0001276187-21-000079 | 10-Q | XBRL Viewer

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DEI Document - shares	9 Months Ended
DEI Document - shares	Sep. 30, 2021	Oct. 29, 2021
Document Information [Line Items]
Entity Registrant Name	ENERGY TRANSFER LP
Document Transition Report	false
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
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	Sep. 30, 2021
Entity File Number	1-32740
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding		2,705,855,172
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Tax Identification Number	30-0108820
Entity Incorporation, State or Country Code	DE
Entity Address, Address Line One	8111 Westchester Drive
Entity Address, Address Line Two	Suite 600
Entity Address, City or Town	Dallas
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	75225
City Area Code	214
Local Phone Number	981-0700
Document Quarterly Report	true
Document Quarterly Report	true
Common Units
Document Information [Line Items]
Trading Symbol	ET
Security Exchange Name	NYSE
Title of 12(b) Security	Common Units
ETprC
Document Information [Line Items]
Trading Symbol	ETprC
Security Exchange Name	NYSE
Title of 12(b) Security	7.375% Series C Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units
ETprD
Document Information [Line Items]
Trading Symbol	ETprD
Security Exchange Name	NYSE
Title of 12(b) Security	7.625% Series D Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units
ETprE
Document Information [Line Items]
Trading Symbol	ETprE
Security Exchange Name	NYSE
Title of 12(b) Security	7.600% Series E Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units

Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
ASSETS
Cash and cash equivalents	$ 313	$ 367
Accounts receivable, net	6,437	3,875
Accounts receivable from related companies	63	79
Inventories	1,811	1,739
Income taxes receivable	42	35
Derivative assets	57	9
Other current assets	326	213
Total current assets	9,049	6,317
Property, plant and equipment	95,775	94,115
Accumulated depreciation and depletion	(21,504)	(19,008)
Property, Plant and Equipment, Net	74,271	75,107
Investments in unconsolidated affiliates	2,958	3,060
Lease, Right of Use Asset, Net	829	866
Other non-current assets, net	1,722	1,657
Intangible assets, net	5,474	5,746
Goodwill	2,395	2,391
Total assets	96,698	95,144
LIABILITIES AND EQUITY
Accounts payable	5,707	2,809
Accounts Payable, Related Parties, Current	0	27
Derivative liabilities	205	238
Operating lease current liabilities	46	53
Accrued and other current liabilities	3,198	2,775
Current maturities of long-term debt	678	21
Total current liabilities	9,834	5,923
Long-term debt, less current maturities	44,793	51,417
Non-current derivative liabilities	187	237
Non-current operating lease liabilities	799	837
Deferred income taxes	3,683	3,428
Other non-current liabilities	1,270	1,152
Commitments and contingencies
Redeemable noncontrolling interests	783	762
Preferred Units, Preferred Partners' Capital Accounts	5,671	0
Limited Partners:
Common Unitholders	21,726	18,531
General Partner	(5)	(8)
Accumulated other comprehensive income	19	6
Total partners’ capital	27,411	18,529
Noncontrolling interests	7,938	12,859
Total equity	35,349	31,388
Total liabilities and equity	$ 96,698	$ 95,144

Consolidated Statements Of Operations - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
REVENUES:
Total revenues	$ 16,664	$ 9,955	$ 48,760	$ 28,920
COSTS AND EXPENSES:
Cost of products sold	13,188	6,376	35,641	18,784
Operating expenses	898	773	2,585	2,422
Depreciation, depletion and amortization	943	912	2,837	2,715
Selling, general and administrative	198	176	583	555
Impairment losses	0	1,474	11	2,803
Total costs and expenses	15,227	9,711	41,657	27,279
OPERATING INCOME	1,437	244	7,103	1,641
OTHER INCOME (EXPENSE):
Interest expense, net of interest capitalized	(558)	(569)	(1,713)	(1,750)
Equity in earnings (losses) of unconsolidated affiliates	71	(32)	191	46
Losses on extinguishments of debt	0	0	(8)	(62)
Gains (losses) on interest rate derivatives	1	55	72	(277)
Other, net	33	71	45	6
INCOME (LOSS) BEFORE INCOME TAX EXPENSE	984	(360)	5,690	(525)
Income tax expense	77	41	234	168
NET INCOME (LOSS)	907	(401)	5,456	(693)
Less: Net income attributable to noncontrolling interests	260	242	870	427
Less: Net income attributable to redeemable noncontrolling interests	12	12	37	37
NET INCOME (LOSS) ATTRIBUTABLE TO PARTNERS	635	(655)	4,549	(1,157)
Net Income (Loss) Allocated to General Partners	1	0	5	(1)
Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Nonredeemable	99	0	185	0
Limited Partners’ interest in net income (loss)	$ 535	$ (655)	$ 4,359	$ (1,156)
NET INCOME (LOSS) PER LIMITED PARTNER UNIT:
Basic	$ 0.20	$ (0.24)	$ 1.61	$ (0.43)
Diluted	$ 0.20	$ (0.24)	$ 1.60	$ (0.43)
Equity Method Investment, Other than Temporary Impairment	$ 0	$ (129)	$ 0	$ (129)
Refined product sales
REVENUES:
Revenue	4,810	2,720	12,737	7,952
Crude sales
REVENUES:
Revenue	4,021	2,298	10,920	7,170
NGL sales
REVENUES:
Revenue	4,005	1,808	10,275	4,751
Gathering, transportation and other fees
REVENUES:
Revenue	2,276	2,283	6,797	6,805
Natural gas sales
REVENUES:
Revenue	1,376	681	7,507	1,783
Other
REVENUES:
Revenue	$ 176	$ 165	$ 524	$ 459

Consolidated Statements Of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Net income (loss)	$ 907	$ (401)	$ 5,456	$ (693)
Other comprehensive income (loss), net of tax:
Change in value of available-for-sale securities	2	3	5	3
Actuarial gain related to pension and other postretirement benefit plans	1	4	6	15
Foreign currency translation adjustments	(21)	18	3	(16)
Change in other comprehensive income (loss) from unconsolidated affiliates	1	1	1	(15)
Other comprehensive income (loss), net of tax	(17)	26	15	(13)
Comprehensive income (loss)	890	(375)	5,471	(706)
Less: Comprehensive income attributable to noncontrolling interests	250	251	872	407
Less: Net income attributable to redeemable noncontrolling interests	12	12	37	37
Comprehensive income (loss) attributable to partners	$ 628	$ (638)	$ 4,562	$ (1,150)

Consolidated Statement Of Equity - USD ($) $ in Millions	Total	Limited Partner [Member]	General Partner	Noncontrolling Interest	AOCI Attributable to Parent [Member]	Preferred Unitholders
Balance, Beginning of Period at Dec. 31, 2019	$ 33,938	$ 21,935	$ (4)	$ 12,018	$ (11)
Partners' Capital Account, Distributions	(1,592)	(1,591)	(1)	0	0
Distributions to noncontrolling interests	(444)	0	0	(444)	0
Subsidiary units issued	1,580	0	0	1,580	0
Capital contributions from noncontrolling interests	95	0	0	95	0
Other comprehensive income, net of tax	(86)	0	0	(38)	(48)
Other, net	15	22	0	(7)	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Excluding Portion Attributable to Redeemable Noncontrolling Interest	(976)	(854)	(1)	(121)	0
Balance, End of Period at Mar. 31, 2020	32,530	19,512	(6)	13,083	(59)
Balance, Beginning of Period at Dec. 31, 2019	33,938	21,935	(4)	12,018	(11)
Other comprehensive income, net of tax	(13)
Net income (loss)	(693)
Balance, End of Period at Sep. 30, 2020	31,291	18,423	(8)	12,880	(4)
Balance, Beginning of Period at Mar. 31, 2020	32,530	19,512	(6)	13,083	(59)
Partners' Capital Account, Distributions	8	9	(1)	0	0
Distributions to noncontrolling interests	(408)	0	0	(408)	0
Capital contributions from noncontrolling interests	83	0	0	83	0
Other comprehensive income, net of tax	47	0	0	9	38
Other, net	(27)	(31)	0	4	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Excluding Portion Attributable to Redeemable Noncontrolling Interest	659	353	0	306	0
Balance, End of Period at Jun. 30, 2020	32,892	19,843	(7)	13,077	(21)
Partners' Capital Account, Distributions	(813)	(812)	(1)	0	0
Distributions to noncontrolling interests	(430)	0	0	(430)	0
Capital contributions from noncontrolling interests	25	0	0	25	0
Other comprehensive income, net of tax	26	0	0	9	17
Other, net	4	47	0	(43)	0
Net income (loss)	(401)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Excluding Portion Attributable to Redeemable Noncontrolling Interest	(413)	(655)	0	242	0
Balance, End of Period at Sep. 30, 2020	31,291	18,423	(8)	12,880	(4)
Balance, Beginning of Period at Dec. 31, 2020	31,388	18,531	(8)	12,859	6	$ 0
Partners' Capital Account, Distributions	(406)	(406)	0	0	0	0
Distributions to noncontrolling interests	(406)	0	0	(406)	0	0
Capital contributions from noncontrolling interests	20	0	0	20	0	0
Other comprehensive income, net of tax	8	0	0	6	2	0
Other, net	21	18	0	3	0	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Excluding Portion Attributable to Redeemable Noncontrolling Interest	3,629	3,285	3	341	0	0
Balance, End of Period at Mar. 31, 2021	34,254	21,428	(5)	12,823	8	0
Balance, Beginning of Period at Dec. 31, 2020	31,388	18,531	(8)	12,859	6	0
Other comprehensive income, net of tax	15
Net income (loss)	5,456
Balance, End of Period at Sep. 30, 2021	35,349	21,726	(5)	7,938	19	5,671
Balance, Beginning of Period at Mar. 31, 2021	34,254	21,428	(5)	12,823	8	0
Partners' Capital Account, Distributions	(492)	(403)	(1)	0	0	(88)
Distributions to noncontrolling interests	(354)	0	0	(354)	0	0
Capital contributions from noncontrolling interests	43	0	0	43	0	0
Other comprehensive income, net of tax	24	0	0	6	18	0
Other, net	16	15	0	2	0	(1)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Excluding Portion Attributable to Redeemable Noncontrolling Interest	895	539	1	269	0	86
Balance, End of Period at Jun. 30, 2021	35,275	21,579	(5)	8,021	26	5,654
Stock Issued During Period, Value, Conversion of Units	0	0	0	(4,768)	0	4,768
Partners' Capital Account, Sale of Units	889	0	0	0	0	889
Partners' Capital Account, Distributions	(485)	(404)	(1)	0	0	(80)
Distributions to noncontrolling interests	(389)		0	(389)	0	0
Capital contributions from noncontrolling interests	51	0	0	51	0	0
Other comprehensive income, net of tax	(17)	0	0	(10)	(7)	0
Other, net	19	16	0	5	0	(2)
Net income (loss)	907
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Excluding Portion Attributable to Redeemable Noncontrolling Interest	895	535	1	260	0	99
Balance, End of Period at Sep. 30, 2021	$ 35,349	$ 21,726	$ (5)	$ 7,938	$ 19	$ 5,671

Consolidated Statements Of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
OPERATING ACTIVITIES:
Net income (loss)	$ 5,456	$ (693)
Reconciliation of net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	2,837	2,715
Deferred income taxes	199	159
Inventory valuation adjustments	(168)	126
Non-cash compensation expense	81	93
Impairment losses	11	2,803
Equity Method Investment, Other than Temporary Impairment	0	129
Losses on extinguishments of debt	(8)	(62)
Distributions on unvested awards	(19)	(33)
Equity in earnings of unconsolidated affiliates	(191)	(46)
Distributions from unconsolidated affiliates	226	176
Other non-cash	13	(130)
Net change in operating assets and liabilities, net of effects of acquisitions	970	94
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	9,423	5,455
INVESTING ACTIVITIES:
Capital expenditures, excluding allowance for equity funds used during construction	(2,046)	(4,030)
Contributions in aid of construction costs	29	61
Contributions to unconsolidated affiliate	4	37
Distributions from unconsolidated affiliates in excess of cumulative earnings	76	144
Proceeds from sales of other assets	38	10
Other	0	9
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	(1,907)	(3,861)
FINANCING ACTIVITIES:
Proceeds from borrowings	11,839	20,651
Repayments of debt	(17,836)	(20,293)
Proceeds from Issuance of Preferred Limited Partners Units	889	0
Subsidiary equity offerings, net of issue costs	0	1,580
Capital contributions from noncontrolling interest	114	203
Distributions to partners	(1,383)	(2,397)
Distributions to noncontrolling interests	(1,149)	(1,282)
Preferred Units, Cumulative Cash Distributions	(37)	(37)
Debt issuance costs	(3)	(53)
Other, net	(4)	18
Net cash used in financing activities	(7,570)	(1,610)
Decrease in cash and cash equivalents	(54)	(16)
Cash and cash equivalents, beginning of period	367	291
Cash and cash equivalents, end of period	$ 313	$ 275

Operations And Organization	3 Months Ended
Operations And Organization	Sep. 30, 2021
Operations And Organization [Abstract]
Operations And Organization	ORGANIZATION AND BASIS OF PRESENTATION Organization The consolidated financial statements presented herein contain the results of Energy Transfer LP and its subsidiaries (the “Partnership,” “we,” “us,” “our” or “ET”). On April 1, 2021, ET, ETO and certain of ETO’s subsidiaries consummated several internal reorganization transactions (the “Rollup Mergers”). In connection with the Rollup Mergers, Sunoco Logistics Operations merged with and into ETO, with ETO surviving, and immediately thereafter, ETO merged with and into ET, with ET surviving. The impacts of the Rollup Mergers also included the following: •All of ETO’s long-term debt was assumed by ET, as more fully described in Note 7. •Each issued and outstanding ETO preferred unit was converted into the right to receive one newly created ET preferred unit. A description of the ET Preferred Units is included in Note 9. •Each of ETO’s issued and outstanding Class K, Class L, Class M and Class N units, all of which were held by ETP Holdco Corporation, a wholly-owned subsidiary of ETO, were converted into an aggregate 675,625,000 newly created Class B Units representing limited partner interests in ET. 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, 2020, filed with the SEC on February 19, 2021. 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. The consolidated financial statements of the Partnership presented herein include the results of operations of our controlled subsidiaries, including Sunoco LP and USAC. Our subsidiaries also own varying undivided interests in certain pipelines. Ownership of these pipelines has been structured as 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. Certain prior period amounts have been reclassified to conform to the current period 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 requires the use of estimates and assumptions made by management that affect the reported amounts of assets, liabilities, revenues, expenses and the accrual for 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.

Acquisitions and Related Transactions	9 Months Ended
Acquisitions and Related Transactions	Sep. 30, 2021
Business Combinations [Abstract]
Business Combination Disclosure	ACQUISITIONS AND RELATED TRANSACTIONS Pending Enable Acquisition On February 16, 2021, the Partnership entered into a definitive merger agreement to acquire Enable. Under the terms of the merger agreement, Enable’s common unitholders will receive 0.8595 of an ET common unit in exchange for each Enable common unit. In addition, each outstanding Enable preferred unit will be exchanged for 0.0265 of a Series G Preferred Unit, and ET will make a $10 million cash payment for Enable’s general partner. In May 2021, the Enable common unitholders voted to approve the merger. The transaction is subject to the satisfaction of customary closing conditions, including Hart-Scott-Rodino Act (“HSR”) clearance.

Cash And Cash Equivalents

9 Months Ended

Sep. 30, 2021

Supplemental Cash Flow Information [Abstract]

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. The Partnership’s consolidated balance sheets did not include any material amounts of restricted cash as of September 30, 2021 or December 31, 2020.

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

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


	Nine Months Ended September 30,
	2021		2020
Accounts receivable	$	(2,562)	$	1,307
Accounts receivable from related companies	16		(258)
Inventories	96		(298)
Other current assets	(127)		108
Other non-current assets, net	(57)		(26)
Accounts payable	2,917		(1,354)
Accounts payable to related companies	(31)		370
Accrued and other current liabilities	711		127
Other non-current liabilities	138		(5)
Derivative assets and liabilities, net	(131)		123
Net change in operating assets and liabilities, net of effects of acquisitions	$	970	$	94

Non-cash activities were as follows:


	Nine Months Ended September 30,
	2021		2020
NON-CASH INVESTING AND FINANCING ACTIVITIES:
Accrued capital expenditures	$	385	$	684

Lease assets obtained in exchange for new lease liabilities	10		130
Distribution reinvestment	24		72

Inventories (Notes)

9 Months Ended

Sep. 30, 2021

Inventory, Net [Abstract]

Inventories

INVENTORIESInventories consist principally of natural gas held in storage, NGLs and refined products, crude oil and spare parts, all of which are valued at the lower of cost or net realizable value utilizing the weighted-average cost method.

Sunoco LP’s fuel inventories are stated at the lower of cost or market using the last-in, first-out (“LIFO”) method. As of September 30, 2021 and December 31, 2020, the carrying value of Sunoco LP’s fuel inventory included lower of cost or market reserves of $143 million and $311 million, respectively, and the inventory carrying value equaled or exceeded its replacement cost. For the three and nine months ended September 30, 2021 and 2020, the Partnership’s consolidated income statements did not include any material amounts of income from the liquidation of LIFO fuel inventory.


	September 30, 2021		December 31, 2020
Natural gas, NGLs and refined products(1)	$	1,238	$	1,013
Crude oil	160		287
Spare parts and other	413		439
Total inventories	$	1,811	$	1,739

(1)Due to changes in fuel prices, Sunoco LP recorded an inventory adjustment on the value of its fuel inventory of $168 million for the nine months ended September 30, 2021.

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

9 Months Ended

Sep. 30, 2021

Fair Value Measurements [Abstract]

Fair Value Measurements

FAIR VALUE MEASURESWe have commodity derivatives and interest rate derivatives 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. During the nine months ended September 30, 2021, no transfers were made between any levels within the fair value hierarchy.

The following tables summarize the gross fair value of our financial assets and liabilities measured and recorded at fair value on a recurring basis as of September 30, 2021 and December 31, 2020 based on inputs used to derive their fair values:


			Fair Value Measurements at September 30, 2021
	Fair Value Total		Level 1		Level 2
Assets:

Commodity derivatives:

Natural Gas:
Basis Swaps IFERC/NYMEX	$	14	$	14	$	—
Swing Swaps IFERC	11		11		—
Fixed Swaps/Futures	4		4		—


Forward Physical Contracts	4		—		4
Power:
Forwards	36		—		36
Futures	4		4		—

Options – Calls	1		1		—
NGLs – Forwards/Swaps	384		384		—
Refined Products – Futures	7		7		—
Crude – Forwards/Swaps	569		569		—

Total commodity derivatives	1,034		994		40
Other non-current assets	37		24		13
Total assets	$	1,071	$	1,018	$	53
Liabilities:
Interest rate derivatives	$	(376)	$	—	$	(376)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(5)		(5)		—
Swing Swaps IFERC	(7)		(7)		—
Fixed Swaps/Futures	(78)		(78)		—


Forward Physical Contracts	(1)		—		(1)
Power:
Forwards	(21)		—		(21)
Futures	(11)		(11)		—
Options – Calls	(2)		(2)		—

NGLs – Forwards/Swaps	(364)		(364)		—
Refined Products – Futures	(10)		(10)		—
Crude – Forwards/Swaps	(582)		(582)		—
Total commodity derivatives	(1,081)		(1,059)		(22)
Total liabilities	$	(1,457)	$	(1,059)	$	(398)


			Fair Value Measurements at December 31, 2020
	Fair Value Total		Level 1		Level 2
Assets:

Commodity derivatives:

Natural Gas:
Basis Swaps IFERC/NYMEX	$	12	$	12	$	—
Swing Swaps IFERC	1		—		1
Fixed Swaps/Futures	13		13		—


Forward Physical Contracts	5		—		5
Power:
Forwards	4		—		4
Futures	2		2		—

Options – Calls	1		1		—
NGLs – Forwards/Swaps	127		127		—
Refined Products – Futures	3		3		—



Total commodity derivatives	168		158		10
Other non-current assets	34		22		12
Total assets	$	202	$	180	$	22
Liabilities:
Interest rate derivatives	$	(448)	$	—	$	(448)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(11)		(11)		—
Swing Swaps IFERC	(3)		—		(3)
Fixed Swaps/Futures	(13)		(13)		—


Forward Physical Contracts	(1)		—		(1)
Power:

Futures	(3)		(3)		—

NGLs – Forwards/Swaps	(227)		(227)		—
Refined Products – Futures	(11)		(11)		—



Total commodity derivatives	(269)		(265)		(4)
Total liabilities	$	(717)	$	(265)	$	(452)

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 September 30, 2021 were $51.26 billion and $45.47 billion, respectively. As of December 31, 2020, the aggregate fair value and carrying amount of our consolidated debt obligations were $56.21 billion and $51.44 billion, respectively. The fair value of our consolidated debt obligations is a Level 2 valuation based on the respective debt obligations’ observable inputs for similar liabilities.

- 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

9 Months Ended

Sep. 30, 2021

Earnings Per Share [Abstract]

Net Income Per Limited Partner Unit

NET INCOME (LOSS) PER LIMITED PARTNER UNIT

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Net income (loss)	$	907	$	(401)	$	5,456	$	(693)
Less: Net income attributable to noncontrolling interests	260		242		870		427
Less: Net income attributable to redeemable noncontrolling interests	12		12		37		37
Net income (loss), net of noncontrolling interests	635		(655)		4,549		(1,157)
Less: General Partner’s interest in income (loss)	1		—		5		(1)
Less: Preferred Unitholders’ interest in income	99		—		185		—
Income (loss) available to Limited Partners	$	535	$	(655)	$	4,359	$	(1,156)
Basic Income (Loss) per Limited Partner Unit:
Weighted average limited partner units	2,705.2		2,696.6		2,704.0		2,694.4
Basic income (loss) per Limited Partner unit	$	0.20	$	(0.24)	$	1.61	$	(0.43)

Diluted Income (Loss) per Limited Partner Unit:
Income (loss) available to Limited Partners	$	535	$	(655)	$	4,359	$	(1,156)
Dilutive effect of equity-based compensation of subsidiaries (1)	1		—		2		—
Diluted income (loss) available to Limited Partners	$	534	$	(655)	$	4,357	$	(1,156)
Weighted average limited partner units	2,705.2		2,696.6		2,704.0		2,694.4
Dilutive effect of unvested unit awards (1)	15.4		—		14.4		—
Weighted average limited partner units, assuming dilutive effect of unvested unit awards	2,720.6		2,696.6		2,718.4		2,694.4
Diluted income (loss) per Limited Partner unit	$	0.20	$	(0.24)	$	1.60	$	(0.43)

(1)Dilutive effects are excluded from the calculation for periods where the impact would have been antidilutive.

Debt Obligations	9 Months Ended
Debt Obligations	Sep. 30, 2021
Debt Obligations [Abstract]
Debt Obligations	DEBT OBLIGATIONS In connection with the Rollup Mergers on April 1, 2021, as discussed in Note 1, ET entered into various supplemental indentures and assumed all the obligations of ETO under the respective indentures and credit agreements. During the first quarter of 2021, ETO redeemed its $600 million aggregate principal amount of 4.40% senior notes due April 1, 2021 and its $800 million aggregate principal amount of 4.65% senior notes due June 1, 2021, using proceeds from the Five-Year Credit Facility. During the third quarter of 2021, ET issued par call notices to redeem in full its $1.0 billion aggregate principal amount of 5.2% senior notes due February 1, 2022, and $900 million aggregate principal amount of 5.875% senior notes due March 1, 2022. The Partnership expects to redeem both series of senior notes during the fourth quarter of 2021, utilizing proceeds from its Five-Year Credit Facility. On October 20, 2021, Sunoco LP completed a private offering of $800 million in aggregate principal amount of 4.500% senior notes due 2030 (the “2030 Notes”). Sunoco LP used the proceeds from the private offering to fund a tender offer and repurchase all of its senior notes due 2026. Credit Facilities and Commercial Paper Term Loan As a result of the Rollup Mergers, on April 1, 2021, ET assumed all of ETO’s obligations in respect of its term loan credit agreement (the “Term Loan”) and Sunoco Logistics Operations was released as a guarantor in respect of the Term Loan. The Partnership’s Term Loan provides for a $2.00 billion three-year term loan credit facility. During the second quarter of 2021, the Partnership repaid $1.5 billion on the Term Loan in part through proceeds from its Series H Preferred Unit issuance. During the third quarter of 2021, the Partnership repaid the remaining $500 million balance and terminated the Term Loan. Five-Year Credit Facility As a result of the Rollup Mergers, on April 1, 2021, ET assumed all of ETO’s obligations in respect of its revolving credit facility (the “Five-Year Credit Facility”) and Sunoco Logistics Operations was released as a guarantor in respect of the Five-Year Credit Facility. The Partnership’s Five-Year Credit Facility allows for unsecured borrowings up to $5.00 billion and matures on December 1, 2024. The Five-Year Credit Facility contains an accordion feature, under which the total aggregate commitment may be increased up to $6.00 billion under certain conditions. As of September 30, 2021, the Five-Year Credit Facility had $599 million of outstanding borrowings, of which $590 million consisted of commercial paper. The amount available for future borrowings was $4.37 billion, after accounting for outstanding letters of credit in the amount of $31 million. The weighted average interest rate on the total amount outstanding as of September 30, 2021 was 0.43%. 364-Day Facility As a result of the Rollup Mergers, on April 1, 2021, ET assumed all of ETO’s obligations in respect of its 364-day revolving credit facility (the “364-Day Facility”) and Sunoco Logistics Operations was released as a guarantor in respect of the 364-Day Facility. The Partnership’s 364-Day Facility allows for unsecured borrowings up to $1.00 billion and matures on November 26, 2021. As of September 30, 2021, the 364-Day Facility had no outstanding borrowings. Sunoco LP Credit Facility Sunoco LP maintains a $1.50 billion revolving credit facility (the “Sunoco LP Credit Facility”). As of September 30, 2021, the Sunoco LP Credit Facility had $250 million of outstanding borrowings and $6 million in standby letters of credit and matures in July 2023. The amount available for future borrowings at September 30, 2021 was $1.24 billion. The weighted average interest rate on the total amount outstanding as of September 30, 2021 was 2.09%. USAC Credit Facility USAC maintains a $1.60 billion revolving credit facility (the “USAC Credit Facility”), which matures on April 2, 2023 and permits up to $400 million of future increases in borrowing capacity. As of September 30, 2021, USAC had $506 million of outstanding borrowings under the USAC Credit Facility. As of September 30, 2021, USAC had $1.09 billion of availability under its credit facility, and subject to compliance with applicable financial covenants, available borrowing capacity of $114 million. The weighted average interest rate on the total amount outstanding as of September 30, 2021 was 2.96%. Energy Transfer Canada Credit Facilities Energy Transfer Canada is party to a credit agreement providing for a C$350 million (US$276 million at the September 30, 2021 exchange rate) senior secured term loan facility (the “Energy Transfer Canada Term Loan A”), a C$525 million (US$414 million at the September 30, 2021 exchange rate) senior secured revolving credit facility (the “Energy Transfer Canada Revolving Credit Facility”), and a C$300 million (US$237 million at the September 30, 2021 exchange rate) senior secured construction loan facility (the “KAPS Facility”). The Energy Transfer Canada Term Loan A and the Energy Transfer Canada Revolving Credit Facility mature on February 25, 2024. The KAPS Facility matures on June 13, 2024. Energy Transfer Canada may incur additional term loans and revolving commitments in an aggregate amount not to exceed C$250 million (US$197 million at the September 30, 2021 exchange rate), subject to receiving commitments for such additional term loans or revolving commitments from either new lenders or increased commitments from existing lenders. As of September 30, 2021, the Energy Transfer Canada Term Loan A and the Energy Transfer Canada Revolving Credit Facility had outstanding borrowings of C$320 million and C$103 million, respectively (US$252 million and US$81 million, respectively, at the September 30, 2021 exchange rate). As of September 30, 2021, the KAPS Facility had outstanding borrowings of C$65 million (US$51 million at the September 30, 2021 exchange rate). Compliance with our Covenants We and our subsidiaries were in compliance with all requirements, tests, limitations, and covenants related to our debt agreements as of September 30, 2021. For the quarter ended September 30, 2021, our leverage ratio, as calculated pursuant to the covenant related to our revolving credit facility, was 3.15x.

- Definition

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

+ References

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
-Topic 470
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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-Section S99
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-URI http://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
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Reference 8: http://www.xbrl.org/2003/role/disclosureRef
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Reference 12: http://www.xbrl.org/2003/role/disclosureRef
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+ Details

Redeemable Noncontrolling Interest (Notes)	9 Months Ended
Redeemable Noncontrolling Interest (Notes)	Sep. 30, 2021
Temporary Equity Disclosure [Abstract]
Redeemable Noncontrolling Interest [Text Block]	REDEEMABLE NONCONTROLLING INTERESTS Certain redeemable noncontrolling interests in the Partnership’s subsidiaries are reflected as mezzanine equity on the consolidated balance sheets. Redeemable noncontrolling interests as of September 30, 2021 included a balance of $477 million related to the USAC Preferred Units described below and a balance of $15 million related to noncontrolling interest holders in one of the Partnership’s consolidated subsidiaries that have the option to sell their interests to the Partnership. In addition, as of September 30, 2021, redeemable noncontrolling interests included a balance of $291 million related to Energy Transfer Canada preferred shares. USAC Preferred Units As of September 30, 2021, USAC had 500,000 USAC Preferred Units issued and outstanding. The USAC Preferred Units are entitled to receive cumulative quarterly distributions equal to $24.375 per USAC Preferred Unit, subject to increase in certain limited circumstances. The USAC Preferred Units will have a perpetual term, unless converted or redeemed. Certain portions of the USAC Preferred Units are convertible into USAC common units at the election of the holders. To the extent the holders of the USAC Preferred Units have not elected to convert their preferred units by April 2023, USAC will have the option to redeem all or any portion of the USAC Preferred Units for cash. In addition, beginning April 2028, the holders of the USAC Preferred Units will have the right to require USAC to redeem all or any portion of the USAC Preferred Units, and USAC may elect to pay up to 50% of such redemption amount in USAC common units. Energy Transfer Canada Redeemable Preferred Stock Energy Transfer Canada has 300,000 shares of cumulative preferred stock issued and outstanding. The preferred stock is redeemable at Energy Transfer Canada’s option at a redemption price of C$1,100 (US$867 at the September 30, 2021 exchange rate) per share. The preferred stock is redeemable by the holder contingent upon a change of control or liquidation of Energy Transfer Canada. The preferred stock is convertible to Energy Transfer Canada common shares in the event of an initial public offering by Energy Transfer Canada. Dividends on the preferred stock were payable in-kind through the quarter ended June 30, 2021. The dividends paid-in-kind increased the liquidation preference such that, as of September 30, 2021, the preferred stock was convertible into 367,521 shares. For the quarter ended September 30, 2021, Energy Transfer Canada declared cash dividends of C$8 million (US$6 million at the September 30, 2021 exchange rate) on the preferred stock that will be paid in the fourth quarter of 2021.

Equity

9 Months Ended

Sep. 30, 2021

Equity [Abstract]

Equity

EQUITY

ET Common Units

The change in ET common units during the nine months ended September 30, 2021 was as follows:


			Number of Units
Number of common units at December 31, 2020			2,702.4
Common units issued in connection with the distribution reinvestment plan			2.7

Common units vested under equity incentive plans and other			0.7
Number of common units at September 30, 2021			2,705.8

ET Repurchase Program

During the nine months ended September 30, 2021, ET did not repurchase any ET common units under its current buyback program. As of September 30, 2021, $911 million remained available to repurchase under the current program.

ET Distribution Reinvestment Program

During the nine months ended September 30, 2021, distributions of $24 million were reinvested under the distribution reinvestment program. As of September 30, 2021, a total of 18 million ET common units remained available to be issued under the existing registration statement in connection with the distribution reinvestment program.

Cash Distributions on ET Common Units

Distributions declared and/or paid with respect to ET common units subsequent to December 31, 2020 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2020

February 8, 2021

February 19, 2021

0.1525

March 31, 2021

May 11, 2021

May 19, 2021

0.1525

June 30, 2021

August 6, 2021

August 19, 2021

0.1525

September 30, 2021

November 5, 2021

November 19, 2021

0.1525

The Partnership’s distribution on its common units with respect to the quarter ended March 31, 2020 was declared on March 31, 2020 and accrued as of that date. For the three months ended March 31, 2020, the consolidated statement of equity reflected distributions to common unitholders for two quarters. For the three months ended June 30, 2020, the amount reflected for distributions to common unitholders in the consolidated statements of equity reflected only the reinvestment of distributions paid in May 2020.

ET Preferred Units

Conversion of ETO Preferred Units to ET Preferred Units

In connection with the Rollup Mergers on April 1, 2021, as discussed in Note 1, all of ETO’s previously outstanding preferred units were converted to ET Preferred Units with identical distribution and redemption rights, as described under “Description of ET Preferred Units” below.

As of and prior to March 31, 2021, the ET Preferred Units were reflected as noncontrolling interests on the Partnership’s consolidated financial statements. Beginning April 1, 2021, the ET Preferred Units are reflected as limited partner interests in the Partnership’s consolidated financial statements.

As of September 30, 2021, ET’s outstanding preferred units included 950,000 Series A Preferred Units, 550,000 Series B Preferred Units, 18,000,000 Series C Preferred Units, 17,800,000 Series D Preferred Units, 32,000,000 Series E Preferred Units, 500,000 Series F Preferred Units, 1,100,000 Series G Preferred Units and 900,000 Series H Preferred Units.

The following table summarizes changes in the ET Preferred Units:


	Preferred Unitholders
	Series A		Series B		Series C		Series D		Series E		Series F		Series G		Series H		Total





Balance, March 31, 2021	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Preferred units conversion	943		547		440		434		786		504		1,114		—		4,768
Units issued for cash	—		—		—		—		—		—		—		889		889
Distributions to partners	—		—		(8)		(9)		(15)		(17)		(39)		—		(88)
Other, net	—		—		—		—		—		—		—		(1)		(1)
Net income	15		9		8		9		15		8		20		2		86
Balance, June 30, 2021	958		556		440		434		786		495		1,095		890		5,654
Distributions to partners	(30)		(18)		(8)		(9)		(15)		—		—		—		(80)
Other, net	—		—		—		—		—		—		—		(2)		(2)
Net income	15		9		8		9		15		8		20		15		99
Balance, September 30, 2021	$	943	$	547	$	440	$	434	$	786	$	503	$	1,115	$	903	$	5,671

Cash Distributions on ET Preferred Units

Distributions declared on the ET Preferred Units were as follows:


Period Ended	Record Date	Payment Date	Series A (1)		Series B (1)		Series C		Series D		Series E		Series F (1)		Series G (1)		Series H (1)

March 31, 2021	May 3, 2021	May 17, 2021	$	—	$	—	$	0.4609	$	0.4766	$	0.4750	$	33.75	$	35.625	$	—
June 30, 2021	August 2, 2021	August 16, 2021	31.25		33.125		0.4609		0.4766		0.4750		—		—		—
September 30, 2021	November 1, 2021	November 15, 2021	—		—		0.4609		0.4766		0.4750		33.75		35.625		27.08		(2)

(1)Series A, Series B, Series F, Series G and Series H distributions are paid on a semi-annual basis.

(2)Represents initial prorated distribution.

Description of ET Preferred Units

Following is a summary of the distribution and redemption rights associated with the ET Preferred Units:

•Series A Preferred Units. Distributions on the Series A Preferred Units will accrue and be cumulative to, but excluding, February 15, 2023, at a rate of 6.250% per annum of the stated liquidation preference of $1,000. On and after February 15, 2023, distributions on the Series A Preferred Units will accumulate at a percentage of the $1,000 liquidation preference equal to an annual floating rate of the three-month LIBOR, determined quarterly, plus a spread of 4.028% per annum. Distributions on the Series A Preferred Units will be payable semi-annually in arrears on the 15th day of February and August of each year. The Series A Preferred Units are redeemable at ET’s option on or after February 15, 2023 at a redemption price of $1,000 per Series A Preferred Unit, plus an amount equal to all accumulated and unpaid distributions thereon to, but excluding, the date of redemption.

•Series B Preferred Units. Distributions on the Series B Preferred Units will accrue and be cumulative to, but excluding, February 15, 2028, at a rate of 6.625% per annum of the stated liquidation preference of $1,000. On and after February 15, 2028, distributions on the Series B Preferred Units will accumulate at a percentage of the $1,000 liquidation preference equal to an annual floating rate of the three-month LIBOR, determined quarterly, plus a spread of 4.155% per annum. Distributions on the Series B Preferred Units will be payable semi-annually in arrears on the 15th day of February and August of each year. The Series B Preferred Units are redeemable at ET’s option on or after February 15, 2028 at a redemption price of $1,000 per Series B Preferred Unit, plus an amount equal to all accumulated and unpaid distributions thereon to, but excluding, the date of redemption.

•Series C Preferred Units. Distributions on the Series C Preferred Units will accrue and be cumulative to, but excluding, May 15, 2023, at a rate of 7.375% per annum of the stated liquidation preference of $25. On and after May 15, 2023, distributions on the Series C Preferred Units will accumulate at a percentage of the $25 liquidation preference equal to an annual floating rate of the three-month LIBOR, determined quarterly, plus a spread of 4.530% per annum. Distributions on the Series C Preferred Units will be payable quarterly in arrears on the 15th day of February, May, August and November of each year. The Series C Preferred Units are redeemable at ET’s option on or after May 15, 2023 at a redemption price of $25 per Series C Preferred Unit, plus an amount equal to all accumulated and unpaid distributions thereon to, but excluding, the date of redemption.

•Series D Preferred Units. Distributions on the Series D Preferred Units will accrue and be cumulative to, but excluding, August 15, 2023, at a rate of 7.625% per annum of the stated liquidation preference of $25. On and after August 15, 2023, distributions on the Series D Preferred Units will accumulate at a percentage of the $25 liquidation preference equal to an annual floating rate of the three-month LIBOR, determined quarterly, plus a spread of 4.738% per annum. Distributions on the Series D Preferred Units will be payable quarterly in arrears on the 15th day of February, May, August and November of each year. The Series D Preferred Units are redeemable at ET’s option on or after August 15, 2023 at a redemption price of $25 per Series D Preferred Unit, plus an amount equal to all accumulated and unpaid distributions thereon to, but excluding, the date of redemption.

•Series E Preferred Units. Distributions on the Series E Preferred Units will accrue and be cumulative to, but excluding, May 15, 2024, at a rate of 7.600% per annum of the stated liquidation preference of $25. On and after May 15, 2024, distributions on the Series E Preferred Units will accumulate at a percentage of the $25 liquidation preference equal to an annual floating rate of the three-month LIBOR, determined quarterly, plus a spread of 5.161% per annum. Distributions on the Series E Preferred Units will be payable quarterly in arrears on the 15th day of February, May, August and November of each year. The Series E Preferred Units are redeemable at ET’s option on or after May 15, 2024 at a redemption price of $25 per Series E Preferred Unit, plus an amount equal to all accumulated and unpaid distributions thereon to, but excluding, the date of redemption.

•Series F Preferred Units. Distributions on the Series F Preferred Units will accrue and be cumulative to, but excluding, May 15, 2025, at a rate equal to 6.750% per annum of the $1,000 liquidation preference. On and after May 15, 2025, the distribution rate on the Series F Preferred Units will equal a percentage of the $1,000 liquidation preference equal

to the five-year U.S. treasury rate plus a spread of 5.134% per annum. Distributions on the Series F Preferred Units will be payable semi-annually in arrears on the 15th day of May and November of each year. The Series F Preferred Units are redeemable at ET’s option on or after May 15, 2025 at a redemption price of $1,000 per Series F Preferred Unit, plus an amount equal to all accumulated and unpaid distributions thereon to, but excluding, the date of redemption.

•Series G Preferred Units. Distributions on the Series G Preferred Units will accrue and be cumulative to, but excluding, May 15, 2030, at a rate equal to 7.125% per annum of the $1,000 liquidation preference. On and after May 15, 2030, the distribution rate on the Series G Preferred Units will equal a percentage of the $1,000 liquidation preference equal to the five-year U.S. treasury rate plus a spread of 5.306% per annum. Distributions on the Series G Preferred Units will be payable semi-annually in arrears on the 15th day of May and November of each year. The Series G Preferred Units are redeemable at ET’s option on or after May 15, 2030 at a redemption price of $1,000 per Series G Preferred Unit, plus an amount equal to all accumulated and unpaid distributions thereon to, but excluding, the date of redemption.

•Series H Preferred Units. On June 15, 2021, the Partnership issued 900,000 Series H Preferred Units at a price to the public of $1,000 per unit. Distributions on the Series H Preferred Units will accrue and be cumulative to, but excluding, November 15, 2026, at a rate equal to 6.500% per annum of the $1,000 liquidation preference. On and after November 15, 2026 and each fifth anniversary thereafter, the distribution rate on the Series H Preferred Units will reset to be a percentage of the $1,000 liquidation preference equal to the five-year U.S. treasury rate plus a spread of 5.694% per annum. Distributions on the Series H Preferred Units will be payable semi-annually in arrears on the 15th day of May and November of each year. The Series H Preferred Units are redeemable at ET’s option during the three-month period prior to, and including, each distribution reset date at a redemption price of $1,000 per Series H Preferred Unit, plus an amount equal to all accumulated and unpaid distributions thereon to, but excluding, the date of redemption.

Noncontrolling Interests

The Partnership’s consolidated financial statements include Sunoco LP and USAC, both of which are publicly traded master limited partnerships, as well as other less-than-wholly-owned, consolidated joint ventures. The following sections describe cash distributions made by our publicly traded subsidiaries, Sunoco LP and USAC, both of which are required by their respective partnership agreements to distribute all cash on hand (less appropriate reserves determined by the boards of directors of their respective general partners) subsequent to the end of each quarter.

Sunoco LP Cash Distributions

Distributions on Sunoco LP’s units declared and/or paid by Sunoco LP subsequent to December 31, 2020 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2020

February 8, 2021

February 19, 2021

0.8255

March 31, 2021

May 11, 2021

May 19, 2021

0.8255

June 30, 2021

August 6, 2021

August 19, 2021

0.8255

September 30, 2021

November 5, 2021

November 19, 2021

0.8255

USAC Cash Distributions

Distributions on USAC’s units declared and/or paid by USAC subsequent to December 31, 2020 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2020

January 25, 2021

February 5, 2021

0.525

March 31, 2021

April 26, 2021

May 7, 2021

0.525

June 30, 2021

July 26, 2021

August 6, 2021

0.525

September 30, 2021

October 25, 2021

November 5, 2021

0.525

Accumulated Other Comprehensive Income (Loss)

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


	September 30, 2021		December 31, 2020
Available-for-sale securities	$	23	$	18
Foreign currency translation adjustment	12		7
Actuarial loss related to pensions and other postretirement benefits	(1)		(7)
Investments in unconsolidated affiliates, net	(13)		(14)

Total AOCI, net of tax	21		4
Amounts attributable to noncontrolling interest	(2)		2
Total AOCI included in partners’ capital, net of tax	$	19	$	6

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities

9 Months Ended

Sep. 30, 2021

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

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities

REGULATORY MATTERS, COMMITMENTS, CONTINGENCIES AND ENVIRONMENTAL LIABILITIES

Winter Storm Impacts

Winter Storm Uri, which occurred in February 2021, resulted in one-time impacts to the Partnership’s consolidated net income and also affected the results of operations in certain segments. The recognition of the impacts of Winter Storm Uri during the nine months ended September 30, 2021 required management to make certain estimates and assumptions, including estimates of expected credit losses and assumptions related to the resolution of disputes with counterparties with respect to certain purchases and sales of natural gas. The ultimate realization of credit losses and the resolution of disputed purchases and sales of natural gas could materially impact the Partnership’s financial condition and results of operations in future periods.

FERC Proceedings

By the Order issued January 16, 2019, the FERC initiated a review of Panhandle’s existing rates pursuant to Section 5 of the Natural Gas Act (“NGA”) to determine whether the rates currently charged by Panhandle are just and reasonable and set the matter for hearing. On August 30, 2019, Panhandle filed a general rate proceeding under Section 4 of the NGA. The Natural Gas Act Section 5 and Section 4 proceedings were consolidated by order of the Chief Judge on October 1, 2019. A hearing in the combined proceedings commenced on August 25, 2020 and adjourned on September 15, 2020. The initial decision by the administrative law judge was issued on March 26, 2021. On April 26, 2021, Panhandle filed its brief on exceptions to the initial decision. On May 17, 2021, Panhandle filed its brief opposing exceptions in this proceeding.

In May 2021, the FERC commenced an audit of Sunoco Pipeline LP (“SPLP”) for the period from January 1, 2018 to present to evaluate SPLP’s compliance with its FERC oil tariffs, the accounting requirements of the Uniform System of Accounts as prescribed by the FERC, and the FERC’s Form No. 6, including Page 700, reporting requirements. The audit is ongoing.

Commitments

In the normal course of business, our subsidiaries purchase, process and sell natural gas pursuant to long-term contracts and enter into long-term transportation and storage agreements. Such contracts contain terms that are customary in the industry. We believe that the terms of these agreements are commercially reasonable and will not have a material adverse effect on the Partnership’s financial position or results of operations.

Our joint venture agreements require that we fund our proportionate share of capital contributions to our unconsolidated affiliates. Such contributions will depend upon the unconsolidated affiliates’ capital requirements, such as for funding capital projects or repayment of long-term obligations.

We have certain non-cancelable rights-of-way (“ROW”) commitments, which require fixed payments and either expire upon our chosen abandonment or at various dates in the future. The table below reflects ROW expense included in operating expenses in the accompanying consolidated statements of operations:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
ROW expense	$	18	$	13	$	33	$	32

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.

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 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.

As of September 30, 2021 and December 31, 2020, accruals of approximately $130 million and $101 million, respectively, were reflected on our consolidated balance sheets related to contingencies that met both the probable and reasonably estimable criteria. In addition, we may recognize additional contingent losses in the future related to (i) contingent matters for which a loss is currently considered reasonably possible but not probable and/or (ii) losses in excess of amounts that have already been accrued for such contingent matters. In some of these cases, we are not able to estimate possible losses or a range of possible losses in excess of amounts accrued. For such matters where additional contingent losses can be reasonably estimated, the range of additional losses is estimated to be up to approximately $80 million.

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 or our estimates of reasonably possible losses prior to resolution of a particular contingency based on changes in facts and circumstances or changes in the expected outcome.

Dakota Access Pipeline

On July 27, 2016, the Standing Rock Sioux Tribe (“SRST”) filed a lawsuit in the United States District Court for the District of Columbia (“District Court”) challenging permits issued by the United States Army Corps of Engineers (“USACE”) that allowed Dakota Access to cross the Missouri River at Lake Oahe in North Dakota. The case was subsequently amended to challenge an easement issued by the USACE that allowed the pipeline to cross land owned by the USACE adjacent to the Missouri River. Dakota Access and the Cheyenne River Sioux Tribe (“CRST”) intervened. Separate lawsuits filed by the Oglala Sioux Tribe (“OST”) and the Yankton Sioux Tribe (“YST”) were consolidated with this action and several individual tribal members intervened (collectively, with SRST and CRST, the “Tribes”). On March 25, 2020, the District Court remanded the case back to the USACE for preparation of an Environment Impact Statement (“EIS”). On July 6, 2020, the District Court vacated the easement and ordered Dakota Access to be shut down and emptied of oil by August 5, 2020. Dakota Access and the USACE appealed to the United States Court of Appeals for the District of Columbia (“Court of Appeals”) which granted an administrative stay of the District Court’s July 6 order and ordered further briefing on whether to fully stay the July 6 order. On August 5, 2020, the Court of Appeals 1) granted a stay of the portion of the District Court order that required Dakota Access to shut the pipeline down and empty it of oil, 2) denied a motion to stay the March 25 order pending a decision on the merits by the Court of Appeals as to whether the USACE would be required to prepare an EIS, and 3) denied a motion to stay the District Court’s order to vacate the easement during this appeal process. The August 5 order also states that the Court of Appeals expected the USACE to clarify its

position with respect to whether USACE intended to allow the continued operation of the pipeline notwithstanding the vacatur of the easement and that the District Court may consider additional relief, if necessary.

On August 10, 2020, the District Court ordered the USACE to submit a status report by August 31, 2020, clarifying its position with regard to its decision-making process with respect to the continued operation of the pipeline. On August 31, 2020, the USACE submitted a status report that indicated that it considered the presence of the pipeline at the Lake Oahe crossing without an easement to constitute an encroachment on federal land, and that it was still considering whether to exercise its enforcement discretion regarding this encroachment. The Tribes subsequently filed a motion seeking an injunction to stop the operation of the pipeline and both of the USACE and Dakota Access filed briefs in opposition of the motion for injunction. The motion for injunction was fully briefed as of January 8, 2021.

On January 26, 2021, the Court of Appeals affirmed the District Court’s March 25, 2020 order requiring an EIS and its July 6, 2020 order vacating the easement. In this same January 26 order, the Court of Appeals also overturned the District Court’s July 6, 2020 order that the pipeline shut down and be emptied of oil. Dakota Access filed for rehearing en banc on April 12, 2021, which the Court of Appeals denied. Dakota Access filed a petition with the U.S. Supreme Court to hear the case.

The District Court scheduled a status conference for February 10, 2021 to discuss the effects of the Court of Appeals’ January 26, 2021 order on the pending motion for injunctive relief, as well as USACE’s expectations as to how it will proceed regarding its enforcement discretion regarding the easement. At the request of the USACE, on February 9, 2021 the District Court granted a two-month continuance for the status conference until April 9, 2021. On April 9, 2021, the District Court granted Dakota Access’s request for the opportunity to file updates to its declarations supporting the opposition to injunctive relief and thereafter granted the Tribes’ request to file updates to their declarations supporting their position with respect to injunctive relief. Dakota Access and the Tribes filed their supplemental declarations on April 19, 2021 and April 26, 2021, respectively. On April 26, 2021, the District Court requested that USACE advise it by May 3, 2021 as to USACE’s current position, if it has one, with respect to the Motion. On May 3, 2021, USACE advised the District Court that it had not changed its position with respect to its opposition to the Tribes’ motion for injunction. The USACE also advised the District Court that it expected that the EIS will be completed by March 2022. On May 21, 2021 the District Court denied the Plaintiffs’ request for an injunction. The District Court further directed the parties to file a joint status report by June 11, 2021 concerning potential next steps in the litigation.

On June 22, 2021, the District Court terminated the consolidated lawsuits and dismissed all remaining outstanding counts without prejudice. The Court noted the availability of a motion to reopen the terminated proceedings if, for example, one of its earlier orders were violated. The Court also noted that should the Plaintiffs seek to challenge the forthcoming EIS, they would need to do so by filing a new complaint, and they could ask that it be assigned to the same Judge.

The pipeline continues to operate pending completion of the EIS. The USACE now estimates that the EIS will be complete by the end of 2022. ET cannot determine when or how future lawsuits will be resolved or the impact they may have on the Dakota Access pipelines; however, ET expects after the law and complete record are fully considered, any such proceeding will be resolved in a manner that will allow the pipeline to continue to operate.

In addition, lawsuits and/or regulatory proceedings or actions of this or a similar nature could result in interruptions to construction or operations of current or future projects, delays in completing those projects and/or increased project costs, all of which could have an adverse effect on our business and results of operations.

Mont Belvieu Incident

On June 26, 2016, a hydrocarbon storage well located on another operator’s facility adjacent to Lone Star NGL LLC’s (“Lone Star”), now known as Energy Transfer GC NGLs LLC, facilities in Mont Belvieu, Texas experienced an over-pressurization resulting in a subsurface release. The subsurface release caused a fire at Lone Star’s South Terminal and damage to Lone Star’s storage well operations at its South and North Terminals. Normal operations resumed at the facilities in the fall of 2016, with the exception of one of Lone Star’s storage wells at the North Terminal that has not been returned to service. Lone Star has obtained payment for most of the losses it has submitted to the adjacent operator. Lone Star continues to quantify and seek reimbursement for outstanding losses.

MTBE Litigation

ETC Sunoco Holdings LLC and Energy Transfer R&M (collectively, “Sunoco Defendants”) are defendants in lawsuits alleging MTBE contamination of groundwater. The plaintiffs, state-level governmental entities, assert product liability, nuisance, trespass, negligence, violation of environmental laws, and/or deceptive business practices claims. The plaintiffs seek to recover compensatory damages, and in some cases also seek natural resource damages, injunctive relief, punitive damages, and attorneys’ fees.

As of September 30, 2021, Sunoco Defendants are defendants in five cases, including one case each initiated by the States of Maryland and Rhode Island, one by the Commonwealth of Pennsylvania and two by the Commonwealth of Puerto Rico. The more recent Puerto Rico action is a companion case alleging damages for additional sites beyond those at issue in the initial Puerto Rico action. The actions brought by the State of Maryland and Commonwealth of Pennsylvania have also named as defendants ETO, ETP Holdco Corporation, and Sunoco Partners Marketing & Terminals L.P. (“SPMT”).

It is reasonably possible that a loss may be realized in the remaining cases; however, we are unable to estimate the possible loss or range of loss in excess of amounts accrued. 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 such adverse determination occurs, but such an adverse determination likely would not have a material adverse effect on the Partnership’s consolidated financial position.

Regency Merger Litigation

On June 10, 2015, Adrian Dieckman (“Dieckman” or “Plaintiff”), a purported Regency unitholder, filed a class action complaint related to the Regency-ETO merger (the “Regency Merger”) in the Court of Chancery of the State of Delaware (the “Regency Merger Litigation”), on behalf of Regency’s common unitholders against Regency GP LP, Regency GP LLC, ET, ETO, Energy Transfer Partners GP, L.P., and the members of Regency’s board of directors.

The Regency Merger Litigation alleges that the Regency Merger breached the Regency partnership agreement. On March 29, 2016, the Delaware Court of Chancery granted the defendants’ motion to dismiss the lawsuit in its entirety. Plaintiff appealed, and the Delaware Supreme Court reversed the judgment of the Court of Chancery. Plaintiff then filed an Amended Verified Class Action Complaint, which defendants moved to dismiss. The Court of Chancery granted in part and denied in part the motions to dismiss, dismissing the claims against all defendants other than Regency GP LP and Regency GP LLC (the “Regency Defendants”). The Court of Chancery later granted Plaintiff’s unopposed motion for class certification. Trial was held on December 10-16, 2019, and a post-trial hearing was held on May 6, 2020. On February 15, 2021, the Court of Chancery ruled in favor of the Regency Defendants on all claims at issue in this litigation, determined that the Regency Merger was fair and reasonable to Regency, and denied Plaintiff any relief.

On March 19, 2021, Plaintiff filed a notice of appeal, and oral argument was held on October 20, 2021. The Regency Defendants cannot predict the outcome of this appeal but intend to vigorously oppose it.

Litigation Filed By or Against Williams

In April and May 2016, the Williams Companies, Inc. (“Williams”) filed two lawsuits (the “Williams Litigation”) against ET, LE GP, and, in one of the lawsuits, Energy Transfer Corp LP, ETE Corp GP, LLC, and Energy Transfer Equity GP, LLC (collectively, “ET Defendants”), alleging that ET Defendants breached their obligations under the ET-Williams merger agreement (the “Merger Agreement”). In general, Williams alleges that ET Defendants breached the Merger Agreement by (a) failing to use commercially reasonable efforts to obtain from Latham & Watkins LLP (“Latham”) the delivery of a tax opinion concerning Section 721 of the Internal Revenue Code (“721 Opinion”), (b) issuing the Partnership’s series A convertible preferred units (the “Issuance”), and (c) making allegedly untrue representations and warranties in the Merger Agreement.

After a two-day trial on June 20 and 21, 2016, the Court ruled in favor of ET Defendants and issued a declaratory judgment that ET could terminate the merger after June 28, 2016 because of Latham’s inability to provide the required 721 Opinion. The Court did not reach a decision regarding Williams’ claims related to the Issuance nor the alleged untrue representations and warranties. On March 23, 2017, the Delaware Supreme Court affirmed the Court’s ruling on the June 2016 trial.

In September 2016, the parties filed amended pleadings. Williams filed an amended complaint seeking a $410 million termination fee based on the alleged breaches of the Merger Agreement listed above. ET Defendants filed amended counterclaims and affirmative defenses, asserting that Williams materially breached the Merger Agreement by, among other things, (a) failing to use its reasonable best efforts to consummate the merger, (b) failing to provide material information to ET for inclusion in the Form S-4 related to the merger, (c) failing to facilitate the financing of the merger, and (d) breaching the Merger Agreement’s forum-selection clause.

Trial was held regarding the parties’ amended claims on May 10-17, 2021, and a post-trial hearing was held on September 16, 2021. ET Defendants cannot predict the outcome of the Williams Litigation nor can the ET Defendants predict the amount of time and expense that will be required to resolve the Williams Litigation. ET Defendants believe that Williams’ claims are without merit and intend to defend vigorously against them.

Rover

On November 3, 2017, the State of Ohio and the Ohio Environmental Protection Agency (“Ohio EPA”) filed suit against Rover and other defendants seeking to recover civil penalties allegedly owed and certain injunctive relief related to permit compliance. The defendants filed several motions to dismiss, which were granted on all counts. The Ohio EPA appealed, and on December 9, 2019, the Fifth District Court of Appeals entered a unanimous judgment affirming the trial court. The Ohio EPA sought review from the Ohio Supreme Court, which the defendants opposed in briefs filed in February 2020. On April 22, 2020, the Ohio Supreme Court granted the Ohio EPA’s request for review. Briefing has concluded and oral argument was held on January 26, 2021. The parties are awaiting a decision.

Revolution

On September 10, 2018, a pipeline release and fire (the “Incident”) occurred on the Revolution pipeline, a natural gas gathering line located in Center Township, Beaver County, Pennsylvania. There were no injuries.

The Pennsylvania Office of Attorney General has commenced an investigation regarding the Incident, and the United States Attorney for the Western District of Pennsylvania has issued a federal grand jury subpoena for documents relevant to the Incident. The scope of these investigations is not further known at this time.

Chester County, Pennsylvania Investigation

In December 2018, the former Chester County District Attorney (the “Chester County DA”) sent a letter to the Partnership stating that his office was investigating the Partnership and related entities for “potential crimes” related to the Mariner East pipelines.

Subsequently, the matter was submitted to an Investigating Grand Jury in Chester County, Pennsylvania, which has issued subpoenas seeking documents and testimony. On September 24, 2019, the Chester County DA sent a Notice of Intent to the Partnership of its intent to pursue an abatement action if certain conditions were not remediated. The Partnership responded to the Notice of Intent within the prescribed time period.

In December 2019, the Chester County DA announced charges against a current employee related to the provision of security services. On June 25, 2020, a preliminary hearing was held on the charges against the employee, and the judge dismissed all charges.

On April 22, 2021, the Chester County DA filed a Complaint and Consent Decree in the Court of Common Pleas of Chester County, Pennsylvania constituting a settlement agreement between the Chester County DA and the Partnership. A status conference was held on May 10, 2021, and an Amended Consent Decree was filed on June 16, 2021, which has not yet been entered by the Court.

Delaware County, Pennsylvania Investigation

On March 11, 2019, the Delaware County District Attorney’s Office (the “Delaware County DA”) announced that the Delaware County DA and the Pennsylvania Attorney General’s Office (the “AG”), at the request of the Delaware County DA, are conducting an investigation of alleged criminal misconduct involving the construction and related activities of the Mariner East pipelines in Delaware County. On March 16, 2020, the AG served a Statewide Investigating Grand Jury subpoena for documents relating to inadvertent returns and water supplies related to the Mariner East pipelines. The Partnership has complied with the subpoena. On October 5, 2021, the AG held a press conference related to the Mariner East pipelines, released a Grand Jury Presentment and subsequently filed a criminal complaint against ET in the Magisterial District Court No. 12-2-02 in Dauphin County, Pennsylvania with respect to 47 misdemeanor charges related to the discharge of industrial waste and pollution and one felony charge related to the failure to report information related to the discharges. The Partnership will defend itself vigorously against these charges. On October 13, 2021, the AG announced that he is running for Governor of Pennsylvania.

Shareholder Litigation Regarding Pennsylvania Pipeline Construction

Four purported unitholders of ET filed derivative actions against various past and current members of ET’s Board of Directors, LE GP, and ET, as a nominal defendant that assert claims for breach of fiduciary duties, unjust enrichment, waste of corporate assets, breach of ET’s limited partnership agreement, tortious interference, abuse of control, and gross mismanagement related primarily to matters involving the construction of pipelines in Pennsylvania. They also seek damages and changes to ET’s corporate governance structure. See Bettiol v. LE GP, Case No. 3:19-cv-02890-X (N.D. Tex.); Davidson v. Kelcy L. Warren, Cause No. DC-20-02322 (44th Judicial District of Dallas County, Texas); Harris v. Kelcy L. Warren, Case No. 2:20-cv-00364-GAM (E.D. Pa.); and King v. LE GP, Case No. 3:20-cv-00719-X (N.D. Tex.).

Another purported unitholder of ET, Allegheny County Employees’ Retirement System (“ACERS”), individually and on behalf of all others similarly situated, filed a suit under the federal securities laws purportedly on behalf of a class, against ET and three of ET’s directors, Kelcy L. Warren, John W. McReynolds, and Thomas E. Long. See Allegheny County Emps.’ Ret. Sys. v. Energy Transfer LP, Case No. 2:20-00200-GAM (E.D. Pa.). On June 15, 2020, ACERS filed an amended complaint and added as additional defendants ET directors Marshall McCrea and Matthew Ramsey, as well as Michael J. Hennigan and Joseph McGinn. The amended complaint asserts claims for violations of Sections 10(b) and 20(a) of the Exchange Act and Rule 10b-5 promulgated thereunder related primarily to matters involving the construction of pipelines in Pennsylvania. On August 14, 2020, the defendants filed a motion to dismiss ACERS’ amended complaint. On April 6, 2021, the court granted in part and denied in part the defendants’ motion to dismiss. The court held that ACERS could proceed with its claims regarding certain statements put at issue by the amended complaint while also dismissing claims based on other statements. The court also dismissed without prejudice the claims against defendants McReynolds, McGinn, and Hennigan. The defendants cannot predict the outcome of these lawsuits or any lawsuits that might be filed subsequent to the date of this filing; nor can the defendants predict the amount of time and expense that will be required to resolve these lawsuits. However, the defendants believe that the claims are without merit and intend to vigorously contest them.

Cline Class Action

On July 7, 2017, Perry Cline filed a class action complaint in the Eastern District of Oklahoma against Sunoco (R&M), LLC (now known as Energy Transfer R&M) and SPMT that alleged SPMT failed to make timely payments of oil and gas proceeds from Oklahoma wells and to pay statutory interest for those untimely payments. On October 3, 2019, the Court certified a class to include all persons who received untimely payments from Oklahoma wells on or after July 7, 2012 and who have not already been paid statutory interest on the untimely payments (the “Class”). Excluded from the Class are those entitled to payments of proceeds that qualify as “minimum pay,” prior period adjustments, and pass through payments, as well as governmental agencies and publicly traded oil and gas companies.

After a bench trial, on August 17, 2020, Judge John Gibney (sitting from the Eastern District of Virginia) issued an opinion that awarded the Class actual damages of $74.8 million for late payment interest for identified and unidentified royalty owners and interest-on-interest. This amount was later amended to $80.7 million to account for interest accrued from trial (the “Order”). Judge Gibney also awarded punitive damages in the amount of $75 million. The Class is also seeking attorneys’ fees.

On August 27, 2020, SPMT filed its Notice of Appeal with the 10th Circuit and appealed the entirety of the Order. The matter has now been fully briefed, and oral argument has been set for November 15, 2021. SPMT cannot predict the outcome of the case, nor can SPMT predict the amount of time and expense that will be required to resolve the appeal, but intends to vigorously appeal the entirety of the Order.

Environmental Matters

Our operations are subject to extensive federal, tribal, 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. Historically, our environmental compliance costs have not had a material adverse effect on our results of operations but there can be no assurance that such costs will not be material in the future or that such future compliance with existing, amended or new legal requirements will not have a material adverse effect on our business and operating results. 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 investigatory, remedial and corrective action obligations, natural resource damages, the issuance of injunctions in affected areas 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 our 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 polychlorinated biphenyls (“PCBs”). PCB assessments are ongoing and, in some cases, our subsidiaries could be contractually responsible for contamination caused by other parties.

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

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

•the Partnership 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 September 30, 2021, the Partnership had been named as a PRP at approximately 33 identified or potentially identifiable “Superfund” sites under federal and/or comparable state law. The Partnership is usually one of a number of companies identified as a PRP at a site. The Partnership has reviewed the nature and extent of its involvement at each site and other relevant circumstances and, based upon the Partnership’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 require disclosure in our consolidated financial statements.


	September 30, 2021		December 31, 2020
Current	$	44	$	44
Non-current	253		262
Total environmental liabilities	$	297	$	306

We have 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 nine months ended September 30, 2021 and 2020, the Partnership recorded $18 million and $22 million, respectively, of expenditures related to environmental cleanup programs.

Our pipeline operations are subject to regulation by the United States Department of Transportation under PHMSA, pursuant to which PHMSA has established requirements relating to the design, installation, testing, construction, operation, replacement and management of pipeline facilities. Moreover, 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.

Our operations are also subject to the requirements of OSHA, and comparable state laws that regulate the protection of the health and safety of employees. In addition, the Occupational Safety and Health Administration’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 past costs for OSHA required activities, including general industry standards, record keeping requirements, and monitoring of occupational exposure to regulated substances have not had a material adverse effect on our results of operations, but there is no assurance that such costs will not be material in the future.

Revenue (Notes)

9 Months Ended

Sep. 30, 2021

Revenue [Abstract]

Revenue from Contract with Customer [Text Block]

REVENUE

Disaggregation of Revenue

The Partnership’s consolidated financial statements reflect eight reportable segments, which also represent the level at which the Partnership aggregates revenue for disclosure purposes. Note 13 depicts the disaggregation of revenue by segment.

Contract Balances with Customers

The Partnership satisfies its obligations by transferring goods or services in exchange for consideration from customers. The timing of performance may differ from the timing the associated consideration is paid to or received from the customer, thus resulting in the recognition of a contract asset or a contract liability.

The Partnership recognizes a contract asset when making upfront consideration payments to certain customers or when providing services to customers prior to the time at which the Partnership is contractually allowed to bill for such services.

The Partnership recognizes a contract liability if the customer’s payment of consideration precedes the Partnership’s fulfillment of the performance obligations. Certain contracts contain provisions requiring customers to pay a fixed minimum fee, but allow customers to apply such fees against services to be provided at a future point in time. These amounts are reflected as deferred revenue until the customer applies the deficiency fees to services provided or becomes unable to use the fees as payment for future services due to expiration of the contractual period the fees can be applied or physical inability of the customer to utilize the fees due to capacity constraints. Additionally, Sunoco LP maintains some franchise agreements requiring dealers to make one-time upfront payments for long term license agreements. Sunoco LP recognizes a contract liability when the upfront payment is received and recognizes revenue over the term of the license.

The following table summarizes the consolidated activity of our contract liabilities:


	Contract Liabilities
Balance, December 31, 2020	$	308
Additions	611
Revenue recognized	(512)
Balance, September 30, 2021	$	407

Balance, December 31, 2019	$	377
Additions	598
Revenue recognized	(614)
Balance, September 30, 2020	$	361

The balances of Sunoco LP’s contract assets were as follows:


	September 30, 2021		December 31, 2020
Contract balances:
Contract assets	$	148	$	121
Accounts receivable from contracts with customers	473		256

Performance Obligations

At contract inception, the Partnership assesses the goods and services promised in its contracts with customers and identifies a performance obligation for each promise to transfer a good or service (or bundle of goods or services) that is distinct. To identify the performance obligations, the Partnership considers all the goods or services promised in the contract, whether explicitly stated or implied based on customary business practices. For a contract that has more than one performance obligation, the Partnership allocates the total contract consideration it expects to be entitled to, to each distinct performance obligation based on a standalone-selling price basis. Revenue is recognized when (or as) the performance obligations are satisfied, that is, when the customer obtains control of the good or service. Certain of our contracts contain variable components, which, when combined with the fixed component are considered a single performance obligation. For these types of contacts, only the fixed component of the contracts are included in the table below.

As of September 30, 2021, the aggregate amount of transaction price allocated to unsatisfied (or partially satisfied) performance obligations was $40.13 billion, and the Partnership expects to recognize this amount as revenue within the time bands illustrated below:


	Years Ending December 31,
	2021
	(remainder)		2022		2023		Thereafter		Total
Revenue expected to be recognized on contracts with customers existing as of September 30, 2021	$	1,662	$	6,010	$	5,504	$	26,950	$	40,126

- Definition

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-URI http://asc.fasb.org/topic&trid=49130388

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130551-203045

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 13
-Subparagraph (b)(2)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130556-203045

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
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Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
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-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130550-203045

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
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-Subparagraph (e)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130554-203045

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130554-203045

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-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
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Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
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-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130558-203045

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
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-Section 50
-Paragraph 12
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130554-203045

+ Details

Derivative Assets And Liabilities

9 Months Ended

Sep. 30, 2021

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, we 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 in 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 utilize swaps, futures and other derivative instruments to mitigate the risk associated with market movements in the price of refined products and NGLs to manage our storage facilities and the purchase and sale of purity NGL. 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. 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:


	September 30, 2021		December 31, 2020
	Notional Volume	Maturity	Notional Volume	Maturity
Mark-to-Market Derivatives
(Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX (1)	(81,963)	2021-2022	(44,225)	2021-2022
Fixed Swaps/Futures	475	2021-2023	1,603	2021-2022



Power (Megawatt):
Forwards	712,400	2021-2029	1,392,400	2021-2029
Futures	(640,800)	2021-2022	18,706	2021-2022
Options – Puts	290,400	2021-2022	519,071	2021
Options – Calls	36,704	2021-2022	2,343,293	2021



(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(8,893)	2021-2022	(29,173)	2021-2022
Swing Swaps IFERC	(48,675)	2021-2022	11,208	2021
Fixed Swaps/Futures	(45,588)	2021-2023	(53,575)	2021-2022
Forward Physical Contracts	(10,071)	2021	(11,861)	2021

NGLs (MBbls) – Forwards/Swaps	2,785	2021-2023	(5,840)	2021-2022
Refined Products (MBbls) – Futures	(3,272)	2021-2023	(2,765)	2021
Crude (MBbls) – Forwards/Swaps	1,693	2021-2022	—	—

Fair Value Hedging Derivatives
(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(21,255)	2021	(30,113)	2021
Fixed Swaps/Futures	(21,255)	2021	(30,113)	2021
Hedged Item – Inventory	21,255	2021	30,113	2021

(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 variable rate debt. We also manage our interest rate exposure by utilizing interest rate swaps to achieve a desired mix of fixed and variable rate debt. We also utilize forward starting interest rate swaps to lock in the rate on a portion of our anticipated debt issuances.

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


Term	Type(1)	Notional Amount Outstanding
		September 30, 2021		December 31, 2020
July 2021(2)(3)	Forward-starting to pay a fixed rate of 3.55% and receive a floating rate	$	—	$	400
July 2022(2)	Forward-starting to pay a fixed rate of 3.80% and receive a floating rate	400		400
July 2023(2)	Forward-starting to pay a fixed rate of 3.78% and receive a floating rate	200		—
July 2024(2)	Forward-starting to pay a fixed rate of 3.88% and receive a floating rate	200		—

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

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

(3)The July 2021 interest rate swaps were amended in June 2021.

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 the Partnership’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, the Partnership may, at times, require collateral under certain circumstances to mitigate credit risk as necessary. The Partnership also uses industry standard commercial agreements which allow for the netting of exposures associated with transactions executed under a single commercial agreement. Additionally, we utilize master netting agreements to offset credit exposure across multiple commercial agreements with a single counterparty or affiliated group of counterparties.

The Partnership’s counterparties consist of a diverse portfolio of customers across the energy industry, including petrochemical companies, commercial and industrial end-users, oil and gas producers, municipalities, gas and electric utilities, midstream companies and independent power generators. Our overall exposure may be affected positively or negatively by macroeconomic or regulatory changes that impact our 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.

The Partnership has maintenance margin deposits with certain counterparties in the OTC market, primarily with 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 us on or about the settlement date for non-exchange traded derivatives, and we exchange 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 our statement of operations or statement of comprehensive income (loss).

Derivative Summary

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


	Fair Value of Derivative Instruments
	Asset Derivatives				Liability Derivatives
	September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	2	$	25	$	(20)	$	(32)
	2		25		(20)		(32)
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	330		90		(400)		(166)
Commodity derivatives	702		53		(661)		(71)
Interest rate derivatives	—		—		(376)		(448)
	1,032		143		(1,437)		(685)
Total derivatives	$	1,034	$	168	$	(1,457)	$	(717)

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	September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020
Derivatives without offsetting agreements	Derivative liabilities	$	—	$	—	$	(376)	$	(448)
Derivatives in offsetting agreements:
OTC contracts	Derivative assets (liabilities)	702		53		(661)		(71)
Broker cleared derivative contracts	Other current assets (liabilities)	332		115		(420)		(198)
Total gross derivatives		1,034		168		(1,457)		(717)
Offsetting agreements:

Counterparty netting	Derivative assets (liabilities)	(645)		(44)		645		44
Counterparty netting	Other current assets (liabilities)	(327)		(64)		327		64
Total net derivatives		$	62	$	60	$	(485)	$	(609)

We disclose the non-exchange traded financial derivative instruments as derivative 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 table summarizes the location and amounts recognized in our consolidated statements of operations with respect to our derivative financial instruments:


	Location	Amount of Gain (Loss) Recognized in Income on Derivatives
		Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
Derivatives not designated as hedging instruments:
Commodity derivatives – Trading	Cost of products sold	$	14	$	4	$	12	$	15
Commodity derivatives – Non-trading	Cost of products sold	(71)		(44)		(206)		53

Interest rate derivatives	Gains (losses) on interest rate derivatives	1		55		72		(277)

Total		$	(56)	$	15	$	(122)	$	(209)

Reportable Segments

9 Months Ended

Sep. 30, 2021

Segment Reporting [Abstract]

Reportable Segments

REPORTABLE SEGMENTS

Our reportable segments, which conduct their business primarily in the United States, are as follows:

•intrastate transportation and storage;

•interstate transportation and storage;

•midstream;

•NGL and refined products transportation and services;

•crude oil transportation and services;

•investment in Sunoco LP;

•investment in USAC; and

•all other.

Consolidated revenues and expenses reflect the elimination of all material intercompany transactions.

Revenues from our intrastate transportation and storage segment are primarily reflected in natural gas sales and gathering, transportation and other fees. Revenues from our interstate transportation and storage segment are primarily reflected in gathering, transportation and other fees. Revenues from our midstream segment are primarily reflected in natural gas sales, NGL sales and gathering, transportation and other fees. Revenues from our NGL and refined products transportation and services segment are primarily reflected in NGL sales and gathering, transportation and other fees. Revenues from our crude oil transportation and services segment are primarily reflected in crude sales. Revenues from our investment in Sunoco LP segment are primarily reflected in refined product sales. Revenues from our investment in USAC segment are primarily reflected in gathering, transportation and other fees. Revenues from our all other segment are primarily reflected in natural gas sales and gathering, transportation and other fees.

We report Segment Adjusted EBITDA and consolidated Adjusted EBITDA as measures of segment performance. We define Segment Adjusted EBITDA and consolidated Adjusted EBITDA as total partnership 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, inventory valuation adjustments, non-cash impairment charges, losses on extinguishments of debt and other non-operating income or expense items. Inventory adjustments that are excluded from the calculation of Adjusted EBITDA represent only the changes in lower of cost or market reserves on inventory that is carried at LIFO. These amounts are unrealized valuation adjustments applied to Sunoco LP’s fuel volumes remaining in inventory at the end of the period.

Segment Adjusted EBITDA and consolidated Adjusted EBITDA reflect amounts for unconsolidated affiliates based on the same recognition and measurement methods used to record equity in earnings of unconsolidated affiliates. Adjusted EBITDA related to unconsolidated affiliates excludes the same items with respect to the unconsolidated affiliate as those

excluded from the calculation of Segment Adjusted EBITDA and consolidated Adjusted EBITDA, such as interest, taxes, depreciation, depletion, amortization and other non-cash items. Although these amounts are excluded from Adjusted EBITDA related to unconsolidated affiliates, such exclusion should not be understood to imply that we have control over the operations and resulting revenues and expenses of such affiliates. We do not control our unconsolidated affiliates; therefore, we do not control the earnings or cash flows of such affiliates. The use of Segment Adjusted EBITDA or Adjusted EBITDA related to unconsolidated affiliates as an analytical tool should be limited accordingly.

The following tables present financial information by segment:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Revenues:
Intrastate transportation and storage:
Revenues from external customers	$	1,112	$	614	$	5,940	$	1,615
Intersegment revenues	105		40		1,126		148
	1,217		654		7,066		1,763
Interstate transportation and storage:
Revenues from external customers	412		466		1,317		1,365
Intersegment revenues	6		5		33		15
	418		471		1,350		1,380
Midstream:
Revenues from external customers	560		585		1,709		1,477
Intersegment revenues	2,359		792		6,081		2,088
	2,919		1,377		7,790		3,565
NGL and refined products transportation and services:
Revenues from external customers	4,499		2,207		11,726		5,991
Intersegment revenues	763		416		2,048		1,466
	5,262		2,623		13,774		7,457
Crude oil transportation and services:
Revenues from external customers	4,577		2,849		12,497		8,873
Intersegment revenues	1		1		1		4
	4,578		2,850		12,498		8,877
Investment in Sunoco LP:
Revenues from external customers	4,772		2,801		12,626		8,104
Intersegment revenues	7		4		16		53
	4,779		2,805		12,642		8,157
Investment in USAC:
Revenues from external customers	156		158		464		500
Intersegment revenues	3		3		9		9
	159		161		473		509
All other:
Revenues from external customers	576		275		2,481		995
Intersegment revenues	120		92		303		377
	696		367		2,784		1,372
Eliminations	(3,364)		(1,353)		(9,617)		(4,160)
Total revenues	$	16,664	$	9,955	$	48,760	$	28,920


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Segment Adjusted EBITDA:
Intrastate transportation and storage	$	172	$	203	$	3,209	$	630
Interstate transportation and storage	334		425		1,118		1,232
Midstream	556		530		1,321		1,280
NGL and refined products transportation and services	706		762		2,089		2,099
Crude oil transportation and services	496		631		1,490		1,741
Investment in Sunoco LP	198		189		556		580
Investment in USAC	99		104		299		315
All other	18		22		153		62
Adjusted EBITDA (consolidated)	2,579		2,866		10,235		7,939
Depreciation, depletion and amortization	(943)		(912)		(2,837)		(2,715)
Interest expense, net of interest capitalized	(558)		(569)		(1,713)		(1,750)
Impairment losses	—		(1,474)		(11)		(2,803)
Gains (losses) on interest rate derivatives	1		55		72		(277)
Non-cash compensation expense	(26)		(30)		(81)		(93)
Unrealized gains (losses) on commodity risk management activities	(19)		(30)		74		(27)
Inventory valuation adjustments (Sunoco LP)	9		11		168		(126)
Losses on extinguishments of debt	—		—		(8)		(62)
Adjusted EBITDA related to unconsolidated affiliates	(141)		(169)		(400)		(480)
Equity in earnings (losses) of unconsolidated affiliates	71		(32)		191		46
Impairment of investment in an unconsolidated affiliate	—		(129)		—		(129)
Other, net	11		53		—		(48)
Income (loss) before income tax expense	984		(360)		5,690		(525)
Income tax expense	(77)		(41)		(234)		(168)


Net income (loss)	$	907	$	(401)	$	5,456	$	(693)

- 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/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
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+ Details

Operations And Organization Accounting policy (Policies)	9 Months Ended
	Sep. 30, 2021
Accounting Policies [Abstract]
Basis of Accounting, Policy [Policy Text Block]	Basis of Presentation The unaudited financial information included in this Form 10-Q has been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2020, filed with the SEC on February 19, 2021. 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.
Use of Estimates, Policy [Policy Text Block]	Use of Estimates The unaudited consolidated financial statements have been prepared in conformity with GAAP, which requires the use of estimates and assumptions made by management that affect the reported amounts of assets, liabilities, revenues, expenses and the accrual for 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.

Cash And Cash Equivalents Cash and Cash Equivalents (Policies)	9 Months Ended
	Sep. 30, 2021
Supplemental Cash Flow Information [Abstract]
Cash and Cash Equivalents, Unrestricted Cash and Cash Equivalents, Policy [Policy Text Block]	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. The Partnership’s consolidated balance sheets did not include any material amounts of restricted cash as of September 30, 2021 or December 31, 2020. We place our cash deposits and temporary cash investments with high credit quality financial institutions. At times, our cash and cash equivalents may be uninsured or in deposit accounts that exceed the Federal Deposit Insurance Corporation insurance limit.

Inventories Inventories (Policies)	9 Months Ended
Inventories Inventories (Policies)	Sep. 30, 2021
Inventory Disclosure [Abstract]
Inventory, Policy [Policy Text Block]	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.

- Definition

Disclosure of inventory accounting policy for inventory classes, including, but not limited to, basis for determining inventory amounts, methods by which amounts are added and removed from inventory classes, loss recognition on impairment of inventories, and situations in which inventories are stated above cost.

+ References + Details

Fair Value Measurements Fair Value Measurements (Policies)	9 Months Ended
	Sep. 30, 2021
Fair Value Disclosures [Abstract]
Fair Value Measurement, Policy [Policy Text Block]	We have commodity derivatives and interest rate derivatives 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. During the nine months ended September 30, 2021, no transfers were made between any levels within the fair value hierarchy

Revenue Revenue (Policies)

9 Months Ended

Sep. 30, 2021

Revenue from Contract with Customer [Abstract]

Revenue [Policy Text Block]

Disaggregation of Revenue

Revenue Recognition, Deferred Revenue [Policy Text Block]

Contract Balances with Customers

The following table summarizes the consolidated activity of our contract liabilities:


	Contract Liabilities
Balance, December 31, 2020	$	308
Additions	611
Revenue recognized	(512)
Balance, September 30, 2021	$	407

Balance, December 31, 2019	$	377
Additions	598
Revenue recognized	(614)
Balance, September 30, 2020	$	361

Performance ObligationsAt contract inception, the Partnership assesses the goods and services promised in its contracts with customers and identifies a performance obligation for each promise to transfer a good or service (or bundle of goods or services) that is distinct. To identify the performance obligations, the Partnership considers all the goods or services promised in the contract, whether explicitly stated or implied based on customary business practices. For a contract that has more than one performance obligation, the Partnership allocates the total contract consideration it expects to be entitled to, to each distinct performance obligation based on a standalone-selling price basis. Revenue is recognized when (or as) the performance obligations are satisfied, that is, when the customer obtains control of the good or service. Certain of our contracts contain variable components, which, when combined with the fixed component are considered a single performance obligation. For these types of contacts, only the fixed component of the contracts are included in the table below.

- Definition

Disclosure of accounting policy for revenue from contract with customer.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 17
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130561-203045

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 20
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130566-203045

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 18
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130563-203045

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-URI http://asc.fasb.org/topic&trid=49130388

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 20
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130566-203045

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 18
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130563-203045

Reference 7: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section 50
-Paragraph 4
-Subparagraph (e)
-URI http://asc.fasb.org/extlink&oid=123372394&loc=d3e18823-107790

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 20
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130566-203045

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 19
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130564-203045

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 20
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130566-203045

+ Details

Derivative Assets And Liabilities Derivative Assets and Liabilities (Policies)	9 Months Ended
	Sep. 30, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Concentration Risk, Credit Risk, Policy [Policy Text Block]	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 the Partnership’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, the Partnership may, at times, require collateral under certain circumstances to mitigate credit risk as necessary. The Partnership also uses industry standard commercial agreements which allow for the netting of exposures associated with transactions executed under a single commercial agreement. Additionally, we utilize master netting agreements to offset credit exposure across multiple commercial agreements with a single counterparty or affiliated group of counterparties. The Partnership’s counterparties consist of a diverse portfolio of customers across the energy industry, including petrochemical companies, commercial and industrial end-users, oil and gas producers, municipalities, gas and electric utilities, midstream companies and independent power generators. Our overall exposure may be affected positively or negatively by macroeconomic or regulatory changes that impact our 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. The Partnership has maintenance margin deposits with certain counterparties in the OTC market, primarily with 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 us on or about the settlement date for non-exchange traded derivatives, and we exchange 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 our statement of operations or statement of comprehensive income (loss).
Derivatives, Policy [Policy Text Block]	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, we 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 in 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 utilize swaps, futures and other derivative instruments to mitigate the risk associated with market movements in the price of refined products and NGLs to manage our storage facilities and the purchase and sale of purity NGL. 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. 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.We disclose the non-exchange traded financial derivative instruments as derivative 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.

Cash And Cash Equivalents (Tables)

9 Months Ended

Sep. 30, 2021

Supplemental Cash Flow Information [Abstract]

Cash Flow, Operating Capital [Table Text Block]

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


	Nine Months Ended September 30,
	2021		2020
Accounts receivable	$	(2,562)	$	1,307
Accounts receivable from related companies	16		(258)
Inventories	96		(298)
Other current assets	(127)		108
Other non-current assets, net	(57)		(26)
Accounts payable	2,917		(1,354)
Accounts payable to related companies	(31)		370
Accrued and other current liabilities	711		127
Other non-current liabilities	138		(5)
Derivative assets and liabilities, net	(131)		123
Net change in operating assets and liabilities, net of effects of acquisitions	$	970	$	94

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

Non-cash activities were as follows:


	Nine Months Ended September 30,
	2021		2020
NON-CASH INVESTING AND FINANCING ACTIVITIES:
Accrued capital expenditures	$	385	$	684

Lease assets obtained in exchange for new lease liabilities	10		130
Distribution reinvestment	24		72

Inventories (Tables)

9 Months Ended

Sep. 30, 2021

Inventory, Net [Abstract]

Schedule Of Inventory


	September 30, 2021		December 31, 2020
Natural gas, NGLs and refined products(1)	$	1,238	$	1,013
Crude oil	160		287
Spare parts and other	413		439
Total inventories	$	1,811	$	1,739

(1)Due to changes in fuel prices, Sunoco LP recorded an inventory adjustment on the value of its fuel inventory of $168 million for the nine months ended September 30, 2021.

Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2021

Fair Value Measurements [Abstract]

Fair Value, by Balance Sheet Grouping [Table Text Block]


			Fair Value Measurements at September 30, 2021
	Fair Value Total		Level 1		Level 2
Assets:

Commodity derivatives:

Natural Gas:
Basis Swaps IFERC/NYMEX	$	14	$	14	$	—
Swing Swaps IFERC	11		11		—
Fixed Swaps/Futures	4		4		—


Forward Physical Contracts	4		—		4
Power:
Forwards	36		—		36
Futures	4		4		—

Options – Calls	1		1		—
NGLs – Forwards/Swaps	384		384		—
Refined Products – Futures	7		7		—
Crude – Forwards/Swaps	569		569		—

Total commodity derivatives	1,034		994		40
Other non-current assets	37		24		13
Total assets	$	1,071	$	1,018	$	53
Liabilities:
Interest rate derivatives	$	(376)	$	—	$	(376)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(5)		(5)		—
Swing Swaps IFERC	(7)		(7)		—
Fixed Swaps/Futures	(78)		(78)		—


Forward Physical Contracts	(1)		—		(1)
Power:
Forwards	(21)		—		(21)
Futures	(11)		(11)		—
Options – Calls	(2)		(2)		—

NGLs – Forwards/Swaps	(364)		(364)		—
Refined Products – Futures	(10)		(10)		—
Crude – Forwards/Swaps	(582)		(582)		—
Total commodity derivatives	(1,081)		(1,059)		(22)
Total liabilities	$	(1,457)	$	(1,059)	$	(398)


			Fair Value Measurements at December 31, 2020
	Fair Value Total		Level 1		Level 2
Assets:

Commodity derivatives:

Natural Gas:
Basis Swaps IFERC/NYMEX	$	12	$	12	$	—
Swing Swaps IFERC	1		—		1
Fixed Swaps/Futures	13		13		—


Forward Physical Contracts	5		—		5
Power:
Forwards	4		—		4
Futures	2		2		—

Options – Calls	1		1		—
NGLs – Forwards/Swaps	127		127		—
Refined Products – Futures	3		3		—



Total commodity derivatives	168		158		10
Other non-current assets	34		22		12
Total assets	$	202	$	180	$	22
Liabilities:
Interest rate derivatives	$	(448)	$	—	$	(448)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(11)		(11)		—
Swing Swaps IFERC	(3)		—		(3)
Fixed Swaps/Futures	(13)		(13)		—


Forward Physical Contracts	(1)		—		(1)
Power:

Futures	(3)		(3)		—

NGLs – Forwards/Swaps	(227)		(227)		—
Refined Products – Futures	(11)		(11)		—



Total commodity derivatives	(269)		(265)		(4)
Total liabilities	$	(717)	$	(265)	$	(452)

Net Income per Limited Partner Unit (Tables)

9 Months Ended

Sep. 30, 2021

Earnings Per Share [Abstract]

Reconciliation Of Net Income And Weighted Average Units

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Net income (loss)	$	907	$	(401)	$	5,456	$	(693)
Less: Net income attributable to noncontrolling interests	260		242		870		427
Less: Net income attributable to redeemable noncontrolling interests	12		12		37		37
Net income (loss), net of noncontrolling interests	635		(655)		4,549		(1,157)
Less: General Partner’s interest in income (loss)	1		—		5		(1)
Less: Preferred Unitholders’ interest in income	99		—		185		—
Income (loss) available to Limited Partners	$	535	$	(655)	$	4,359	$	(1,156)
Basic Income (Loss) per Limited Partner Unit:
Weighted average limited partner units	2,705.2		2,696.6		2,704.0		2,694.4
Basic income (loss) per Limited Partner unit	$	0.20	$	(0.24)	$	1.61	$	(0.43)

Diluted Income (Loss) per Limited Partner Unit:
Income (loss) available to Limited Partners	$	535	$	(655)	$	4,359	$	(1,156)
Dilutive effect of equity-based compensation of subsidiaries (1)	1		—		2		—
Diluted income (loss) available to Limited Partners	$	534	$	(655)	$	4,357	$	(1,156)
Weighted average limited partner units	2,705.2		2,696.6		2,704.0		2,694.4
Dilutive effect of unvested unit awards (1)	15.4		—		14.4		—
Weighted average limited partner units, assuming dilutive effect of unvested unit awards	2,720.6		2,696.6		2,718.4		2,694.4
Diluted income (loss) per Limited Partner unit	$	0.20	$	(0.24)	$	1.60	$	(0.43)

(1)Dilutive effects are excluded from the calculation for periods where the impact would have been antidilutive.

Equity (Tables)

9 Months Ended

Sep. 30, 2021

Schedule of Capital Units [Table Text Block]

The change in ET common units during the nine months ended September 30, 2021 was as follows:


			Number of Units
Number of common units at December 31, 2020			2,702.4
Common units issued in connection with the distribution reinvestment plan			2.7

Common units vested under equity incentive plans and other			0.7
Number of common units at September 30, 2021			2,705.8

Accumulated Other Comprehensive Income

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


	September 30, 2021		December 31, 2020
Available-for-sale securities	$	23	$	18
Foreign currency translation adjustment	12		7
Actuarial loss related to pensions and other postretirement benefits	(1)		(7)
Investments in unconsolidated affiliates, net	(13)		(14)

Total AOCI, net of tax	21		4
Amounts attributable to noncontrolling interest	(2)		2
Total AOCI included in partners’ capital, net of tax	$	19	$	6

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

Cash Distributions on ET Preferred Units

Distributions declared on the ET Preferred Units were as follows:


Period Ended	Record Date	Payment Date	Series A (1)		Series B (1)		Series C		Series D		Series E		Series F (1)		Series G (1)		Series H (1)

March 31, 2021	May 3, 2021	May 17, 2021	$	—	$	—	$	0.4609	$	0.4766	$	0.4750	$	33.75	$	35.625	$	—
June 30, 2021	August 2, 2021	August 16, 2021	31.25		33.125		0.4609		0.4766		0.4750		—		—		—
September 30, 2021	November 1, 2021	November 15, 2021	—		—		0.4609		0.4766		0.4750		33.75		35.625		27.08		(2)

(1)Series A, Series B, Series F, Series G and Series H distributions are paid on a semi-annual basis.

(2)Represents initial prorated distribution.

Schedule of Preferred Units [Table Text Block]

The following table summarizes changes in the ET Preferred Units:


	Preferred Unitholders
	Series A		Series B		Series C		Series D		Series E		Series F		Series G		Series H		Total





Balance, March 31, 2021	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Preferred units conversion	943		547		440		434		786		504		1,114		—		4,768
Units issued for cash	—		—		—		—		—		—		—		889		889
Distributions to partners	—		—		(8)		(9)		(15)		(17)		(39)		—		(88)
Other, net	—		—		—		—		—		—		—		(1)		(1)
Net income	15		9		8		9		15		8		20		2		86
Balance, June 30, 2021	958		556		440		434		786		495		1,095		890		5,654
Distributions to partners	(30)		(18)		(8)		(9)		(15)		—		—		—		(80)
Other, net	—		—		—		—		—		—		—		(2)		(2)
Net income	15		9		8		9		15		8		20		15		99
Balance, September 30, 2021	$	943	$	547	$	440	$	434	$	786	$	503	$	1,115	$	903	$	5,671

Parent Company [Member]

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

Distributions declared and/or paid with respect to ET common units subsequent to December 31, 2020 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2020

February 8, 2021

February 19, 2021

0.1525

March 31, 2021

May 11, 2021

May 19, 2021

0.1525

June 30, 2021

August 6, 2021

August 19, 2021

0.1525

September 30, 2021

November 5, 2021

November 19, 2021

0.1525

Sunoco LP [Member]

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

Distributions on Sunoco LP’s units declared and/or paid by Sunoco LP subsequent to December 31, 2020 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2020

February 8, 2021

February 19, 2021

0.8255

March 31, 2021

May 11, 2021

May 19, 2021

0.8255

June 30, 2021

August 6, 2021

August 19, 2021

0.8255

September 30, 2021

November 5, 2021

November 19, 2021

0.8255

USA Compression Partners, LP [Member]

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

Distributions on USAC’s units declared and/or paid by USAC subsequent to December 31, 2020 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2020

January 25, 2021

February 5, 2021

0.525

March 31, 2021

April 26, 2021

May 7, 2021

0.525

June 30, 2021

July 26, 2021

August 6, 2021

0.525

September 30, 2021

October 25, 2021

November 5, 2021

0.525

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

9 Months Ended

Sep. 30, 2021

Environmental Exit Costs by Cost


	September 30, 2021		December 31, 2020
Current	$	44	$	44
Non-current	253		262
Total environmental liabilities	$	297	$	306

Right Of Way [Member]

Lease, Cost


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
ROW expense	$	18	$	13	$	33	$	32

Revenue (Tables)

9 Months Ended

Sep. 30, 2021

Revenue [Abstract]

Contract with Customer, Contract Asset, Contract Liability, and Receivable [Table Text Block]

The following table summarizes the consolidated activity of our contract liabilities:


	Contract Liabilities
Balance, December 31, 2020	$	308
Additions	611
Revenue recognized	(512)
Balance, September 30, 2021	$	407

Balance, December 31, 2019	$	377
Additions	598
Revenue recognized	(614)
Balance, September 30, 2020	$	361

The balances of Sunoco LP’s contract assets were as follows:


	September 30, 2021		December 31, 2020
Contract balances:
Contract assets	$	148	$	121
Accounts receivable from contracts with customers	473		256

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction


	Years Ending December 31,
	2021
	(remainder)		2022		2023		Thereafter		Total
Revenue expected to be recognized on contracts with customers existing as of September 30, 2021	$	1,662	$	6,010	$	5,504	$	26,950	$	40,126

Derivative Assets And Liabilities (Tables)

9 Months Ended

Sep. 30, 2021

Outstanding Commodity-Related Derivatives

The following table details our outstanding commodity-related derivatives:


	September 30, 2021		December 31, 2020
	Notional Volume	Maturity	Notional Volume	Maturity
Mark-to-Market Derivatives
(Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX (1)	(81,963)	2021-2022	(44,225)	2021-2022
Fixed Swaps/Futures	475	2021-2023	1,603	2021-2022



Power (Megawatt):
Forwards	712,400	2021-2029	1,392,400	2021-2029
Futures	(640,800)	2021-2022	18,706	2021-2022
Options – Puts	290,400	2021-2022	519,071	2021
Options – Calls	36,704	2021-2022	2,343,293	2021



(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(8,893)	2021-2022	(29,173)	2021-2022
Swing Swaps IFERC	(48,675)	2021-2022	11,208	2021
Fixed Swaps/Futures	(45,588)	2021-2023	(53,575)	2021-2022
Forward Physical Contracts	(10,071)	2021	(11,861)	2021

NGLs (MBbls) – Forwards/Swaps	2,785	2021-2023	(5,840)	2021-2022
Refined Products (MBbls) – Futures	(3,272)	2021-2023	(2,765)	2021
Crude (MBbls) – Forwards/Swaps	1,693	2021-2022	—	—

Fair Value Hedging Derivatives
(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(21,255)	2021	(30,113)	2021
Fixed Swaps/Futures	(21,255)	2021	(30,113)	2021
Hedged Item – Inventory	21,255	2021	30,113	2021

(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:


Term	Type(1)	Notional Amount Outstanding
		September 30, 2021		December 31, 2020
July 2021(2)(3)	Forward-starting to pay a fixed rate of 3.55% and receive a floating rate	$	—	$	400
July 2022(2)	Forward-starting to pay a fixed rate of 3.80% and receive a floating rate	400		400
July 2023(2)	Forward-starting to pay a fixed rate of 3.78% and receive a floating rate	200		—
July 2024(2)	Forward-starting to pay a fixed rate of 3.88% and receive a floating rate	200		—

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

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

(3)The July 2021 interest rate swaps were amended in June 2021.

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
	September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	2	$	25	$	(20)	$	(32)
	2		25		(20)		(32)
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	330		90		(400)		(166)
Commodity derivatives	702		53		(661)		(71)
Interest rate derivatives	—		—		(376)		(448)
	1,032		143		(1,437)		(685)
Total derivatives	$	1,034	$	168	$	(1,457)	$	(717)

Derivatives, Offsetting Fair Value Amounts [Table Text Block]


		Asset Derivatives				Liability Derivatives
	Balance Sheet Location	September 30, 2021		December 31, 2020		September 30, 2021		December 31, 2020
Derivatives without offsetting agreements	Derivative liabilities	$	—	$	—	$	(376)	$	(448)
Derivatives in offsetting agreements:
OTC contracts	Derivative assets (liabilities)	702		53		(661)		(71)
Broker cleared derivative contracts	Other current assets (liabilities)	332		115		(420)		(198)
Total gross derivatives		1,034		168		(1,457)		(717)
Offsetting agreements:

Counterparty netting	Derivative assets (liabilities)	(645)		(44)		645		44
Counterparty netting	Other current assets (liabilities)	(327)		(64)		327		64
Total net derivatives		$	62	$	60	$	(485)	$	(609)

Derivatives Not Designated as Hedging Instruments [Table Text Block]


	Location	Amount of Gain (Loss) Recognized in Income on Derivatives
		Three Months Ended September 30,				Nine Months Ended September 30,
		2021		2020		2021		2020
Derivatives not designated as hedging instruments:
Commodity derivatives – Trading	Cost of products sold	$	14	$	4	$	12	$	15
Commodity derivatives – Non-trading	Cost of products sold	(71)		(44)		(206)		53

Interest rate derivatives	Gains (losses) on interest rate derivatives	1		55		72		(277)

Total		$	(56)	$	15	$	(122)	$	(209)

- 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://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=125515794&loc=SL5624163-113959

Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1B
-URI http://asc.fasb.org/extlink&oid=125515794&loc=SL5580258-113959

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=125515794&loc=d3e41620-113959

Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=125515794&loc=SL5579245-113959

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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-URI http://asc.fasb.org/extlink&oid=125515794&loc=d3e41638-113959

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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-Section 50
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-URI http://asc.fasb.org/extlink&oid=125515794&loc=d3e41678-113959

Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
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Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
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-URI http://asc.fasb.org/extlink&oid=125515794&loc=SL5579240-113959

+ Details

Reportable Segments (Tables)

9 Months Ended

Sep. 30, 2021

Financial Information By Segment

The following tables present financial information by segment:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Revenues:
Intrastate transportation and storage:
Revenues from external customers	$	1,112	$	614	$	5,940	$	1,615
Intersegment revenues	105		40		1,126		148
	1,217		654		7,066		1,763
Interstate transportation and storage:
Revenues from external customers	412		466		1,317		1,365
Intersegment revenues	6		5		33		15
	418		471		1,350		1,380
Midstream:
Revenues from external customers	560		585		1,709		1,477
Intersegment revenues	2,359		792		6,081		2,088
	2,919		1,377		7,790		3,565
NGL and refined products transportation and services:
Revenues from external customers	4,499		2,207		11,726		5,991
Intersegment revenues	763		416		2,048		1,466
	5,262		2,623		13,774		7,457
Crude oil transportation and services:
Revenues from external customers	4,577		2,849		12,497		8,873
Intersegment revenues	1		1		1		4
	4,578		2,850		12,498		8,877
Investment in Sunoco LP:
Revenues from external customers	4,772		2,801		12,626		8,104
Intersegment revenues	7		4		16		53
	4,779		2,805		12,642		8,157
Investment in USAC:
Revenues from external customers	156		158		464		500
Intersegment revenues	3		3		9		9
	159		161		473		509
All other:
Revenues from external customers	576		275		2,481		995
Intersegment revenues	120		92		303		377
	696		367		2,784		1,372
Eliminations	(3,364)		(1,353)		(9,617)		(4,160)
Total revenues	$	16,664	$	9,955	$	48,760	$	28,920


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Segment Adjusted EBITDA:
Intrastate transportation and storage	$	172	$	203	$	3,209	$	630
Interstate transportation and storage	334		425		1,118		1,232
Midstream	556		530		1,321		1,280
NGL and refined products transportation and services	706		762		2,089		2,099
Crude oil transportation and services	496		631		1,490		1,741
Investment in Sunoco LP	198		189		556		580
Investment in USAC	99		104		299		315
All other	18		22		153		62
Adjusted EBITDA (consolidated)	2,579		2,866		10,235		7,939
Depreciation, depletion and amortization	(943)		(912)		(2,837)		(2,715)
Interest expense, net of interest capitalized	(558)		(569)		(1,713)		(1,750)
Impairment losses	—		(1,474)		(11)		(2,803)
Gains (losses) on interest rate derivatives	1		55		72		(277)
Non-cash compensation expense	(26)		(30)		(81)		(93)
Unrealized gains (losses) on commodity risk management activities	(19)		(30)		74		(27)
Inventory valuation adjustments (Sunoco LP)	9		11		168		(126)
Losses on extinguishments of debt	—		—		(8)		(62)
Adjusted EBITDA related to unconsolidated affiliates	(141)		(169)		(400)		(480)
Equity in earnings (losses) of unconsolidated affiliates	71		(32)		191		46
Impairment of investment in an unconsolidated affiliate	—		(129)		—		(129)
Other, net	11		53		—		(48)
Income (loss) before income tax expense	984		(360)		5,690		(525)
Income tax expense	(77)		(41)		(234)		(168)


Net income (loss)	$	907	$	(401)	$	5,456	$	(693)

Operations And Organization Narrative (Details)	Apr. 01, 2021 shares
Class B Units
Limited Partners' Capital Account, Units Issued	675,625,000

Acquisitions and Related Transactions (Details) - Enable $ in Millions	1 Months Ended
	Feb. 28, 2021 USD ($) shares
Business Acquisition [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	0.8595
Business Combination, Consideration Transferred \| $	$ 10
Series G Preferred Units [Member]
Business Acquisition [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	0.0265

Cash And Cash Equivalents Net Change in Operating Assets and Liabilities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Accounts receivable	$ (2,562)	$ 1,307
Accounts receivable from related companies	16	(258)
Inventories	96	(298)
Other current assets	(127)	108
Other non-current assets, net	(57)	(26)
Accounts payable	2,917	(1,354)
Accounts payable to related companies	(31)	370
Accrued and other current liabilities	711	127
Other non-current liabilities	138	(5)
Derivative assets and liabilities, net	(131)	123
Net change in operating assets and liabilities, net of effects of acquisitions	$ (970)	$ (94)

Cash And Cash Equivalents Non-Cash Activities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
NON-CASH INVESTING AND FINANCING ACTIVITIES:
Accrued capital expenditures	$ 385	$ 684
Right-of-Use Assets Obtained in Exchange for Liabilities	$ 10	$ 130

Inventories Table - Inventory Balances (Details) - USD ($)
$ in Millions

Sep. 30, 2021

Dec. 31, 2020

Inventory [Line Items]

Natural gas, NGLs and refined products(1)

^[1]

$ 1,238

$ 1,013

Crude oil

160

287

Spare parts and other

413

439

Total inventories

$ 1,811

$ 1,739

[1]	Due to changes in fuel prices, Sunoco LP recorded an inventory adjustment on the value of its fuel inventory of $168 million for the nine months ended September 30, 2021.

Inventories Inventory Narrative (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Inventory [Line Items]
Inventory Write-down	$ 168
Sunoco LP [Member]
Inventory [Line Items]
Inventory, LIFO Reserve	$ 143	$ 311

Fair Value Measurements Narrative (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Fair Value Measurements [Abstract]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net	$ 0
Debt obligations, fair value	51,260	$ 56,210
Long-term Debt	$ 45,470	$ 51,440

- Definition

Amount, after unamortized (discount) premium and debt issuance costs, of long-term debt. Includes, but not limited to, notes payable, bonds payable, debentures, mortgage loans and commercial paper. Excludes capital lease obligations.

+ References + Details

Net Income per Limited Partner Unit Table - Income Reconciliation (Details) - USD ($)
$ / shares in Units, shares in Millions, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2021

Sep. 30, 2020

Sep. 30, 2021

Sep. 30, 2020

Earnings Per Share [Abstract]

Net Income (Loss), Including Portion Attributable to Noncontrolling Interest

$ 907

$ (401)

$ 5,456

$ (693)

Less: Net income attributable to noncontrolling interests

260

242

870

427

Less: Net income attributable to redeemable noncontrolling interests

NET INCOME (LOSS) ATTRIBUTABLE TO PARTNERS

635

(655)

4,549

(1,157)

General Partner’s interest in net income (loss)

(1)

Limited Partners’ interest in net income (loss)

$ 535

$ (655)

$ 4,359

$ (1,156)

Basic Income from Continuing Operations per Limited Partner Unit:

Weighted average limited partner units

2,705.2

2,696.6

2,704.0

2,694.4

Basic income (loss) per Limited Partner unit

$ 0.20

$ (0.24)

$ 1.61

$ (0.43)

Diluted Income from Continuing Operations per Limited Partner Unit:

Net Income (Loss) Available to Common Stockholders, Diluted

$ 534

$ (655)

$ 4,357

$ (1,156)

Weighted average limited partner units, assuming dilutive effect of unvested unit awards

2,720.6

2,696.6

2,718.4

2,694.4

Diluted income (loss) per Limited Partner unit

$ 0.20

$ (0.24)

$ 1.60

$ (0.43)

Dilutive effect of equity-based compensation of subsidiaries (1)

^[1]

$ 1

$ 0

$ 2

$ 0

Dilutive effect of unvested unit awards (1)

^[1]

15.4

0.0

14.4

0.0

Noncontrolling Interest in Net Income (Loss) Preferred Unit Holders, Nonredeemable

$ 99

$ 0

$ 185

$ 0

[1]	Dilutive effects are excluded from the calculation for periods where the impact would have been antidilutive.

Debt Obligations Narrative (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Jun. 30, 2021	Sep. 30, 2021	Sep. 30, 2020
Debt Instrument [Line Items]
Long-term Line of Credit	$ 506.0		$ 506.0
Repayments of Long-term Debt			17,836.0	$ 20,293.0
Proceeds from Issuance of Long-term Debt			$ 11,839.0	$ 20,651.0
Banking Regulation, Supplementary Leverage Ratio, Actual	3.15		3.15
ETO Credit Facility due December 2022 [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity	$ 4,370.0		$ 4,370.0
Long-term Line of Credit	599.0		599.0
Letters of Credit Outstanding, Amount	$ 31.0		$ 31.0
Line of Credit Facility, Interest Rate at Period End	0.43%		0.43%
Line of Credit Facility, Maximum Borrowing Capacity	$ 5,000.0		$ 5,000.0
Commercial Paper	590.0		590.0
ETO Credit Facility due December 2022 [Member] \| Accordion feature [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	6,000.0		6,000.0
ETO 364-day Credit Facility due November 2019 [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	0.0		0.0
Line of Credit Facility, Maximum Borrowing Capacity	1,000.0		1,000.0
Sunoco LP $1.5 billion Revolving Credit Facility due July 2023 [Member] \| Sunoco LP [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	1,500.0		1,500.0
Letters of Credit Outstanding, Amount	$ 6.0		$ 6.0
Line of Credit Facility, Interest Rate at Period End	2.09%		2.09%
Line of Credit Facility, Remaining Borrowing Capacity	$ 1,240.0		$ 1,240.0
Line of Credit Facility, Fair Value, Basis for Measurement			250 million
ETO Term Loan [Member]
Debt Instrument [Line Items]
Repayments of Long-term Debt	500.0	$ 1,500.0
Line of Credit Facility, Maximum Borrowing Capacity	2,000.0		$ 2,000.0
SemCAMS C$350 million senior secured term loan facility [Member] \| SemCAMS [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	276.0		276.0
Line of Credit Facility, Fair Value of Amount Outstanding	252.0		252.0
SemCAMS C$525 million senior secured revolving credit facility [Member] \| SemCAMS [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	414.0		414.0
SemCAMS C$300 million senior secured construction loan facility [Member] \| SemCAMS [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	237.0		237.0
Line of Credit Facility, Fair Value of Amount Outstanding	81.0		81.0
KAPS Facility [Member] \| SemCAMS [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	197.0		197.0
Line of Credit Facility, Fair Value of Amount Outstanding	$ 51.0		51.0
4.40% Senior Notes due April 2021 \| ETO [Member]
Debt Instrument [Line Items]
Early Repayment of Senior Debt			$ 600.0
Debt Instrument, Interest Rate, Stated Percentage	4.40%		4.40%
4.65% Senior Notes due June 2021 \| ETO [Member]
Debt Instrument [Line Items]
Early Repayment of Senior Debt			$ 800.0
Debt Instrument, Interest Rate, Stated Percentage	4.65%		4.65%
USAC Credit Facility, due 2023 [Member] \| USAC [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity	$ 1,600.0		$ 1,600.0
Long-term Line of Credit	$ 1,090.0		$ 1,090.0
Line of Credit Facility, Interest Rate at Period End	2.96%		2.96%
Line of Credit Facility, Maximum Borrowing Capacity	$ 400.0		$ 400.0
Line of Credit Facility, Remaining Borrowing Capacity	$ 114.0		114.0
4.50% senior notes due 2030
Debt Instrument [Line Items]
Early Repayment of Senior Debt			800.0
5.2% Senior Notes due 2022
Debt Instrument [Line Items]
Early Repayment of Senior Debt			$ 1,000.0
Debt Instrument, Interest Rate, Stated Percentage	5.20%		5.20%
5.875% Senior Notes due 2022
Debt Instrument [Line Items]
Early Repayment of Senior Debt			$ 900.0
Debt Instrument, Interest Rate, Stated Percentage	5.875%		5.875%
4.5% senior notes due 2030
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	450.00%		450.00%
Canada, Dollars \| SemCAMS C$350 million senior secured term loan facility [Member] \| SemCAMS [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	$ 350.0		$ 350.0
Line of Credit Facility, Fair Value of Amount Outstanding	320.0		320.0
Canada, Dollars \| SemCAMS C$525 million senior secured revolving credit facility [Member] \| SemCAMS [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	525.0		525.0
Canada, Dollars \| SemCAMS C$300 million senior secured construction loan facility [Member] \| SemCAMS [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	300.0		300.0
Line of Credit Facility, Fair Value of Amount Outstanding	103.0		103.0
Canada, Dollars \| KAPS Facility [Member] \| SemCAMS [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	250.0		250.0
Line of Credit Facility, Fair Value of Amount Outstanding	$ 65.0		$ 65.0

Redeemable Noncontrolling Interest (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Redeemable noncontrolling interests	$ 783	$ 762
Preferred Units, Issued	900,000
Preferred Stock, Redemption Price Per Share	$ 867
Dividends, Preferred Stock, Cash	$ 6
USAC [Member]
Redeemable noncontrolling interests	477
ETO [Member]
Redeemable noncontrolling interests	15
SemCAMS [Member]
Redeemable noncontrolling interests	$ 291
Preferred Stock, Shares Outstanding	300,000
Preferred Units [Member] \| USAC [Member]
Preferred Units, Issued	500,000
Distribution Made to Limited Partner, Distributions Declared, Per Unit	$ 24.375
Preferred Units [Member] \| SemCAMS [Member]
Preferred Units, Issued	367,521
Canada, Dollars
Preferred Stock, Redemption Price Per Share	$ 1,100
Dividends, Preferred Stock, Cash	$ 8

Equity Narrative (Details) - USD ($)	9 Months Ended
Equity Narrative (Details) - USD ($)	Sep. 30, 2021	Sep. 30, 2020
Stock Repurchase Program, Remaining Authorized Repurchase Amount	$ 911,000,000
Stock Issued During Period, Value, Dividend Reinvestment Plan	$ 24,000,000	$ 72,000,000
Preferred Units, Issued	900,000
Stock Issued During Period, Shares, Dividend Reinvestment Plan	2,700,000
Common Units Remaining Available to be Issued Under Distribution Reinvestment Plan	18,000,000
Series F Preferred Units [Member]
Preferred Stock, Dividend Rate, Percentage	6.75%
Shares Issued, Price Per Share	$ 1,000
Preferred Units, Liquidation Spread, Percent	5.134%
Preferred Stock, Redemption Amount	$ 1,000
Preferred Stock, Liquidation Preference, Value	$ 1,000
Series G Preferred Units [Member]
Preferred Stock, Dividend Rate, Percentage	7.125%
Shares Issued, Price Per Share	$ 1,000
Preferred Units, Liquidation Spread, Percent	5.306%
Preferred Stock, Redemption Amount	$ 1,000
Preferred Stock, Liquidation Preference, Value	$ 1,000
Series H Preferred Units
Preferred Stock, Dividend Rate, Percentage	6.50%
Preferred Units, Liquidation Spread, Percent	5.694%
Preferred Stock, Redemption Amount	$ 1,000
Preferred Stock, Liquidation Preference, Value	$ 1,000
Series F Preferred Units [Member]
Preferred Stock, Shares Outstanding	500,000
Series G Preferred Units [Member]
Preferred Stock, Shares Outstanding	1,100,000
Series E Preferred Units [Member]
Preferred Stock, Dividend Rate, Percentage	7.60%
Shares Issued, Price Per Share	$ 25
Preferred Units, Liquidation Spread, Percent	516.10%
Preferred Stock, Redemption Amount	$ 25
Preferred Stock, Liquidation Preference, Value	$ 25
Preferred Stock, Shares Outstanding	32,000,000
Series D Preferred Units [Member]
Preferred Stock, Dividend Rate, Percentage	7.625%
Shares Issued, Price Per Share	$ 25
Preferred Units, Liquidation Spread, Percent	4.738%
Preferred Stock, Redemption Amount	$ 25
Preferred Stock, Liquidation Preference, Value	$ 25
Preferred Stock, Shares Outstanding	17,800,000
Series C Preferred Units [Member]
Preferred Stock, Dividend Rate, Percentage	7.375%
Shares Issued, Price Per Share	$ 25
Preferred Units, Liquidation Spread, Percent	4.53%
Preferred Stock, Redemption Amount	$ 25
Preferred Stock, Liquidation Preference, Value	$ 25
Preferred Stock, Shares Outstanding	18,000,000
Series B Preferred Units [Member]
Preferred Stock, Dividend Rate, Percentage	6.625%
Shares Issued, Price Per Share	$ 1,000
Preferred Units, Liquidation Spread, Percent	4.155%
Preferred Stock, Shares Outstanding	550,000
Series A Preferred Units [Member]
Preferred Stock, Dividend Rate, Percentage	6.25%
Shares Issued, Price Per Share	$ 1,000
Preferred Units, Liquidation Spread, Percent	4.028%
Preferred Stock, Redemption Amount	$ 1,000
Preferred Stock, Liquidation Preference, Value	$ 1,000
Preferred Stock, Shares Outstanding	950,000
Series H Preferred Units
Preferred Stock, Shares Outstanding	900,000

Equity - Change In ETE Common Units (Details) - USD ($) $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2021	Dec. 31, 2020	Dec. 31, 2019
Class of Stock [Line Items]
Limited Partners' Capital Account, Units Outstanding	2,705,800,000						2,705,800,000	2,702,400,000
Stock Issued During Period, Shares, Dividend Reinvestment Plan							2,700,000
Partners' Capital Account, Unit-based Payment Arrangement, Number of Units							700,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 35,349	$ 35,275	$ 34,254	$ 31,291	$ 32,892	$ 32,530	$ 35,349	$ 31,388	$ 33,938
Stock Issued During Period, Value, Conversion of Units		0
Partners' Capital Account, Sale of Units		889
Distributions to partners	(485)	(492)	(406)	$ (813)	$ 8	$ (1,592)
Series H Preferred Units
Class of Stock [Line Items]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	903	890	0				$ 903
Stock Issued During Period, Value, Conversion of Units		0
Partners' Capital Account, Sale of Units		889
Distributions to partners	0	0
Stockholders' Equity, Other	(2)	(1)
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest	$ 15	2
Preferred Stock, Shares Outstanding	900,000						900,000
Series A Preferred Units [Member]
Class of Stock [Line Items]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 943	958	0				$ 943
Stock Issued During Period, Value, Conversion of Units		943
Partners' Capital Account, Sale of Units		0
Distributions to partners	(30)	0
Stockholders' Equity, Other	0	0
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest	$ 15	15
Preferred Stock, Shares Outstanding	950,000						950,000
Series C Preferred Units [Member]
Class of Stock [Line Items]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 440	440	0				$ 440
Stock Issued During Period, Value, Conversion of Units		440
Partners' Capital Account, Sale of Units		0
Distributions to partners	(8)	(8)
Stockholders' Equity, Other	0	0
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest	$ 8	8
Preferred Stock, Shares Outstanding	18,000,000						18,000,000
Series B Preferred Units [Member]
Class of Stock [Line Items]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 547	556	0				$ 547
Stock Issued During Period, Value, Conversion of Units		547
Partners' Capital Account, Sale of Units		0
Distributions to partners	(18)	0
Stockholders' Equity, Other	0	0
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest	$ 9	9
Preferred Stock, Shares Outstanding	550,000						550,000
Series D Preferred Units [Member]
Class of Stock [Line Items]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 434	434	0				$ 434
Stock Issued During Period, Value, Conversion of Units		434
Partners' Capital Account, Sale of Units		0
Distributions to partners	(9)	(9)
Stockholders' Equity, Other	0	0
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest	$ 9	9
Preferred Stock, Shares Outstanding	17,800,000						17,800,000
Series E Preferred Units [Member]
Class of Stock [Line Items]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 786	786	0				$ 786
Stock Issued During Period, Value, Conversion of Units		786
Partners' Capital Account, Sale of Units		0
Distributions to partners	(15)	(15)
Stockholders' Equity, Other	0	0
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest	$ 15	15
Preferred Stock, Shares Outstanding	32,000,000						32,000,000
Series F Preferred Units [Member]
Class of Stock [Line Items]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 503	495	0				$ 503
Stock Issued During Period, Value, Conversion of Units		504
Partners' Capital Account, Sale of Units		0
Distributions to partners	0	(17)
Stockholders' Equity, Other	0	0
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest	$ 8	8
Preferred Stock, Shares Outstanding	500,000						500,000
Series G Preferred Units [Member]
Class of Stock [Line Items]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 1,115	1,095	0				$ 1,115
Stock Issued During Period, Value, Conversion of Units		1,114
Partners' Capital Account, Sale of Units		0
Distributions to partners	0	(39)
Stockholders' Equity, Other	0	0
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest	$ 20	20
Preferred Stock, Shares Outstanding	1,100,000						1,100,000
Preferred Unitholders
Class of Stock [Line Items]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 5,671	5,654	0				$ 5,671	$ 0
Stock Issued During Period, Value, Conversion of Units		4,768
Partners' Capital Account, Sale of Units		889
Distributions to partners	(80)	(88)	$ 0
Stockholders' Equity, Other	(2)	(1)
Net Income (Loss), Including Portion Attributable to Nonredeemable Noncontrolling Interest	$ 99	$ 86

Equity - Quarterly Distributions of Available Cash (Details) - $ / shares

3 Months Ended

Sep. 30, 2021

Jun. 30, 2021

Mar. 31, 2021

Dec. 31, 2020

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.1525

Series A Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

^[1]

31.25

Series B Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

^[1]

33.125

Series C Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

0.4609

Series D Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

0.4766

Series E Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

0.4750

Series F Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

^[1]

33.75

Series G Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

^[1]

35.625

Series H Preferred Units

Distribution Made to Limited Partner, Distributions Paid, Per Unit

^[1]

27.08

^[2]

USAC [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

0.525

Sunoco LP [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.8255

[1]	Series A, Series B, Series F, Series G and Series H distributions are paid on a semi-annual basis.
[2]	Represents initial prorated distribution.

Equity - Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Equity [Abstract]
Available-for-sale securities	$ 23	$ 18
Foreign currency translation adjustment	12	7
Actuarial gain related to pensions and other postretirement benefits	(1)	(7)
AOCI attributable to equity method investments	(13)	(14)
Total AOCI, net of tax	21	4
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Noncontrolling Interest	(2)	2
Accumulated other comprehensive income	$ 19	$ 6

- 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

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Narrative (Details) $ in Millions		6 Months Ended	9 Months Ended
	Aug. 01, 2020 USD ($)	Jun. 30, 2021 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Dec. 31, 2020 USD ($)
Payments for Environmental Liabilities			$ 18.0	$ 22.0
Document Period End Date			Sep. 30, 2021
Accrual for Environmental Loss Contingencies			$ 297.0		$ 306.0
Loss Contingency, Estimate of Possible Loss			80.0
Related To Deductibles
Loss Contingency Accrual, at Carrying Value			$ 130.0		$ 101.0
Sunoco, Inc. [Member]
Loss Contingency, Pending Claims, Number			5
Sunoco [Member]
Site Contingency, Number of Sites Needing Remediation			33
Williams Litigation [Member]
Loss Contingency, Damages Sought, Value			$ 410.0
Cline Class Action \| Actual Damages
Payments for Legal Settlements	$ 74.8	$ 80.7
Cline Class Action \| punitive damages
Payments for Legal Settlements		$ 75.0

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Table - Accrued Environmental Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Environmental Exit Cost [Line Items]
Current	$ 44	$ 44
Non-current	253	262
Total environmental liabilities	$ 297	$ 306

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Schedule of Right of Way Expense (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
ROW Expense	$ 18	$ 13	$ 33	$ 32

Revenue Revenue Contract Liabilities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020	Dec. 31, 2019
Contract with Customer, Liability	$ 407	$ 361	$ 308	$ 377
Additions	611	598
Revenue Recognized	(512)	$ (614)
Sunoco LP [Member]
Contract assets	148		121
Accounts receivable from contracts with customers	$ 473		$ 256

Revenue, Remaining performance obligations (Details) $ in Millions	Sep. 30, 2021 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 40,126
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-12-31
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 1,662
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Year	2021
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 6,010
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Year	2022
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year 3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 5,504
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Year	2023
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	2 years 3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 26,950
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	3 years 3 months

Derivative Assets And Liabilities Table - Outstanding Commodity-Related Derivatives (Details)

Sep. 30, 2021

MMbtu

Megawatt

bbl

barrels

Dec. 31, 2020

MMbtu

Megawatt

bbl

barrels

Natural Gas Liquids [Member] | Mark-To-Market Derivatives [Member] | Non Trading [Member] | Forwards Swaps [Member] | Short [Member]

Derivative, Nonmonetary Notional Amount | bbl

5,840

Natural Gas Liquids [Member] | Mark-To-Market Derivatives [Member] | Non Trading [Member] | Forwards Swaps [Member] | Long [Member]

Derivative, Nonmonetary Notional Amount | bbl

2,785

Natural Gas [Member] | Mark-To-Market Derivatives [Member] | Non Trading [Member] | Basis Swaps IFERC/NYMEX [Member] | Short [Member]

Derivative, Nonmonetary Notional Amount

8,893

29,173

Natural Gas [Member] | Mark-To-Market Derivatives [Member] | Non Trading [Member] | Swing Swaps IFERC [Member] | Short [Member]

Derivative, Nonmonetary Notional Amount

48,675

Natural Gas [Member] | Mark-To-Market Derivatives [Member] | Non Trading [Member] | Swing Swaps IFERC [Member] | Long [Member]

Derivative, Nonmonetary Notional Amount

11,208

Natural Gas [Member] | Mark-To-Market Derivatives [Member] | Non Trading [Member] | Fixed Swaps/Futures [Member] | Short [Member]

Derivative, Nonmonetary Notional Amount

45,588

53,575

Natural Gas [Member] | Mark-To-Market Derivatives [Member] | Non Trading [Member] | Forward Physical Contracts [Member] | Short [Member]

Derivative, Nonmonetary Notional Amount

10,071

11,861

Natural Gas [Member] | Mark-To-Market Derivatives [Member] | Trading [Member] | Basis Swaps IFERC/NYMEX [Member] | Short [Member]

Derivative, Nonmonetary Notional Amount

^[1]

81,963

44,225

Natural Gas [Member] | Mark-To-Market Derivatives [Member] | Trading [Member] | Fixed Swaps/Futures [Member] | Long [Member]

Derivative, Nonmonetary Notional Amount

475

1,603

Natural Gas [Member] | Fair Value Hedging [Member] | Non Trading [Member] | Basis Swaps IFERC/NYMEX [Member] | Short [Member]

Derivative, Nonmonetary Notional Amount

21,255

30,113

Natural Gas [Member] | Fair Value Hedging [Member] | Non Trading [Member] | Fixed Swaps/Futures [Member] | Short [Member]

Derivative, Nonmonetary Notional Amount

21,255

30,113

Natural Gas [Member] | Fair Value Hedging [Member] | Non Trading [Member] | Hedged Item - Inventory (MMBtu) [Member] | Long [Member]

Derivative, Nonmonetary Notional Amount

21,255

30,113

Power [Member] | Mark-To-Market Derivatives [Member] | Trading [Member] | Options - Puts [Member] | Long [Member]

Derivative, Nonmonetary Notional Amount | Megawatt

290,400

Power [Member] | Mark-To-Market Derivatives [Member] | Trading [Member] | Call Option [Member] | Long [Member]

Derivative, Nonmonetary Notional Amount | Megawatt

36,704

2,343,293

Power [Member] | Mark-To-Market Derivatives [Member] | Trading [Member] | Forwards Swaps [Member] | Long [Member]

Derivative, Nonmonetary Notional Amount | Megawatt

712,400

1,392,400

Power [Member] | Mark-To-Market Derivatives [Member] | Trading [Member] | Future [Member] | Short [Member]

Derivative, Nonmonetary Notional Amount | Megawatt

640,800

Power [Member] | Mark-To-Market Derivatives [Member] | Trading [Member] | Future [Member] | Long [Member]

Derivative, Nonmonetary Notional Amount | Megawatt

18,706

Power [Member] | Mark-To-Market Derivatives [Member] | Trading [Member] | Put Option [Member] | Long [Member]

Derivative, Nonmonetary Notional Amount | Megawatt

519,071

Crude Oil [Member] | Mark-To-Market Derivatives [Member] | Non Trading [Member] | Forwards Swaps [Member] | Long [Member]

Derivative, Nonmonetary Notional Amount | bbl

1,693

Refined product sales | Mark-To-Market Derivatives [Member] | Non Trading [Member] | Future [Member] | Short [Member]

Derivative, Nonmonetary Notional Amount | barrels

3,272

2,765

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

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

9 Months Ended

Sep. 30, 2021

Dec. 31, 2020

Discussion of Interest Rate Derivative Risk Management Policy

Interest Rate RiskWe 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 variable rate debt. We also manage our interest rate exposure by utilizing interest rate swaps to achieve a desired mix of fixed and variable rate debt. We also utilize forward starting interest rate swaps to lock in the rate on a portion of our anticipated debt issuances.

July 2021 [Member]

Description of Interest Rate Derivative Activities

^[1],[2],[3]

Forward-starting to pay a fixed rate of 3.55% and receive a floating rate

Derivative, Notional Amount

^[2],[3]

$ 0

$ 400

July 2022 [Member]

Description of Interest Rate Derivative Activities

^[1],[2]

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

Derivative, Notional Amount

^[2]

$ 400

400

July 2023 [Domain]

Description of Interest Rate Derivative Activities

^[1],[2]

Forward-starting to pay a fixed rate of 3.78% and receive a floating rate

Derivative, Notional Amount

^[2]

$ 200

July 2024

Description of Interest Rate Derivative Activities

^[1],[2]

Forward-starting to pay a fixed rate of 3.88% and receive a floating rate

Derivative, Notional Amount

^[2]

$ 200

$ 0

[1]	Floating rates are based on 3-month LIBOR.
[2]	Represents the effective date. These forward-starting swaps have terms of 30 years with a mandatory termination date the same as the effective date.
[3]	The July 2021 interest rate swaps were amended in June 2021.

Derivative Assets And Liabilities Table - Fair Value of Derivative Instruments (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Total derivatives assets	$ 1,034	$ 168
Total derivatives liabilities	(1,457)	(717)
Designated as Hedging Instrument [Member]
Total derivatives assets	2	25
Total derivatives liabilities	(20)	(32)
Not Designated as Hedging Instrument [Member]
Total derivatives assets	1,032	143
Total derivatives liabilities	(1,437)	(685)
Fair Value, Recurring [Member]
Price Risk Derivative Liabilities, at Fair Value	1,081	269
Forward Physical Swaps [Member] \| Fair Value, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member]
Price Risk Derivative Liabilities, at Fair Value	1
Level 1 \| Fair Value, Recurring [Member]
Price Risk Derivative Liabilities, at Fair Value	1,059	265
Level 1 \| Forward Physical Swaps [Member] \| Fair Value, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member]
Price Risk Derivative Liabilities, at Fair Value	0
Level 2 \| Fair Value, Recurring [Member]
Price Risk Derivative Liabilities, at Fair Value	22	4
Level 2 \| Forward Physical Swaps [Member] \| Fair Value, Recurring [Member] \| Commodity Derivatives - Natural Gas [Member]
Price Risk Derivative Liabilities, at Fair Value	1
Commodity Derivatives [Member] \| Not Designated as Hedging Instrument [Member]
Total derivatives assets	702	53
Total derivatives liabilities	(661)	(71)
Commodity Derivatives (Margin Deposits) [Member] \| Designated as Hedging Instrument [Member]
Total derivatives assets	2	25
Total derivatives liabilities	(20)	(32)
Commodity Derivatives (Margin Deposits) [Member] \| Not Designated as Hedging Instrument [Member]
Total derivatives assets	330	90
Total derivatives liabilities	(400)	(166)
Interest Rate Derivatives [Member] \| Not Designated as Hedging Instrument [Member]
Total derivatives assets	0	0
Total derivatives liabilities	$ (376)	$ (448)

Derivative Assets And Liabilities Table - Gross FV and Netting Offset (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 1,034	$ 168
Derivative Liability, Fair Value, Gross Liability	(1,457)	(717)
Counterparty netting	(645)	(44)
Counterparty netting	645	44
Payments on margin deposit	(327)	(64)
Derivative Liability, Collateral, Right to Reclaim Cash, Offset	327	64
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	62	60
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	485	609
Without offsetting agreements [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0
Derivative Liability, Fair Value, Gross Liability	(376)	(448)
OTC Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	702	53
Derivative Liability, Fair Value, Gross Liability	(661)	(71)
Broker cleared derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	332	115
Derivative Liability, Fair Value, Gross Liability	$ (420)	$ (198)

Derivative Assets And Liabilities Table - Partnership's Derivative Assets and Liabilities Amount of Gain (Loss) Recognized (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Amount of Gain/(Loss) Recognized in Income on Derivatives	$ (56)	$ 15	$ (122)	$ (209)
Gains (losses) on interest rate derivatives	1	55	72	(277)
Commodity Derivatives [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	(71)	(44)	(206)	53
Commodity Derivatives - Trading [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	$ 14	$ 4	$ 12	$ 15

Reportable Segments Table - Revenues (External and Intersegment) by Investments (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Revenues	$ (16,664)	$ (9,955)	$ (48,760)	$ (28,920)
Intersegment Eliminations [Member]
Revenues	3,364	1,353	(9,617)	(4,160)
Intrastate Transportation And Storage [Member]
Revenues	(1,217)	(654)	(7,066)	(1,763)
Investment In Sunoco LP [Member]
Revenues	(4,779)	(2,805)	(12,642)	(8,157)
Investment In USAC [Member]
Revenues	(159)	(161)	(473)	(509)
Interstate Transportation and Storage [Member]
Revenues	(418)	(471)	(1,350)	(1,380)
Midstream [Member]
Revenues	(2,919)	(1,377)	(7,790)	(3,565)
NGL and refined products transportation and services [Member]
Revenues	(5,262)	(2,623)	(13,774)	(7,457)
Crude oil transportation and services [Member]
Revenues	(4,578)	(2,850)	(12,498)	(8,877)
Other Segments [Member]
Revenues	(696)	(367)	(2,784)	(1,372)
Intersegment [Member] \| Intrastate Transportation And Storage [Member]
Revenues	(105)	(40)	(1,126)	(148)
Intersegment [Member] \| Investment In Sunoco LP [Member]
Revenues	(7)	(4)	(16)	(53)
Intersegment [Member] \| Investment In USAC [Member]
Revenues	(3)	(3)	(9)	(9)
Intersegment [Member] \| Interstate Transportation and Storage [Member]
Revenues	(6)	(5)	(33)	(15)
Intersegment [Member] \| Midstream [Member]
Revenues	(2,359)	(792)	(6,081)	(2,088)
Intersegment [Member] \| NGL and refined products transportation and services [Member]
Revenues	(763)	(416)	(2,048)	(1,466)
Intersegment [Member] \| Crude oil transportation and services [Member]
Revenues	(1)	(1)	(1)	(4)
Intersegment [Member] \| Other Segments [Member]
Revenues	(120)	(92)	(303)	(377)
External Customers [Member] \| Intrastate Transportation And Storage [Member]
Revenues	(1,112)	(614)	(5,940)	(1,615)
External Customers [Member] \| Investment In Sunoco LP [Member]
Revenues	(4,772)	(2,801)	(12,626)	(8,104)
External Customers [Member] \| Investment In USAC [Member]
Revenues	(156)	(158)	(464)	(500)
External Customers [Member] \| Interstate Transportation and Storage [Member]
Revenues	(412)	(466)	(1,317)	(1,365)
External Customers [Member] \| Midstream [Member]
Revenues	(560)	(585)	(1,709)	(1,477)
External Customers [Member] \| NGL and refined products transportation and services [Member]
Revenues	(4,499)	(2,207)	(11,726)	(5,991)
External Customers [Member] \| Crude oil transportation and services [Member]
Revenues	(4,577)	(2,849)	(12,497)	(8,873)
External Customers [Member] \| Other Segments [Member]
Revenues	$ (576)	$ (275)	$ (2,481)	$ (995)

Reportable Segments Table - Segment Adjusted EBITDA (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	$ 2,579	$ 2,866	$ 10,235	$ 7,939
Depreciation, depletion and amortization	(943)	(912)	(2,837)	(2,715)
Interest expense, net	(558)	(569)	(1,713)	(1,750)
Impairment losses	0	(1,474)	(11)	(2,803)
Gains (losses) on interest rate derivatives	1	55	72	(277)
Non-cash compensation expense	(26)	(30)	(81)	(93)
Losses on extinguishments of debt	0	0	(8)	(62)
Inventory valuation adjustments	9	11	168	(126)
Equity in earnings (losses) of unconsolidated affiliates	71	(32)	191	46
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAX EXPENSE	984	(360)	5,690	(525)
Income tax (benefit) expense from continuing operations	(77)	(41)	(234)	(168)
Net income (loss)	907	(401)	5,456	(693)
Unrealized gains (losses) on commodity risk management activities	(19)	(30)	74	(27)
Adjusted EBITDA related to unconsolidated affiliates	(141)	(169)	(400)	(480)
Other	11	53	0	(48)
Equity Method Investment, Other than Temporary Impairment	0	(129)	0	(129)
Intrastate Transportation And Storage [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	172	203	3,209	630
Investment In Sunoco LP [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	198	189	556	580
Investment In USAC [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	99	104	299	315
Interstate Transportation and Storage [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	334	425	1,118	1,232
Midstream [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	556	530	1,321	1,280
NGL and refined products transportation and services [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	706	762	2,089	2,099
Crude oil transportation and services [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	496	631	1,490	1,741
All Other Segment
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA	$ 18	$ 22	$ 153	$ 62

Fair Value Measurements Table - Fair Value of Financial Assets and Liabilities (Details) - Fair Value, Recurring [Member] - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Price Risk Derivative Assets, at Fair Value	$ 1,034	$ 168
Other Assets, Fair Value Disclosure	37	34
Assets, Fair Value Disclosure	1,071	202
Interest Rate Derivative Liabilities, at Fair Value	(376)	(448)
Price Risk Derivative Liabilities, at Fair Value	(1,081)	(269)
Financial and Nonfinancial Liabilities, Fair Value Disclosure	(1,457)	(717)
Level 1
Price Risk Derivative Assets, at Fair Value	994	158
Other Assets, Fair Value Disclosure	24	22
Assets, Fair Value Disclosure	1,018	180
Interest Rate Derivative Liabilities, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	(1,059)	(265)
Financial and Nonfinancial Liabilities, Fair Value Disclosure	(1,059)	(265)
Level 2
Price Risk Derivative Assets, at Fair Value	40	10
Other Assets, Fair Value Disclosure	13	12
Assets, Fair Value Disclosure	53	22
Interest Rate Derivative Liabilities, at Fair Value	(376)	(448)
Price Risk Derivative Liabilities, at Fair Value	(22)	(4)
Financial and Nonfinancial Liabilities, Fair Value Disclosure	(398)	(452)
Commodity Derivatives - Natural Gas [Member] \| Basis Swaps IFERC/NYMEX [Member]
Price Risk Derivative Assets, at Fair Value	14	12
Price Risk Derivative Liabilities, at Fair Value	(5)	(11)
Commodity Derivatives - Natural Gas [Member] \| Swing Swaps IFERC [Member]
Price Risk Derivative Assets, at Fair Value	11	1
Price Risk Derivative Liabilities, at Fair Value	(7)	(3)
Commodity Derivatives - Natural Gas [Member] \| Fixed Swaps/Futures [Member]
Price Risk Derivative Assets, at Fair Value	4	13
Price Risk Derivative Liabilities, at Fair Value	(78)	(13)
Commodity Derivatives - Natural Gas [Member] \| Forward Physical Swaps [Member]
Price Risk Derivative Assets, at Fair Value	4	5
Price Risk Derivative Liabilities, at Fair Value	(1)
Commodity Derivatives - Natural Gas [Member] \| Forward Physical Contracts [Member]
Price Risk Derivative Liabilities, at Fair Value		(1)
Commodity Derivatives - Natural Gas [Member] \| Level 1 \| Basis Swaps IFERC/NYMEX [Member]
Price Risk Derivative Assets, at Fair Value	14	12
Price Risk Derivative Liabilities, at Fair Value	(5)	(11)
Commodity Derivatives - Natural Gas [Member] \| Level 1 \| Swing Swaps IFERC [Member]
Price Risk Derivative Assets, at Fair Value	11	0
Price Risk Derivative Liabilities, at Fair Value	(7)	0
Commodity Derivatives - Natural Gas [Member] \| Level 1 \| Fixed Swaps/Futures [Member]
Price Risk Derivative Assets, at Fair Value	4	13
Price Risk Derivative Liabilities, at Fair Value	(78)	(13)
Commodity Derivatives - Natural Gas [Member] \| Level 1 \| Forward Physical Swaps [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0
Commodity Derivatives - Natural Gas [Member] \| Level 1 \| Forward Physical Contracts [Member]
Price Risk Derivative Liabilities, at Fair Value		0
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
Commodity Derivatives - Natural Gas [Member] \| Level 2 \| Swing Swaps IFERC [Member]
Price Risk Derivative Assets, at Fair Value	0	1
Price Risk Derivative Liabilities, at Fair Value	0	(3)
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
Commodity Derivatives - Natural Gas [Member] \| Level 2 \| Forward Physical Swaps [Member]
Price Risk Derivative Assets, at Fair Value	4	5
Price Risk Derivative Liabilities, at Fair Value	(1)
Commodity Derivatives - Natural Gas [Member] \| Level 2 \| Forward Physical Contracts [Member]
Price Risk Derivative Liabilities, at Fair Value		(1)
Commodity Derivatives - Refined Products [Member] \| Future [Member]
Price Risk Derivative Assets, at Fair Value	7	3
Price Risk Derivative Liabilities, at Fair Value	(10)	(11)
Commodity Derivatives - Refined Products [Member] \| Level 1 \| Future [Member]
Price Risk Derivative Assets, at Fair Value	7	3
Price Risk Derivative Liabilities, at Fair Value	(10)	(11)
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
Commodity Derivatives - Crude [Member] \| Future [Member]
Price Risk Derivative Assets, at Fair Value	569
Price Risk Derivative Liabilities, at Fair Value	(582)
Commodity Derivatives - Crude [Member] \| Level 1 \| Future [Member]
Price Risk Derivative Assets, at Fair Value	569
Price Risk Derivative Liabilities, at Fair Value	(582)
Commodity Derivatives - Crude [Member] \| Level 2 \| Future [Member]
Price Risk Derivative Assets, at Fair Value	0
Price Risk Derivative Liabilities, at Fair Value	0
Commodity Derivatives - Power [Member] \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	36	4
Price Risk Derivative Liabilities, at Fair Value	(21)
Commodity Derivatives - Power [Member] \| Call Option [Member]
Price Risk Derivative Assets, at Fair Value	1	1
Price Risk Derivative Liabilities, at Fair Value	(2)
Commodity Derivatives - Power [Member] \| Future [Member]
Price Risk Derivative Assets, at Fair Value	4	2
Price Risk Derivative Liabilities, at Fair Value	(11)	(3)
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
Commodity Derivatives - Power [Member] \| Level 1 \| Call Option [Member]
Price Risk Derivative Assets, at Fair Value	1	1
Price Risk Derivative Liabilities, at Fair Value	(2)
Commodity Derivatives - Power [Member] \| Level 1 \| Future [Member]
Price Risk Derivative Assets, at Fair Value	4	2
Price Risk Derivative Liabilities, at Fair Value	(11)	(3)
Commodity Derivatives - Power [Member] \| Level 2 \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	36	4
Price Risk Derivative Liabilities, at Fair Value	(21)
Commodity Derivatives - Power [Member] \| Level 2 \| Call Option [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0
Commodity Derivatives - Power [Member] \| Level 2 \| Future [Member]
Price Risk Derivative Assets, at Fair Value	0	0
Price Risk Derivative Liabilities, at Fair Value	0	0
Commodity Derivatives - NGLs [Member] \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	384	127
Price Risk Derivative Liabilities, at Fair Value	(364)	(227)
Commodity Derivatives - NGLs [Member] \| Level 1 \| Forward Swaps [Member]
Price Risk Derivative Assets, at Fair Value	384	127
Price Risk Derivative Liabilities, at Fair Value	(364)	(227)
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