	—
Actuarial loss related to pensions and other postretirement benefits	(1		)	8
Subtotal	(10		)	4
Amounts attributable to noncontrolling interest	10			(4		)
Total AOCI, net of tax	$	—		$	—

Parent Company [Member]

Distributions Made to Limited Partner, by Distribution [Table Text Block]

Following are distributions declared and/or paid by us subsequent to December 31, 2015:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2015	February 4, 2016	February 19, 2016	$	0.2850
March 31, 2016	May 6, 2016	May 19, 2016	0.2850

ETP [Member]

Distributions Made to Limited Partner, by Distribution [Table Text Block]

Following are distributions declared and/or paid by ETP subsequent to December 31, 2015:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2015	February 8, 2016	February 16, 2016	$	1.0550
March 31, 2016	May 6, 2016	May 16, 2016	1.0550

Sunoco Logistics [Member]

Distributions Made to Limited Partner, by Distribution [Table Text Block]

Following are distributions declared and/or paid by Sunoco Logistics subsequent to December 31, 2015:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2015	February 8, 2016	February 12, 2016	$	0.4790
March 31, 2016	May 9, 2016	May 13, 2016	0.4890

Sunoco LP [Member]

Distributions Made to Limited Partner, by Distribution [Table Text Block]

Following are distributions declared and/or paid by Sunoco LP subsequent to December 31, 2015:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2015	February 5, 2016	February 16, 2016	$	0.8013
March 31, 2016	May 6, 2016	May 16, 2016	0.8173

- Definition

The entire disclosure for comprehensive income, which includes, but is not limited to, 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.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e689-108580

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=36458714&loc=SL7669619-108580

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
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-Section 45
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-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e640-108580

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
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-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e716-108580

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 16
-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e709-108580

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
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-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
-URI http://asc.fasb.org/extlink&oid=27012166&loc=d3e187085-122770

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
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-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e637-108580

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
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-Paragraph 14
-URI http://asc.fasb.org/extlink&oid=36458714&loc=d3e681-108580

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

+ Details

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

3 Months Ended

Mar. 31, 2016

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

Schedule of Rent Expense [Table Text Block]



	Three Months Ended March 31,
	2016			2015
Rental expense⁽¹⁾	$	51		$	52
Less: Sublease rental income	(7		)	(8		)
Rental expense, net	$	44		$	44


⁽¹⁾	Includes contingent rentals totaling

Environmental Exit Costs by Cost



	March 31, 2016		December 31, 2015
Current	$	40	$	42
Non-current	293		326
Total environmental liabilities	$	333	$	368

Derivative Assets And Liabilities (Tables)

3 Months Ended

Mar. 31, 2016

Outstanding Commodity-Related Derivatives

The following table details our outstanding commodity-related derivatives:



	March 31, 2016			December 31, 2015
	Notional Volume		Maturity	Notional Volume		Maturity
Mark-to-Market Derivatives
(Trading)
Natural Gas (MMBtu):
Fixed Swaps/Futures	1,712,500		2016-2017	(602,500	)	2016-2017
Basis Swaps IFERC/NYMEX ⁽¹⁾	63,825,000		2016-2017	(31,240,000	)	2016-2017
Power (Megawatt):
Forwards	(344,954	)	2016-2017	357,092		2016-2017
Futures	2,675,597		2016-2017	(109,791	)	2016
Options — Puts	(227,600	)	2016	260,534		2016
Options — Calls	1,011,600		2016	1,300,647		2016
Crude (Bbls):
Futures	(616,000	)	2016-2017	(591,000	)	2016-2017
Options — Puts	(300,000	)	2016	—		—
Options — Calls	300,000		2016	—		—
(Non-Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX	(9,175,000	)	2016-2017	(6,522,500	)	2016-2017
Swing Swaps IFERC	105,170,000		2016-2017	71,340,000		2016-2017
Fixed Swaps/Futures	(6,862,500	)	2016-2018	(14,380,000	)	2016-2018
Forward Physical Contracts	26,156,570		2016-2017	21,922,484		2016-2017
Natural Gas Liquid and Crude (Bbls) — Forwards/Swaps	(6,273,000	)	2016	(8,146,800	)	2016-2018
Refined Products (Bbls) — Futures	(2,846,000	)	2016-2017	(1,289,000	)	2016-2017
Corn (Bushels) — Futures	122,000		2016	1,185,000		2016
Fair Value Hedging Derivatives
(Non-Trading)
Natural Gas (MMBtu):
Basis Swaps IFERC/NYMEX	(23,215,000	)	2016	(37,555,000	)	2016
Fixed Swaps/Futures	(23,215,000	)	2016	(37,555,000	)	2016
Hedged Item — Inventory	23,215,000		2016	37,555,000		2016


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

Interest Rate Swaps Outstanding

The following table summarizes our interest rate swaps outstanding none of which were designated as hedges for accounting purposes:



		Notional Amount Outstanding
Term	Type⁽¹⁾	March 31, 2016		December 31, 2015
July 2016⁽²⁾	Forward-starting to pay a fixed rate of 3.80% and receive a floating rate	$	200	$	200
July 2017⁽³⁾	Forward-starting to pay a fixed rate of 3.84% and receive a floating rate	300		300
July 2018⁽³⁾	Forward-starting to pay a fixed rate of 4.00% and receive a floating rate	200		200
December 2018	Pay a floating rate based on a 3-month LIBOR and receive a fixed rate of 1.53%	1,200		1,200
March 2019	Pay a floating rate based on a 3-month LIBOR and receive a fixed rate of 1.42%	300		300
July 2019⁽³⁾	Forward-starting to pay a fixed rate of 3.25% and receive a floating rate	200		200


⁽¹⁾	Floating rates are based on 3-month LIBOR.


⁽²⁾	Represents the effective date. These forward-starting swaps have a term of 10 and 30 years with a mandatory termination date the same as the effective date.


⁽³⁾	Represents the effective date. These forward-starting swaps have terms of 30 years with a mandatory termination date the same as the effective date.

Fair Value Of Derivative Instruments

The following table provides a summary of our derivative assets and liabilities:



	Fair Value of Derivative Instruments
	Asset Derivatives				Liability Derivatives
	March 31, 2016		December 31, 2015		March 31, 2016			December 31, 2015
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	4	$	38	$	—		$	(3	)
	4		38		—			(3		)
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	$	115	$	353	$	(98	)	$	(306	)
Commodity derivatives	35		63		(32		)	(47		)
Interest rate derivatives	25		—		(267		)	(171		)
Embedded derivatives in the ETP Preferred Units	—		—		(5		)	(5		)
	175		416		(402		)	(529		)
Total derivatives	$	179	$	454	$	(402	)	$	(532	)

Derivatives, Offsetting Fair Value Amounts [Table Text Block]



		Asset Derivatives						Liability Derivatives
	Balance Sheet Location	March 31, 2016			December 31, 2015			March 31, 2016			December 31, 2015
Derivatives without offsetting agreements	Derivative assets (liabilities)	$	25		$	—		$	(272	)	$	(176	)
Derivatives in offsetting agreements:
OTC contracts	Derivative assets (liabilities)	35			63			(32		)	(47		)
Broker cleared derivative contracts	Other current assets	119			391			(98		)	(309		)
Total gross derivatives		179			454			(402		)	(532		)
Less offsetting agreements:
Counterparty netting	Derivative assets (liabilities)	(17		)	(17		)	17			17
Payments on margin deposit	Other current assets	(98		)	(309		)	98			309
Total net derivatives		$	64		$	128		$	(287	)	$	(206	)

Partnership's Derivative Assets And Liabilities Recognized OCI On Derivatives

The following tables summarize the amounts recognized with respect to our derivative financial instruments:



	Change in Value Recognized in OCI on Derivatives (Effective Portion)
	Three Months Ended March 31,
	2016		2015
Derivatives in cash flow hedging relationships:
Commodity derivatives	$	—	$	1
Total	$	—	$	1

Schedule of Cash Flow Hedging Instruments, Statements of Financial Performance and Financial Position, Location [Table Text Block]



	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
	Location of Gain/(Loss) Recognized in Income on Derivatives	Three Months Ended March 31,
		2016			2015
Derivatives in fair value hedging relationships (including hedged item):
Commodity derivatives	Cost of products sold	$	(4	)	$	(3	)
Total		$	(4	)	$	(3	)

Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location [Table Text Block]



	Location of Gain/(Loss) Recognized in Income on Derivatives	Amount of Gain/(Loss) Recognized in Income on Derivatives
	Location of Gain/(Loss) Recognized in Income on Derivatives	Three Months Ended March 31,
		2016			2015
Derivatives not designated as hedging instruments:
Commodity derivatives – Trading	Cost of products sold	$	(9	)	$	(2	)
Commodity derivatives – Non-trading	Cost of products sold	8			(8		)
Interest rate derivatives	Gains (losses) on interest rate derivatives	(70		)	(77		)
Embedded derivatives	Other, net	—			2
Total		$	(71	)	$	(85	)

- 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 5
-URI http://asc.fasb.org/extlink&oid=56946850&loc=d3e41641-113959

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=56946850&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 8
-URI http://asc.fasb.org/extlink&oid=56946850&loc=d3e41678-113959

Reference 4: 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=56946850&loc=d3e41638-113959

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-Name Accounting Standards Codification
-Topic 815
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-Section 50
-Paragraph 1B
-URI http://asc.fasb.org/extlink&oid=56946850&loc=SL5580258-113959

Reference 6: 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=56946850&loc=SL5579245-113959

Reference 7: 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=56946850&loc=SL5624171-113959

Reference 8: 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

Reference 9: 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=56946850&loc=SL5579240-113959

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=56946850&loc=d3e41620-113959

Reference 11: 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=26873400&loc=d3e23780-122690

+ Details

Reportable Segments (Tables)

3 Months Ended

Mar. 31, 2016

Operating Segments [Member]

Financial Information By Segment



	Three Months Ended March 31,
	2016			2015
Segment Adjusted EBITDA:
Investment in ETP	$	1,412		$	1,366
Investment in Sunoco LP	159			128
Investment in Lake Charles LNG	44			49
Corporate and Other	(37		)	(23		)
Adjustments and Eliminations	—			(125		)
Total	1,578			1,395
Depreciation, depletion and amortization	(562		)	(493		)
Interest expense, net	(427		)	(371		)
Losses on interest rate derivatives	(70		)	(77		)
Non-cash unit-based compensation expense	(1		)	(23		)
Unrealized losses on commodity risk management activities	(60		)	(75		)
Inventory valuation adjustments	(13		)	(34		)
Equity in earnings of unconsolidated affiliates	61			57
Adjusted EBITDA related to unconsolidated affiliates	(219		)	(146		)
Other, net	(6		)	—
Income before income tax expense	$	281		$	233

Assets Segments [Member]

Financial Information By Segment



	March 31, 2016			December 31, 2015
Assets:
Investment in ETP	$	64,315		$	65,173
Investment in Sunoco LP	8,803			8,842
Investment in Lake Charles LNG	1,405			1,369
Corporate and Other	656			638
Adjustments and Eliminations	(2,414		)	(4,833		)
Total assets	$	72,765		$	71,189

Sales Revenue, Segment [Member]

Financial Information By Segment



	Three Months Ended March 31,
	2016			2015
Revenues:
Investment in ETP:
Revenues from external customers	$	4,434		$	10,326
Intersegment revenues	47			—
	4,481			10,326
Investment in Sunoco LP:
Revenues from external customers	3,199			4,342
Intersegment revenues	3			—
	3,202			4,342
Investment in Lake Charles LNG:
Revenues from external customers	49			54

Adjustments and Eliminations	(50		)	(4,342		)
Total revenues	$	7,682		$	10,380

Investment In ETP [Member]

Revenue from External Customers by Products and Services [Table Text Block]

Investment in ETP



	Three Months Ended March 31,
	2016		2015
Intrastate Transportation and Storage	$	446	$	541
Interstate Transportation and Storage	254		271
Midstream	527		749
Liquids Transportation and Services	829		812
Investment in Sunoco Logistics	1,729		2,526
Retail Marketing	—		4,782
All Other	696		645
Total revenues	4,481		10,326
Less: Intersegment revenues	47		—
Revenues from external customers	$	4,434	$	10,326

Investment In Sunoco LP [Member]

Revenue from External Customers by Products and Services [Table Text Block]

Investment in Sunoco LP



	Three Months Ended March 31,
	2016		2015
Retail operations	$	1,675	$	1,888
Wholesale operations	1,527		2,454
Total revenues	3,202		4,342
Less: Intersegment revenues	3		—
Revenues from external customers	$	3,199	$	4,342

Supplemental Financial Statement Information (Tables)

3 Months Ended

Mar. 31, 2016

Parent [Member]

Schedule Of Balance Sheets

BALANCE SHEETS

(unaudited)



	March 31, 2016			December 31, 2015
ASSETS
Current assets:
Cash and cash equivalents	$	8		$	1
Accounts receivable from related companies	37			34
Other current assets	1			—
Total current assets	46			35
Property, plant and equipment, net	27			20
Advances to and investments in unconsolidated affiliates	5,106			5,764
Intangible assets, net	5			6
Goodwill	9			9
Other non-current assets, net	10			10
Total assets	$	5,203		$	5,844
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accounts payable to related companies	$	44		$	111
Interest payable	85			66
Accrued and other current liabilities	6			1
Total current liabilities	135			178
Long-term debt, less current maturities	6,439			6,332
Note payable to affiliate	315			265
Other non-current liabilities	—			1
Commitments and contingencies
Partners’ capital:
General Partner	(2		)	(2		)
Limited Partners:
Common Unitholders	(1,684		)	(952		)
Class D Units	—			22
Series A Convertible Preferred Units	—			—
Total partners’ capital	(1,686		)	(932		)
Total liabilities and partners’ capital	$	5,203		$	5,844

Schedule Of Statements Of Operations

STATEMENTS OF OPERATIONS

(unaudited)



	Three Months Ended March 31,
	2016			2015
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES⁽¹⁾	$	(37	)	$	(28	)
OTHER INCOME (EXPENSE):
Interest expense, net	(81		)	(61		)
Equity in earnings of unconsolidated affiliates	430			373
Other, net	—			1
INCOME BEFORE INCOME TAXES	312			285
Income tax benefit	—			1
NET INCOME	312			284
General Partner’s interest in net income	1			1
Class D Unitholder’s interest in net income	—			1
Limited Partners’ interest in net income	$	311		$	282


⁽¹⁾	Includes management fees paid by ETE to ETP.

Parent Company [Member]

Schedule Of Statements Of Cash Flows

STATEMENTS OF CASH FLOWS

(unaudited)



	Three Months Ended March 31,
	2016			2015
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	$	223		$	198
CASH FLOWS FROM INVESTING ACTIVITIES:
Cash paid for Bakken Pipeline Transaction	—			(817		)
Contributions to unconsolidated affiliate	(65		)	—
Capital expenditures	(7		)	(5		)
Net cash used in investing activities	(72		)	(822		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings	105			1,692
Principal payments on debt	—			(865		)
Proceeds from affiliate	50			54
Distributions to partners	(299		)	(244		)
Debt issuance costs	—			(11		)
Net cash provided by (used in) financing activities	(144		)	626
INCREASE IN CASH AND CASH EQUIVALENTS	7			2
CASH AND CASH EQUIVALENTS, beginning of period	1			2
CASH AND CASH EQUIVALENTS, end of period	$	8		$	4

Operations And Organization Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Operations [Abstract]
Excise Taxes Collected	$ 311	$ 317

Acquisitions Narrative (Details)	1 Months Ended
Acquisitions Narrative (Details)	Mar. 31, 2016 USD ($) $ / shares shares
Sunoco, LLC [Member] \| Dropdown of Sunoco LLC Interest [Member]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	68.42%
Legacy Sunoco, Inc. [Member] \| Dropdown of Sunoco LLC Interest [Member]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	100.00%
Sunoco LP [Member] \| Dropdown of Sunoco LLC Interest [Member]
Business Combination, Consideration Transferred \| $	$ 2,230,000,000
Payments to Acquire Businesses, Gross \| $	$ 2,200,000,000
Sale of Stock, Number of Shares Issued in Transaction \| shares	5,700,000
Equity and Cash Option [Member] \| Proposed WMB Merger [Member]
Proposed Business Combination, Cash Consideration, Per Share \| $ / shares	$ 8.00
Business Acquisition, Number Of Share Received In Exchange Of Each Share \| shares	1.5274
Equity Option [Member] \| Proposed WMB Merger [Member]
Business Acquisition, Number Of Share Received In Exchange Of Each Share \| shares	1.8716
Cash Option [Member] \| Proposed WMB Merger [Member]
Proposed Business Combination, Cash Consideration \| $	$ 43.50

Cash And Cash Equivalents Non-Cash Activities (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures	$ 829	$ 658
Net losses from subsidiary common unit issuances	$ (12)	$ 0

Inventories Table - Inventory Balances (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Inventory, Net [Abstract]
Natural gas and NGLs	$ 331	$ 415
Crude oil	453	424
Refined products	342	420
Other	373	377
Total inventories	$ 1,499	$ 1,636

Fair Value Measurements Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Fair Value Measurements [Abstract]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net	$ 0
Debt obligations, fair value	35,610	$ 33,220
Long-term Debt	$ 38,330	$ 36,970

Fair Value Measurements Table - Reconciliation of Level 3 Derivatives (Details) $ in Millions	3 Months Ended
	Mar. 31, 2016 USD ($)
Net unrealized gains included in other income (expense)	$ 0
Level 3 \| Fair Value, Measurements, Recurring [Member]
Balance, December 31, 2015	(5)
Balance, March 31, 2016	$ (5)

Net Income per Limited Partner Unit Table - Income Reconciliation (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Reconciliation of income from continuing operations to income from continuing operations available to limited partners [Line Items]
Net Income	$ 336	$ 221
Less: Income (loss) attributable to noncontrolling interest	24	(63)
Net Income, net of noncontrolling interest	312	284
Less: General Partner’s interest in income	1	1
Less: Class D Unitholder’s interest in income	0	1
Income available to Limited Partners	$ 311	$ 282
Basic Income from Continuing Operations per Limited Partner Unit:
Weighted average limited partner units	1,044.8	1,077.6
Basic income per Limited Partner unit	$ 0.30	$ 0.26
Diluted Income from Continuing Operations per Limited Partner Unit:
Dilutive effect of equity-based compensation of subsidiaries and distributions to Class D Unitholder	$ 0	$ 1
Diluted income available to Limited Partners	$ 311	$ 281
Dilutive effect of unconverted unit awards	0.0	1.4
Diluted weighted average limited partner units	1,044.8	1,079.0
Diluted income per Limited Partner unit	$ 0.30	$ 0.26

Debt Obligations Narrative (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Apr. 30, 2016	Mar. 31, 2016	Mar. 31, 2015
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt		$ 5,750	$ 8,731
Parent Company [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt		105	$ 1,692
ETE Senior Secured Revolving Credit Facilities [Member] \| Parent Company [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity		1,500
Line of Credit Facility, Amount Outstanding		965
Line of Credit Facility, Remaining Borrowing Capacity		535
Term loan due 2019 [Member] \| Sunoco LP [Member]
Debt Instrument [Line Items]
Senior Notes		2,040
6.25% Senior Notes due 2021 [Member] \| Sunoco LP [Member]
Debt Instrument [Line Items]
Senior Notes		$ 800
Debt Instrument, Interest Rate, Stated Percentage		6.25%
ETP Revolving Credit Facility, due October 2017 [Member] \| ETP [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity		$ 3,750
Line of Credit Facility, Amount Outstanding		4
Sunoco Logistics' $2.5 billion revolving credit facility due March 2020 [Member] \| Sunoco Logistics [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity		2,500
Line of Credit Facility, Amount Outstanding		942
Line of Credit Facility, Maximum Borrowing Capacity		3,250
Sunoco LP $1.5 Billion Revolving Credit Facility Due September 2019 [Member] \| Sunoco LP [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity		1,500
Line Of Credit Facility, Additional Borrowing Capacity Subject To Lender Approval		250
Line of Credit Facility, Amount Outstanding		$ 675
Subsequent Event [Member] \| 6.25% Senior Notes due 2021 [Member] \| Sunoco LP [Member]
Debt Instrument [Line Items]
Senior Notes	$ 800
Debt Instrument, Interest Rate, Stated Percentage	6.25%
Proceeds from Issuance of Long-term Debt	$ 789

Equity Narrative (Details) - USD ($)	1 Months Ended	3 Months Ended
Equity Narrative (Details) - USD ($)	Mar. 31, 2016	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015
Net losses from subsidiary common unit issuances		$ (12,000,000)		$ 0
Stock Issued During Period, Value, Dividend Reinvestment Plan		$ 39,000,000
Stock Issued During Period, Shares, Dividend Reinvestment Plan		1,800,000
Common Units Remaining Available to be Issued Under Distribution Reinvestment Plan	9,700,000	9,700,000
Stock Issued During Period, Shares, New Issues		0
Ratio of Convertible Units to Common Units	31.50%	31.50%
Convertible Unit Distribution to ETE Common Unit Distribution, Percent	40.00%	40.00%
Conversion Price of Preferred Units	$ 6.56	$ 6.56
Stock Repurchase Program, Remaining Authorized Repurchase Amount	936,000,000	$ 936,000,000
Parent Company [Member]
Rate		$ 0.2850	$ 0.2850
ETP [Member]
Equity Distribution Agreement Program, Capacity Remaining, Dollar Amount	0	$ 0
Rate		$ 1.0550	1.0550
Sunoco Logistics [Member]
Rate		$ 0.4890	0.4790
Sunoco LP [Member]
Stock Issued During Period, Shares, New Issues		2,300,000
Rate		$ 0.8173	$ 0.8013
Kelcy L. Warren [Member] \| ETE [Member]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		18.00%
Equity distribution agreement [Member] \| ETP [Member]
Proceeds from Issuance of Common Stock, net		$ 324,000,000
Fees and Commissions		3,000,000
Equity distribution agreement [Member] \| Sunoco Logistics [Member]
Proceeds from Issuance of Common Limited Partners Units		301,000,000
Fees and Commissions		$ 3,000,000
Messrs. McReynolds, Ramsey and McCrea [Member] \| ETE [Member]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		2.20%
Mr. Ray Davis [Member] \| ETE [Member]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		6.90%
Mr. Ray Davis [Member] \| LE GP, LLC [Member]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		18.80%
Common Unitholders
Net losses from subsidiary common unit issuances		$ (12,000,000)
Convertible Preferred Stock [Member]
Stock Issued During Period, Shares, New Issues		329,299,267
Distribution Made to Limited Partner, Distributions Declared, Per Unit		$ 0.11
Convertible Preferred Stock [Member] \| Kelcy L. Warren [Member]
Stock Issued During Period, Shares, New Issues		187,313,942
Convertible Preferred Stock [Member] \| Mr. McReynolds [Member]
Stock Issued During Period, Shares, New Issues		21,382,155
Convertible Preferred Stock [Member] \| Mr. Ramsey [Member]
Stock Issued During Period, Shares, New Issues		51,317
Convertible Preferred Stock [Member] \| Mr. McCrea [Member]
Stock Issued During Period, Shares, New Issues		1,112,728
Convertible Preferred Stock [Member] \| Mr. Ray Davis [Member]
Stock Issued During Period, Shares, New Issues		72,042,486
Class C Units [Member] \| Sunoco LP [Member]
Stock Issued During Period, Shares, New Issues		16,400,000
Class C Units [Member] \| Aloha Contribution [Member] \| Sunoco LP [Member]
Stock Issued During Period, Shares, New Issues		5,200,000
Class C Units [Member] \| Class A Unit Exchange [Member] \| Sunoco LP [Member]
Stock Issued During Period, Shares, New Issues		11,200,000
Dropdown of Sunoco LLC Interest [Member] \| Sunoco LP [Member]
Business Combination, Consideration Transferred	2,230,000,000
Payments to Acquire Businesses, Gross	$ 2,200,000,000
Sale of Stock, Number of Shares Issued in Transaction	5,700,000
Dropdown of Sunoco LLC Interest [Member] \| Sunoco, LLC [Member]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	68.42%
Dropdown of Sunoco LLC Interest [Member] \| Legacy Sunoco, Inc. [Member]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	100.00%

Equity Table - Change In ETE Common Units (Details)	3 Months Ended
Equity Table - Change In ETE Common Units (Details)	Mar. 31, 2016 shares
Class of Stock [Line Items]
Outstanding at December 31, 2015	1,044,800,000
Stock Issued During Period, Shares, New Issues	0
Outstanding at March 31, 2016	1,044,800,000
Convertible Preferred Stock [Member]
Class of Stock [Line Items]
Outstanding at December 31, 2015	0
Stock Issued During Period, Shares, New Issues	329,299,267
Outstanding at March 31, 2016	329,300,000

Equity Table - Quarterly Distributions of Available Cash (Details) - $ / shares	3 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Sunoco Logistics [Member]
Record Date	May 09, 2016	Feb. 08, 2016
Payment Date	May 13, 2016	Feb. 12, 2016
Rate	$ 0.4890	$ 0.4790
Parent Company [Member]
Record Date	May 06, 2016	Feb. 04, 2016
Payment Date	May 19, 2016	Feb. 19, 2016
Rate	$ 0.2850	$ 0.2850
ETP [Member]
Record Date	May 06, 2016	Feb. 08, 2016
Payment Date	May 16, 2016	Feb. 16, 2016
Rate	$ 1.0550	$ 1.0550
Sunoco LP [Member]
Record Date	May 06, 2016	Feb. 05, 2016
Payment Date	May 16, 2016	Feb. 16, 2016
Rate	$ 0.8173	$ 0.8013

Equity Table - IDR Schedule (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Subsequent Event [Member]
Relinquishment of Incentive Distributions	$ 103	$ 95	$ 105	$ 128

Equity Table - Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Partners' Capital Notes [Abstract]
Available-for-sale securities	$ 2	$ 0
Foreign currency translation adjustment	(5)	(4)
Net loss on interest rate derivatives	(6)	0
Actuarial loss related to pensions and other postretirement benefits	(1)	8
Subtotal	(10)	4
Amounts attributable to noncontrolling interest	10	(4)
Accumulated other comprehensive income, net	$ 0	$ 0

- 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 + Details

Income Taxes (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
Income Taxes (Details) - USD ($) $ in Millions	Mar. 31, 2016	Mar. 31, 2016
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount		$ 9
Sunoco, LLC [Member] \| Dropdown of Sunoco LLC Interest [Member]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	68.42%
Legacy Sunoco, Inc. [Member] \| Dropdown of Sunoco LLC Interest [Member]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	100.00%

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Narrative (Details)	1 Months Ended	3 Months Ended
	Jan. 31, 2012 USD ($)	Mar. 31, 2016 USD ($) sites	Mar. 31, 2015 USD ($)	Dec. 31, 2015 USD ($)
Lease Expiration Date		Dec. 31, 2058
Operating Leases, Rent Expense, Contingent Rentals		$ 16,000,000	$ 4,000,000
Loss Contingency Accrual, at Carrying Value		59,000,000		$ 40,000,000
Amounts recorded in balance sheets for contingencies and current litigation not disclosed		0
Payments for Environmental Liabilities		$ 8,000,000	$ 7,000,000
Site Contingency, Number of Sites Needing Remediation \| sites		19
Environmental Costs Recognized, Recovery Credited to Expense		$ 19,000,000
Accrual for Environmental Loss Contingencies		333,000,000		$ 368,000,000
Proposed Environmental Penalty		200,000
Supplemental Environmental Project [Member]
Proposed Environmental Penalty		21,000
Compensatory Damages [Member]
Gain Contingency, Unrecorded Amount		319,000,000
Disgorgement [Member]
Gain Contingency, Unrecorded Amount		595,000,000
Expense Reimbursement [Member]
Gain Contingency, Unrecorded Amount		1,000,000
Final Judgement [Member]
Gain Contingency, Unrecorded Amount		536,000,000
New Mexico Environmental Department [Member]
Accrual for Environmental Loss Contingencies		250,000
Texas Commission on Environmental Quality [Member]
Accrual for Environmental Loss Contingencies		300,000
TCEQ [Member]
Proposed Environmental Penalty		$ 21,000
AmeriGas [Member]
Contingent Residual Support Agreement, Amount	$ 1,550,000,000
Sunoco LP [Member] \| 6.375% Senior Notes due April 2023 [Member]
Debt Instrument, Interest Rate, Stated Percentage		6.375%
Senior Notes		$ 800,000,000
Sunoco LP [Member] \| 6.25% Senior Notes due 2021 [Member]
Debt Instrument, Interest Rate, Stated Percentage		6.25%
Senior Notes		$ 800,000,000
Sunoco LP [Member] \| Term loan due 2019 [Member]
Senior Notes		$ 2,040,000,000
Sunoco, Inc. [Member]
Loss Contingency, Pending Claims, Number		5
Sunoco, Inc. [Member] \| Multidistrict Legislation [Member]
Loss Contingency, Pending Claims, Number		4
Southern Union [Member]
Percentage Of Recovery		50.00%
Loss Contingency, Estimated Recovery from Third Party		150000
Sunoco [Member]
Site Contingency, Number of Sites Needing Remediation		48
PHMSA [Member]
Proposed Environmental Penalty		$ 100,000

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Table - Accrued Environmental Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Environmental Exit Cost [Line Items]
Current	$ 40	$ 42
Non-current	293	326
Total environmental liabilities	$ 333	$ 368

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Rent expense table (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Rental expense(1)	$ 51	$ 52
Less: Sublease rental income	(7)	(8)
Rental expense, net	$ 44	$ 44

Derivative Assets And Liabilities Table - Interest Rate Swaps Outstanding (Details) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2016

Dec. 31, 2015

July 2016 [Member]

Notional Amount

^[1]

$ 200

Type

^[1],[2]

Forward-starting to pay a fixed rate of 3.80% and receive a floating rate

July 2017 [Member]

Notional Amount

^[3]

$ 300

300

Type

^[2],[3]

Forward-starting to pay a fixed rate of 3.84% and receive a floating rate

July 2018 [Member]

Notional Amount

^[3]

$ 200

200

Type

^[2],[3]

Forward-starting to pay a fixed rate of 4.00% and receive a floating rate

March 2019 [Member]

Notional Amount

$ 300

300

Type

^[2]

Pay a floating rate based on a 3-month LIBOR and receive a fixed rate of 1.42%

July 2019 [Member]

Notional Amount

^[3]

$ 200

200

Type

^[2],[3]

Forward-starting to pay a fixed rate of 3.25% and receive a floating rate

December 2018 [Member]

Notional Amount

$ 1,200

Type

^[2]

Pay a floating rate based on a 3-month LIBOR and receive a fixed rate of 1.53%

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

Derivative Assets And Liabilities Table - Fair Value of Derivative Instruments (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Total derivatives assets	$ 179	$ 454
Total derivatives liabilities	(402)	(532)
Designated as Hedging Instrument [Member]
Total derivatives assets	4	38
Total derivatives liabilities	0	(3)
Designated as Hedging Instrument [Member] \| Commodity Derivatives (Margin Deposits) [Member]
Total derivatives assets	4	38
Total derivatives liabilities	0	(3)
Not Designated as Hedging Instrument [Member]
Total derivatives assets	175	416
Total derivatives liabilities	(402)	(529)
Not Designated as Hedging Instrument [Member] \| Commodity Derivatives (Margin Deposits) [Member]
Total derivatives assets	115	353
Total derivatives liabilities	(98)	(306)
Not Designated as Hedging Instrument [Member] \| Commodity Derivatives [Member]
Total derivatives assets	35	63
Total derivatives liabilities	(32)	(47)
Not Designated as Hedging Instrument [Member] \| Interest Rate Derivatives [Member]
Total derivatives assets	25	0
Total derivatives liabilities	(267)	(171)
Not Designated as Hedging Instrument [Member] \| Embedded Derivatives [Member]
Total derivatives assets	0	0
Total derivatives liabilities	$ (5)	$ (5)

Derivative Assets And Liabilities Table - Gross FV and Netting Offset (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 179	$ 454
Derivative Liability, Fair Value, Gross Liability	(402)	(532)
Counterparty netting	(17)	(17)
Counterparty netting	17	17
Payments on margin deposit	(98)	(309)
Derivative Liability, Collateral, Right to Reclaim Cash, Offset	98	309
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	64	128
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	(287)	(206)
Without offsetting agreements [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	25	0
Derivative Liability, Fair Value, Gross Liability	(272)	(176)
OTC Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	35	63
Derivative Liability, Fair Value, Gross Liability	(32)	(47)
Broker cleared derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	119	391
Derivative Liability, Fair Value, Gross Liability	$ (98)	$ (309)

Derivative Assets And Liabilities Table - Partnership's Derivative Assets and Liabilities Recognized OCI on Derivatives (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Change in Value Recognized in OCI on Derivatives (Effective Portion)	$ 0	$ 1
Commodity Derivatives [Member]
Change in Value Recognized in OCI on Derivatives (Effective Portion)	$ 0	$ 1

Derivative Assets And Liabilities Table - Partnership's Derivative Assets and Liabilities Amount of Gain (Loss) Recognized (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Amount of Gain/(Loss) Recognized in Income Representing Hedge Ineffectiveness and Amount Excluded from the Assessment of Effectiveness	$ (4)	$ (3)
Amount of Gain/(Loss) Recognized in Income on Derivatives	(71)	(85)
Commodity Derivatives - Trading [Member] \| Cost of Products Sold [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	(9)	(2)
Commodity Derivatives [Member] \| Cost of Products Sold [Member]
Amount of Gain/(Loss) Recognized in Income Representing Hedge Ineffectiveness and Amount Excluded from the Assessment of Effectiveness	(4)	(3)
Amount of Gain/(Loss) Recognized in Income on Derivatives	8	(8)
Interest Rate Derivatives [Member] \| Gains On Interest Rate Derivatives [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	(70)	(77)
Embedded Derivatives [Member] \| Other Income (Expenses) [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	$ 0	$ 2

Related Party Transactions Related Party Revenue (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Related Party Transactions [Abstract]
Revenue from Related Parties	$ 81	$ 76

Reportable Segments Table - Segment Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	$ 1,578	$ 1,395
Depreciation, depletion and amortization	562	493
Interest expense, net	427	371
Losses on interest rate derivatives	(70)	(77)
Non-cash unit-based compensation expense	(1)	(23)
Unrealized losses on commodity risk management activities	(60)	(75)
Inventory valuation adjustments	(13)	(34)
Equity in earnings of unconsolidated affiliates	61	57
Adjusted EBITDA related to unconsolidated affiliates	(219)	(146)
Other, net	6	0
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT)	281	233
Investment In ETP [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	1,412	1,366
Investment In Sunoco LP [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	159	128
Investment in Lake Charles LNG [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	44	49
Corporate and Other [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	(37)	(23)
Adjustments And Eliminations [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	$ 0	$ (125)

Reportable Segments Table - Segment Assets (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Assets	$ 72,765	$ 71,189
Investment In ETP [Member]
Assets	64,315	65,173
Investment In Sunoco LP [Member]
Assets	8,803	8,842
Investment in Lake Charles LNG [Member]
Assets	1,405	1,369
Corporate and Other [Member]
Assets	656	638
Adjustments And Eliminations [Member]
Assets	$ (2,414)	$ (4,833)

Reportable Segments Table - Revenues (External and Intersegment) by Investments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Revenues	$ 7,682	$ 10,380
Investment In ETP [Member]
Revenues	4,481	10,326
Investment In Sunoco LP [Member]
Revenues	3,202	4,342
Adjustments And Eliminations [Member]
Revenues	(50)	(4,342)
Intersegment [Member] \| Investment In ETP [Member]
Revenues	47	0
Intersegment [Member] \| Investment In Sunoco LP [Member]
Revenues	3	0
External Customers [Member] \| Investment In ETP [Member]
Revenues	4,434	10,326
External Customers [Member] \| Investment In Sunoco LP [Member]
Revenues	3,199	4,342
External Customers [Member] \| Investment in Lake Charles LNG [Member]
Revenues	$ 49	$ 54

Reportable Segments Table - Revenues from External Customers by Segment (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Segment Reporting Information [Line Items]
Revenues	$ 7,682	$ 10,380
Investment In Sunoco LP [Member]
Segment Reporting Information [Line Items]
Revenues	3,202	4,342
Investment In ETP [Member]
Segment Reporting Information [Line Items]
Revenues	4,481	10,326
Intersegment [Member] \| Investment In Sunoco LP [Member]
Segment Reporting Information [Line Items]
Revenues	3	0
Intersegment [Member] \| Investment In ETP [Member]
Segment Reporting Information [Line Items]
Revenues	47	0
External Customers [Member] \| Investment In Sunoco LP [Member]
Segment Reporting Information [Line Items]
Revenues	3,199	4,342
External Customers [Member] \| Investment In ETP [Member]
Segment Reporting Information [Line Items]
Revenues	4,434	10,326
Retail Operations [Member] \| Investment In Sunoco LP [Member]
Segment Reporting Information [Line Items]
Revenues	1,675	1,888
Interstate Transportation and Storage [Member] \| Investment In ETP [Member]
Segment Reporting Information [Line Items]
Revenues	254	271
Midstream [Member] \| Investment In ETP [Member]
Segment Reporting Information [Line Items]
Revenues	527	749
Liquids Transportation And Services [Member] \| Investment In ETP [Member]
Segment Reporting Information [Line Items]
Revenues	829	812
Investment in Sunoco Logistics [Member] \| Investment In ETP [Member]
Segment Reporting Information [Line Items]
Revenues	1,729	2,526
Retail Marketing [Member] \| Investment In ETP [Member]
Segment Reporting Information [Line Items]
Revenues	0	4,782
Other Segments [Member] \| Investment In ETP [Member]
Segment Reporting Information [Line Items]
Revenues	696	645
Intrastate Transportation And Storage [Member] \| Investment In ETP [Member]
Segment Reporting Information [Line Items]
Revenues	446	541
Wholesale Operations [Member] \| Investment In Sunoco LP [Member]
Segment Reporting Information [Line Items]
Revenues	$ 1,527	$ 2,454

Supplemental Financial Statement Information Table - Balance Sheets (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2014
Cash and cash equivalents	$ 807	$ 606	$ 1,863	$ 847
Accounts receivable from related companies	96	119
Other current assets	743	603
Total current assets	5,584	5,410
Property, plant and equipment, net	50,125	48,683
Advances to and investments in unconsolidated affiliates	3,442	3,462
Intangible assets, net	5,396	5,431
Goodwill	7,471	7,473
Other non-current assets, net	731	730
Total assets	72,765	71,189
Accounts payable to related companies	15	28
Accrued and other current liabilities	2,273	2,408
Total current liabilities	5,691	4,910
Long-term debt, less current maturities	37,401	36,837
Other non-current liabilities	1,117	1,069
Commitments and contingencies
General Partner	(2)	(2)
Common Unitholders	(1,684)	(952)
Class D Units	0	22
Series A Convertible Preferred Units	0	0
Total partners’ capital	(1,686)	(932)
Total liabilities and equity	72,765	71,189
Parent Company [Member]
Cash and cash equivalents	8	1	$ 4	$ 2
Accounts receivable from related companies	37	34
Other current assets	1	0
Total current assets	46	35
Property, plant and equipment, net	27	20
Advances to and investments in unconsolidated affiliates	5,106	5,764
Intangible assets, net	5	6
Goodwill	9	9
Other non-current assets, net	10	10
Total assets	5,203	5,844
Accounts payable to related companies	44	111
Interest payable	85	66
Accrued and other current liabilities	6	1
Total current liabilities	135	178
Long-term debt, less current maturities	6,439	6,332
Note payable to affiliate	315	265
Other non-current liabilities	0	1
Commitments and contingencies
General Partner	(2)	(2)
Common Unitholders	(1,684)	(952)
Class D Units	0	22
Total partners’ capital	(1,686)	(932)
Total liabilities and equity	$ 5,203	$ 5,844

Supplemental Financial Statement Information Schedule of Statements of Operations (Details) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2016

Mar. 31, 2015

SELLING, GENERAL AND ADMINISTRATIVE EXPENSES(1)

$ (156)

$ (155)

Interest expense, net

(427)

(371)

Equity in earnings of unconsolidated affiliates

Other, net

Income tax benefit

(55)

NET INCOME

312

284

General Partner’s interest in net income

Class D Unitholder’s interest in net income

Limited Partners’ interest in net income

311

282

Parent Company [Member]

SELLING, GENERAL AND ADMINISTRATIVE EXPENSES(1)

^[1]

(37)

(28)

Interest expense, net

(81)

(61)

Equity in earnings of unconsolidated affiliates

430

373

Other, net

INCOME BEFORE INCOME TAXES

312

285

Income tax benefit

NET INCOME

312

284

General Partner’s interest in net income

Class D Unitholder’s interest in net income

Limited Partners’ interest in net income

$ 311

$ 282

[1]	Includes management fees paid by ETE to ETP.

Supplemental Financial Statement Information Schedule Of Statements of Cash Flows (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	$ 985	$ 575
Cash paid for Bakken Pipeline Transaction	(2)	(370)
Contributions to unconsolidated affiliate	31	34
Capital expenditures	(1,948)	(2,158)
Net cash used in investing activities	(1,942)	(2,585)
Proceeds from borrowings	5,750	8,731
Repayments of long-term debt	(4,422)	(5,938)
Proceeds from affiliate	132	219
Distributions to partners	(299)	(244)
Debt issuance costs	(19)	(33)
Net cash provided by (used in) financing activities	1,158	3,026
INCREASE IN CASH AND CASH EQUIVALENTS	201	1,016
Cash and cash equivalents, beginning of period	606	847
Cash and cash equivalents, end of period	807	1,863
Parent Company [Member]
NET CASH FLOWS PROVIDED BY OPERATING ACTIVITIES	223	198
Cash paid for Bakken Pipeline Transaction	0	(817)
Contributions to unconsolidated affiliate	65	0
Capital expenditures	(7)	(5)
Net cash used in investing activities	(72)	(822)
Proceeds from borrowings	105	1,692
Repayments of long-term debt	0	(865)
Proceeds from affiliate	50	54
Distributions to partners	(299)	(244)
Debt issuance costs	0	(11)
Net cash provided by (used in) financing activities	(144)	626
INCREASE IN CASH AND CASH EQUIVALENTS	7	2
Cash and cash equivalents, beginning of period	1	2
Cash and cash equivalents, end of period	$ 8	$ 4

Fair Value Measurements Table - Fair Value of Financial Assets and Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Liabilities, Fair Value Disclosure, Recurring	$ (402)	$ (532)
Level 1
Liabilities, Fair Value Disclosure, Recurring	(103)	(324)
Level 2
Liabilities, Fair Value Disclosure, Recurring	(294)	(203)
Level 3
Liabilities, Fair Value Disclosure, Recurring	(5)	(5)
Commodity Derivatives - Power [Member] \| Call Option [Member]
Trading Securities		1
Commodity Derivatives - Power [Member] \| Options - Puts [Member]
Trading Securities		1
Commodity Derivatives - Power [Member] \| Level 1 \| Call Option [Member]
Trading Securities		1
Commodity Derivatives - Power [Member] \| Level 1 \| Options - Puts [Member]
Trading Securities		1
Commodity Derivatives - Power [Member] \| Level 2 \| Call Option [Member]
Trading Securities		0
Commodity Derivatives - Power [Member] \| Level 2 \| Options - Puts [Member]
Trading Securities		0
Commodity Derivatives - Power [Member] \| Level 3 \| Call Option [Member]
Trading Securities		0
Commodity Derivatives - Power [Member] \| Level 3 \| Options - Puts [Member]
Trading Securities		0
Fair Value, Measurements, Recurring [Member]
Interest Rate Derivative Assets, at Fair Value	25
Price Risk Derivative Assets, at Fair Value	154	454
Assets, Fair Value Disclosure	179	454
Interest Rate Derivative Liabilities, at Fair Value	(267)	(171)
Embedded Derivative, Fair Value of Embedded Derivative Liability	(5)	(5)
Price Risk Derivative Liabilities, at Fair Value	(130)	(356)
Fair Value, Measurements, Recurring [Member] \| Level 1
Interest Rate Derivative Assets, at Fair Value	0
Price Risk Derivative Assets, at Fair Value	128	420
Assets, Fair Value Disclosure	128	420
Interest Rate Derivative Liabilities, at Fair Value	0	0
Embedded Derivative, Fair Value of Embedded Derivative Liability	0	0
Price Risk Derivative Liabilities, at Fair Value	(103)	(324)
Fair Value, Measurements, Recurring [Member] \| Level 2
Interest Rate Derivative Assets, at Fair Value	25
Price Risk Derivative Assets, at Fair Value	26	34
Assets, Fair Value Disclosure	51	34
Interest Rate Derivative Liabilities, at Fair Value	(267)	(171)
Embedded Derivative, Fair Value of Embedded Derivative Liability	0	0
Price Risk Derivative Liabilities, at Fair Value	(27)	(32)
Fair Value, Measurements, Recurring [Member] \| Level 3
Interest Rate Derivative Assets, at Fair Value	0
Price Risk Derivative Assets, at Fair Value	0	0
Assets, Fair Value Disclosure	0	0
Interest Rate Derivative Liabilities, at Fair Value	0	0
Embedded Derivative, Fair Value of Embedded Derivative Liability	(5)	(5)
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Basis Swaps IFERC/NYMEX [Member]
Price Risk Derivative Assets, at Fair Value	6	16
Price Risk Derivative Liabilities, at Fair Value	(9)	(16)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Swing Swaps IFERC [Member]
Price Risk Derivative Assets, at Fair Value	1	10
Price Risk Derivative Liabilities, at Fair Value	(2)	(12)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Fixed Swaps/Futures [Member]
Price Risk Derivative Assets, at Fair Value	67	274
Price Risk Derivative Liabilities, at Fair Value	(50)	(203)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Forward Physical Swaps [Member]
Price Risk Derivative Assets, at Fair Value	3	4
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 1 \| Basis Swaps IFERC/NYMEX [Member]
Price Risk Derivative Assets, at Fair Value	6	16
Price Risk Derivative Liabilities, at Fair Value	(9)	(16)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 1 \| Swing Swaps IFERC [Member]
Price Risk Derivative Assets, at Fair Value	0	2
Price Risk Derivative Liabilities, at Fair Value	(1)	(2)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 1 \| Fixed Swaps/Futures [Member]
Price Risk Derivative Assets, at Fair Value	67	274
Price Risk Derivative Liabilities, at Fair Value	(50)	(203)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 1 \| Forward Physical Swaps [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 2 \| Basis Swaps IFERC/NYMEX [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 2 \| Swing Swaps IFERC [Member]
Price Risk Derivative Assets, at Fair Value	1	8
Price Risk Derivative Liabilities, at Fair Value	(1)	(10)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 2 \| Fixed Swaps/Futures [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 2 \| Forward Physical Swaps [Member]
Price Risk Derivative Assets, at Fair Value	3	4
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 3 \| Basis Swaps IFERC/NYMEX [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 3 \| Swing Swaps IFERC [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 3 \| Fixed Swaps/Futures [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member] \| Level 3 \| Forward Physical Swaps [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Refined Products [Member] \| Future [Member]
Price Risk Derivative Assets, at Fair Value	6	15
Price Risk Derivative Liabilities, at Fair Value	(4)	(6)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Refined Products [Member] \| Level 1 \| Future [Member]
Price Risk Derivative Assets, at Fair Value	6	15
Price Risk Derivative Liabilities, at Fair Value	(4)	(6)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Refined Products [Member] \| Level 2 \| Future [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Refined Products [Member] \| Level 3 \| Future [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Crude [Member] \| Future [Member]
Price Risk Derivative Assets, at Fair Value	12	9
Price Risk Derivative Liabilities, at Fair Value	(5)	(5)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Crude [Member] \| Level 1 \| Future [Member]
Price Risk Derivative Assets, at Fair Value	12	9
Price Risk Derivative Liabilities, at Fair Value	(5)	(5)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Crude [Member] \| Level 2 \| Future [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Crude [Member] \| Level 3 \| Future [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	22	22
Price Risk Derivative Liabilities, at Fair Value	(26)	(22)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Fixed Swaps/Futures [Member]
Price Risk Derivative Assets, at Fair Value	1
Price Risk Derivative Liabilities, at Fair Value	(1)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Call Option [Member]
Price Risk Derivative Assets, at Fair Value	2
Price Risk Derivative Liabilities, at Fair Value		(1)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Future [Member]
Price Risk Derivative Assets, at Fair Value		3
Price Risk Derivative Liabilities, at Fair Value		(2)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 1 \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 1 \| Fixed Swaps/Futures [Member]
Price Risk Derivative Assets, at Fair Value	1
Price Risk Derivative Liabilities, at Fair Value	(1)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 1 \| Call Option [Member]
Price Risk Derivative Assets, at Fair Value	2
Price Risk Derivative Liabilities, at Fair Value		(1)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 1 \| Future [Member]
Price Risk Derivative Assets, at Fair Value		3
Price Risk Derivative Liabilities, at Fair Value		(2)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 2 \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	22	22
Price Risk Derivative Liabilities, at Fair Value	(26)	(22)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 2 \| Fixed Swaps/Futures [Member]
Price Risk Derivative Assets, at Fair Value	0
Price Risk Derivative Liabilities, at Fair Value	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 2 \| Call Option [Member]
Price Risk Derivative Assets, at Fair Value	0
Price Risk Derivative Liabilities, at Fair Value		0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 2 \| Future [Member]
Price Risk Derivative Assets, at Fair Value		0
Price Risk Derivative Liabilities, at Fair Value		0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 3 \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 3 \| Fixed Swaps/Futures [Member]
Price Risk Derivative Assets, at Fair Value	0
Price Risk Derivative Liabilities, at Fair Value	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 3 \| Call Option [Member]
Price Risk Derivative Assets, at Fair Value	0
Price Risk Derivative Liabilities, at Fair Value		0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - Power [Member] \| Level 3 \| Future [Member]
Price Risk Derivative Assets, at Fair Value		0
Price Risk Derivative Liabilities, at Fair Value		0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - NGLs [Member] \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	34	99
Price Risk Derivative Liabilities, at Fair Value	(33)	(89)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - NGLs [Member] \| Level 1 \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	34	99
Price Risk Derivative Liabilities, at Fair Value	(33)	(89)
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - NGLs [Member] \| Level 2 \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Fair Value, Measurements, Recurring [Member] \| Commodity Derivatives - NGLs [Member] \| Level 3 \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	$ 0	$ 0