0001276187-20-000011 | 10-K | XBRL Viewer

Print Document View Excel Document

Cover Page Cover Page - USD ($) $ in Millions	12 Months Ended
Cover Page Cover Page - USD ($) $ in Millions	Dec. 31, 2019	Feb. 13, 2020	Jun. 30, 2019
Cover page.
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2019
Document Transition Report	false
Entity File Number	1-32740
Entity Registrant Name	ENERGY TRANSFER LP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	30-0108820
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
Title of 12(b) Security	Common Units
Trading Symbol	ET
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 30,570
Entity Common Stock, Shares Outstanding		2,689,897,793
Documents Incorporated by Reference	None
Entity Central Index Key	0001276187
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	FY
Amendment Flag	false

Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
ASSETS
Cash and cash equivalents	$ 291	$ 419
Accounts receivable, net	5,038	4,009
Accounts receivable from related companies	159	111
Inventories	1,935	1,677
Income taxes receivable	146	73
Derivative assets	23	111
Other current assets	275	350
Total current assets	7,867	6,750
Property, plant and equipment	89,790	79,776
Accumulated depreciation and depletion	(15,597)	(12,813)
Property, Plant and Equipment, Net	74,193	66,963
Advances to and investments in unconsolidated affiliates	3,460	2,642
Lease, Right of Use Asset, Net	964
Operating Lease, Right-of-Use Asset	1,000	0
Other non-current assets, net	1,075	1,006
Intangible assets, net	6,154	6,000
Goodwill	5,167	4,885
Total assets	98,880	88,246
LIABILITIES AND EQUITY
Accounts payable	4,118	3,493
Accounts payable to related companies	31	59
Derivative liabilities	147	185
Operating Lease, Liability, Current	60	0
Accrued and other current liabilities	3,342	2,918
Current maturities of long-term debt	26	2,655
Total current liabilities	7,724	9,310
Long-term debt, less current maturities	51,028	43,373
Non-current derivative liabilities	273	104
Operating Lease, Liability, Noncurrent	901	0
Deferred income taxes	3,208	2,926
Other non-current liabilities	1,162	1,184
Commitments and contingencies
Redeemable noncontrolling interests	739	499
Partners' Capital
General Partner	(4)	(5)
Limited Partners:
Common Unitholders (2,689,580,631 and 2,619,368,605 units authorized, issued and outstanding as of December 31, 2019 and 2018, respectively)	21,842	20,606
Accumulated other comprehensive loss	(11)	(42)
Total partners’ capital	21,827	20,559
Noncontrolling interests	12,018	10,291
Total equity	33,845	30,850
Total liabilities and equity	$ 98,880	$ 88,246

Consolidated Balance Sheets Balance Sheet (Paranthetical)	Dec. 31, 2018 shares
Class of Stock [Line Items]
Authorized	2,619,368,605
Issued	2,619,368,605
Outstanding	2,619,368,605

Consolidated Statements Of Operations - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
REVENUES:
Total revenues	$ 54,213	$ 54,087	$ 40,523
COSTS AND EXPENSES:
Cost of Goods and Services Sold	39,727	41,658	30,966
Operating expenses	3,294	3,089	2,644
Depreciation, depletion and amortization	3,147	2,859	2,554
Selling, general and administrative	694	702	599
Impairment losses	74	431	1,039
Total costs and expenses	46,936	48,739	37,802
OPERATING INCOME	7,277	5,348	2,721
OTHER INCOME (EXPENSE):
Interest expense, net of interest capitalized	(2,331)	(2,055)	(1,922)
Equity in earnings of unconsolidated affiliates	302	344	144
Impairment of investments in unconsolidated affiliates	0	0	(313)
Losses on extinguishments of debt	(18)	(112)	(89)
Gains (losses) on interest rate derivatives	(241)	47	(37)
Other, net	105	62	206
Income from continuing operations before income tax (expense) benefit	5,094	3,634	710
Income tax expense (benefit) from continuing operations	195	4	(1,833)
INCOME FROM CONTINUING OPERATIONS	4,899	3,630	2,543
Loss from discontinued operations	0	(265)	(177)
NET INCOME	4,899	3,365	2,366
Less: Net income attributable to noncontrolling interests	1,256	1,632	1,412
Less: Net income attributable to redeemable noncontrolling interests	51	39	0
NET INCOME ATTRIBUTABLE TO PARTNERS	3,592	1,694	954
General Partner’s interest in net income	4	3	2
Convertible Unitholders’ interest in net income	0	33	37
Limited Partners’ interest in net income	$ 3,588	$ 1,658	$ 915
INCOME FROM CONTINUING OPERATIONS PER LIMITED PARTNER UNIT (USD $ per unit):
Basic	$ 1.37	$ 1.17	$ 0.86
Diluted	1.36	1.16	0.84
NET INCOME PER LIMITED PARTNER UNIT (USD $ per Unit):
Basic	1.37	1.16	0.85
Diluted	$ 1.36	$ 1.15	$ 0.83
Refined product sales
REVENUES:
Revenue from Contract with Customer, Including Assessed Tax	$ 16,752	$ 17,458	$ 11,166
Crude sales
REVENUES:
Revenue from Contract with Customer, Including Assessed Tax	15,917	14,425	10,706
Natural gas sales
REVENUES:
Revenue from Contract with Customer, Including Assessed Tax	3,295	4,452	4,172
Gathering, transportation and other fees
REVENUES:
Revenue from Contract with Customer, Including Assessed Tax	9,086	6,797	4,435
NGL sales
REVENUES:
Revenue from Contract with Customer, Including Assessed Tax	8,290	9,986	7,781
Other
REVENUES:
Revenue from Contract with Customer, Including Assessed Tax	$ 873	$ 969	$ 2,263

Consolidated Statements Of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Net income	$ 4,899	$ 3,365	$ 2,366
Other comprehensive income (loss), net of tax:
Change in value of available-for-sale securities	11	(4)	6
Actuarial gain (loss) relating to pension and other postretirement benefits	24	(43)	(12)
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Adjustment, Net of Tax, Portion Attributable to Parent	6	0	0
Change in other comprehensive income from unconsolidated affiliates	(10)	4	1
Other comprehensive income (loss), net of tax, total	31	(43)	(5)
Comprehensive income	4,930	3,322	2,361
Less: Comprehensive income attributable to noncontrolling interests	1,256	1,632	1,407
Less: Comprehensive income attributable to redeemable noncontrolling interests	51	39	0
Comprehensive income attributable to partners	$ 3,623	$ 1,651	$ 954

Consolidated Statement Of Equity - USD ($) $ in Millions	Total	General Partner [Member]	AOCI Attributable to Parent [Member]	Limited Partner [Member]	Series A Convertible Preferred Units [Member]	Noncontrolling Interest [Member]	PennTex Acquisition [Member] General Partner [Member]	PennTex Acquisition [Member] AOCI Attributable to Parent [Member]	PennTex Acquisition [Member] Limited Partner [Member]	PennTex Acquisition [Member] Series A Convertible Preferred Units [Member]	PennTex Acquisition [Member] Noncontrolling Interest [Member]	Sale of Bakken Pipeline interest [Member]	Sale of Bakken Pipeline interest [Member] General Partner [Member]	Sale of Bakken Pipeline interest [Member] AOCI Attributable to Parent [Member]	Sale of Bakken Pipeline interest [Member] Limited Partner [Member]	Sale of Bakken Pipeline interest [Member] Series A Convertible Preferred Units [Member]	Sale of Bakken Pipeline interest [Member] Noncontrolling Interest [Member]	Sale of Rover Pipeline interest [Member]	Sale of Rover Pipeline interest [Member] General Partner [Member]	Sale of Rover Pipeline interest [Member] AOCI Attributable to Parent [Member]	Sale of Rover Pipeline interest [Member] Limited Partner [Member]	Sale of Rover Pipeline interest [Member] Series A Convertible Preferred Units [Member]	Sale of Rover Pipeline interest [Member] Noncontrolling Interest [Member]
Balance at Dec. 31, 2016	$ 22,431	$ (3)	$ 0	$ (1,871)	$ 180	$ 24,125
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Distributions to partners	(1,010)	(2)	0	(1,008)	0	0
Distributions to noncontrolling interest	(2,999)	0	0	0	0	(2,999)
Distributions reinvested	0	0	0	234	(234)	0
Units repurchased under buyback program	0
Partners' Capital Account, Sale of Units	568	0	0	568	0	0
Subsidiary unit transactions	3,235	0	0	(55)	(1)	3,291
Capital contributions received from noncontrolling interest	2,202	0	0	0	0	2,202
Other, net	(6)	0	0	0	0	(6)
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	(280)						$ 0	$ 0	$ (2)	$ 0	$ (278)
Acquisition and disposition of noncontrolling interest												$ (2,000)	$ 0	$ 0	$ (42)	$ 0	$ (1,958)	$ (1,478)	$ 0	$ 0	$ (2)	$ 0	$ (1,476)
Other comprehensive income, net of tax	(5)	0	0	0	0	(5)
Net income	2,366	2	0	915	37	1,412
Balance at Dec. 31, 2017	29,980	(3)	0	(1,643)	450	31,176
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Distributions to partners	(1,684)	(3)	0	(1,681)	0	0
Distributions to noncontrolling interest	(3,117)	0	0	0	0	(3,117)
Distributions reinvested	0	0	0	115	(115)
Units repurchased under buyback program	0
Subsidiary unit transactions	924	0	0	1	0	923
Capital contributions received from noncontrolling interest	649	0	0	0	0	649
Non-cash compensation expense, net of units tendered by employees for tax withholdings	0	0	0	21,869	0	(21,869)
Other, net	61	(2)	1	47	(2)	17
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	(24)	0	0	(119)	(7)	102
Other comprehensive income, net of tax	(43)	0	(43)	0	0	0
Net income	3,365
Noncontrolling Interest, Increase from Business Combination	832	0	0	0	0	832
Stock Issued During Period, Value, Conversion of Units	0	0	0	589	(589)	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Excluding Portion Attributable to Redeemable Noncontrolling Interest	3,326	3	0	1,658	33	1,632
Balance at Dec. 31, 2018	30,850	(5)	(42)	20,606	0	10,291
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Cumulative Effect of New Accounting Principle in Period of Adoption	(54)	0	0	0	0	(54)
Distributions to partners	(3,054)	(3)	0	(3,051)	0	0
Distributions to noncontrolling interest	(1,597)	0	0	0	0	(1,597)
Units repurchased under buyback program	(25)	0	0	(25)	0	0
Subsidiary unit transactions	780	0	0	0	0	780
Capital contributions received from noncontrolling interest	348	0	0	0	0	348
Non-cash compensation expense, net of units tendered by employees for tax withholdings	1,471	0	0	652	0	819
Other, net	100	0	0	72	0	28
Acquisition and disposition of noncontrolling interest	(93)	0	0	0	0	(93)
Other comprehensive income, net of tax	31	0	31	0	0	0
Net income	4,899
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Excluding Portion Attributable to Redeemable Noncontrolling Interest	4,848	4	0	3,588	0	1,256
Balance at Dec. 31, 2019	$ 33,845	$ (4)	$ (11)	$ 21,842	$ 0	$ 12,018

Consolidated Statements Of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$ 4,899	$ 3,365	$ 2,366
Reconciliation of net income to net cash provided by operating activities:
Loss from discontinued operations	0	265	177
Depreciation, depletion and amortization	3,147	2,859	2,554
Deferred income taxes	(217)	7	1,871
Inventory valuation adjustments	(79)	85	(24)
Non-cash compensation expense	113	105	99
Impairment losses	74	431	1,039
Impairment of investments in unconsolidated affiliates	0	0	313
Losses on extinguishments of debt	18	112	89
Distributions On Unvested Unit Awards	38	38	35
Proceeds from Equity Method Investment, Distribution	290	328	297
Other non-cash	(182)	(56)	239
Equity in earnings of unconsolidated affiliates	(302)	(344)	(144)
Net change in operating assets and liabilities, net of effects of acquisitions and deconsolidations	(518)	289	(192)
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	8,003	7,506	4,429
INVESTING ACTIVITIES:
Cash received for sale of noncontrolling interest	93	0	0
Cash Acquired from Acquisition	0	461	0
Cash paid for acquisitions, net of cash received	(7)	(429)	(303)
Capital expenditures, excluding allowance for equity funds used during construction	(5,960)	(7,407)	(8,444)
Contributions in aid of construction costs	80	109	31
Contributions to unconsolidated affiliates	(523)	(26)	(268)
Distributions from unconsolidated affiliates in excess of cumulative earnings	98	69	135
Proceeds from the sale of other assets	54	87	48
Other	18	61	(3)
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	(6,934)	(7,075)	(5,606)
FINANCING ACTIVITIES:
Proceeds from borrowings	22,583	29,001	31,608
Repayments of long-term debt	(20,101)	(28,948)	(31,268)
Cash received from affiliate notes	0	0	(255)
Proceeds from Issuance of Common Limited Partners Units	0	0	568
Subsidiary units issued for cash	780	1,402	3,235
Distributions to partners	(3,054)	(1,684)	(1,010)
Distributions to noncontrolling interests	(1,597)	(3,117)	(2,961)
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	0	24	0
Redemption of preferred units	0	0	(53)
Debt issuance costs	(117)	(171)	(131)
Capital contributions from noncontrolling interests	348	649	1,214
Units repurchased under buyback program	(25)	0	0
Payments for Repurchase of Common Units by Subsidiary	0	24	0
Other, net	(14)	(166)	6
Net cash provided by (used in) financing activities	(1,197)	(3,082)	953
Cash Provided by (Used in) Operating Activities, Discontinued Operations	0	(484)	136
Cash Provided by (Used in) Investing Activities, Discontinued Operations	0	3,207	(38)
Increase (Decrease) in Assets Held-for-sale	0	11	(5)
Net increase in cash and cash equivalents of discontinued operations	0	2,734	93
Increase (decrease) in cash and cash equivalents	(128)	83	(131)
Cash and cash equivalents, beginning of period	419	336	467
Cash and cash equivalents, end of period	291	419	336
Bakken Pipeline [Member]
INVESTING ACTIVITIES:
Proceeds from Divestiture of Interest in Joint Venture	0	0	2,000
Rover Pipeline LLC [Member]
INVESTING ACTIVITIES:
Proceeds from Divestiture of Interest in Joint Venture	0	0	1,478
SemGroup [Member]
INVESTING ACTIVITIES:
Cash paid for acquisitions, net of cash received	787	0	0
PennTex [Member]
INVESTING ACTIVITIES:
Cash paid for acquisitions, net of cash received	$ 0	$ 0	$ 280

Operations And Organization

12 Months Ended

Dec. 31, 2019

Operations And Organization [Abstract]

Operations And Organization

OPERATIONS AND BASIS OF PRESENTATION:

The consolidated financial statements presented herein contain the results of Energy Transfer LP and its subsidiaries (the “Partnership,” “we,” “us,” “our” or “ET”). References to the “Parent Company” mean Energy Transfer LP on a stand-alone basis.

In October 2018, we completed the merger of ETO with a wholly-owned subsidiary of ET in a unit-for-unit exchange (the “Energy Transfer Merger”). In connection with the transaction, the former common unitholders (other than ET and its subsidiaries) received 1.28 common units of ET for each common unit of ETO they owned. Following the closing of the Energy Transfer Merger, Energy Transfer Partners, L.P. was renamed Energy Transfer Operating, L.P. In addition, Energy Transfer Equity, L.P. was renamed Energy Transfer LP, and its common units began trading on the NYSE under the “ET” ticker symbol on Friday, October 19, 2018.

Immediately prior to the closing of the Energy Transfer Merger, the following also occurred:


•	the IDRs in Energy Transfer Partners, L.P. were converted into 1,168,205,710 common units;


•	the general partner interest in ETO was converted to a non-economic general partner interest and ETO issued 18,448,341 ETO common units to ETP GP;


•	ET contributed its 2,263,158 Sunoco LP common units to ETO in exchange for 2,874,275 ETO common units and 100 percent of the limited liability company interests in Sunoco GP LLC, the sole general partner of Sunoco LP, and all of the IDRs in Sunoco LP, to ETO in exchange for 42,812,389 ETO common units;


•	ET contributed its 12,466,912 common units representing limited partner interests in USAC and 100 percent of the limited liability company interests in USA Compression GP, LLC, the general partner of USAC, to ETO in exchange for 16,134,903 ETO common units; and


•	ET contributed its 100 percent limited liability company interest in Lake Charles LNG and a 60 percent limited liability company interest in each of Energy Transfer LNG Export, LLC, ET Crude Oil Terminals, LLC and ETC Illinois LLC (collectively, “Lake Charles LNG and Other”) to ETO in exchange for 37,557,815 ETO common units.

Subsequent to the Energy Transfer Merger, substantially all of the Partnership’s cash flows are derived from distributions related to its investment in ETO, whose cash flows are derived from its subsidiaries, including ETO’s investments in Sunoco LP and USAC. The Parent Company’s primary cash requirements are for general and administrative expenses, debt service requirements and distributions to its partners. Parent Company-only assets are not available to satisfy the debts and other obligations of ET’s subsidiaries.

Our financial statements reflect the following reportable segments:

•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

•corporate and other, including the following:


•	activities of the Parent Company; and


•	certain operations and investments that are not separately reflected as reportable segments.

The Partnership is engaged in the gathering and processing, compression, treating and transportation of natural gas, focusing on providing midstream services in some of the most prolific natural gas producing regions in the United States, including the Eagle Ford, Haynesville, Barnett, Fayetteville, Marcellus, Utica, Bone Spring and Avalon shales.

The Partnership owns and operates intrastate natural gas pipeline systems and storage facilities that are engaged in the business of purchasing, gathering, transporting, processing, and marketing natural gas and NGLs in the states of Texas, Louisiana, New Mexico and West Virginia.

The Partnership owns and operates interstate pipelines, either directly or through equity method investments, that transport natural gas to various markets in the United States.

The Partnership owns and operates a logistics business, consisting of a geographically diverse portfolio of complementary pipeline, terminalling, and acquisition and marketing assets, which are used to facilitate the purchase and sale of crude oil, NGLs and refined products.

The Partnership owns a controlling interest in Sunoco LP which is engaged in the wholesale distribution of motor fuels to convenience stores, independent dealers, commercial customers, and distributors, as well as the retail sale of motor fuels and merchandise through Sunoco LP operated convenience stores and retail fuel sites. As of December 31, 2019, our interest in Sunoco LP consisted of 100% of the general partner and IDRs, as well as 28.5 million common units.

The Partnership owns a controlling interest in USAC which provides compression services to producers, processors, gatherers and transporters of natural gas and crude oil. As of December 31, 2019, our interest in USAC consisted of 100% of the general partner and 46.1 million common units.

Basis of Presentation. The consolidated financial statements of Energy Transfer LP presented herein for the years ended December 31, 2019, 2018 and 2017, have been prepared in accordance with GAAP and pursuant to the rules and regulations of the SEC. We consolidate all majority-owned subsidiaries and limited partnerships, which we control as the general partner or owner of the general partner. All significant intercompany transactions and accounts are eliminated in consolidation.

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


•	the Parent Company;


•	our controlled subsidiary, Energy Transfer Operating, L.P.; and


•	Energy Transfer Partners GP, L.P. (“ETP GP”), the general partner of ETO, and Energy Transfer Partners, L.L.C. (“ETP LLC”), the general partner of ETP GP.

For prior periods herein, certain balances have been reclassified to assets and liabilities held for sale and certain revenues and expenses to discontinued operations. These reclassifications had no impact on net income or total equity.

Estimates, Significant Accounting Policies and Balance Sheet Detail

12 Months Ended

Dec. 31, 2019

Accounting Policies [Abstract]

Estimates, Significant Accounting Policies and Balance Sheet Detail

ESTIMATES, SIGNIFICANT ACCOUNTING POLICIES AND BALANCE SHEET DETAIL:

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the accrual for and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.

The natural gas industry conducts its business by processing actual transactions at the end of the month following the month of delivery. Consequently, the most current month’s financial results for the midstream, NGL and intrastate transportation and storage operations are estimated using volume estimates and market prices. Any differences between estimated results and actual results are recognized in the following month’s financial statements. Management believes that the estimated operating results represent the actual results in all material respects.

Some of the other significant estimates made by management include, but are not limited to, the timing of certain forecasted transactions that are hedged, the fair value of derivative instruments, useful lives for depreciation and amortization, purchase accounting allocations and subsequent realizability of intangible assets, fair value measurements used in the goodwill impairment test, market value of inventory, assets and liabilities resulting from the regulated ratemaking process, contingency reserves and environmental reserves. Actual results could differ from those estimates.

Lease Accounting

In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-02, Leases (Topic 842), which has amended the FASB Accounting Standards Codification (“ASC”) and introduced Topic 842, Leases. On January 1, 2019, the Partnership has adopted ASC Topic 842 (“Topic 842”), which is effective for interim and annual reporting periods beginning on or after December 15, 2018. Topic 842 requires entities to recognize lease assets

and liabilities on the balance sheet for all leases with a term of more than one year, including operating leases, which historically were not recorded on the balance sheet in accordance with the prior standard.

To adopt Topic 842, the Partnership recognized a cumulative catch-up adjustment to the opening balance sheet as of January 1, 2019 related to certain leases that existed as of that date. As permitted, we have not retrospectively modified our consolidated financial statements for comparative purposes. The adoption of the standard had a material impact on our consolidated balance sheet, but did not have an impact on our consolidated statements of operations, comprehensive income or cash flows. As a result of adoption, we have recorded additional net right-of-use (“ROU”) lease assets and lease liabilities of approximately $888 million and $888 million, respectively, as of January 1, 2019. In addition, we have updated our business processes, systems, and internal controls to support the on-going reporting requirements under the new standard.

To adopt Topic 842, the Partnership elected the package of practical expedients permitted under the transition guidance within the standard. The expedient package allowed us not to reassess whether existing contracts contained a lease, the lease classification of existing leases and initial direct cost for existing leases. In addition to the package of practical expedients, the Partnership has elected not to capitalize amounts pertaining to leases with terms less than twelve months, to use the portfolio approach to determine discount rates, not to separate non-lease components from lease components and not to apply the use of hindsight to the active lease population.

Cumulative-effect adjustments made to the opening balance sheet at January 1, 2019 were as follows:



	Balance at December 31, 2018, as previously reported		Adjustments due to Topic 842 (Leases)			Balance at January 1, 2019
Assets:
Property, plant and equipment, net	$	66,963	$	(1	)	$	66,962
Lease right-of-use assets, net	—		889			889
Liabilities:
Operating lease current liabilities	$	—	$	71		$	71
Accrued and other current liabilities	2,918		(1		)	2,917
Current maturities of long-term debt	2,655		1			2,656
Long-term debt, less current maturities	43,373		6			43,379
Non-current operating lease liabilities	—		823			823
Other non-current liabilities	1,184		(12		)	1,172

Additional disclosures related to lease accounting are included in Note 13.

Regulatory Accounting – Regulatory Assets and Liabilities

Our interstate transportation and storage segment is subject to regulation by certain state and federal authorities, and certain subsidiaries in that segment have accounting policies that conform to the accounting requirements and ratemaking practices of the regulatory authorities. The application of these accounting policies allows certain of our regulated entities to defer expenses and revenues on the balance sheet as regulatory assets and liabilities when it is probable that those expenses and revenues will be allowed in the ratemaking process in a period different from the period in which they would have been reflected in the consolidated statement of operations by an unregulated company. These deferred assets and liabilities will be reported in results of operations in the period in which the same amounts are included in rates and recovered from or refunded to customers. Management’s assessment of the probability of recovery or pass through of regulatory assets and liabilities will require judgment and interpretation of laws and regulatory commission orders. If, for any reason, we cease to meet the criteria for application of regulatory accounting treatment for these entities, the regulatory assets and liabilities related to those portions ceasing to meet such criteria would be eliminated from the consolidated balance sheet for the period in which the discontinuance of regulatory accounting treatment occurs.

Although Panhandle’s natural gas transmission systems and storage operations are subject to the jurisdiction of the FERC in accordance with the Natural Gas Act of 1938 and Natural Gas Policy Act of 1978, it does not currently apply regulatory accounting policies in accounting for its operations. Panhandle does not apply regulatory accounting policies primarily due to the level of discounting from tariff rates and its inability to recover specific costs.

Cash, Cash Equivalents and Supplemental Cash Flow Information

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

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

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



	Years Ended December 31,
	2019			2018			2017
Accounts receivable	$	(473	)	$	541		$	(948	)
Accounts receivable from related companies	(69		)	162			24
Inventories	(117		)	282			58
Other current assets	117			7			38
Other non-current assets, net	(78		)	(92		)	84
Accounts payable	146			(766		)	712
Accounts payable to related companies	(32		)	(202		)	(178		)
Accrued and other current liabilities	(44		)	382			(97		)
Other non-current liabilities	(186		)	28			106
Derivative assets and liabilities, net	218			(53		)	9
Net change in operating assets and liabilities, net of effects of acquisitions	$	(518	)	$	289		$	(192	)

Non-cash investing and financing activities and supplemental cash flow information are as follows:



	Years Ended December 31,
	2019		2018			2017
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures	$	1,334	$	1,030		$	1,060
Lease assets obtained in exchange for new lease liabilities	68		—			—
Net losses from subsidiary common unit transactions	—		(126		)	(56		)
NON-CASH FINANCING ACTIVITIES:
Contribution of assets from noncontrolling interests	$	—	$	—		$	988
SUPPLEMENTAL CASH FLOW INFORMATION:
Cash paid for interest, net of interest capitalized	$	1,932	$	1,870		$	1,914
Cash paid for income taxes	31		508			50

Accounts Receivable

Our operations deal with a variety of counterparties across the energy sector, some of which are investment grade, and most of which are not. Internal credit ratings and credit limits are assigned to all counterparties and limits are monitored against credit exposure. Letters of credit or prepayments may be required from those counterparties that are not investment grade depending on the internal credit rating and level of commercial activity with the counterparty.

We have a diverse portfolio of customers; however, because of the midstream and transportation services we provide, many of our customers are engaged in the exploration and production segment. We manage trade credit risk to mitigate credit losses and exposure to uncollectible trade receivables. Prospective and existing customers are reviewed regularly for creditworthiness to manage credit risk within approved tolerances. Customers that do not meet minimum credit standards are required to provide

additional credit support in the form of a letter of credit, prepayment, or other forms of security. We establish an allowance for doubtful accounts on trade receivables based on the expected ultimate recovery of these receivables and consider many factors including historical customer collection experience, general and specific economic trends, and known specific issues related to individual customers, sectors, and transactions that might impact collectability. Increases in the allowance are recorded as a component of operating expenses; reductions in the allowance are recorded when receivables are subsequently collected or written-off. Past due receivable balances are written-off when our efforts have been unsuccessful in collecting the amount due.

Inventories

Inventories 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.

Inventories consisted of the following:



	December 31,
	2019		2018
Natural gas, NGLs and refined products ⁽¹⁾	$	833	$	833
Crude oil	654		506
Spare parts and other	448		338
Total inventories	$	1,935	$	1,677


⁽¹⁾	Due to changes in fuel prices, Sunoco LP recorded a write-down on the value of its fuel inventory of $85 million as of December 31, 2018.

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.

Other Current Assets

Other current assets consisted of the following:



	December 31,
	2019		2018
Deposits paid to vendors	$	95	$	141
Prepaid expenses and other	180		209
Total other current assets	$	275	$	350

Property, Plant and Equipment

Property, plant and equipment are stated at cost less accumulated depreciation. Depreciation is computed using the straight-line method over the estimated useful or FERC-mandated lives of the assets, if applicable. Expenditures for maintenance and repairs that do not add capacity or extend the useful life are expensed as incurred. Expenditures to refurbish assets that either extend the useful lives of the asset or prevent environmental contamination are capitalized and depreciated over the remaining useful life of the asset. Additionally, we capitalize certain costs directly related to the construction of assets including internal labor costs, interest and engineering costs. Upon disposition or retirement of pipeline components or natural gas plant components, any gain or loss is recorded to accumulated depreciation. When entire pipeline systems, gas plants or other property and equipment are retired or sold, any gain or loss is included in our consolidated statements of operations.

Property, plant and equipment is reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. If such a review should indicate that the carrying amount of long-lived assets is not recoverable, we reduce the carrying amount of such assets to fair value.

In 2019, USAC recognized a $6 million fixed asset impairment related to certain idle compressor assets. Sunoco LP recognized a $47 million write-down on assets held for sale related to its ethanol plant in Fulton, New York.

In 2018, USAC recognized a $9 million fixed asset impairment related to certain idle compressor assets.

In 2017, the Partnership recorded a $127 million fixed asset impairment related to Sea Robin primarily due to a reduction in expected future cash flows due to an increase during 2017 in insurance costs related to offshore assets.

Capitalized interest is included for pipeline construction projects, except for certain interstate projects for which an allowance for funds used during construction (“AFUDC”) is accrued. Interest is capitalized based on the current borrowing rate of our revolving credit facilities when the related costs are incurred. AFUDC is calculated under guidelines prescribed by the FERC and capitalized as part of the cost of utility plant for interstate projects. It represents the cost of servicing the capital invested in construction work-in-process. AFUDC is segregated into two component parts – borrowed funds and equity funds.

Components and useful lives of property, plant and equipment were as follows:



	December 31,
	2019			2018
Land and improvements	$	1,264		$	1,168
Buildings and improvements (1 to 45 years)	2,632			2,664
Pipelines and equipment (5 to 83 years)	64,678			58,783
Product storage and related facilities (2 to 83 years)	5,898			4,978
Right of way (20 to 83 years)	4,859			4,533
Other (1 to 48 years)	1,964			1,583
Construction work-in-process	8,495			6,067
	89,790			79,776
Less – Accumulated depreciation and depletion	(15,597		)	(12,813		)
Property, plant and equipment, net	$	74,193		$	66,963

We recognized the following amounts for the periods presented:



	Years Ended December 31,
	2019		2018		2017
Depreciation, depletion and amortization expense	$	2,839	$	2,538	$	2,204
Capitalized interest	166		294		286

Advances to and Investments in Unconsolidated Affiliates

We own interests in a number of related businesses that are accounted for by the equity method. In general, we use the equity method of accounting for an investment for which we exercise significant influence over, but do not control, the investee’s operating and financial policies. An impairment of an investment in an unconsolidated affiliate is recognized when circumstances indicate that a decline in the investment value is other than temporary.

Other Non-Current Assets, net

Other non-current assets, net are stated at cost less accumulated amortization. Other non-current assets, net consisted of the following:



	December 31,
	2019		2018
Regulatory assets	$	42	$	43
Pension assets	84		68
Deferred charges	178		173
Restricted funds	178		178
Other	593		544
Total other non-current assets, net	$	1,075	$	1,006

Restricted funds include an immaterial amount of restricted cash primarily held in our wholly-owned captive insurance companies.

Intangible Assets

Intangible assets are stated at cost, net of amortization computed on the straight-line method. The Partnership removes the gross carrying amount and the related accumulated amortization for any fully amortized intangibles in the year they are fully amortized.

Components and useful lives of intangible assets were as follows:



	December 31, 2019					December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Gross Carrying Amount		Accumulated Amortization
Amortizable intangible assets:
Customer relationships, contracts and agreements (3 to 46 years)	$	7,535	$	(1,743	)	$	7,106	$	(1,493	)
Patents (10 years)	48		(35		)	48		(30		)
Trade names (20 years)	66		(31		)	66		(28		)
Other (5 to 20 years)	19		(12		)	33		(9		)
Total amortizable intangible assets	7,668		(1,821		)	7,253		(1,560		)
Non-amortizable intangible assets:
Trademarks	295		—			295		—
Other	12		—			12		—
Total non-amortizable intangible assets	307		—			307		—
Total intangible assets	$	7,975	$	(1,821	)	$	7,560	$	(1,560	)

Aggregate amortization expense of intangible assets was as follows:



	Years Ended December 31,
	2019		2018		2017
Reported in depreciation, depletion and amortization expense	$	308	$	321	$	344

Estimated aggregate amortization expense of intangible assets for the next five years was as follows:



Years Ending December 31:
2020	$	394
2021	390
2022	360
2023	320
2024	307

We review amortizable intangible assets for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. If such a review should indicate that the carrying amount of amortizable intangible assets is not recoverable, we reduce the carrying amount of such assets to fair value. We review non-amortizable intangible assets for impairment annually, or more frequently if circumstances dictate.

Sunoco LP performed impairment tests on its indefinite-lived intangible assets during the fourth quarter of 2018 and recognized a $30 million impairment charge on its contractual rights primarily due to decreases in projected future revenues and cash flows from the date the intangible assets were originally recorded.

Sunoco LP performed impairment tests on its indefinite-lived intangible assets during the fourth quarter of 2017 and recognized a total of $17 million in impairment charges on their contractual rights and liquor licenses primarily due to decreases in projected future revenues and cash flows from the date the intangible assets were originally recorded.

Goodwill

Goodwill is tested for impairment annually or more frequently if circumstances indicate that goodwill might be impaired. The annual impairment test is performed during the fourth quarter.

Changes in the carrying amount of goodwill were 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		All Other			Total
Balance, December 31, 2017	$	10	$	196		$	870		$	693	$	1,167	$	1,430		$	—	$	402		$	4,768
Acquired	—		—			—			—		—		129			366		—			495
CDM Contribution	—		—			—			—		—		—			253		(253		)	—
Impaired	—		—			(378		)	—		—		—			—		—			(378		)
Other	—		—			—			—		—		—			—		—			—
Balance, December 31, 2018	10		196			492			693		1,167		1,559			619		149			4,885
Acquired	—		42			—			—		230		—			—		35			307
Impaired	—		(12		)	(9		)	—		—		—			—		—			(21		)
Other	—		—			—			—		—		(4		)	—		—			(4		)
Balance, December 31, 2019	$	10	$	226		$	483		$	693	$	1,397	$	1,555		$	619	$	184		$	5,167

Goodwill is recorded at the acquisition date based on a preliminary purchase price allocation and generally may be adjusted when the purchase price allocation is finalized. During the fourth quarter of 2019, $265 million goodwill was recorded in conjunction with the acquisition of SemGroup.

During the third quarter of 2019, the Partnership recognized a goodwill impairment of $12 million related to the Southwest Gas operations within the interstate segment primarily due to decreases in projected future revenues and cash flows. During the fourth quarter of 2019, the Partnership recognized a goodwill impairment of $9 million related to our North Central operations within the midstream segment primarily due to changes in assumptions related to projected future revenues and cash flows.

During the fourth quarter of 2018, the Partnership recognized goodwill impairments of $378 million related to our Northeast operations within the midstream segment primarily due to changes in assumptions related to projected future revenues and cash flows from the dates the goodwill was originally recorded. These changes in assumptions reflect delays in the construction of third-party takeaway capacity in the Northeast.

During the fourth quarter of 2017, the Partnership recognized goodwill impairments of $262 million in the interstate transportation and storage segment, $79 million in the NGL and refined products transportation and services segment and $452 million in the all other segment primarily due to changes in assumptions related to projected future revenues and cash flows from the dates the goodwill was originally recorded. Sunoco LP recognized goodwill impairments of $387 million, of which $102 million was allocated to continuing operations, primarily due to changes in assumptions related to projected future revenues and cash flows from the dates the goodwill was originally recorded.

In connection with aforementioned impairments, the Partnership determined the fair value of our reporting units using a weighted combination of the discounted cash flow method and the guideline company method. Determining the fair value of a reporting unit requires judgment and the use of significant estimates and assumptions. Such estimates and assumptions include revenue growth rates, operating margins, weighted average costs of capital and future market conditions, among others. The Partnership believes the estimates and assumptions used in our impairment assessments are reasonable and based on available market information, but variations in any of the assumptions could result in materially different calculations of fair value and determinations of whether or not an impairment is indicated. Under the discounted cash flow method, the Partnership determined fair value based on estimated future cash flows of each reporting unit including estimates for capital expenditures, discounted to present value using the risk-adjusted industry rate, which reflect the overall level of inherent risk of the reporting unit. Cash flow projections are derived from one year budgeted amounts and five year operating forecasts plus an estimate of later period cash flows, all of which are evaluated by management. Subsequent period cash flows are developed for each reporting unit using growth rates that management believes are reasonably likely to occur. Under the guideline company method, the Partnership determined the estimated fair value of each of our reporting units by applying valuation multiples of comparable publicly-traded companies to each reporting unit’s projected EBITDA and then averaging that estimate with similar historical calculations using a three year average. In addition, the Partnership estimated a reasonable

control premium representing the incremental value that accrues to the majority owner from the opportunity to dictate the strategic and operational actions of the business.

Management does not believe that any of the goodwill balances in its reporting units is currently at significant risk of impairment; however, of the $5.17 billion of goodwill on the Partnership’s consolidated balance sheet as of December 31, 2019, approximately $380 million is recorded in reporting units for which the estimated fair value exceeded the carrying value by less than 20% in the most recent quantitative test.

Asset Retirement Obligations

We have determined that we are obligated by contractual or regulatory requirements to remove facilities or perform other remediation upon retirement of certain assets. The fair value of any ARO is determined based on estimates and assumptions related to retirement costs, which the Partnership bases on historical retirement costs, future inflation rates and credit-adjusted risk-free interest rates. These fair value assessments are considered to be Level 3 measurements, as they are based on both observable and unobservable inputs. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO.

An ARO is required to be recorded when a legal obligation to retire an asset exists and such obligation can be reasonably estimated. We will record an ARO in the periods in which management can reasonably estimate the settlement dates.

Except for certain amounts discussed below, management was not able to reasonably measure the fair value of AROs as of December 31, 2019 and 2018, in most cases because the settlement dates were indeterminable. Although a number of other onshore assets in Panhandle’s system are subject to agreements or regulations that give rise to an ARO upon Panhandle’s discontinued use of these assets, AROs were not recorded because these assets have an indeterminate removal or abandonment date given the expected continued use of the assets with proper maintenance or replacement. ETC Sunoco has legal AROs for several other assets at its previously owned refineries, pipelines and terminals, for which it is not possible to estimate when the obligations will be settled. Consequently, the retirement obligations for these assets cannot be measured at this time. At the end of the useful life of these underlying assets, ETC Sunoco is legally or contractually required to abandon in place or remove the asset. We believe we may have additional AROs related to ETC Sunoco’s pipeline assets and storage tanks, for which it is not possible to estimate whether or when the AROs will be settled. Consequently, these AROs cannot be measured at this time. Sunoco LP has AROs related to the estimated future cost to remove underground storage tanks.

As of December 31, 2019 and 2018, other non-current liabilities in the Partnership’s consolidated balance sheets included AROs of $247 million and $193 million, respectively. For the years ended December 31, 2019, 2018 and 2017 aggregate accretion expense related to AROs was $5 million, $13 million and $9 million, respectively.

Individual component assets have been and will continue to be replaced, but the pipeline and the natural gas gathering and processing systems will continue in operation as long as supply and demand for natural gas exists. Based on the widespread use of natural gas in industrial and power generation activities, management expects supply and demand to exist for the foreseeable future. We have in place a rigorous repair and maintenance program that keeps the pipelines and the natural gas gathering and processing systems in good working order. Therefore, although some of the individual assets may be replaced, the pipelines and the natural gas gathering and processing systems themselves will remain intact indefinitely.

Other non-current assets on the Partnership’s consolidated balance sheet included $31 million and $26 million of legally restricted funds for the purpose of settling AROs as of December 31, 2019 and 2018, respectively.

Accrued and Other Current Liabilities

Accrued and other current liabilities consisted of the following:



	December 31,
	2019		2018
Interest payable	$	579	$	571
Customer advances and deposits	123		128
Accrued capital expenditures	1,334		1,030
Accrued wages and benefits	217		283
Taxes payable other than income taxes	263		256
Exchanges payable	67		112
Other	759		538
Total accrued and other current liabilities	$	3,342	$	2,918

Deposits or advances are received from our customers as prepayments for natural gas deliveries in the following month. Prepayments and security deposits may be required when customers exceed their credit limits or do not qualify for open credit.

Redeemable Noncontrolling Interests

Our redeemable noncontrolling interests relate to certain preferred unitholders of one of our consolidated subsidiaries that have the option to convert their preferred units to such subsidiary’s common units at the election of the holders and the noncontrolling interest holders in one of our consolidated subsidiaries that have the option to sell their interests to us. In accordance with applicable accounting guidance, the noncontrolling interest is excluded from total equity and reflected as redeemable noncontrolling interests on our consolidated balance sheet. See Note 7 for further information.

Environmental Remediation

We accrue environmental remediation costs for work at identified sites where an assessment has indicated that cleanup costs are probable and reasonably estimable. Such accruals are undiscounted and are based on currently available information, estimated timing of remedial actions and related inflation assumptions, existing technology and presently enacted laws and regulations. If a range of probable environmental cleanup costs exists for an identified site, the minimum of the range is accrued unless some other point in the range is more likely in which case the most likely amount in the range is accrued.

Fair Value of Financial Instruments

The carrying amounts of cash and cash equivalents, accounts receivable and accounts payable approximate their fair value.

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 debt obligations as of December 31, 2019 was $54.79 billion and $51.05 billion, respectively. As of December 31, 2018, the aggregate fair value and carrying amount of our debt obligations was $45.06 billion and $46.03 billion, respectively. The fair value of our consolidated debt obligations is a Level 2 valuation based on the observable inputs used for similar liabilities.

We have commodity derivatives, interest rate derivatives and embedded derivatives in our preferred units that are accounted for as assets and liabilities at fair value in our consolidated balance sheets. We determine the fair value of our assets and liabilities subject to fair value measurement by using the highest possible “level” of inputs. Level 1 inputs are observable quotes in an active market for identical assets and liabilities. We consider the valuation of marketable securities and commodity derivatives transacted through a clearing broker with a published price from the appropriate exchange as a Level 1 valuation. Level 2 inputs are inputs observable for similar assets and liabilities. We consider OTC commodity derivatives entered into directly with third parties as a Level 2 valuation since the values of these derivatives are quoted on an exchange for similar transactions. Additionally, we consider our options transacted through our clearing broker as having Level 2 inputs due to the level of activity of these contracts on the exchange in which they trade. We consider the valuation of our interest rate derivatives as Level 2 as the primary input, the LIBOR curve, is based on quotes from an active exchange of Eurodollar futures for the same period as the future interest swap settlements. Level 3 inputs are unobservable. During the year ended December 31, 2019, no transfers were made between any levels within the fair value hierarchy.

The following tables summarize the fair value of our financial assets and liabilities measured and recorded at fair value on a recurring basis as of December 31, 2019 and 2018 based on inputs used to derive their fair values:



	Fair Value Total			Fair Value Measurements at December 31, 2019
				Level 1			Level 2
Assets:
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	$	17		$	17		$	—
Swing Swaps IFERC	1			—			1
Fixed Swaps/Futures	65			65			—
Forward Physical Contracts	3			—			3
Power:
Forwards	11			—			11
Futures	4			4			—
Options – Puts	1			1			—
Options – Calls	1			1			—
NGLs – Forwards/Swaps	260			260			—
Refined Products – Futures	8			8			—
Crude – Forwards/Swaps	13			13			—
Total commodity derivatives	384			369			15
Other non-current assets	31			20			11
Total assets	$	415		$	389		$	26
Liabilities:
Interest rate derivatives	$	(399	)	$	—		$	(399	)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(49		)	(49		)	—
Swing Swaps IFERC	(1		)	—			(1		)
Fixed Swaps/Futures	(43		)	(43		)	—
Power:
Forwards	(5		)	—			(5		)
Futures	(3		)	(3		)	—
NGLs – Forwards/Swaps	(278		)	(278		)	—
Refined Products – Futures	(10		)	(10		)	—
Total commodity derivatives	(389		)	(383		)	(6		)
Total liabilities	$	(788	)	$	(383	)	$	(405	)



	Fair Value Total			Fair Value Measurements at December 31, 2018
				Level 1			Level 2
Assets:
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	$	42		$	42		$	—
Swing Swaps IFERC	52			8			44
Fixed Swaps/Futures	97			97			—
Forward Physical Contracts	20			—			20
Power:
Power – Forwards	48			—			48
Futures	1			1			—
Options – Calls	1			1			—
NGLs – Forwards/Swaps	291			291			—
Refined Products – Futures	7			7			—
Crude - Forwards/Swaps	1			1			—
Total commodity derivatives	560			448			112
Other non-current assets	26			17			9
Total assets	$	586		$	465		$	121
Liabilities:
Interest rate derivatives	$	(163	)	$	—		$	(163	)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(91		)	(91		)	—
Swing Swaps IFERC	(40		)	—			(40		)
Fixed Swaps/Futures	(88		)	(88		)	—
Forward Physical Contracts	(21		)	—			(21		)
Power:
Forwards	(42		)	—			(42		)
Futures	(1		)	(1		)	—
NGLs – Forwards/Swaps	(224		)	(224		)	—
Refined Products – Futures	(15		)	(15		)	—
Crude - Forwards/Swaps	(61		)	(61		)	—
Total commodity derivatives	(583		)	(480		)	(103		)
Total liabilities	$	(746	)	$	(480	)	$	(266	)

Contributions in Aid of Construction Costs

On certain of our capital projects, third parties are obligated to reimburse us for all or a portion of project expenditures. The majority of such arrangements are associated with pipeline construction and production well tie-ins. Contributions in aid of construction costs (“CIAC”) are netted against our project costs as they are received, and any CIAC which exceeds our total project costs, is recognized as other income in the period in which it is realized.

Shipping and Handling Costs

Shipping and handling costs are included in cost of products sold, except for shipping and handling costs related to fuel consumed for compression and treating which are included in operating expenses.

Costs and Expenses

Cost of products sold include actual cost of fuel sold, adjusted for the effects of our hedging and other commodity derivative activities, and the cost of appliances, parts and fittings. Operating expenses include all costs incurred to provide products to customers, including compensation for operations personnel, insurance costs, vehicle maintenance, advertising costs, purchasing costs and plant operations. Selling, general and administrative expenses include all partnership related expenses and compensation for executive, partnership, and administrative personnel.

We record the collection of taxes to be remitted to government authorities on a net basis except for our all other segment in which consumer excise taxes on sales of refined products and merchandise are included in both revenues and costs and expenses in the consolidated statements of operations, with no effect on net income. Excise taxes collected by Sunoco LP’s retail locations where Sunoco LP holds the inventory were $386 million, $370 million and $234 million for the years ended December 31, 2019, 2018 and 2017, respectively.

Issuances of Subsidiary Units

We record changes in our ownership interest of our subsidiaries as equity transactions, with no gain or loss recognized in consolidated net income or comprehensive income. For example, upon our subsidiary’s issuance of common units in a public offering, we record any difference between the amount of consideration received or paid and the amount by which the noncontrolling interests are adjusted as a change in partners’ capital.

Income Taxes

ET is a publicly traded limited partnership and is not taxable for federal and most state income tax purposes. As a result, our earnings or losses, to the extent not included in a taxable subsidiary, for federal and most state purposes are included in the tax returns of the individual partners. Net earnings for financial statement purposes may differ significantly from taxable income reportable to Unitholders as a result of differences between the tax basis and financial reporting basis of assets and liabilities, in addition to the allocation requirements related to taxable income under our Third Amended and Restated Agreement of Limited Partnership (the “Partnership Agreement”).

As a publicly traded limited partnership, we are subject to a statutory requirement that our “qualifying income” (as defined by the Internal Revenue Code, related Treasury Regulations, and Internal Revenue Service (“IRS”) pronouncements) exceed 90% of our total gross income, determined on a calendar year basis. If our qualifying income does not meet this statutory requirement, ET would be taxed as a corporation for federal and state income tax purposes. For the years ended December 31, 2019, 2018 and 2017, our qualifying income met the statutory requirement.

The Partnership conducts certain activities through corporate subsidiaries which are subject to federal, state and local income taxes. These corporate subsidiaries include ETP Holdco, Inland Corporation, Sunoco Property Company LLC and Aloha. The Partnership and its corporate subsidiaries account for income taxes under the asset and liability method.

Under this method, deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. Deferred tax assets and liabilities are measured using enacted tax rates in effect for the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rate is recognized in earnings in the period that includes the enactment date. Valuation allowances are established when necessary to reduce deferred tax assets to the amounts more likely than not to be realized.

The determination of the provision for income taxes requires significant judgment, use of estimates, and the interpretation and application of complex tax laws. Significant judgment is required in assessing the timing and amounts of deductible and taxable items and the probability of sustaining uncertain tax positions. The benefits of uncertain tax positions are recorded in our financial statements only after determining a more-likely-than-not probability that the uncertain tax positions will withstand challenge, if any, from taxing authorities. When facts and circumstances change, we reassess these probabilities and record any changes through the provision for income taxes.

Accounting for Derivative Instruments and Hedging Activities

For qualifying hedges, we formally document, designate and assess the effectiveness of transactions that receive hedge accounting treatment and the gains and losses offset related results on the hedged item in the statement of operations. The market prices used to value our financial derivatives and related transactions have been determined using independent third-party prices, readily available market information, broker quotes and appropriate valuation techniques.

At inception of a hedge, we formally document the relationship between the hedging instrument and the hedged item, the risk management objectives, and the methods used for assessing and testing effectiveness and how any ineffectiveness will be measured and recorded. We also assess, both at the inception of the hedge and on a quarterly basis, whether the derivatives that are used in our hedging transactions are highly effective in offsetting changes in cash flows. If we determine that a derivative is no longer highly effective as a hedge, we discontinue hedge accounting prospectively by including changes in the fair value of the derivative in net income for the period.

If we designate a commodity hedging relationship as a fair value hedge, we record the changes in fair value of the hedged asset or liability in cost of products sold in our consolidated statements of operations. This amount is offset by the changes in fair value of the related hedging instrument. Any ineffective portion or amount excluded from the assessment of hedge ineffectiveness is also included in the cost of products sold in the consolidated statements of operations.

Cash flows from derivatives accounted for as cash flow hedges are reported as cash flows from operating activities, in the same category as the cash flows from the items being hedged.

If we designate a derivative financial instrument as a cash flow hedge and it qualifies for hedge accounting, the change in the fair value is deferred in AOCI until the underlying hedged transaction occurs. Any ineffective portion of a cash flow hedge’s change in fair value is recognized each period in earnings. Gains and losses deferred in AOCI related to cash flow hedges remain in AOCI until the underlying physical transaction occurs, unless it is probable that the forecasted transaction will not occur by the end of the originally specified time period or within an additional two-month period of time thereafter. For financial derivative instruments that do not qualify for hedge accounting, the change in fair value is recorded in cost of products sold in the consolidated statements of operations.

We manage a portion of our interest rate exposures by utilizing interest rate swaps and similar instruments. Certain of our interest rate derivatives are accounted for as either cash flow hedges or fair value hedges. For interest rate derivatives accounted for as either cash flow or fair value hedges, we report realized gains and losses and ineffectiveness portions of those hedges in interest expense. For interest rate derivatives not designated as hedges for accounting purposes, we report realized and unrealized gains and losses on those derivatives in “Gains (losses) on interest rate derivatives” in the consolidated statements of operations.

In August 2017, the FASB issued ASU No. 2017-12, Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities. The amendments in this update improve the financial reporting of hedging relationships to better portray the economic results of an entity’s risk management activities in its financial statements. In addition, the amendments in this update make certain targeted improvements to simplify the application of the hedge accounting guidance in current GAAP. The Partnership adopted the new rules in the first quarter of 2019, and the adoption of the new accounting rules did not have a material impact on the consolidated financial statements and related disclosures.

Non-Cash Compensation

For awards of restricted units, we recognize compensation expense over the vesting period based on the grant-date fair value, which is determined based on the market price of the underlying common units on the grant date. For awards of cash restricted units, we remeasure the fair value of the award at the end of each reporting period based on the market price of the underlying common units as of the reporting date, and the fair value is recorded in other non-current liabilities on our consolidated balance sheets.

Pensions and Other Postretirement Benefit Plans

The Partnership recognizes the overfunded or underfunded status of defined benefit pension and other postretirement plans, measured as the difference between the fair value of the plan assets and the benefit obligation (the projected benefit obligation for pension plans and the accumulated postretirement benefit obligation for other postretirement plans). Each overfunded plan is recognized as an asset and each underfunded plan is recognized as a liability. Changes in the funded status of the plan are recorded in the year in which the change occurs within AOCI in equity or, for entities applying regulatory accounting, as a regulatory asset or regulatory liability.

Allocation of Income

For purposes of maintaining partner capital accounts, the Partnership Agreement specifies that items of income and loss shall generally be allocated among the partners in accordance with their percentage interests.

Acquisitions and Related Transactions

12 Months Ended

Dec. 31, 2019

Acquisitions and Dispositions [Abstract]

Acquisitions and Related Transactions

ACQUISITIONS, DIVESTITURES AND RELATED TRANSACTIONS:

2019 and 2020 Transactions

SemGroup Acquisition and ET Contribution of SemGroup Assets to ETO

On December 5, 2019, ET completed the acquisition of SemGroup pursuant to the terms of the Agreement and Plan of Merger, dated as of September 15, 2019 (the “Merger Agreement”). Under the terms of the Merger Agreement, a wholly owned subsidiary of ET merged with and into SemGroup (the “SemGroup Transaction”), with SemGroup surviving the Merger. At the effective time of the SemGroup Transaction on December 5, 2019, each share of class A common stock, par value $0.01 per share, of SemGroup issued and outstanding immediately prior to the effective time was converted into the right to receive (i) $6.80 in cash, without interest, and (ii) 0.7275 ET Common Units representing limited partner interests in ET. Each share of Series A Cumulative Perpetual Convertible Preferred Stock, par value $0.01 per share, of SemGroup that was issued and outstanding as of immediately prior to the effective time was redeemed by SemGroup for cash at a price per share equal to 101% of the liquidation preference.

During the first quarter of 2020, ET contributed certain SemGroup assets to ETO through sale and contribution transactions.

Summary of Assets Acquired and Liabilities Assumed

The SemGroup merger was recorded using the acquisition method of accounting, which requires, among other things, that assets acquired and liabilities assumed be recognized on the balance sheet at their fair values as of the acquisition date. The purchase price allocation below is preliminary, as management is currently evaluating certain tax-related assumptions.

The total purchase price was allocated as follows:



	At December 5, 2019
Total current assets	$	794
Property, plant and equipment	3,914
Other non-current assets	623
Goodwill⁽¹⁾	265
Intangible assets	460
Total assets	6,056

Total current liabilities	629
Long-term debt, less current maturities ⁽²⁾	2,576
Other non-current liabilities	196
SemCAMS Preferred shares	241
Total liabilities	3,642

Noncontrolling interest	822

Total consideration ⁽³⁾	1,592
Cash received⁽⁴⁾	153
Total consideration, net of cash received	$	1,439


⁽¹⁾	None of the goodwill is expected to be deductible for tax purposes. Goodwill recognized from the business combination primarily relates to the value attributed to additional growth opportunities, synergies and operating leverage within SemGroup’s operations.


⁽²⁾	Long-term debt at December 5, 2019 includes SemGroup senior notes with an aggregate principal amount of $1.375 billion and SemGroup subsidiary debt of $593 million, all of which were redeemed in total in December 2019, subsequent to the close of the SemGroup Transaction, utilizing proceeds from an intercompany promissory note from ETO.


⁽³⁾	Total consideration includes (i) cash paid to SemGroup shareholders, (ii) fair value of ET Common Units issued in the acquisition and (iii) cash paid to redeem SemGroup’s preferred shares.


⁽⁴⁾	Cash received represents cash and cash equivalents held by SemGroup as of the acquisition date.

The fair values of the assets acquired and liabilities assumed were determined using various valuation techniques, including the income and market approaches.

2018 Transactions

ET Contribution of Assets to ETO

Immediately prior to the closing of the Energy Transfer Merger discussed in Note 1, ET contributed the following to ETO:


•	2,263,158 common units representing limited partner interests in Sunoco LP to ETO in exchange for 2,874,275 ETO common units;


•	100 percent of the limited liability company interests in Sunoco GP LLC, the sole general partner of Sunoco LP, and all of the IDRs in Sunoco LP, to ETO in exchange for 42,812,389 ETO common units;


•	12,466,912 common units representing limited partner interests in USAC and 100 percent of the limited liability company interests in USA Compression GP, LLC, the general partner of USAC, to ETO in exchange for 16,134,903 ETO common units; and


•	a 100 percent limited liability company interest in Lake Charles LNG and a 60 percent limited liability company interest in each of Energy Transfer LNG Export, LLC, ET Crude Oil Terminals, LLC and ETC Illinois LLC to ETO in exchange for 37,557,815 ETO common units.

USAC Acquisition

On April 2, 2018, ET acquired a controlling interest in USAC, a publicly traded partnership that provides compression services in the United States. Specifically the Partnership acquired (i) all of the outstanding limited liability company interests in USA Compression GP, LLC (“USAC GP”), the general partner of USAC, and (ii) 12,466,912 USAC common units representing limited partner interests in USAC for cash consideration equal to $250 million (the “USAC Transaction”). Concurrently, USAC cancelled its IDRs and converted its economic general partner interest into a non-economic general partner interest in exchange for the issuance of 8,000,000 USAC common units to USAC GP.

Concurrent with these transactions, ETO contributed to USAC all of the issued and outstanding membership interests of CDM for aggregate consideration of approximately $1.7 billion, consisting of (i) 19,191,351 USAC common units, (ii) 6,397,965 units of a newly authorized and established class of units representing limited partner interests in USAC (“USAC Class B Units”) and (iii) $1.23 billion in cash, including customary closing adjustments (the “CDM Contribution”). The USAC Class B Units are a new class of partnership interests of USAC that have substantially all of the rights and obligations of a USAC common unit, except the USAC Class B Units will not participate in distributions for the first four quarters following the closing date of April 2, 2018. Each USAC Class B Unit will automatically convert into one USAC common unit on the first business day following the record date attributable to the quarter ending June 30, 2019.

Prior to the USAC acquisition, the CDM entities were indirect wholly-owned subsidiaries of ETO. Beginning April 2018,

ETE’s consolidated financial statements reflected USAC as a consolidated subsidiary.

Summary of Assets Acquired and Liabilities Assumed

The USAC Transaction was recorded using the acquisition method of accounting, which requires, among other things, that assets acquired and liabilities assumed be recognized on the balance sheet at their fair values as of the acquisition date.

The total purchase price was allocated as follows:



	At April 2, 2018
Total current assets	$	786
Property, plant and equipment	1,332
Other non-current assets	15
Goodwill⁽¹⁾	366
Intangible assets	222
Total assets	2,721

Total current liabilities	110
Long-term debt, less current maturities	1,527
Other non-current liabilities	2
Total liabilities	1,639

Noncontrolling interest	832

Total consideration	250
Cash received⁽²⁾	711
Total consideration, net of cash received⁽²⁾	$	(461	)


⁽¹⁾	None of the goodwill is expected to be deductible for tax purposes. Goodwill recognized from the business combination primarily relates to the value attributed to additional growth opportunities, synergies and operating leverage within USAC’s operations.


⁽²⁾	Cash received represents cash and cash equivalents held by USAC as of the acquisition date.

The fair values of the assets acquired and liabilities assumed were determined using various valuation techniques, including the income and market approaches.

Sunoco LP Retail Store Divestment

On January 23, 2018, Sunoco LP completed the disposition of assets pursuant to the purchase agreement with 7-Eleven, Inc. (the “7-Eleven Transaction”). As a result of the 7-Eleven Transaction, previously eliminated wholesale motor fuel sales to Sunoco LP’s retail locations are reported as wholesale motor fuel sales to third parties. Also, the related accounts receivable from such sales are no longer eliminated from the Partnership’s consolidated balance sheets and are reported as accounts receivable.

In connection with the 7-Eleven Transaction, Sunoco LP entered into a Distributor Motor Fuel Agreement dated as of January 23, 2018 (“Supply Agreement”), with 7-Eleven and SEI Fuel (collectively, “Distributor”). The Supply Agreement consists of a 15-year take-or-pay fuel supply arrangement under which Sunoco LP has agreed to supply approximately 2.0 billion gallons of fuel annually plus additional aggregate growth volumes of up to 500 million gallons to be added incrementally over the first four years. For the period from January 1, 2018 through January 22, 2018 and the years ended December 31, 2017, Sunoco LP recorded sales to the sites that were subsequently sold to 7-Eleven of $199 million and $3.2 billion, respectively, which were eliminated in consolidation. Sunoco LP received payments on trade receivables of $3.7 billion and $3.4 billion, respectively, from 7-Eleven for the years ended December 31, 2019 and December 31, 2018 subsequent to the closing of the sale.

The Partnership has concluded that it meets the accounting requirements for reporting the financial position, results of operations and cash flows of Sunoco LP’s retail divestment as discontinued operations.

There were no results of operations associated with discontinued operations for the year ended December 31, 2019. The results of operations associated with discontinued operations for the years ended December 31, 2018 and 2017 are presented in the following table:



	Years Ended December 31,
	2018			2017
REVENUES	$	349		$	6,964

COSTS AND EXPENSES
Cost of products sold	305			5,806
Operating expenses	61			763
Depreciation, depletion and amortization	—			34
Selling, general and administrative	7			168
Impairment losses	—			285
Total costs and expenses	373			7,056
OPERATING LOSS	(24		)	(92		)
OTHER EXPENSE
Interest expense, net	2			36
Loss on extinguishment of debt	20			—
Other, net	61			1
LOSS FROM DISCONTINUED OPERATIONS BEFORE INCOME TAX EXPENSE	(107		)	(129		)
Income tax expense	158			48
LOSS FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	$	(265	)	$	(177	)
LOSS FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES ATTRIBUTABLE TO ET	$	(10	)	$	(6	)

2017 Transactions

Rover Contribution Agreement

In October 2017, ETO completed the previously announced contribution transaction with a fund managed by Blackstone Energy Partners and Blackstone Capital Partners, pursuant to which ETO exchanged a 49.9% interest in the holding company that owns 65% of the Rover pipeline (“Rover Holdco”). As a result, Rover Holdco is now owned 50.1% by ETO and 49.9% by Blackstone. Upon closing, Blackstone contributed funds to reimburse ETO for its pro rata share of the Rover construction costs incurred by ETO through the closing date, along with the payment of additional amounts subject to certain adjustments.

ETO and Sunoco Logistics Merger

As discussed in Note 1, in April 2017, Energy Transfer Partners, L.P. and Sunoco Logistics completed the Sunoco Logistics Merger.

Permian Express Partners

In February 2017, the Partnership formed PEP, a strategic joint venture with ExxonMobil. The Partnership contributed its Permian Express 1, Permian Express 2, Permian Longview and Louisiana Access pipelines. ExxonMobil contributed its Longview to Louisiana and Pegasus pipelines, Hawkins gathering system, an idle pipeline in southern Oklahoma, and its Patoka, Illinois terminal. Assets contributed to PEP by ExxonMobil were reflected at fair value on the Partnership’s consolidated balance sheet at the date of the contribution, including $547 million of intangible assets and $435 million of property, plant and equipment.

In July 2017, ETO contributed an approximate 15% ownership interest in Dakota Access and ETCO to PEP, which resulted in an increase in ETO’s ownership interest in PEP to approximately 88%. ETO maintains a controlling financial and voting interest in PEP and is the operator of all of the assets. As such, PEP is reflected as a consolidated subsidiary of the Partnership.

ExxonMobil’s interest in PEP is reflected as noncontrolling interest in the consolidated balance sheets. ExxonMobil’s contribution resulted in an increase of $988 million in noncontrolling interest, which is reflected in “Capital contributions from noncontrolling interest” in the consolidated statement of equity.

Bakken Equity Sale

In February 2017, Bakken Holdings Company LLC, an entity in which ETO indirectly owns a 100% membership interest, sold a 49% interest in its wholly-owned subsidiary, Bakken Pipeline Investments LLC, to MarEn Bakken Company LLC, an entity jointly owned by MPLX LP and Enbridge Energy Partners, L.P., for $2.00 billion in cash. Bakken Pipeline Investments LLC indirectly owns a 75% interest in each of Dakota Access and ETCO. The remaining 25% of each of Dakota Access and ETCO is owned by wholly-owned subsidiaries of Phillips 66. ETO continues to consolidate Dakota Access and ETCO subsequent to this transaction.

Advances to and Investments in Unconsolidated Affiliates

12 Months Ended

Dec. 31, 2019

Investment In Affiliates [Abstract]

Investments In Affiliates

ADVANCES TO AND INVESTMENTS IN UNCONSOLIDATED AFFILIATES:

Citrus

ETO owns CrossCountry Energy, LLC, a wholly-owned subsidiary of ETO, which in turn owns a 50% interest in Citrus. The other 50% interest in Citrus is owned by a subsidiary of KMI. Citrus owns 100% of FGT, an approximately 5,362-mile natural gas pipeline system that originates in Texas and delivers natural gas to the Florida peninsula. Our investment in Citrus is reflected in our interstate transportation and storage segment.

FEP

ETO has a 50% interest in FEP which owns an approximately 185-mile natural gas pipeline that originates in Conway County, Arkansas, continues eastward through White County, Arkansas and terminates at an interconnect with Trunkline in Panola County, Mississippi. ETO’s investment in FEP is reflected in the interstate transportation and storage segment. The Partnership evaluated its investment in FEP for impairment as of December 31, 2017, based on FASB Accounting Standards Codification 323, Investments - Equity Method and Joint Ventures. The Partnership recorded an impairment of its investment in FEP of $141 million during the year ended December 31, 2017 due to a negative outlook for long-term transportation contracts as a result of a decrease in production in the Fayetteville basin and a customer re-contracting with a competitor.

MEP

ETO owns a 50% interest in MEP, which owns approximately 500 miles of natural gas pipeline that extends from Southeast Oklahoma, across Northeast Texas, Northern Louisiana and Central Mississippi to an interconnect with the Transcontinental natural gas pipeline system in Butler, Alabama. ETO’s investment in MEP is reflected in the interstate transportation and storage segment.

The carrying values of the Partnership’s investments advances to and in unconsolidated affiliates as of December 31, 2019 and 2018 were as follows:



	December 31,
	2019		2018
Citrus	$	1,876	$	1,737
FEP	218		107
MEP	429		225
Others	937		573
Total	$	3,460	$	2,642

The following table presents equity in earnings (losses) of unconsolidated affiliates:



	Years Ended December 31,
	2019		2018		2017
Citrus	$	148	$	141	$	144
FEP	59		55		53
MEP	15		31		38
Other	80		117		(91		)
Total equity in earnings of unconsolidated affiliates	$	302	$	344	$	144

Summarized Financial Information

The following tables present aggregated selected balance sheet and income statement data for our unconsolidated affiliates, Citrus, FEP, and MEP (on a 100% basis) for all periods presented, except as noted below:



	December 31,
	2019		2018
Current assets	$	247	$	212
Property, plant and equipment, net	7,680		7,800
Other assets	40		39
Total assets	$	7,967	$	8,051

Current liabilities	$	738	$	1,534
Non-current liabilities	3,242		3,439
Equity	3,987		3,078
Total liabilities and equity	$	7,967	$	8,051



	Years Ended December 31,
	2019		2018 ⁽¹⁾		2017
Revenue	$	1,192	$	1,249	$	1,358
Operating income	683		723		407
Net income	443		460		145


⁽¹⁾	Selected income data related to HPC for the year ended December 31, 2018 reflects HPC’s results for January 1, 2018 through March 31, 2018. HPC was fully consolidated beginning April 1, 2018 as discussed above.

In addition to the equity method investments described above we have other equity method investments which are not significant to our consolidated financial statements.

Net Income Per Limited Partner Unit

12 Months Ended

Dec. 31, 2019

Earnings Per Share [Abstract]

Net Income Per Limited Partner Unit

NET INCOME PER LIMITED PARTNER UNIT:

Basic net income per limited partner unit is computed by dividing net income, after considering the General Partner’s interest, by the weighted average number of limited partner interests outstanding. Diluted net income per limited partner unit is computed by dividing net income (as adjusted as discussed herein), after considering the General Partner’s interest, by the weighted average number of limited partner interests outstanding and the assumed conversion of the ET Series A Convertible Preferred Units, as discussed in Note 8. For the diluted earnings per share computation, income allocable to the limited partners is reduced, where applicable, for the decrease in earnings from ET’s limited partner unit ownership in ETO or Sunoco LP that would have resulted assuming the incremental units related to our or Sunoco LP’s equity incentive plans, as applicable, had been issued during the respective periods. Such units have been determined based on the treasury stock method.

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



	Years Ended December 31,
	2019			2018			2017
Income from continuing operations	$	4,899		$	3,630		$	2,543
Less: Net income attributable to redeemable noncontrolling interests	51			39			—
Less: Income (loss) from continuing operations attributable to noncontrolling interests	1,256			1,888			1,583
Income from continuing operations, net of noncontrolling interests	3,592			1,703			960
Less: General Partner’s interest in income from continuing operations	4			3			2
Less: ET Series A Convertible Preferred Unitholders’ interest in net income from continuing operations	—			33			38
Income from continuing operations available to Limited Partners	$	3,588		$	1,667		$	920
Basic Income from Continuing Operations per Limited Partner Unit:
Weighted average limited partner units	2,628.0			1,423.8			1,078.2
Basic income from continuing operations per Limited Partner unit	$	1.37		$	1.17		$	0.86
Basic loss from discontinued operations per Limited Partner unit	$	—		$	(0.01	)	$	(0.01	)
Diluted Income from Continuing Operations per Limited Partner Unit:
Income from continuing operations available to Limited Partners	$	3,588		$	1,667		$	920
Dilutive effect of equity-based compensation of subsidiaries and distributions to convertible units	(1		)	33			38
Diluted income from continuing operations available to Limited Partners	3,587			1,700			958
Weighted average limited partner units	2,628.0			1,423.8			1,078.2
Dilutive effect of unconverted unit awards and ET Series A Convertible Preferred Units	—			30.3			72.6
Dilutive effect of unvested unit awards	9.6			7.3			—
Weighted average limited partner units, assuming dilutive effect of unvested unit awards	2,637.6			1,461.4			1,150.8
Diluted income from continuing operations per Limited Partner unit	$	1.36		$	1.16		$	0.84
Diluted loss from discontinued operations per Limited Partner unit	$	—		$	(0.01	)	$	(0.01	)

Debt Obligations

12 Months Ended

Dec. 31, 2019

Debt Obligations [Abstract]

Debt Disclosure [Text Block]

DEBT OBLIGATIONS:

Our debt obligations consist of the following:



	December 31,
	2019		2018
Parent Company Indebtedness:
7.50% Senior Notes due October 15, 2020 ⁽¹⁾	$	52	$	1,187
4.25% Senior Notes due March 15, 2023	5		1,000
5.875% Senior Notes due January 15, 2024	23		1,150
5.50% Senior Notes due June 1, 2027	44		1,000
ET Senior Secured Term Loan	—		1,220
Unamortized premiums, discounts and fair value adjustments, net	—		(10		)
Deferred debt issuance costs	—		(27		)
	124		5,520

Subsidiary Indebtedness:
ETO Debt
9.70% Senior Notes due March 15, 2019	—		400
9.00% Senior Notes due April 15, 2019	—		450
5.50% Senior Notes due February 15, 2020 ⁽¹⁾	250		250
5.75% Senior Notes due September 1, 2020 ⁽¹⁾	400		400
4.15% Senior Notes due October 1, 2020 ⁽¹⁾	1,050		1,050
7.50% Senior Notes due October 15, 2020 ⁽¹⁾	1,135		—
4.40% Senior Notes due April 1, 2021	600		600
4.65% Senior Notes due June 1, 2021	800		800
5.20% Senior Notes due February 1, 2022	1,000		1,000
4.65% Senior Notes due February 15, 2022	300		300
5.875% Senior Notes due March 1, 2022	900		900
5.00% Senior Notes due October 1, 2022	700		700
3.45% Senior Notes due January 15, 2023	350		350
3.60% Senior Notes due February 1, 2023	800		800
4.25% Senior Notes due March 15, 2023	995		—
4.20% Senior Notes due September 15, 2023	500		500
4.50% Senior Notes due November 1, 2023	600		600
5.875% Senior Notes due January 15, 2024	1,127		—
4.90% Senior Notes due February 1, 2024	350		350
7.60% Senior Notes due February 1, 2024	277		277
4.25% Senior Notes due April 1, 2024	500		500
4.50% Senior Notes due April 15, 2024	750		—
9.00% Debentures due November 1, 2024	65		65
4.05% Senior Notes due March 15, 2025	1,000		1,000
5.95% Senior Notes due December 1, 2025	400		400
4.75% Senior Notes due January 15, 2026	1,000		1,000
3.90% Senior Notes due July 15, 2026	550		550
4.20% Senior Notes due April 15, 2027	600		600
5.50% Senior Notes due June 1, 2027	956		—
4.00% Senior Notes due October 1, 2027	750		750
4.95% Senior Notes due June 15, 2028	1,000		1,000
5.25% Senior Notes due April 15, 2029	1,500		—
8.25% Senior Notes due November 15, 2029	267		267



4.90% Senior Notes due March 15, 2035	500		500
6.625% Senior Notes due October 15, 2036	400		400
5.80% Senior Notes due June 15, 2038	500		500
7.50% Senior Notes due July 1, 2038	550		550
6.85% Senior Notes due February 15, 2040	250		250
6.05% Senior Notes due June 1, 2041	700		700
6.50% Senior Notes due February 1, 2042	1,000		1,000
6.10% Senior Notes due February 15, 2042	300		300
4.95% Senior Notes due January 15, 2043	350		350
5.15% Senior Notes due February 1, 2043	450		450
5.95% Senior Notes due October 1, 2043	450		450
5.30% Senior Notes due April 1, 2044	700		700
5.15% Senior Notes due March 15, 2045	1,000		1,000
5.35% Senior Notes due May 15, 2045	800		800
6.125% Senior Notes due December 15, 2045	1,000		1,000
5.30% Senior Notes due April 15, 2047	900		900
5.40% Senior Notes due October 1, 2047	1,500		1,500
6.00% Senior Notes due June 15, 2048	1,000		1,000
6.25% Senior Notes due April 15, 2049	1,750		—
Floating Rate Junior Subordinated Notes due November 1, 2066	546		546
ETO $2.00 billion Term Loan facility due October 2022	2,000		—
ETO $5.00 billion Revolving Credit Facility due December 2023	4,214		3,694
Unamortized premiums, discounts and fair value adjustments, net	(5	)	17
Deferred debt issuance costs	(207	)	(178	)
	42,120		32,288

Transwestern Debt
5.36% Senior Notes due December 9, 2020 ⁽¹⁾	175		175
5.89% Senior Notes due May 24, 2022	150		150
5.66% Senior Notes due December 9, 2024	175		175
6.16% Senior Notes due May 24, 2037	75		75
Deferred debt issuance costs	(1	)	(1	)
	574		574

Panhandle Debt
8.125% Senior Notes due June 1, 2019	—		150
7.60% Senior Notes due February 1, 2024	82		82
7.00% Senior Notes due July 15, 2029	66		66
8.25% Senior Notes due November 15, 2029	33		33
Floating Rate Junior Subordinated Notes due November 1, 2066	54		54
Unamortized premiums, discounts and fair value adjustments, net	11		14
	246		399




Bakken Project Debt
3.625% Senior Notes due April 1, 2022	650			—
3.90% Senior Notes due April 1, 2024	1,000			—
4.625% Senior Notes due April 1, 2029	850			—
Bakken $2.50 billion Credit Facility due August 2019	—			2,500
Unamortized premiums, discounts and fair value adjustments, net	(3		)	—
Deferred debt issuance costs	(16		)	(3		)
	2,481			2,497

Sunoco LP Debt
4.875% Senior Notes Due January 15, 2023	1,000			1,000
5.50% Senior Notes Due February 15, 2026	800			800
6.00% Senior Notes Due April 15, 2027	600			—
5.875% Senior Notes Due March 15, 2028	400			400
Sunoco LP $1.50 billion Revolving Credit Facility due July 2023	162			700
Lease-related obligations	135			107
Deferred debt issuance costs	(26		)	(23		)
	3,071			2,984

USAC Debt
6.875% Senior Notes due April 1, 2026	725			725
6.875% Senior Notes due September 1, 2027	750			—
USAC $1.60 billion Revolving Credit Facility due April 2023	403			1,050
Deferred debt issuance costs	(26		)	(16		)
	1,852			1,759

SemGroup Debt
HFOTCO Tax Exempt Notes due 2050	225			—
SemCAMS Revolver due February 25, 2024	92			—
SemCAMS Term Loan A due February 25, 2024	269			—
Unamortized premiums, discounts and fair value adjustments, net	1			—
Deferred debt issuance costs	(3		)	—
	584			—

Other	2			7
Total debt	51,054			46,028
Less: Current maturities of long-term debt	26			2,655
Long-term debt, less current maturities	$	51,028		$	43,373


⁽¹⁾	As of December 31, 2019, these notes were classified as long-term as management had the intent and ability to refinance the borrowings on a long-term basis. The notes were redeemed in January 2020.

The following table reflects future maturities of long-term debt for each of the next five years and thereafter. These amounts exclude $279 million in unamortized premiums, fair value adjustments and deferred debt issuance costs, net:



2020	$	3,086
2021	1,412
2022	5,792
2023	8,965
2024	4,708
Thereafter	27,366
Total	$	51,329

Long-term debt reflected on our consolidated balance sheets includes fair value adjustments related to interest rate swaps, which represent fair value adjustments that had been recorded in connection with fair value hedge accounting prior to the termination of the interest rate swap.

Notes and Debentures

ET Senior Notes

The ET Senior Notes are the Parent Company’s senior obligations, ranking equally in right of payment with our other existing and future unsubordinated debt and senior to any of its future subordinated debt. The Parent Company’s obligations under the ET Senior Notes previously were secured on a first-priority basis with its obligations under the Revolver Credit Agreement and the ET Term Loan Facility, by a lien on substantially all of the Parent Company’s and certain of its subsidiaries’ tangible and intangible assets, subject to certain exceptions and permitted liens. Subsequent to the termination of the Revolver Credit Agreement and the ET Term Loan Facility, the collateral securing the ET Senior Notes was released. The ET Senior Notes are not guaranteed by any of the Parent Company’s subsidiaries.

The covenants related to the ET Senior Notes include a limitation on liens, a limitation on transactions with affiliates, a restriction on sale-leaseback transactions and limitations on mergers and sales of all or substantially all of the Parent Company’s assets.

ETO Senior Notes

The ETO senior notes were registered under the Securities Act of 1933 (as amended). The Partnership may redeem some or all of the ETO senior notes at any time, or from time to time, pursuant to the terms of the indenture and related indenture supplements related to the ETO senior notes. The balance is payable upon maturity. Interest on the ETO senior notes is paid semi-annually.

The ETO senior notes are unsecured obligations of the Partnership and as a result, the ETO senior notes effectively rank junior to any future indebtedness of ours or our subsidiaries that is both secured and unsubordinated to the extent of the value of the assets securing such indebtedness, and the ETO senior notes effectively rank junior to all indebtedness and other liabilities of our existing and future subsidiaries.

ETO January 2020 Senior Notes Offering and Redemption

On January 22, 2020, ETO completed a registered offering (the “January 2020 Senior Notes Offering”) of $1 billion aggregate principal amount of ETO’s 2.900% Senior Notes due 2025, $1.5 billion aggregate principal amount of ETO’s 3.750% Senior Notes due 2030, and $2 billion aggregate principal amount of ETO’s 5.000% Senior Notes due 2050, (collectively, the “Notes”). The Notes are fully and unconditionally guaranteed by the Partnership’s wholly-owned subsidiary, Sunoco Logistics Partners Operations L.P., on a senior unsecured basis.

Utilizing proceeds from the January 2020 Senior Notes Offering, ETO redeemed its $400 million aggregate principal amount of 5.75% Senior Notes due September 1, 2020, its $1.05 billion aggregate principal amount of 4.15% Senior Notes due October 1, 2020, its $1.14 billion aggregate principal amount of 7.50% Senior Notes due October 15, 2020, its $250 million aggregate principal amount of 5.50% Senior Notes due February 15, 2020, ET’s $52 million aggregate principal amount of 7.50% Senior Notes due October 15, 2020 and Transwestern’s $175 million aggregate principal amount of 5.36% Senior Notes due December 9, 2020.

ET-ETO Senior Notes Exchange

In February 2019, ETO commenced offers to exchange all of ET’s outstanding senior notes for senior notes issued by ETO (the “ET-ETO senior notes exchange”). Approximately 97% of ET’s outstanding senior notes were tendered and accepted, and substantially all the exchanges settled on March 25, 2019. In connection with the exchange, ETO issued $4.21 billion aggregate principal amount of the following senior notes:

•$1.14 billion aggregate principal amount of 7.50% senior notes due 2020;

•$995 million aggregate principal amount of 4.25% senior notes due 2023;

•$1.13 billion aggregate principal amount of 5.875% senior notes due 2024; and

•$956 million aggregate principal amount of 5.50% senior notes due 2027.

2019 ETO Senior Notes Offering and Redemption

In January 2019, ETO issued the following senior notes:

•$750 million aggregate principal amount of 4.50% senior notes due 2024;

•$1.50 billion aggregate principal amount of 5.25% senior notes due 2029; and

•$1.75 billion aggregate principal amount of 6.25% senior notes due 2049.

The $3.96 billion net proceeds from the offering were used to make an intercompany loan to ET (which ET used to repay its term loan in full), for general partnership purposes and to redeem at maturity all of the following:

•ETO’s $400 million aggregate principal amount of 9.70% senior notes due March 15, 2019;

•ETO’s $450 million aggregate principal amount of 9.00% senior notes due April 15, 2019; and

•Panhandle’s $150 million aggregate principal amount of 8.125% senior notes due June 1, 2019.

Panhandle Senior Notes Redemption

In June 2019, Panhandle’s $150 million aggregate principal amount of 8.125% senior notes matured and were repaid with borrowings under an affiliate loan agreement with ETO.

Bakken Senior Notes Offering

In March 2019, Midwest Connector Capital Company LLC, a wholly-owned subsidiary of Dakota Access, issued the following senior notes related to the Bakken pipeline:

•$650 million aggregate principal amount of 3.625% senior notes due 2022;

•$1.00 billion aggregate principal amount of 3.90% senior notes due 2024; and

•$850 million aggregate principal amount of 4.625% senior notes due 2029.

The $2.48 billion in net proceeds from the offering were used to repay in full all amounts outstanding on the Bakken credit facility and the facility was terminated.

Sunoco LP Senior Notes Offering

In March 2019, Sunoco LP issued $600 million aggregate principal amount of 6.00% senior notes due 2027 in a private placement to eligible purchasers. The net proceeds from this offering were used to repay a portion of Sunoco LP’s existing borrowings under its credit facility. In July 2019, Sunoco LP completed an exchange of these notes for registered notes with substantially identical terms.

USAC Senior Notes

In March 2019, USAC issued $750 million aggregate principal amount of 6.875% senior notes due 2027 in a private placement, and in December 2019, USAC exchanged those notes for substantially identical senior notes registered under the Securities Act. The net proceeds from this offering were used to repay a portion of USAC’s existing borrowings under its credit facility and for general partnership purposes.

Transwestern Senior Notes

The Transwestern senior notes are redeemable at any time in whole or pro rata, subject to a premium or upon a change of control event or an event of default, as defined. The balance is payable upon maturity. Interest is paid semi-annually.

Term Loans, Credit Facilities and Commercial Paper

ET Term Loan Facility

On February 2, 2017, the Partnership entered into a Senior Secured Term Loan Agreement (the “Term Credit Agreement”) with Credit Suisse AG, Cayman Islands Branch, as administrative agent, and the other lenders party thereto. The Term Credit Agreement had a scheduled maturity date of February 2, 2024, with an option for the Parent Company to extend the term subject to the terms and conditions set forth therein. The Term Credit Agreement contained an accordion feature, under which the total commitments may be increased, subject to the terms thereof. In connection with the Parent Company’s entry into the Senior Secured Term Loan Agreement on February 2, 2017, the Parent Company terminated its previous term loan agreements.

Pursuant to the Term Credit Agreement, the Term Lenders provided senior secured financing in an aggregate principal amount of $2.2 billion (the “Term Loan Facility”). Under the Term Credit Agreement, the obligations of the Parent Company were secured by a lien on substantially all of the Parent Company’s and certain of its subsidiaries’ tangible and intangible assets.

Interest accrued on advances at a LIBOR rate or a base rate, based on the election of the Parent Company for each interest period, plus an applicable margin.

On January 15, 2019, Energy Transfer LP paid in full all outstanding borrowings under its Senior Secured Term Loan Agreement and thereafter terminated the term loan agreement. In connection with the termination of the term loan agreement, the collateral securing certain series of the Partnership’s outstanding senior notes was released in accordance with the terms of the applicable indentures governing such senior notes.

ETO Term Loan

On October 17, 2019, ETO entered into a term loan credit agreement (the “ETO Term Loan”) providing for a $2.00 billion three-year term loan credit facility. Borrowings under the term loan agreement mature on October 17, 2022 and are available for working capital purposes and for general partnership purposes. The term loan agreement is unsecured and is guaranteed by our subsidiary, Sunoco Logistics Partners Operations L.P.

As of December 31, 2019, the ETO Term Loan had $2.00 billion outstanding and was fully drawn. The weighted average interest rate on the total amount outstanding as of December 31, 2019 was 2.78%.

ETO Five-Year Credit Facility

ETO’s revolving credit facility (the “ETO Five-Year Credit Facility”) allows for unsecured borrowings up to $5.00 billion and matures on December 1, 2023. The ETO 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 December 31, 2019, the ETO Five-Year Credit Facility had $4.21 billion outstanding, of which $1.64 billion was commercial paper. The amount available for future borrowings was $709 million after taking into account letters of credit of $77 million. The weighted average interest rate on the total amount outstanding as of December 31, 2019 was 2.88%.

ETO 364-Day Facility

ETO’s 364-day revolving credit facility (the “ETO 364-Day Facility”) allows for unsecured borrowings up to $1.00 billion and matures on November 27, 2020. As of December 31, 2019, the ETO 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 December 31, 2019, the Sunoco LP Credit Facility had $162 million outstanding borrowings and $8 million in standby letters of credit. The amount available for future borrowings was $1.33 billion at December 31, 2019. The weighted average interest rate on the total amount outstanding as of December 31, 2019 was 3.75%.

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 December 31, 2019, USAC had $403 million of outstanding borrowings and no outstanding letters of credit under the credit agreement. As of December 31, 2019, USAC had $1.2 billion of availability under its credit facility. The weighted average interest rate on the total amount outstanding as of December 31, 2019 was 4.31%.

SemCAMS Credit Facilities

SemCAMS is party to a credit agreement providing for a C$350 million (US$270 million at the December 31, 2019 exchange rate) senior secured term loan facility, a C$525 million (US$404 million at the December 31, 2019 exchange rate) senior secured revolving credit facility, and a C$300 million (US$231 million at the December 31, 2019 exchange rate) senior secured construction loan facility (the “KAPS Facility”). The term loan facility and the revolving credit facility mature on February 25, 2024. The KAPS Facility matures on June 13, 2024. SemCAMS may incur additional term loans and revolving commitments in an aggregate amount not to exceed C$250 million (US$193 million at the December 31, 2019 exchange rate), subject to receiving commitments for such additional term loans or revolving commitments from either new lenders or increased commitments from existing lenders.

Covenants Related to Our Credit Agreements

Covenants Related to the Parent Company

The Term Loan Facility and ET Revolving Credit Facility contain customary representations, warranties, covenants and events of default, including a change of control event of default and limitations on incurrence of liens, new lines of business, merger, transactions with affiliates and restrictive agreements.

The Term Loan Facility and ET Revolving Credit Facility contain financial covenants as follows:


•	Maximum Leverage Ratio – Consolidated Funded Debt (as defined therein) of the Parent Company to Consolidated EBITDA (as defined therein) of the Parent Company of not more than 6.0 to 1, with a permitted increase to 7 to 1 during a specified acquisition period following the close of a specified acquisition; and


•	Consolidated EBITDA (as defined therein) to interest expense of not less than 1.5 to 1.

Covenants Related to ETO

The agreements relating to the ETO senior notes contain restrictive covenants customary for an issuer with an investment-grade rating from the rating agencies, which covenants include limitations on liens and a restriction on sale-leaseback transactions.

The ETO Credit Facilities contain covenants that limit (subject to certain exceptions) the Partnership’s and certain of the Partnership’s subsidiaries’ ability to, among other things:


•	incur indebtedness;


•	grant liens;


•	enter into mergers;


•	dispose of assets;


•	make certain investments;


•	make Distributions (as defined in the ETO Credit Facilities) during certain Defaults (as defined in the ETO Credit Facilities) and during any Event of Default (as defined in the ETO Credit Facilities);


•	engage in business substantially different in nature than the business currently conducted by the Partnership and its subsidiaries;


•	engage in transactions with affiliates; and


•	enter into restrictive agreements.

The ETO Credit Facilities applicable margin and rate used in connection with the interest rates and commitment fees, respectively, are based on the credit ratings assigned to our senior, unsecured, non-credit enhanced long-term debt. The applicable margin for eurodollar rate loans under the ETO Five-Year Facility ranges from 1.125% to 2.000% and the applicable margin for base rate loans ranges from 0.125% to 1.000%. The applicable rate for commitment fees under the ETO Five-Year Facility ranges from 0.125% to 0.300%. The applicable margin for eurodollar rate loans under the ETO 364-Day Facility

ranges from 1.250% to 1.750% and the applicable margin for base rate loans ranges from 0.250% to 0.750%. The applicable rate for commitment fees under the ETO 364-Day Facility ranges from 0.125% to 0.225%.

The ETO Credit Facilities contain various covenants including limitations on the creation of indebtedness and liens, and related to the operation and conduct of our business. The ETO Credit Facilities also limit us, on a rolling four quarter basis, to a maximum Consolidated Funded Indebtedness to Consolidated EBITDA ratio, as defined in the underlying credit agreements, of 5.0 to 1, which can generally be increased to 5.5 to 1 during a Specified Acquisition Period. Our Leverage Ratio was 4.04 to 1 at December 31, 2019, as calculated in accordance with the credit agreements.

The agreements relating to the Transwestern senior notes contain certain restrictions that, among other things, limit the incurrence of additional debt, the sale of assets and the payment of dividends and specify a maximum debt to capitalization ratio.

Failure to comply with the various restrictive and affirmative covenants of our revolving credit facilities could require us to pay debt balances prior to scheduled maturity and could negatively impact the Partnership’s or our subsidiaries’ ability to incur additional debt and/or our ability to pay distributions to Unitholders.

Covenants Related to Panhandle

Panhandle is not party to any lending agreement that would accelerate the maturity date of any obligation due to a failure to maintain any specific credit rating, nor would a reduction in any credit rating, by itself, cause an event of default under any of Panhandle’s lending agreements.

Panhandle’s restrictive covenants include restrictions on liens securing debt and guarantees and restrictions on mergers and on the sales of assets. A breach of any of these covenants could result in acceleration of Panhandle’s debt.

Covenants Related to Sunoco LP

The Sunoco LP Credit Facility contains various customary representations, warranties, covenants and events of default, including a change of control event of default, as defined therein. Sunoco LP’s Credit Facility requires Sunoco LP to maintain a Net Leverage Ratio of not more than 5.5 to 1. The maximum Net Leverage Ratio is subject to upwards adjustment of not more than 6.0 to 1 for a period not to exceed three fiscal quarters in the event Sunoco LP engages in certain specified acquisitions of not less than $50 million (as permitted under Sunoco LP’s Credit Facility agreement). The Sunoco LP Credit Facility also requires Sunoco LP to maintain an Interest Coverage Ratio (as defined in the Sunoco LP’s Credit Facility agreement) of not less than 2.25 to 1.

Covenants Related to USAC

The USAC Credit Facility contains covenants that limit (subject to certain exceptions) USAC’s ability to, among other things:


•	grant liens;


•	make certain loans or investments;


•	incur additional indebtedness or guarantee other indebtedness;


•	merge or consolidate;


•	sell our assets; or


•	make certain acquisitions.

The credit facility is also subject to the following financial covenants, including covenants requiring us to maintain:


•	a minimum EBITDA to interest coverage ratio of 2.5 to 1.0, determined as of the last day of each fiscal quarter; and

•

a maximum funded debt to EBITDA ratio, determined as of the last day of each fiscal quarter, for the annualized trailing three months of (i) 5.5 to 1 through the end of the fiscal quarter ending December 31, 2019 and (ii) 5.0 to 1.0 thereafter, in each case subject to a provision for increases to such thresholds by 0.50 in connection with certain future acquisitions for the six consecutive month period following the period in which any such acquisition occurs.

Covenants Related to the HFOTCO Tax Exempt Notes

The indentures covering HFOTCO's tax exempt notes due 2050 ("IKE Bonds") include customary representations and warranties and affirmative and negative covenants. Such covenants include limitations on the creation of new liens, indebtedness, making of certain restricted payments and payments on indebtedness, making certain dispositions, making

material changes in business activities, making fundamental changes including liquidations, mergers or consolidations, making certain investments, entering into certain transactions with affiliates, making amendments to certain credit or organizational agreements, modifying the fiscal year, creating or dealing with hazardous materials in certain ways, entering into certain hedging arrangements, entering into certain restrictive agreements, funding or engaging in sanctioned activities, taking actions or causing the trustee to take actions that materially adversely affect the rights, interests, remedies or security of the bondholders, taking actions to remove the trustee, making certain amendments to the bond documents, and taking actions or omitting to take actions that adversely impact the tax exempt status of the IKE Bonds.

Compliance With Our Covenants

Failure to comply with the various restrictive and affirmative covenants of our revolving credit facilities and note agreements could require us or our subsidiaries to pay debt balances prior to scheduled maturity and could negatively impact the subsidiaries ability to incur additional debt and/or our ability to pay distributions.

We and our subsidiaries were in compliance with all requirements, tests, limitations, and covenants related to our debt agreements as of December 31, 2019.

Redeemable Preferred Units	12 Months Ended
Redeemable Preferred Units	Dec. 31, 2019
Preferred Units, Preferred Partners' Capital Account [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 sheet. Redeemable noncontrolling interests as of December 31, 2019 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, redeemable noncontrolling interests includes a balance of $247 million in SemCAMS preferred shares acquired as part of the merger with SemGroup. USAC Series A Preferred Units In 2018, USAC issued 500,000 USAC Preferred Units in a private placement at a price of $1,000 per USAC Preferred Unit, for total gross proceeds of $500 million in a private placement. 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 will be convertible into USAC common units at the election of the holders beginning in 2021. To the extent the holders of the USAC Preferred Units have not elected to convert their preferred units by the fifth anniversary of the issue date, USAC will have the option to redeem all or any portion of the USAC Preferred Units for cash. In addition, at any time on or after the tenth anniversary of the issue date, 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 the Partnership may elect to pay up to 50% of such redemption amount in USAC common units. SemCAMS Redeemable Preferred Stock SemCAMS has 300,000 shares of cumulative preferred stock issued and outstanding. The preferred stock is redeemable at SemCAMS’s option subsequent to January 3, 2021 at a redemption price of C$1,100 (US$845 at the December 31, 2019 exchange rate) per share. The preferred stock is redeemable by the holder contingent upon a change of control or liquidation of SemCAMS. The preferred stock is convertible to SemCAMS common shares in the event of an initial public offering by SemCAMS. The preferred stock was recorded at fair value in connection with the SemGroup purchase accounting. Dividends on the preferred stock are payable in-kind through the quarter ending June 30, 2020. The dividends paid-in-kind increased the liquidation preference such that as of December 31, 2019, the preferred stock was convertible into 315,859 shares.

Equity

12 Months Ended

Dec. 31, 2019

Partners' Capital Notes [Abstract]

Equity

EQUITY:

Limited Partner Units

Limited partner interests in the Partnership are represented by Common Units that entitle the holders thereof to the rights and privileges specified in the Partnership Agreement. The Partnership’s Common Units are registered under the Securities Exchange Act of 1934 (as amended) and are listed for trading on the NYSE. Each holder of a Common Unit is entitled to one vote per unit on all matters presented to the Limited Partners for a vote. In addition, if at any time any person or group (other than the Partnership’s General Partner and its affiliates) owns beneficially 20% or more of all Common Units, any Common Units owned by that person or group may not be voted on any matter and are not considered to be outstanding when

sending notices of a meeting of Unitholders (unless otherwise required by law), calculating required votes, determining the presence of a quorum or for other similar purposes under the Partnership Agreement. The Common Units are entitled to distributions of Available Cash as described below under “Parent Company Quarterly Distributions of Available Cash.”

As of December 31, 2019, there were issued and outstanding 2.69 billion Common Units representing an aggregate 99.9% limited partner interest in the Partnership.

Our Partnership Agreement contains specific provisions for the allocation of net earnings and losses to the partners for purposes of maintaining the partner capital accounts. For any fiscal year that the Partnership has net profits, such net profits are first allocated to the General Partner until the aggregate amount of net profits for the current and all prior fiscal years equals the aggregate amount of net losses allocated to the General Partner for the current and all prior fiscal years. Second, such net profits shall be allocated to the Limited Partners pro rata in accordance with their respective sharing ratios. For any fiscal year in which the Partnership has net losses, such net losses shall be first allocated to the Limited Partners in proportion to their respective adjusted capital account balances, as defined by the Partnership Agreement, (before taking into account such net losses) until their adjusted capital account balances have been reduced to zero. Second, all remaining net losses shall be allocated to the General Partner. The General Partner may distribute to the Limited Partners funds of the Partnership that the General Partner reasonably determines are not needed for the payment of existing or foreseeable Partnership obligations and expenditures.

Common Units

The change in ET Common Units during the years ended December 31, 2019, 2018 and 2017 was as follows:



	Years Ended December 31,
	2019		2018	2017
Number of Common Units, beginning of period	2,619.4		1,079.1	1,046.9
Conversion of ET Series A Convertible Preferred Units to common units	—		79.1	—
Common Units issued in mergers and acquisitions	57.6		1,458.9	—
Common Units repurchased	(1.9	)	—	—
Issuance of Common Units	14.5		2.3	32.2
Number of Common Units, end of period	2,689.6		2,619.4	1,079.1

In October 2018, ET issued 1.46 billion ET Common Units in connection with the Energy Transfer Merger.

In December 2019, ET issued 57.6 million ET Common Units in connection with the SemGroup acquisition.

ET Equity Distribution Agreement

In March 2017, the Partnership entered into an equity distribution agreement relating to at-the-market offerings of its common units with an aggregate offering price up to $1 billion. As of December 31, 2019, there have been no sales of common units under the equity distribution agreement.

ET Series A Convertible Preferred Units

In May 2018, the Partnership converted its 329.3 million Series A Convertible Preferred Units into approximately 79.1 million ET common units in accordance with the terms of ET’s partnership agreement.

ET Class A Units

In connection with the Energy Transfer Merger, the Partnership issued 647,745,099 Class A units (“ET Class A Units”) representing limited partner interests in the Partnership to LE GP, LLC (“LE GP”), the general partner of ET. The number of ET Class A Units issued allows LE GP and its affiliates to retain a voting interest in the Partnership that is identical to their voting interest in the Partnership prior to the completion of the Merger. The ET Class A Units are entitled to vote together with the Partnership’s common units, as a single class, except as required by law. Additionally, ET’s partnership agreement provides that, under certain circumstances, upon the issuance by the Partnership of additional common units or any securities that have voting rights that are pari passu with the Partnership common units, the Partnership will issue to any holder of ET Class A Units additional ET Class A Units such that the holder maintains a voting interest in the Partnership that is identical to its voting interest in the Partnership prior to such issuance. The ET Class A Units are not entitled to distributions and otherwise have no economic attributes.

ET Repurchase Program

In February 2015, the Partnership announced a common unit repurchase program, whereby the Partnership may repurchase up to an additional $2 billion of ET Common Units in the open market at the Partnership’s discretion, subject to market conditions and other factors, and in accordance with applicable regulatory requirements. The Partnership repurchased 1.9 million ET Common Units under this program in 2019 and no ET Common Units in 2018 or 2017 and there was $911 million available to use under the program as of December 31, 2019.

ET Distribution Reinvestment Program

During the year ended December 31, 2019, distributions of $148 million were reinvested under the distribution reinvestment program. As of December 31, 2019, a total of 29 million common units remain available to be issued under the existing registration statement in connection with the distribution reinvestment program.

Sale of Common Units by Subsidiaries

The Parent Company accounts for the difference between the carrying amount of its investment in subsidiaries and the underlying book value arising from issuance of units by subsidiaries (excluding unit issuances to the Parent Company) as a capital transaction. If a subsidiary issues units at a price less than the Parent Company’s carrying value per unit, the Parent Company assesses whether the investment has been impaired, in which case a provision would be reflected in our statement of operations. The Parent Company did not recognize any impairment related to the issuances of subsidiary common units during the periods presented.

ETO Class K Units

As of December 31, 2019, a total of 101.5 million Class K Units were held by wholly-owned subsidiaries of ETO. Each Class K Unit is entitled to a quarterly cash distribution of $0.67275 per Class K Unit prior to ETO making distributions of available cash to any class of units, excluding any cash available distributions or dividends or capital stock sales proceeds received by ETO from ETP Holdco. If the Partnership is unable to pay the Class K Unit quarterly distribution with respect to any quarter, the accrued and unpaid distributions will accumulate until paid and any accumulated balance will accrue 1.5% per annum until paid.

ETO Class L Units

On December 31, 2018, ETO issued a new class of limited partner interests titled Class L Units to two wholly-owned subsidiaries of the Partnership when the Partnership’s previously outstanding Class E units and Class G units held by such subsidiaries were converted into Class L Units. As a result of the conversion, the Class E units and Class G units were cancelled.

The Class L Units generally do not have any voting rights. The Class L Units are entitled to aggregate cash distributions equal to 7.65% per annum of the total amount of cash generated by us and our subsidiaries, other than ETP Holdco, and available for distribution. Distributions shall be paid quarterly, in arrears, within 45 days after the end of each quarter. As the Class L Units are owned by a wholly-owned subsidiary, the cash distributions on those units are eliminated in our consolidated financial statements.

ETO Class M Units

On July 1, 2019, ETO issued a new class of limited partner interests titled Class M Units to ETP Holdco, a wholly-owned subsidiary of the Partnership, in exchange for the contribution of ETP Holdco’s equity ownership interest in Panhandle to the Partnership.

The Class M Units generally do not have any voting rights. The Class M Units are entitled to aggregate cash distributions equal to 8.00% per annum of the total amount of cash generated by us and our subsidiaries, other than ETP Holdco, and available for distribution. Distributions shall be paid quarterly, in arrears, within 45 days after the end of each quarter. As the Class M Units are owned by a wholly-owned subsidiary, the cash distributions on those units are eliminated in our consolidated financial statements.

ETO Preferred Units

In November 2017, ETO issued 950,000 of its 6.250% Series A Preferred Units at a price of $1,000 per unit and 550,000 of its 6.625% Series B Preferred Units at a price of $1,000 per unit. In April 2018, ETO issued 18 million of its 7.375% Series C Preferred Units at a price of $25 per unit. In July 2018, ETO issued 17.8 million of its 7.625% Series D Preferred Units at a price of $25 per unit. In April 2019, ETO issued 32 million of its 7.600% Series E Preferred Units at a price of $25 per unit.

As of December 31, 2019 all of ETO Series A, Series B, Series C, Series D and Series E Preferred Units issued remain outstanding.

ETO Series A Preferred Units

Distributions on the Series A Preferred Units will accrue and be cumulative from and including the date of original issue 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. The Series A Preferred Units are redeemable at ETO’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.

ETO Series B Preferred Units

Distributions on the Series B Preferred Units will accrue and be cumulative from and including the date of original issue 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. The Series B Preferred Units are redeemable at ETO’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.

ETO Series C Preferred Units

Distributions on the Series C Preferred Units will accrue and be cumulative from and including the date of original issue 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. The Series C Preferred Units are redeemable at ETO’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.

ETO Series D Preferred Units

Distributions on the Series D Preferred Units will accrue and be cumulative from and including the date of original issue 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. The Series D Preferred Units are redeemable at ETO’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.

ETO Series E Preferred Units

Distributions on the Series E Preferred Units will accrue and be cumulative from and including the date of original issue 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. The Series E Preferred Units are redeemable at ETO’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.

ETO Series F Preferred Units

On January 22, 2020, the Partnership issued 500,000 of its 6.750% Series F Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Units representing limited partner interest in the Partnership, at a price to the public of $1,000 per unit. Distributions on the Series F Preferred Units are cumulative from and including the original issue date and will be payable semi-annually in arrears on the 15th day of May and November of each year, commencing on May 15, 2020 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. The Series F Preferred Units are redeemable at ETO’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.

ETO Series G Preferred Units

On January 22, 2020, the Partnership issued 1,100,000 of its 7.125% Series G Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Units representing limited partner interest in the Partnership, at a price to the public of $1,000 per unit. Distributions on the Series G Preferred Units are cumulative from and including the original issue date and will be payable semi-annually in arrears on the 15th day of May and November of each year, commencing on May 15, 2020 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. The Series G Preferred Units are redeemable at ETO’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.

PennTex Tender Offer and Limited Call Right Exercise

In June 2017, ETO purchased all of the outstanding PennTex common units not previously owned by ETO for $20.00 per common unit in cash. ETO now owns all of the economic interests of PennTex, and PennTex common units are no longer publicly traded or listed on the NASDAQ.

Subsidiary Equity Transactions

Sunoco LP’s Common Unit Repurchase

In February 2018, after the record date for Sunoco LP’s fourth quarter 2017 cash distributions, Sunoco LP repurchased 17,286,859 Sunoco LP common units owned by ETO for aggregate cash consideration of approximately $540 million. ETO used the proceeds from the sale of the Sunoco LP common units to repay amounts outstanding under its revolving credit facility.

Sunoco LP’s Equity Distribution Program

Sunoco LP is party to an equity distribution agreement for an at-the-market (“ATM”) offering pursuant to which Sunoco LP may sell its common units from time to time. For the years ended December 31, 2019 and 2018, Sunoco LP issued no units under its ATM program. For the year ended December 31, 2017, Sunoco LP issued an additional 1.3 million units with total net proceeds of $33 million , net of commissions of $0.3 million. As of December 31, 2019, $295 million of Sunoco LP common units remained available to be issued under the currently effective equity distribution agreement.

Sunoco LP’s Series A Preferred Units

On March 30, 2017, ET purchased 12.0 million Sunoco LP Series A Preferred Units representing limited partner interests in Sunoco LP in a private placement transaction for an aggregate purchase price of $300 million. The distribution rate of Sunoco LP Series A Preferred Units is 10.00%, per annum, of the $25.00 liquidation preference per unit until March 30, 2022, at which point the distribution rate will become a floating rate of 8.00% plus three-month LIBOR of the liquidation preference.

In January 2018, Sunoco LP redeemed all outstanding Sunoco LP Series A Preferred Units held by ET for an aggregate redemption amount of approximately $313 million. The redemption amount included the original consideration of $300 million and a 1% call premium plus accrued and unpaid quarterly distributions.

USAC’s Distribution Reinvestment Program

During the year ended December 31, 2019 and nine months ended December 31, 2018, distributions of $1 million and $0.6 million, respectively, were reinvested under the USAC distribution reinvestment program resulting in the issuance of approximately 60,584 and 39,280 USAC common units, respectively.

USAC’s Warrant Private Placement

On April 2, 2018, USAC issued two tranches of warrants to purchase USAC common units (the “USAC Warrants”), which included USAC Warrants to purchase 5,000,000 common units with a strike price of $17.03 per unit and USAC Warrants to purchase 10,000,000 common units with a strike price of $19.59 per unit. The USAC Warrants may be exercised by the holders thereof at any time beginning on the one year anniversary of the closing date and before the tenth anniversary of the closing date. Upon exercise of the USAC Warrants, USAC may, at its option, elect to settle the USAC Warrants in common units on a net basis.

USAC’s Class B Units

The USAC Class B Units, all of which are owned by ETO, are a new class of partnership interests of USAC that have substantially all of the rights and obligations of a USAC common unit, except the USAC Class B Units will not participate in distributions for the first four quarters following the closing date of the USAC Transaction on April 2, 2018. Each USAC Class B Unit automatically converted into one USAC common unit on the first business day following the record date attributable to the quarter ending June 30, 2019.

On July 30, 2019, the 6,397,965 USAC Class B units held by the Partnership converted into 6,397,965 common units representing limited partner interests in USAC. These common units participate in distributions declared by USAC.

Parent Company Quarterly Distributions of Available Cash

Our distribution policy is consistent with the terms of our Partnership Agreement, which requires that we distribute all of our available cash quarterly. The Parent Company’s only cash-generating assets currently consist of distributions from its interest in ETO.

Our distributions declared and paid with respect to our common units were as follows:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2016 ⁽¹⁾	February 7, 2017	February 21, 2017	$	0.2850
March 31, 2017 ⁽¹⁾	May 10, 2017	May 19, 2017	0.2850
June 30, 2017 ⁽¹⁾	August 7, 2017	August 21, 2017	0.2850
September 30, 2017 ⁽¹⁾	November 7, 2017	November 20, 2017	0.2950
December 31, 2017 ⁽¹⁾	February 8, 2018	February 20, 2018	0.3050
March 31, 2018	May 7, 2018	May 21, 2018	0.3050
June 30, 2018	August 6, 2018	August 20, 2018	0.3050
September 30, 2018	November 8, 2018	November 19, 2018	0.3050
December 31, 2018	February 8, 2019	February 19, 2019	0.3050
March 31, 2019	May 7, 2019	May 20, 2019	0.3050
June 30, 2019	August 6, 2019	August 19, 2019	0.3050
September 30, 2019	November 5, 2019	November 19, 2019	0.3050
December 31, 2019	February 7, 2020	February 19, 2020	0.3050

⁽¹⁾

Certain common unitholders elected to participate in a plan pursuant to which those unitholders elected to forego their cash distributions on all or a portion of their common units for a period of up to nine quarters commencing with the distribution for the quarter ended March 31, 2016 and, in lieu of receiving cash distributions on these common units for each such quarter, each said unitholder received ET Series A Convertible Preferred Units (on a one-for-one basis for each common unit as to which the participating unitholder elected be subject to this plan) that entitled them to receive a cash distribution of up to $0.11 per unit. See additional information below.

Our distributions declared and paid with respect to ET Series A Convertible Preferred Unit were as follows:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2016	February 7, 2017	February 21, 2017	$	0.1100
March 31, 2017	May 10, 2017	May 19, 2017	0.1100
June 30, 2017	August 7, 2017	August 21, 2017	0.1100
September 30, 2017	November 7, 2017	November 20, 2017	0.1100
December 31, 2017	February 8, 2018	February 20, 2018	0.1100
March 31, 2018	May 7, 2018	May 21, 2018	0.1100

ETO Preferred Unit Distributions

Distributions on the ETO’s Series A, Series B, Series C, Series D and Series E preferred units declared and/or paid by ETO were as follows:



Period Ended	Record Date	Payment Date	Series A⁽¹⁾			Series B⁽¹⁾			Series C			Series D			Series E
December 31, 2017	February 1, 2018	February 15, 2018	$	15.4510	^*	$	16.3780	^*	$	—		$	—		$	—
June 30, 2018	August 1, 2018	August 15, 2018	31.2500			33.1250			0.5634		^*	—			—
September 30, 2018	November 1, 2018	November 15, 2018	—			—			0.4609			0.5931		^*	—
December 31, 2018	February 1, 2019	February 15, 2019	31.2500			33.1250			0.4609			0.4766			—
March 31, 2019	May 1, 2019	May 15, 2019	—			—			0.4609			0.4766			—
June 30, 2019	August 1, 2019	August 15, 2019	31.2500			33.1250			0.4609			0.4766			0.5806		^*
September 30, 2019	November 1, 2019	November 15, 2019	—			—			0.4609			0.4766			0.4750
December 31, 2019	February 3, 2020	February 18, 2020	31.2500			33.1250			0.4609			0.4766			0.4750


^*	Represent prorated initial distributions. Prorated initial distributions on the recently issued ETO Series F Preferred Units and ETO Series G Preferred Units will be payable in May 2020.

⁽¹⁾ ETO Series A Preferred Units and ETO Series B Preferred Unit distributions are paid on a semi-annual basis.

Sunoco LP Cash Distributions

The following table illustrates the percentage allocations of available cash from operating surplus between Sunoco LP’s common unitholders and the holder of its IDRs based on the specified target distribution levels, after the payment of distributions to Class C unitholders. The amounts set forth under “marginal percentage interest in distributions” are the percentage interests of the IDR holder and the common unitholders in any available cash from operating surplus which Sunoco LP distributes up to and including the corresponding amount in the column “total quarterly distribution per unit target amount.” The percentage interests shown for common unitholders and IDR holder for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution.



		Marginal Percentage Interest in Distributions
	Total Quarterly Distribution Target Amount	Common Unitholders	Holder of IDRs
Minimum Quarterly Distribution	$0.4375	100%	—%
First Target Distribution	$0.4375 to $0.503125	100%	—%
Second Target Distribution	$0.503125 to $0.546875	85%	15%
Third Target Distribution	$0.546875 to $0.656250	75%	25%
Thereafter	Above $0.656250	50%	50%

Distributions on Sunoco LP’s units declared and/or paid by Sunoco LP were as follows:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2016	February 13, 2017	February 21, 2017	$	0.8255
March 31, 2017	May 9, 2017	May 16, 2017	0.8255
June 30, 2017	August 7, 2017	August 15, 2017	0.8255
September 30, 2017	November 7, 2017	November 14, 2017	0.8255
December 31, 2017	February 6, 2018	February 14, 2018	0.8255
March 31, 2018	May 7, 2018	May 15, 2018	0.8255
June 30, 2018	August 7, 2018	August 15, 2018	0.8255
September 30, 2018	November 6, 2018	November 14, 2018	0.8255
December 31, 2018	February 6, 2019	February 14, 2019	0.8255
March 31, 2019	May 7, 2019	May 15, 2019	0.8255
June 30, 2019	August 6, 2019	August 14, 2019	0.8255
September 30, 2019	November 5, 2019	November 19, 2019	0.8255
December 31, 2019	February 7, 2020	February 19, 2020	0.8255

USAC Cash Distributions

Subsequent to the Energy Transfer Merger and USAC Transactions described in Note 1 and Note 3, respectively, ETO owned approximately 39.7 million USAC common units and 6.4 million USAC Class B units. Subsequent to the conversion of the USAC Class B Units to USAC common units on July 30, 2019, ETO owns approximately 46.1 million USAC common units. As of December 31, 2019, USAC had approximately 96.6 million common units outstanding. USAC currently has a non-economic general partner interest and no outstanding IDRs.

Distributions on USAC’s units declared and/or paid by USAC subsequent to the USAC transaction on April 2, 2018 were as follows:



Quarter Ended	Record Date	Payment Date	Rate
March 31, 2018	May 1, 2018	May 11, 2018	$	0.5250
June 30, 2018	July 30, 2018	August 10, 2018	0.5250
September 30, 2018	October 29, 2018	November 09, 2018	0.5250
December 31, 2018	January 28, 2019	February 8, 2019	0.5250
March 31, 2019	April 29, 2019	May 10, 2019	0.5250
June 30, 2019	July 29, 2019	August 9, 2019	0.5250
September 30, 2019	October 28, 2019	November 8, 2019	0.5250
December 31, 2019	January 27, 2020	February 7, 2020	0.5250

Accumulated Other Comprehensive Income

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



	December 31,
	2019			2018
Available-for-sale securities	$	13		$	2
Foreign currency translation adjustment	2			(5		)
Actuarial loss related to pensions and other postretirement benefits	(25		)	(48		)
Investments in unconsolidated affiliates, net	(1		)	9
Total AOCI, net of tax	$	(11	)	$	(42	)

The table below sets forth the tax amounts included in the respective components of other comprehensive income:



	December 31,
	2019			2018
Available-for-sale securities	$	(1	)	$	(1	)
Foreign currency translation adjustment	2			2
Actuarial loss relating to pension and other postretirement benefits	8			12
Total	$	9		$	13

Unit-Based Compensation Plans

12 Months Ended

Dec. 31, 2019

Share-based Payment Arrangement, Expensed and Capitalized, Amount [Abstract]

Unit-Based Compensation Plans

NON-CASH COMPENSATION PLANS:

ET Non-Cash Compensation Plan

We, Sunoco LP and USAC, have issued equity incentive plans for employees, officers and directors, which provide for various types of awards, including options to purchase Common Units, restricted units, phantom units, distribution equivalent rights (“DERs”), common unit appreciation rights, cash restricted units and other non-cash compensation awards. As of December 31, 2019, an aggregate total of 6.5 million ET Common Units remain available to be awarded under our equity incentive plans.

ET Long-Term Incentive Plan

We have granted restricted unit awards to employees that vest over a specified time period, typically a five-year service vesting requirement, with vesting based on continued employment as of each applicable vesting date. Upon vesting, ET Common Units are issued. These unit awards entitle the recipients of the unit awards to receive, with respect to each Common Unit subject to such award that has not either vested or been forfeited, a cash payment equal to each cash distribution per Common Unit made by us on our Common Units promptly following each such distribution by us to our Unitholders. We refer to these rights as “distribution equivalent rights.” Under our equity incentive plans, our non-employee directors each receive grants with a five-year service vesting requirement.

The following table shows the activity of the awards granted to employees and non-employee directors:



	Number of Units		Weighted Average Grant-Date Fair Value Per Unit
Unvested awards as of December 31, 2018	22.4		$	15.94
Replacement awards issued in the SemGroup Transaction	1.4		11.60
Awards granted	8.9		12.51
Awards vested	(4.0	)	21.09
Awards forfeited	(0.7	)	15.70
Unvested awards as of December 31, 2019	28.0		13.89

During the years ended December 31, 2019, 2018, and 2017, the weighted average grant-date fair value per unit award granted was $12.51, $13.00 and $17.01, respectively. The total fair value of awards vested was $47 million, $49 million, and $40 million, respectively, based on the market price of the respective Common Units as of the vesting date. As of December 31, 2019, a total of 28.0 million unit awards remain unvested, for which ET expects to recognize a total of $258 million in compensation expense over a weighted average period of 2.6 years.

Cash Restricted Units. We previously granted cash restricted units, which entitled the award recipient to receive cash equal to the market value of one ET Common Unit upon vesting. The Partnership does not currently have any cash restricted units outstanding.

Subsidiary Long-Term Incentive Plans

Each of Sunoco LP and USAC has granted restricted or phantom unit awards (collectively, the “Subsidiary Unit Awards”) to employees and directors that entitle the grantees to receive common units of the respective subsidiary. In some cases, at the discretion of the respective subsidiary’s compensation committee, the grantee may instead receive an amount of cash equivalent to the value of common units upon vesting. Substantially all of the Subsidiary Unit Awards are time-vested grants, which

generally vest over a three or five-year period, that entitles the grantees of the unit awards to receive an amount of cash equal to the per unit cash distributions made by the respective subsidiaries during the period the restricted unit is outstanding.

The following table summarizes the activity of the Subsidiary Unit Awards:



	Sunoco LP				USAC
	Number of Units		Weighted Average Grant-Date Fair Value Per Unit		Number of Units		Weighted Average Grant-Date Fair Value Per Unit
Unvested awards as of December 31, 2018	2.1		$	29.15	1.4		$	14.98
Awards granted	0.7		30.70		0.7		15.88
Awards vested	(0.5	)	30.04		(0.3	)	13.06
Awards forfeited	(0.2	)	28.16		—		16.78
Unvested awards as of December 31, 2019	2.1		29.21		1.8		15.09

The following table summarizes the weighted average grant-date fair value per unit award granted:



	Years Ended December 31,
	2019		2018		2017
Sunoco LP	$	30.70	$	27.67	$	28.31
USAC	15.88		15.47		N/A

The total fair value of Subsidiary Unit Awards vested for the years ended December 31, 2019, 2018 and 2017 was $17 million, $22 million, and $9 million, respectively, based on the market price of Sunoco LP and USAC common units as of the vesting date for the years ended December 31, 2019 and 2018 and Sunoco LP for the year ended December 31, 2017. As of December 31, 2019, estimated compensation cost related to Subsidiary Unit Awards not yet recognized was $57 million, and the weighted average period over which this cost is expected to be recognized in expense is 3.6 years.

Income Taxes Income Taxes (Notes)

12 Months Ended

Dec. 31, 2019

Income Tax Disclosure [Abstract]

Income Tax Disclosure [Text Block]

INCOME TAXES:

As a partnership, we are not subject to United States federal income tax and most state income taxes. However, the Partnership conducts certain activities through corporate subsidiaries which are subject to federal and state income taxes. The components of the federal and state income tax expense (benefit) of our taxable subsidiaries were summarized as follows:



	Years Ended December 31,
	2019			2018			2017
Current expense (benefit):
Federal	$	(20	)	$	(8	)	$	54
State	(2		)	19			(16		)
Total	(22		)	11			38
Deferred expense (benefit):
Federal	174			181			(2,055		)
State	43			(188		)	184
Total	217			(7		)	(1,871		)
Total income tax expense (benefit) from continuing operations	$	195		$	4		$	(1,833	)

Historically, our effective tax rate has differed from the statutory rate primarily due to partnership earnings that are not subject to United States federal and most state income taxes at the partnership level. A reconciliation of income tax expense at the United States statutory rate to the Partnership’s income tax benefit for the years ended December 31, 2019, 2018 and 2017 is as follows:



	Years Ended December 31,
	2019			2018			2017
Income tax expense at United States statutory rate	$	1,070		$	763		$	248
Increase (reduction) in income taxes resulting from:
Partnership earnings not subject to tax	(882		)	(635		)	(477		)
Goodwill impairment	—			—			207
State tax, net of federal tax benefit	12			(125		)	124
Dividend received deduction	(3		)	(5		)	(14		)
Federal rate change	—			—			(1,812		)
Change in tax status of subsidiary	—			—			(124		)
Other	(2		)	6			15
Income tax expense (benefit) from continuing operations	$	195		$	4		$	(1,833	)

Deferred taxes result from the temporary differences between financial reporting carrying amounts and the tax basis of existing assets and liabilities. The table below summarizes the principal components of the deferred tax assets (liabilities) as follows:



	December 31,
	2019			2018
Deferred income tax assets:
Net operating losses, alternative minimum tax credit and other carryforwards	$	936		$	768
Pension and other postretirement benefits	7			34
Long-term debt	—			13
Other	85			181
Total deferred income tax assets	1,028			996
Valuation allowance	(95		)	(96		)
Net deferred income tax assets	933			900

Deferred income tax liabilities:
Property, plant and equipment	(501		)	(782		)
Investments in affiliates	(3,547		)	(2,872		)
Trademarks	(72		)	(63		)
Other	(21		)	(109		)
Total deferred income tax liabilities	(4,141		)	(3,826		)
Net deferred income taxes	$	(3,208	)	$	(2,926	)

As of December 31, 2019, ETP Holdco had a federal net operating loss carryforward of $2.65 billion, of which $1.10 billion will expire between 2031 and 2037 while the remaining can be carried forward indefinitely. As of December 31, 2019, Semgroup Corporation had a federal net operating loss carryforward of $766 million of which $185 million will expire between 2031 and 2037 while the remaining can be carried forward indefinitely. As of December 31, 2019, Sunoco Property Company LLC, a corporate subsidiary of Sunoco LP, has no federal net operating loss carryforward.

Our corporate subsidiaries have $15 million of federal alternative minimum tax credits at December 31, 2019, of which $8 million is expected to be reclassified to current income tax receivable in 2020 pursuant to the Tax Cuts and Jobs Act. Our corporate subsidiaries have state net operating loss carryforward benefits of $118 million, net of federal tax, which expire between 2020 and 2038, while others are carried forward indefinitely. Our corporate subsidiaries have Canadian net operating losses of $68 million that will begin to expire in 2033 and foreign tax credits of $45 million that will begin to expire in 2020. Our corporate subsidiaries have cumulative excess business interest expense of $35 million available for carryforward indefinitely. A valuation allowance of $49 million is attributable to state net operating loss carryforward benefits primarily attributable to significant restrictions on their use in the Commonwealth of Pennsylvania. A separate valuation allowance of $46 million is attributable to foreign tax credits.

The following table sets forth the changes in unrecognized tax benefits:



	Years Ended December 31,
	2019			2018		2017
Balance at beginning of year	$	624		$	609	$	615
Additions attributable to tax positions taken in the current year	—			8		—
Additions attributable to tax positions taken in prior years	11			7		28
Reduction attributable to tax positions taken in prior years	(541		)	—		(25		)
Lapse of statute	—			—		(9		)
Balance at end of year	$	94		$	624	$	609

As of December 31, 2019, we have $90 million ($72 million after federal income tax benefits) related to tax positions which, if recognized, would impact our effective tax rate.

Our policy is to accrue interest expense and penalties on income tax underpayments (overpayments) as a component of income tax expense. During 2019, we recognized interest and penalties of less than $1 million. At December 31, 2019, we have interest and penalties accrued of $3 million, net of tax.

We appealed the adverse Court of Federal Claims decision against ETC Sunoco regarding the IRS' denial of ethanol blending credits claims under Section 6426 to the Federal Circuit. The Federal Circuit affirmed the CFC's denial on November 1, 2018. ETC Sunoco filed a petition for certiorari with the Supreme Court on May 24, 2019 to review the Federal Circuit's affirmation of the CFC's ruling, and the Court denied ETC Sunoco's petition on October 7, 2019. The petition for certiorari applied to Sunoco's 2004 through 2009 tax years, and 2010 - 2011 are on extension with the IRS through March 30, 2020, via a Form 907 (Agreement to Extend the Time to Bring Suit). Due to the uncertainty surrounding the litigation, a reserve of $530 million was previously established for the full amount of the pending refund claims, and the receivable and reserve for this issue were netted in the balance sheet. Subsequent to the Supreme Court's denial of the petition in October 2019, the receivable and reserve have been reversed, with no impact to the Partnership's financial position and results of operations.

In November 2015, the Pennsylvania Commonwealth Court determined in Nextel Communications v. Commonwealth (“Nextel”) that the Pennsylvania limitation on NOL carryforward deductions violated the uniformity clause of the Pennsylvania Constitution and struck the NOL limitation in its entirety. In October 2017, the Pennsylvania Supreme Court affirmed the decision with respect to the uniformity clause violation; however, the Court reversed with respect to the remedy and instead severed the flat-dollar limitation, leaving the percentage-based limitation intact. Nextel subsequently filed a petition for writ of certiorari with the United States Supreme Court, and this was denied on June 11, 2018. Now certain Pennsylvania taxpayers are proceeding with litigation in Pennsylvania state courts on issues not addressed by the Pennsylvania Supreme Court in Nextel, specifically, whether the Due Process and Equal Protection Clauses of the United States Constitution and the Remedies Clause of the Pennsylvania Constitution require a court to grant the taxpayer relief. ETC Sunoco has recognized approximately $67 million ($53 million after federal income tax benefits) in tax benefit based on previously filed tax returns and certain previously filed protective claims as relates to its cases currently held pending the Nextel matter. However, based upon the Pennsylvania Supreme Court’s October 2017 decision, and because of uncertainty in the breadth of the application of the decision, we have reserved $34 million ($27 million after federal income tax benefits) against the receivable.

In general, ET and its subsidiaries are no longer subject to examination by the IRS, and most state jurisdictions, for the 2014 and prior tax years.

ET and its subsidiaries also have various state and local income tax returns in the process of examination or administrative appeal in various jurisdictions. We believe the appropriate accruals or unrecognized tax benefits have been recorded for any potential assessment with respect to these examinations.

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities

12 Months Ended

Dec. 31, 2019

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

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities

REGULATORY MATTERS, COMMITMENTS, CONTINGENCIES AND ENVIRONMENTAL LIABILITIES:

FERC Proceedings

By Order issued January 16, 2019, the FERC initiated a review of Panhandle’s existing rates pursuant to Section 5 of the Natural Gas Act 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 Natural Gas Act. The Natural Gas Act Section 5 and Section 4 proceedings were consolidated by the Order dated October 1, 2019. A hearing in the combined proceedings is scheduled for August 2020, with an initial decision expected in early 2021.

By Order issued February 19, 2019, the FERC initiated a review of Southwest Gas’ existing rates pursuant to Section 5 of the Natural Gas Act to determine whether the rates currently charged by Southwest Gas are just and reasonable and set the matter for hearing. Southwest Gas filed a cost and revenue study on May 6, 2019. On July 10, 2019, Southwest Gas filed an Offer of Settlement in this Section 5 proceeding, which settlement was supported or not opposed by Commission Trial Staff and all active parties. By order dated October 29, 2019, the FERC approved the settlement as filed, and there is not a material impact on revenue.

In addition, on November 30, 2018, Sea Robin filed a rate case pursuant to Section 4 of the Natural Gas Act. On July 22, 2019, Sea Robin filed an Offer of Settlement in this Section 4 proceeding, which settlement was supported or not opposed by Commission Trial Staff and all active parties. By order dated October 17, 2019, the FERC approved the settlement as filed, and there is not a material impact on revenue.

Commitments

In the normal course of business, ETO purchases, processes and sells natural gas pursuant to long-term contracts and enters into long-term transportation and storage agreements. Such contracts contain terms that are customary in the industry. ETO believes that the terms of these agreements are commercially reasonable and will not have a material adverse effect on its financial position or results of operations.

Our joint venture agreements require that we funds our proportionate share of capital contributions to its unconsolidated affiliates. Such contributions will depend upon our 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 statements of operations:



	Years Ended December 31,
	2019		2018		2017
ROW expense	$	45	$	46	$	46

PES Refinery Fire and Bankruptcy

We own an approximately 7.4% non-operating interest in PES, which owns a refinery in Philadelphia. In addition, the Partnership provides logistics services to PES under commercial contracts and Sunoco LP has historically purchased refined products from PES. In June 2019, an explosion and fire occurred at the refinery complex.

On July 21, 2019, PES Holdings, LLC and seven of its subsidiaries (collectively, the "Debtors") filed voluntary petitions in the United States Bankruptcy Court for the District of Delaware seeking relief under the provisions of Chapter 11 of the United States Bankruptcy Code, as a result of the explosion and fire at the Philadelphia refinery complex. The Debtors have also defaulted on a $75 million note payable to a subsidiary of the Partnership. The Partnership has not recorded a valuation allowance related to the note receivable as of December 31, 2019, because management is not yet able to determine the collectability of the note in bankruptcy.

In addition, the Partnership’s subsidiaries retained certain environmental remediation liabilities when the refinery was sold to PES. As of December 31, 2019, the Partnership has funded these environmental remediation liabilities through its wholly-owned captive insurance company, based upon actuarially determined estimates for such costs, and these liabilities are included in the total environmental liabilities discussed below under “Environmental Remediation.” In the event that the PES property is sold in connection with the bankruptcy proceeding, it may be necessary for the Partnership to record additional environmental remediation liabilities in the future depending upon the proposed use of such property by the buyer of the property; however, management is not currently able to estimate such additional liabilities.

PES has rejected certain of the Partnership’s commercial contracts pursuant to Section 365 of the Bankruptcy Code; however, the impact of the bankruptcy on the Partnership’s commercial contracts and related revenue loss (temporary or permanent) is unknown at this time. In addition, Sunoco LP has been successful at acquiring alternative supplies to replace fuel volume lost from PES and does not anticipate any material impact to its business going forward.

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.

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 challenging permits issued by the United States Army Corps of Engineers (“USACE”) permitting Dakota Access, LLC (“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 allowing 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”). Plaintiffs and Defendants filed cross motions for summary judgment, and the parties await a ruling.

While we believe that the pending lawsuits are unlikely to halt or suspend operation of the pipeline, we cannot assure this outcome. Energy Transfer cannot determine when or how these lawsuits will be resolved or the impact they may have on the Dakota Access project.

Mont Belvieu Incident

On June 26, 2016, a hydrocarbon storage well located on another operator’s facility adjacent to Lone Star NGL Mont Belvieu’s (“Lone Star”) 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 have resumed at the facilities with the exception of one of Lone Star’s storage wells, however, Lone Star is still quantifying the extent of its incurred and ongoing damages and has obtained, and will continue to seek, reimbursement for these losses.

MTBE Litigation

ETC Sunoco Holdings LLC and Sunoco (R&M), LLC (collectively, “Sunoco”) 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 December 31, 2019, Sunoco is a defendant 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”), 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, ETP GP, 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 the parties await a ruling from the court.

The Regency Defendants cannot predict the outcome of the Regency Merger Litigation or any lawsuits that might be filed subsequent to the date of this filing; nor can the Regency Defendants predict the amount of time and expense that will be required to resolve the Regency Merger Litigation. The Regency Defendants believe the Regency Merger Litigation is without merit and intend to vigorously defend against it.

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

On January 27, 2014, a trial commenced between ETO against Enterprise Products Partners, L.P. and Enterprise Products Operating LLC (collectively, “Enterprise”) and Enbridge (US) Inc. Trial resulted in a verdict in favor of ETO against Enterprise that consisted of $319 million in compensatory damages and $595 million in disgorgement to ETO. The jury also found that ETO owed Enterprise $1 million under a reimbursement agreement. On July 29, 2014, the trial court entered a final judgment in favor of ETO and awarded ETO $536 million, consisting of compensatory damages, disgorgement, and pre-judgment interest. The trial court also ordered that ETO shall be entitled to recover post-judgment interest and costs of court and that Enterprise is not entitled to any net recovery on its counterclaims. Enterprise filed a notice of appeal with the Court of Appeals. On July 18, 2017, the Court of Appeals issued its opinion and reversed the trial court’s judgment. ETO’s motion for rehearing to the Court of Appeals was denied. On November 27, 2017, ETO filed a Petition for Review with the Texas Supreme Court. On June 8, 2018, the Texas Supreme Court ordered briefing on the merits. On June 28, 2019, the Texas Supreme Court granted ETO’s petition for review and oral argument was heard on October 8, 2019. On January 31, 2020, the Texas Supreme Court affirmed the judgment of the Court of Appeals.

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, “Defendants”), alleging that Defendants breached their obligations under the ET-Williams merger agreement (the “Merger Agreement”). In general, Williams alleges that 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 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. 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 is currently set for June 2020. Defendants cannot predict the outcome of the Williams Litigation or any lawsuits that might be filed subsequent to the date of this filing; nor can Defendants predict the amount of time and expense that will be required to resolve these lawsuits. Defendants believe that Williams’ claims are without merit and intend to defend vigorously against them.

Unitholder Litigation Relating to the Issuance

ET unitholders filed a putative class action lawsuits against ET, LE GP, Kelcy Warren, John McReynolds, Marshall McCrea, Matthew Ramsey, Ted Collins, K. Rick Turner, William Williams, Ray Davis, and Richard Brannon in the Delaware Court of Chancery (the “Issuance Litigation”). Plaintiffs alleged that the issuance of ET Series A Convertible Preferred Units (“Issuance”) breached various provisions of ET’s partnership agreement. Plaintiffs sought, among other things, preliminary and permanent injunctive relief and class-wide damages allegedly resulting from the Issuance.

The matter was tried on February 19-21, 2018. In a May 17, 2018 opinion, the court found that one provision of the Issuance breached ET’s partnership agreement, but that this breach caused no damages. The court denied Plaintiffs’ requests for injunctive relief and declined to award damages or any other form of relief. Plaintiffs subsequently filed a motion seeking $8.5 million in attorneys’ fees and expenses, which the defendants opposed. On May 6, 2019, the Court entered an Order and Final Judgment, consistent with its May 2018 post-trial opinion, in which it ordered Energy Transfer to pay $4.5 million in attorneys’ fees and expenses and granted Plaintiffs’ Motion for Class Certification.

On June 5, 2019, Plaintiffs filed a notice of appeal to the Supreme Court of Delaware from, among other things, the May 17, 2018 Memorandum Opinion and the May 6, 2019 Order and Final Judgment. The Delaware Supreme Court summarily affirmed the Court’s rulings. The case was closed on December 12, 2019, ending the litigation.

Rover

On November 3, 2017, the State of Ohio and the Ohio Environmental Protection Agency (“Ohio EPA”) filed suit against Rover and other defendants (collectively, the Defendants”) seeking to recover approximately $2.6 million in 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 Defendants intend to oppose.

Bayou Bridge

On January 11, 2018, environmental groups and a trade association filed suit against the U.S. Army Corps of Engineers (“USACE”) in the United States District Court for the Middle District of Louisiana alleging violations of the National Environmental Policy Act, the Clean Water Act, and the Rivers and Harbors Act. ETO, through its subsidiary Bayou Bridge Pipeline, LLC (“Bayou Bridge”), intervened.

In February 2018, the District Court initially granted Plaintiffs’ motion for a preliminary injunction, but the Fifth Circuit Court of Appeals subsequently vacated that decision. The Fifth Circuit’s ruling allowed construction to continue and be completed during the pendency of the case. Plaintiffs filed a second motion for preliminary injunction in January 2019, which was denied. Plaintiffs and Defendants filed cross motions for summary judgment, and the parties await a ruling.

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. On February 8, 2019, the Pennsylvania Department of Environmental Protection (“PADEP”) issued a Permit Hold on any requests for approvals/permits or permit amendments for any project in Pennsylvania pursuant to the state’s water laws. The Partnership filed an appeal of the Permit Hold with the Pennsylvania Environmental Hearing Board. On January 3, 2020, the Partnership entered into a Consent Order and Agreement with the Department in which, among other things, the Permit Hold was lifted, the Partnership agreed to pay a $28.6 million civil penalty and fund a $2 million community environmental project, and all related appeals were withdrawn.

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 (“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 former 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 proscribed time period. To date, the Partnership is not aware of any further action with regard to this Notice.

In December 2019, the former DA announced charges against a current employee related to the provision of security services. The Partnership has secured independent counsel for the employee. While the Partnership will continue to cooperate with the investigation, it intends to vigorously defend itself.

Delaware County, Pennsylvania Investigation

On March 11, 2019, the Delaware County District Attorney’s Office (“DA”) announced that the DA and the Pennsylvania Attorney General’s Office, at the request of the DA, are conducting an investigation of alleged criminal misconduct involving the construction and related activities of the Mariner East pipelines in Delaware County. The Partnership has not been appraised of the specific conduct under investigation. While the Partnership will cooperate with the investigation, it intends to vigorously defend itself.

Recently Filed Litigation Involving Energy Transfer LP

Two purported unitholders of ET filed securities class actions against ET’s Board of Directors and ET as a nominal defendant. See Bettiol v. LP GP, Case No. 3:19-cv-02890-X and Donel Davidson v. Kelcy L. Warren, Cause No. DC-20-02322. The complaints assert claims for breach of fiduciary duties, unjust enrichment, waste of corporate assets, abuse of control, and gross mismanagement and seek damages on behalf of ET related to an alleged decline in ET’s unit value and also seek changes to ET’s corporate governance structure, attorney’s fees, and litigation costs.

Another purported unitholder of ET, Allegheny County Employees’ Retirement System (“ACERS”), individually and on behalf of all other similarly situated, filed a federal securities class action suit against ET and three of ET’s directors: Kelcy L. Warren, John W. McReynolds, and Thomas E. Long. The complaint asserts claims for violations of Sections 10(b) and 20(a) of the Securities Exchange Act of 1934 and Rule 10b-5 promulgated thereunder. ACERS seeks damages allegedly sustained by it and the class in connection with an alleged decline in ET’s unit value, as well as attorney’s fees, litigation costs, and any other relief the court deems proper.

The lawsuits allege, among other things, the existence of wrongdoing by ET during permitting and construction of its Mariner East pipeline project, including that ET made materially false and misleading statements regarding its business, operations, and compliance policies related to the project.

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.

Other Litigation and Contingencies

We or our subsidiaries are a party to various legal proceedings and/or regulatory proceedings incidental to our businesses. For each of these matters, we evaluate the merits of the case, our exposure to the matter, possible legal or settlement strategies, the likelihood of an unfavorable outcome and the availability of insurance coverage. If we determine that an unfavorable outcome of a particular matter is probable and can be estimated, we accrue the contingent obligation, as well as any expected insurance recoverable amounts related to the contingency. As of December 31, 2019 and 2018, accruals of approximately $120 million and $56 million, respectively, were reflected on our consolidated balance sheets related to these contingent obligations. As new information becomes available, our estimates may change. The impact of these changes may have a significant effect on our results of operations in a single period.

The outcome of these matters cannot be predicted with certainty and there can be no assurance that the outcome of a particular matter will not result in the payment of amounts that have not been accrued for the matter. Furthermore, we may revise accrual amounts prior to resolution of a particular contingency based on changes in facts and circumstances or changes in the expected outcome. Currently, we are not able to estimate possible losses or a range of possible losses in excess of amounts accrued.

In addition, other legal proceedings exist that are considered reasonably possible to result in unfavorable outcomes. For those where possible losses can be estimated, the range of possible losses related to these contingent obligations is estimated to be up to $80 million; however, no accruals have been recorded as of December 31, 2019.

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 the results of operations for any single period, we believe that such costs will not have a material adverse effect on our financial position.

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

In February 2017, we received letters from the DOJ on behalf of EPA and Louisiana Department of Environmental Quality (“LDEQ”) notifying SPLP and Mid-Valley that enforcement actions were being pursued for three separate crude oil releases: (a) an estimated 550 barrels released from the Colmesneil-to-Chester pipeline in Tyler County, Texas (“Colmesneil”) which allegedly occurred in February 2013; (b) an estimated 4,509 barrels released from the Longview-to-Mayersville pipeline in Caddo Parish, Louisiana (a/k/a Milepost 51.5) which allegedly occurred in October 2014; and (c) an estimated 40 barrels released from the Wakita 4-inch gathering line in Oklahoma which allegedly occurred in January 2015. In January 2019, a Consent Decree approved by all parties as well as an accompanying Complaint was filed in the United States District Court for the Western District of Louisiana seeking public comment and final court approval to resolve all penalties with DOJ and LDEQ for the three releases. Subsequently, the court approved the Consent Decree and the penalty payment of $5.4 million was satisfied. The Consent Decree requires certain injunctive relief to be completed on the Longview-to-Mayersville pipeline within three years but the injunctive relief is not expected to have any material impact on operations. In addition to resolution of the civil penalty and injunctive relief, we continue to discuss natural resource damages with the Louisiana trustees related to the Caddo Parish, Louisiana release.

In October 2018, Pipeline Hazardous Materials Safety Administration (“PHMSA”) issued a notice of proposed safety order (the “Notice”) to SPMT, a wholly owned subsidiary of ETO. The Notice alleged that conditions exist on certain pipeline facilities owned and operated by SPMT in Nederland, Texas that pose a pipeline integrity risk to public safety, property or the environment. The Notice also made preliminary findings of fact and proposed corrective measures. SPMT responded to the Notice by submitting a timely written response on November 2, 2018, attended an informal consultation held on January 30, 2019 and entered into a consent agreement with PHMSA resolving the issues in the Notice as of March 2019. SPMT is currently awaiting response from PHMSA regarding the approval status of the submitted Remedial Work Plan.

On June 4, 2019, the Oklahoma Corporation Commission’s (“OCC”) Transportation Division filed a complaint against SPLP seeking a penalty of up to $1 million related to a May 2018 rupture near Edmond, Oklahoma. The release occurred on the Noble to Douglas 8” pipeline in an area of external corrosion and caused the release of approximately fifteen barrels of crude oil. SPLP responded immediately to the release and remediated the surrounding environment and pipeline in cooperation with the OCC. The OCC filed the complaint alleging that SPLP failed to provide adequate cathodic protection to the pipeline causing the failure. SPLP is negotiating a settlement agreement with the OCC for a lesser penalty. The OCC has accepted our counter offer in conjunction with a proposed consent order. The Consent Order will be presented to the OCC at a final hearing the date of which is to be determined.

Environmental Remediation

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


•	certain of our interstate pipelines conduct soil and groundwater remediation related to contamination from past uses of PCBs. PCB assessments are ongoing and, in some cases, our subsidiaries could 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 that are subject to environmental assessments, including formerly owned terminals and other logistics assets, retail sites that Sunoco no longer operates, closed and/or sold refineries and other formerly owned sites.

•

Sunoco 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 December 31, 2019, Sunoco had been named as a PRP at approximately 40 identified or potentially identifiable “Superfund” sites under federal and/or comparable state law. Sunoco is usually one of a number of companies identified as a PRP at a site. Sunoco has reviewed the nature and extent of its involvement at each site and other relevant circumstances and, based upon Sunoco’s purported nexus to the sites, believes that its potential liability associated with such sites will not be significant.

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

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



	December 31,
	2019		2018
Current	$	46	$	42
Non-current	274		295
Total environmental liabilities	$	320	$	337

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 years ended December 31, 2019 and 2018, the Partnership recorded $39 million and $48 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)

12 Months Ended

Dec. 31, 2019

Revenue from Contract with Customer [Abstract]

Revenue from Contract with Customer [Text Block]

REVENUE:

The following disclosures discuss the Partnership’s revised revenue recognition policies upon the adoption of ASU 2014-09 on January 1, 2018. These policies were applied to the amounts reflected in the Partnership’s consolidated financial statements for the years ended December 31, 2019 and 2018, while the amounts reflected in the Partnership’s consolidated financial statements for the year ended December 31, 2017 were recorded under the Partnership’s previous accounting policies.

Disaggregation of revenue

The major types of revenue within our reportable segments, 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;


•	fuel distribution and marketing;


•	all other;

•investment in USAC;


•	contract operations;


•	retail parts and services; and

•all other.

Note 17 depicts the disaggregation of revenue by segment, with revenue amounts reflected in accordance with ASC Topic 606 for 2019 and 2018 and ASC Topic 605 for 2017.

Intrastate transportation and storage revenue

Our intrastate transportation and storage segment’s revenues are determined primarily by the volume of capacity our customers reserve as well as the actual volume of natural gas that flows through the transportation pipelines or that is injected or withdrawn into or out of our storage facilities. Firm transportation and storage contracts require customers to pay certain minimum fixed fees regardless of the volume of commodity they transport or store. These contracts typically include a variable incremental charge based on the actual volume of transportation commodity throughput or stored commodity injected/withdrawn. Under interruptible transportation and storage contracts, customers are not required to pay any fixed minimum amounts, but are instead billed based on actual volume of commodity they transport across our pipelines or inject/withdraw into or out of our storage facilities. Payment for services under these contracts are typically due the month after the services have been performed.

The performance obligation with respect to firm contracts is a promise to provide a single type of service (transportation or storage) daily over the life of the contract, which is fundamentally a “stand-ready” service. While there can be multiple activities required to be performed, these activities are not separable because such activities in combination are required to successfully transfer the overall service for which the customer has contracted. The fixed consideration of the transaction price is allocated ratably over the life of the contract and revenue for the fixed consideration is recognized over time, because the customer simultaneously receives and consumes the benefit of this “stand-ready” service. Incremental fees associated with actual volume for each respective period are recognized as revenue in the period the incremental volume of service is performed.

The performance obligation with respect to interruptible contracts is also a promise to provide a single type of service, but such promise is made on a case-by-case basis at the time the customer requests the service and we accept the customer’s request. Revenue is recognized for interruptible contracts at the time the services are performed.

Our intrastate transportation and storage segment also generates revenues and margin from the sale of natural gas to electric utilities, independent power plants, local distribution companies, industrial end-users and other marketing companies on the HPL System. Generally, we purchase natural gas from the market, including purchases from our marketing operations, and from producers at the wellhead.

Interstate transportation and storage revenue

Our interstate transportation and storage segment’s revenues are determined primarily by the amount of capacity our customers reserve as well as the actual volume of natural gas that flows through the transportation pipelines or that is injected into or withdrawn out of our storage facilities. Our interstate transportation and storage segment’s contracts can be firm or interruptible. Firm transportation and storage contracts require customers to pay certain minimum fixed fees regardless of the volume of commodity transported or stored. In exchange for such fees, we must stand ready to perform a contractually agreed-upon

minimum volume of services whenever the customer requests such services. These contracts typically include a variable incremental charge based on the actual volume of transportation commodity throughput or stored commodity injected or withdrawn. Under interruptible transportation and storage contracts, customers are not required to pay any fixed minimum amounts, but are instead billed based on actual volume of commodity they transport across our pipelines or inject into or withdraw out of our storage facilities. Consequently, we are not required to stand ready to provide any contractually agreed-upon volume of service, but instead provides the services based on existing capacity at the time the customer requests the services. Payment for services under these contracts are typically due the month after the services have been performed.

The performance obligation with respect to interruptible contracts is also a promise to provide a single type of services, but such promise is made on a case-by-case basis at the time the customer requests the service and we accept the customer’s request. Revenue is recognized for interruptible contracts at the time the services are performed.

Lake Charles LNG’s revenues are primarily derived from terminalling services for shippers by receiving LNG at the facility for storage and delivering such LNG to shippers, either in liquid state or gaseous state after regasification. Lake Charles LNG derives all of its revenue from a series of long term contracts with a wholly-owned subsidiary of Royal Dutch Shell plc (“Shell”). Terminalling revenue is generated from fees paid by Shell for storage and other associated services at the terminal. Payment for services under these contracts are typically due the month after the services have been performed.

The terminalling agreements are considered to be firm agreements, because they include fixed fee components that are charged regardless of the volumes transported by Shell or services provided at the terminal.

The performance obligation with respect to firm contracts is a promise to provide a single type of service (terminalling) daily over the life of the contract, which is fundamentally a “stand-ready” service. While there can be multiple activities required to be performed, these activities are not separable because such activities in combination are required to successfully transfer the overall service for which the customer has contracted. The fixed consideration of the transaction price is allocated ratably over the life of the contract and revenue for the fixed consideration is recognized over time, because the customer simultaneously receives and consumes the benefit of this “stand-ready” service. Incremental fees associated with actual volume for each respective period are recognized as revenue in the period the incremental volume of service is performed.

Midstream revenue

Our midstream segment’s revenues are derived primarily from margins we earn for natural gas volumes that are gathered, processed, and/or transported. The various types of revenue contracts our midstream segment enters into include:

Fixed fee gathering and processing: Contracts under which we provide gathering and processing services in exchange for a fixed cash fee per unit of volume. Revenue for cash fees is recognized when the service is performed.

Keepwhole: Contracts under which we gather raw natural gas from a third party producer, process the gas to convert it to pipeline quality natural gas, and redeliver to the producer a thermal-equivalent volume of pipeline quality natural gas. In exchange for these services, we retain the NGLs extracted from the raw natural gas received from the producer as well as cash fees paid by the producer. The value of NGLs retained as well as cash fees is recognized as revenue when the services are performed.

Percent of Proceeds (“POP”): Contracts under which we provide gathering and processing services in exchange for a specified percentage of the producer’s commodity (“POP percentage”) and also in some cases additional cash fees. The two types of POP revenue contracts are described below:


•	In-Kind POP: We retain our POP percentage (non-cash consideration) and also any additional cash fees in exchange for providing the services. We recognize revenue for the non-cash consideration and cash fees at the time the services are performed.


•	Mixed POP: We purchase NGLs from the producer and retain a portion of the residue gas as non-cash consideration for services provided. We may also receive cash fees for such services. Under Topic 606, these agreements were determined

to be hybrid agreements which were partially supply agreements (for the NGLs we purchased) and customer agreements (for the services provided related to the product that was returned to the customer). Given that these are hybrid agreements, we split the cash and non-cash consideration between revenue and a reduction of costs based on the value of the service provided vs. the value of the supply received.

Payment for services under these contracts are typically due the month after the services have been performed.

The performance obligations with respect to our midstream segment’s contracts are to provide gathering, transportation and processing services, each of which would be completed on or about the same time, and each of which would be recognized on the same line item on the income statement, therefore identification of separate performance obligations would not impact the timing or geography of revenue recognition.

Certain contracts of our midstream segment include throughput commitments under which customers commit to purchasing a certain minimum volume of service over a specified time period. If such volume of service is not purchased by the customer, deficiency fees are billed to the customer. In some cases, the customer is allowed to apply any deficiency fees paid to future purchases of services. In such cases, we defer revenue recognition until the customer uses the deficiency fees for 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.

Our midstream segment also generates revenues from the sale of residue gas and NGLs at the tailgate of our processing facilities primarily to affiliates and some third-party customers.

NGL and refined products transportation and services revenue

Our NGL and refined products segment’s revenues are primarily derived from transportation, fractionation, blending, and storage of NGL and refined products as well as acquisition and marketing activities. Revenues are generated utilizing a complementary network of pipelines, storage and blending facilities, and strategic off-take locations that provide access to multiple NGL markets. Transportation, fractionation, and storage revenue is generated from fees charged to customers under a combination of firm and interruptible contracts. Firm contracts are in the form of take-or-pay arrangements where certain fees will be charged to customers regardless of the volume of service they request for any given period. Under interruptible contracts, customers are not required to pay any fixed minimum amounts, but are instead billed based on actual volume of service provided for any given period. Payment for services under these contracts are typically due the month after the services have been performed.

The performance obligation with respect to firm contracts is a promise to provide a single type of service (transportation, fractionation, blending, or storage) daily over the life of the contract, which is fundamentally a “stand-ready” service. While there can be multiple activities required to be performed, these activities are not separable because such activities in combination are required to successfully transfer the overall service for which the customer has contracted. The fixed consideration of the transaction price is allocated ratably over the life of the contract and revenue for the fixed consideration is recognized over time, because the customer simultaneously receives and consumes the benefit of this “stand-ready” service. Incremental fees associated with actual volume for each respective period are recognized as revenue in the period the incremental volume of service is performed.

Acquisition and marketing contracts are in most cases short-term agreements involving purchase and/or sale of NGLs and other related hydrocarbons at market rates. These contracts were not affected by ASC 606.

Crude oil transportation and services revenue

Our crude oil transportation and services segment revenues are primarily derived from providing transportation, terminalling and acquisition and marketing services to crude oil markets throughout the southwest, midwest and northeastern United States. Crude oil transportation revenue is generated from tariffs paid by shippers utilizing our transportation services and is generally recognized as the related transportation services are provided. Crude oil terminalling revenue is generated from fees paid by customers for storage and other associated services at the terminal. Crude oil acquisition and marketing revenue is generated from sale of crude oil acquired from a variety of suppliers to third parties. Payment for services under these contracts are typically due the month after the services have been performed.

Certain transportation and terminalling agreements are considered to be firm agreements, because they include fixed fee components that are charged regardless of the volume of crude oil transported by the customer or services provided at the

terminal. For these agreements, any fixed fees billed in excess of services provided are not recognized as revenue until the earlier of (i) the time at which the customer applies the fees against cost of service provided in a later period, or (ii) the customer becomes unable to apply the fees against cost of future service due to capacity constraints or contractual terms.

The performance obligation with respect to firm contracts is a promise to provide a single type of service (transportation or terminalling) daily over the life of the contract, which is fundamentally a “stand-ready” service. While there can be multiple activities required to be performed, these activities are not separable because such activities in combination are required to successfully transfer the overall service for which the customer has contracted. The fixed consideration of the transaction price is allocated ratably over the life of the contract and revenue for the fixed consideration is recognized over time, because the customer simultaneously receives and consumes the benefit of this “stand-ready” service. Incremental fees associated with actual volume for each respective period are recognized as revenue in the period the incremental volume of service is performed.

The performance obligation with respect to interruptible contracts is also a promise to provide a single type of service, but such promise is made on a case-by-case basis at the time the customer requests the service and/or product and we accept the customer’s request. Revenue is recognized for interruptible contracts at the time the services are performed.

Acquisition and marketing contracts are in most cases short-term agreements involving purchase and/or sale of crude oil at market rates. These contracts were not affected by ASC 606.

Sunoco LP’s fuel distribution and marketing revenue

Sunoco LP’s fuel distribution and marketing operations earn revenue from the following channels: sales to Dealers, sales to Distributors, Unbranded Wholesale Revenue, Commission Agent Revenue, Rental Income and Other Income. Motor fuel revenue consists primarily of the sale of motor fuel under supply agreements with third party customers and affiliates. Fuel supply contracts with Sunoco LP’s customers generally provide that Sunoco LP distribute motor fuel at a formula price based on published rates, volume-based profit margin, and other terms specific to the agreement. The customer is invoiced the agreed-upon price with most payment terms ranging less than 30 days. If the consideration promised in a contract includes a variable amount, Sunoco LP estimates the variable consideration amount and factors in such an estimate to determine the transaction price under the expected value method.

Revenue is recognized under the motor fuel contracts at the point in time the customer takes control of the fuel. At the time control is transferred to the customer the sale is considered final, because the agreements do not grant customers the right to return motor fuel. Under the new standard, to determine when control transfers to the customer, the shipping terms of the contract are assessed as shipping terms are considered a primary indicator of the transfer of control. For FOB shipping point terms, revenue is recognized at the time of shipment. The performance obligation with respect to the sale of goods is satisfied at the time of shipment since the customer gains control at this time under the terms. Shipping and/or handling costs that occur before the customer obtains control of the goods are deemed to be fulfillment activities and are accounted for as fulfillment costs. Once the goods are shipped, Sunoco LP is precluded from redirecting the shipment to another customer and revenue is recognized.

Commission agent revenue consists of sales from commission agent agreements between Sunoco LP and select operators. Sunoco LP supplies motor fuel to sites operated by commission agents and sells the fuel directly to the end customer. In commission agent arrangements, control of the product is transferred at the point in time when the goods are sold to the end customer. To reflect the transfer of control, Sunoco LP recognizes commission agent revenue at the point in time fuel is sold to the end customer.

Sunoco LP receives rental income from leased or subleased properties. Revenue from leasing arrangements for which Sunoco LP is the lessor are recognized ratably over the term of the underlying lease.

Sunoco LP’s all other revenue

Sunoco LP’s all other operations earn revenue from the following channels: Motor Fuel Sales, Rental Income and Other Income. Motor Fuel Sales consist of fuel sales to consumers at company-operated retail stores. Other income includes merchandise revenue that comprises the in-store merchandise and food service sales at company-operated retail stores, and other revenue that represents a variety of other services within Sunoco LP’s all other operations including credit card processing, car washes, lottery, automated teller machines, money orders, prepaid phone cards and wireless services. Revenue from all other operations is recognized when (or as) the performance obligations are satisfied (i.e. when the customer obtains control of the good or the service is provided).

USAC’s contract operations revenue

USAC’s revenue from contracted compression, station, gas treating and maintenance services is recognized ratably under its fixed-fee contracts over the term of the contract as services are provided to its customers. Initial contract terms typically range from six months to five years, however USAC usually continues to provide compression services at a specific location beyond the initial contract term, either through contract renewal or on a month-to-month or longer basis. USAC primarily enters into fixed-fee contracts whereby its customers are required to pay the monthly fee even during periods of limited or disrupted throughput. Services are generally billed monthly, one month in advance of the commencement of the service month, except for certain customers who are billed at the beginning of the service month, and payment is generally due 30 days after receipt of the invoice. Amounts invoiced in advance are recorded as deferred revenue until earned, at which time they are recognized as revenue. The amount of consideration USAC receives and revenue it recognizes is based upon the fixed fee rate stated in each service contract.

Variable consideration exists in select contracts when billing rates vary based on actual equipment availability or volume of total installed horsepower.

USAC’s contracts with customers may include multiple performance obligations. For such arrangements, USAC allocates revenues to each performance obligation based on its relative standalone service fee. USAC generally determine standalone service fees based on the service fees charged to customers or using expected cost plus margin.

The majority of USAC’s service performance obligations are satisfied over time as services are rendered at selected customer locations on a monthly basis and based upon specific performance criteria identified in the applicable contract. The monthly service for each location is substantially the same service month to month and is promised consecutively over the service contract term. USAC measures progress and performance of the service consistently using a straight-line, time-based method as each month passes, because its performance obligations are satisfied evenly over the contract term as the customer simultaneously receives and consumes the benefits provided by its service. If variable consideration exists, it is allocated to the distinct monthly service within the series to which such variable consideration relates. USAC has elected to apply the invoicing practical expedient to recognize revenue for such variable consideration, as the invoice corresponds directly to the value transferred to the customer based on its performance completed to date.

There are typically no material obligations for returns or refunds. USAC’s standard contracts do not usually include material non-cash consideration.

USAC’s retail parts and services revenue

USAC’s retail parts and service revenue is earned primarily on freight and crane charges that are directly reimbursable by USAC’s customers and maintenance work on units at its customers’ locations that are outside the scope of its core maintenance activities. Revenue from retail parts and services is recognized at the point in time the part is transferred or service is provided and control is transferred to the customer. At such time, the customer has the ability to direct the use of the benefits of such part or service after USAC has performed its services. USAC bills upon completion of the service or transfer of the parts, and payment is generally due 30 days after receipt of the invoice. The amount of consideration USAC receives and revenue it recognizes is based upon the invoice amount. There are typically no material obligations for returns, refunds, or warranties. USAC’s standard contracts do not usually include material variable or non-cash consideration.

All other revenue

Our all other segment primarily includes our compression equipment business which provides full-service compression design and manufacturing services for the oil and gas industry. It also includes the management of coal and natural resources properties and the related collection of royalties. We also earn revenues from other land management activities, such as selling standing timber, leasing coal-related infrastructure facilities, and collecting oil and gas royalties. These operations also include end-user coal handling facilities. There were no material changes to the manner in which revenues within this segment are recorded under the new standard.

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 fee for a right to use our assets, but allows 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, January 1, 2018	$	221
Additions	765
Revenue recognized	(592		)
Balance, December 31, 2018	394
Additions	664
Revenue recognized	(681		)
Balance, December 31, 2019	$	377

The balances of receivables from contracts with customers listed in the table below include both current trade receivables and long-term receivables, net of allowance for doubtful accounts. The allowance for receivables represents Sunoco LP’s best estimate of the probable losses associated with potential customer defaults. Sunoco LP determines the allowance based on historical experience and on a specific identification basis.

The balances of Sunoco LP’s contract assets and contract liabilities as of December 31, 2019 and 2018 were as follows:



	December 31, 2019		December 31, 2018
Contract Balances
Contract asset	$	117	$	75
Accounts receivable from contracts with customers	366		347
Contract liability	—		1

Costs to Obtain or Fulfill a Contract

Sunoco LP recognizes an asset from the costs incurred to obtain a contract (e.g. sales commissions) only if it expects to recover those costs. On the other hand, the costs to fulfill a contract are capitalized if the costs are specifically identifiable to a contract, would result in enhancing resources that will be used in satisfying performance obligations in future and are expected to be recovered. These capitalized costs are recorded as a part of other current assets and other non-current assets and are amortized on a systematic basis consistent with the pattern of transfer of the goods or services to which such costs relate. The amount of amortization expense that Sunoco LP recognized for the years ended December 31, 2019 and 2018 was $17 million and $14 million, respectively. Sunoco LP has also made a policy election of expensing the costs to obtain a contract, as and when they are incurred, in cases where the expected amortization period is one year or less.

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 contracts, only the fixed component of the contracts are included in the table below.

Sunoco LP distributes fuel under long-term contracts to branded distributors, branded and unbranded third party dealers, and branded and unbranded retail fuel outlets. Sunoco LP branded supply contracts with distributors generally have both time and volume commitments that establish contract duration. These contracts have an initial term of approximately nine years, with an estimated, volume-weighted term remaining of approximately four years.

As part of the asset purchase agreement with 7-Eleven, Sunoco LP and 7-Eleven and SEI Fuel (collectively, the “Distributor”) have entered into a 15-year take-or-pay fuel supply agreement in which the Distributor is required to purchase a volume of fuel that provides Sunoco LP a minimum amount of gross profit annually. Sunoco LP expects to recognize this revenue in accordance with the contract as Sunoco LP transfers control of the product to the customer. However, in case of annual shortfall Sunoco LP will recognize the amount payable by the Distributor at the sooner of the time at which the Distributor makes up the shortfall or becomes contractually or operationally unable to do so. The transaction price of the contract is variable in nature, fluctuating based on market conditions. The Partnership has elected to take the practical expedient not to estimate the amount of variable consideration allocated to wholly unsatisfied performance obligations.

In some contractual arrangements, Sunoco LP grants dealers a franchise license to operate Sunoco LP’s retail stores over the life of a franchise agreement. In return for the grant of the retail store license, the dealer makes a one-time nonrefundable franchise fee payment to Sunoco LP plus sales based royalties payable to Sunoco LP at a contractual rate during the period of the franchise agreement. Under the requirements of ASC Topic 606, the franchise license is deemed to be a symbolic license for which recognition of revenue over time is the most appropriate measure of progress toward complete satisfaction of the performance obligation. Revenue from this symbolic license is recognized evenly over the life of the franchise agreement.

As of December 31, 2019, the aggregate amount of transaction price allocated to unsatisfied (or partially satisfied) performance obligations is $43.59 billion and the Partnership expects to recognize this amount as revenue within the time bands illustrated below:



	Years Ending December 31,
	2020		2021		2022		Thereafter		Total
Revenue expected to be recognized on contracts with customers existing as of December 31, 2019	$	6,232	$	5,300	$	4,899	$	27,158	$	43,589

Practical Expedients Utilized by the Partnership

The Partnership elected the following practical expedients in accordance with Topic 606:

•

Right to invoice: The Partnership elected to utilize an output method to recognize revenue that is based on the amount to which the Partnership has a right to invoice a customer for services performed to date, if that amount corresponds directly with the value provided to the customer for the related performance or its obligation completed to date. As such, the Partnership recognized revenue in the amount to which it had the right to invoice customers.


•	Significant financing component: The Partnership elected not to adjust the promised amount of consideration for the effects of significant financing component if the Partnership expects, at contract inception, that the period between the transfer of a promised good or service to a customer and when the customer pays for that good or service will be one year or less.


•	Unearned variable consideration: The Partnership elected to only disclose the unearned fixed consideration associated with unsatisfied performance obligations related to our various customer contracts which contain both fixed and variable components.

•

Incremental costs of obtaining a contract: The Partnership generally expenses sales commissions when incurred because the amortization period would have been less than one year. We record these costs within general and administrative expenses. The Partnership elected to expense the incremental costs of obtaining a contract when the amortization period for such contracts would have been one year or less.


•	Shipping and handling costs: The Partnership elected to account for shipping and handling activities that occur after the customer has obtained control of a good as fulfillment activities (i.e., an expense) rather than as a promised service.


•	Measurement of transaction price: The Partnership has elected to exclude from the measurement of transaction price all taxes assessed by a governmental authority that are both imposed on and concurrent with a specific revenue-producing transaction and collected by the Partnership from a customer (i.e., sales tax, value added tax, etc.).

•

Variable consideration of wholly unsatisfied performance obligations: The Partnership has elected to exclude the estimate of variable consideration to the allocation of wholly unsatisfied performance obligations.

Lease Accounting (Notes)

12 Months Ended

Dec. 31, 2019

Leases [Abstract]

Lessee, Operating Leases [Text Block]

LEASE ACCOUNTING:

Lessee Accounting

The Partnership leases terminal facilities, tank cars, office space, land and equipment under non-cancelable operating leases whose initial terms are typically five to 15 years, with some real estate leases having terms of 40 years or more, along with options that permit renewals for additional periods. At the inception of each, we determine if the arrangement is a lease or contains an embedded lease and review the facts and circumstances of the arrangement to classify lease assets as operating or finance leases under Topic 842. The Partnership has elected not to record any leases with terms of 12 months or less on the balance sheet.

At present, the majority of the Partnership’s active leases are classified as operating in accordance with Topic 842. Balances related to operating leases are included in operating lease ROU assets, accrued and other current liabilities, operating lease current liabilities and non-current operating lease liabilities in our consolidated balance sheets. Finance leases represent a small portion of the active lease agreements and are included in finance lease ROU assets, current maturities of long-term debt and long-term debt, less current maturities in our consolidated balance sheets. The ROU assets represent the Partnership’s right to use an underlying asset for the lease term and lease liabilities represent the obligation of the Partnership to make minimum lease payments arising from the lease for the duration of the lease term.

Most leases include one or more options to renew, with renewal terms that can extend the lease term from one to 20 years or greater. The exercise of lease renewal options is typically at the sole discretion of the Partnership and lease extensions are evaluated on a lease-by-lease basis. Leases containing early termination clauses typically require the agreement of both parties to the lease. At the inception of a lease, all renewal options reasonably certain to be exercised are considered when determining the lease term. Presently, the Partnership does not have leases that include options to purchase or automatic transfer of ownership of the leased property to the Partnership. The depreciable life of lease assets and leasehold improvements are limited by the expected lease term.

To determine the present value of future minimum lease payments, we use the implicit rate when readily determinable. Presently, because many of our leases do not provide an implicit rate, the Partnership applies its incremental borrowing rate based on the information available at the lease commencement date to determine the present value of minimum lease payments. The operating and finance lease ROU assets include any lease payments made and exclude lease incentives.

Minimum rent payments are expensed on a straight-line basis over the term of the lease. In addition, some leases require additional contingent or variable lease payments, which are based on the factors specific to the individual agreement. Variable lease payments the Partnership is typically responsible for include payment of real estate taxes, maintenance expenses and insurance.

For short-term leases (leases that have term of twelve months or less upon commencement), lease payments are recognized on a straight-line basis and no ROU assets are recorded.

The components of operating and finance lease amounts recognized in the accompanying consolidated balance sheet as of December 31, 2019 were as follows:



	December 31, 2019
Operating leases:
Lease right-of-use assets, net	$	935
Operating lease current liabilities	60
Accrued and other current liabilities	1
Non-current operating lease liabilities	901
Finance leases:
Property, plant and equipment, net	$	1
Lease right-of-use assets, net	29
Accrued and other current liabilities	1
Current maturities of long-term debt	6
Long-term debt, less current maturities	26
Other non-current liabilities	2

The components of lease expense for the year ended December 31, 2019 were as follows:



	Income Statement Location	Year Ended December 31, 2019
Operating lease costs:
Operating lease cost	Cost of goods sold	$	28
Operating lease cost	Operating expenses	73
Operating lease cost	Selling, general and administrative	16
Total operating lease costs		117
Finance lease costs:
Amortization of lease assets	Depreciation, depletion and amortization	6
Interest on lease liabilities	Interest expense, net of capitalized interest	1
Total finance lease costs		7
Short-term lease cost	Operating expenses	42
Variable lease cost	Operating expenses	17
Lease costs, gross		183
Less: Sublease income	Other revenue	47
Lease costs, net		$	136

The weighted average remaining lease terms and weighted average discount rates as of December 31, 2019 were as follows:



	December 31, 2019
Weighted-average remaining lease term (years):
Operating leases	24
Finance leases	5
Weighted-average discount rate (%):
Operating leases	5	%
Finance leases	5	%

Cash flows and non-cash activity related to leases for the year ended December 31, 2019 were as follows:



	Year Ended December 31, 2019
Operating cash flows from operating leases	$	(159	)
Lease assets obtained in exchange for new finance lease liabilities	28
Lease assets obtained in exchange for new operating lease liabilities	40

Maturities of lease liabilities as of December 31, 2019 are as follows:



	Operating leases		Finance leases		Total
2020	$	104	$	8	$	112
2021	96		8		104
2022	83		8		91
2023	77		7		84
2024	74		4		78
Thereafter	1,342		5		1,347
Total lease payments	1,776		40		1,816
Less: present value discount	815		5		820
Present value of lease liabilities	$	961	$	35	$	996

Lessor Accounting

The Partnership leases or subleases a portion of its real estate portfolio to third-party companies as a stable source of long-term revenue. Our lessor and sublease portfolio consists mainly of operating leases with convenience store operators. At this time, most lessor agreements contain five-year terms with renewal options to extend and early termination options based on established terms specific to the individual agreement.

Rental income included in other revenue in our consolidated statement of operations for the year ended December 31, 2019 was $149 million.

Future minimum operating lease payments receivable as of December 31, 2019 are as follows:



	Lease Payments
2020	$	138
2021	112
2022	75
2023	20
2024	15
Thereafter	12
Total undiscounted cash flows	$	372

Derivative Assets And Liabilities

12 Months Ended

Dec. 31, 2019

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 on our interstate transportation and storage segment. These contracts are not designated as hedges for accounting purposes.

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

We 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:



	December 31, 2019			December 31, 2018
	Notional Volume		Maturity	Notional Volume		Maturity
Mark-to-Market Derivatives
(Trading)
Natural Gas (BBtu):
Fixed Swaps/Futures	1,483		2020	468		2019
Basis Swaps IFERC/NYMEX⁽¹⁾	(35,208	)	2020-2024	16,845		2019-2020
Options – Puts	—		—	10,000		2019
Power (Megawatt):
Forwards	3,213,450		2020-2029	3,141,520		2019
Futures	(353,527	)	2020	56,656		2019-2021
Options – Puts	51,615		2020	18,400		2019
Options – Calls	(2,704,330	)	2020-2021	284,800		2019
(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(18,923	)	2020-2022	(30,228	)	2019-2021
Swing Swaps IFERC	(9,265	)	2020	54,158		2019-2020
Fixed Swaps/Futures	(3,085	)	2020-2021	(1,068	)	2019-2021
Forward Physical Contracts	(13,364	)	2020-2021	(123,254	)	2019-2020
NGL (MBbls) – Forwards/Swaps	(1,300	)	2020-2021	(2,135	)	2019
Crude (MBbls) – Forwards/Swaps	4,465		2020	20,888		2019
Refined Products (MBbls) – Futures	(2,473	)	2020-2021	(1,403	)	2019
Corn (thousand bushels)	(1,210	)	2020	(1,920	)	2019
Fair Value Hedging Derivatives
(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(31,780	)	2020	(17,445	)	2019
Fixed Swaps/Futures	(31,780	)	2020	(17,445	)	2019
Hedged Item – Inventory	31,780		2020	17,445		2019


⁽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
Term	Type ⁽¹⁾	December 31, 2019		December 31, 2018
March 2019	Pay a floating rate and receive a fixed rate of 1.42%	$	—	$	300
July 2019 ⁽²⁾	Forward-starting to pay a fixed rate of 3.56% and receive a floating rate	—		400
July 2020 ⁽²⁾⁽³⁾	Forward-starting to pay a fixed rate of 3.52% and receive a floating rate	400		400
July 2021 ⁽²⁾	Forward-starting to pay a fixed rate of 3.55% and receive a floating rate	400		400
July 2022 ⁽²⁾	Forward-starting to pay a fixed rate of 3.80% and receive a floating rate	400		—


⁽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 2020 interest rate swaps were terminated in January 2020.

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 net income or other comprehensive income.

Derivative Summary

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



	Fair Value of Derivative Instruments
	Asset Derivatives				Liability Derivatives
	December 31, 2019		December 31, 2018		December 31, 2019			December 31, 2018
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	24	$	—	$	—		$	(13	)
	24		—		—			(13		)
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	319		402		(350		)	(397		)
Commodity derivatives	41		158		(39		)	(173		)
Interest rate derivatives	—		—		(399		)	(163		)
	360		560		(788		)	(733		)
Total derivatives	$	384	$	560	$	(788	)	$	(746	)

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	December 31, 2019			December 31, 2018			December 31, 2019			December 31, 2018
Derivatives without offsetting agreements	Derivative liabilities	$	—		$	—		$	(399	)	$	(163	)
Derivatives in offsetting agreements:
OTC contracts	Derivative assets (liabilities)	41			158			(39		)	(173		)
Broker cleared derivative contracts	Other current assets (liabilities)	343			402			(350		)	(410		)
		384			560			(788		)	(746		)
Offsetting agreements:
Counterparty netting	Derivative assets (liabilities)	(18		)	(47		)	18			47
Counterparty netting	Other current assets (liabilities)	(318		)	(397		)	318			397
Total net derivatives		$	48		$	116		$	(452	)	$	(302	)

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



	Location of Gain (Loss) Recognized in Income on Derivatives	Amount of Gain (Loss) Recognized in Income Representing Hedge Ineffectiveness and Amount Excluded from the Assessment of Effectiveness
		Years Ended December 31,
		2019		2018			2017
Derivatives in fair value hedging relationships (including hedged item):
Commodity derivatives	Cost of products sold	$	—	$	(3	)	$	26



	Location of Gain (Loss) Recognized in Income on Derivatives	Amount of Gain (Loss) Recognized in Income on Derivatives
		Years Ended December 31,
		2019			2018			2017
Derivatives not designated as hedging instruments:
Commodity derivatives – Trading	Revenues	$	(3	)	$	—		$	—
Commodity derivatives – Trading	Cost of products sold	21			32			31
Commodity derivatives – Non-trading	Cost of products sold	(78		)	(102		)	5
Interest rate derivatives	Gains (losses) on interest rate derivatives	(241		)	47			(37		)
Embedded derivatives	Other, net	—			—			1
Total		$	(301	)	$	(23	)	$	—

Retirement Benefits

12 Months Ended

Dec. 31, 2019

Retirement Benefits [Abstract]

Retirement Benefits

RETIREMENT BENEFITS:

Savings and Profit Sharing Plans

We and our subsidiaries sponsor defined contribution savings and profit sharing plans, which collectively cover virtually all eligible employees, including those of ETO, Lake Charles LNG, Sunoco LP and USAC. Employer matching contributions are calculated using a formula based on employee contributions. We and our subsidiaries made matching contributions of $66 million, $62 million and $59 million to these 401(k) savings plans for the years ended December 31, 2019, 2018 and 2017, respectively.

Pension and Other Postretirement Benefit Plans

Panhandle

Postretirement benefits expense for the years ended December 31, 2019, 2018, and 2017 reflect the impact of changes Panhandle or its affiliates adopted as of September 30, 2013, to modify its retiree medical benefits program, effective January 1, 2014. The modification placed all eligible retirees on a common medical benefit platform, subject to limits on Panhandle’s annual contribution toward eligible retirees’ medical premiums. Prior to January 1, 2013, affiliates of Panhandle offered postretirement health care and life insurance benefit plans (other postretirement plans) that covered substantially all employees. Effective January 1, 2013, participation in the plan was frozen and medical benefits were no longer offered to non-union employees. Effective January 1, 2014, retiree medical benefits were no longer offered to union employees.

Effective January 1, 2018, the plan was amended to extend coverage to a closed group of former employees based on certain criteria.

ETC Sunoco

ETC Sunoco has a plan which provides health care benefits for substantially all of its current retirees. The cost to provide the postretirement benefit plan is shared by ETC Sunoco and its retirees. Access to postretirement medical benefits was phased out or eliminated for all employees retiring after July 1, 2010. In March, 2012, ETC Sunoco established a trust for its postretirement benefit liabilities. ETC Sunoco made a tax-deductible contribution of approximately $200 million to the trust. The funding of the trust eliminated substantially all of ETC Sunoco future exposure to variances between actual results and assumptions used to estimate retiree medical plan obligations.

SemGroup

SemGroup sponsors two defined benefit pension plans and a supplemental defined benefit pension plan (collectively, the “Semgroup Plans”) for certain employees. The Semgroup Plans are closed to new participants and do not accrue any additional benefits.

Obligations and Funded Status

Pension and other postretirement benefit liabilities are accrued on an actuarial basis during the years an employee provides services.

The following table contains information at the dates indicated about the obligations and funded status of pension and other postretirement plans on a combined basis:



	December 31, 2019									December 31, 2018
	Pension Benefits									Pension Benefits
	Funded Plans			Unfunded Plans			Other Postretirement Benefits			Funded Plans		Unfunded Plans			Other Postretirement Benefits
Change in benefit obligation:
Benefit obligation at beginning of period	$	1		$	37		$	198		$	1	$	47		$	156
Service cost	—			—			1			—		—			1
Interest cost	2			1			7			—		1			5
Amendments	—			—			—			—		—			60
Benefits paid, net	(1		)	(7		)	(16		)	—		(7		)	(17		)
Actuarial (gain) loss and other	4			—			18			—		(4		)	(7		)
Settlements	(4		)	—			—			—		—			—
SemGroup Acquisition	50			3			—			—		—			—
Benefit obligation at end of period	52			34			208			1		37			198

Change in plan assets:
Fair value of plan assets at beginning of period	1			—			241			1		—			257
Return on plan assets and other	6			—			35			—		—			(8		)
Employer contributions	1			—			10			—		—			9
Benefits paid, net	(1		)	—			(16		)	—		—			(17		)
Settlements	(4		)	—			—			—		—			—
SemGroup Acquisition	40			—			—			—		—			—
Fair value of plan assets at end of period	43			—			270			1		—			241

Amount underfunded (overfunded) at end of period	$	9		$	34		$	(62	)	$	—	$	37		$	(43	)

Amounts recognized in the consolidated balance sheets consist of:
Non-current assets	$	—		$	—		$	88		$	—	$	—		$	68
Current liabilities	—			(5		)	(2		)	—		(6		)	(2		)
Non-current liabilities	(9		)	(29		)	(24		)	—		(31		)	(23		)
	$	(9	)	$	(34	)	$	62		$	—	$	(37	)	$	43

Amounts recognized in accumulated other comprehensive income (loss) (pre-tax basis) consist of:
Net actuarial gain (loss)	$	—		$	1		$	(5	)	$	—	$	1		$	(7	)
Prior service cost	—			—			40			—		—			66
	$	—		$	1		$	35		$	—	$	1		$	59

The following table summarizes information at the dates indicated for plans with an accumulated benefit obligation in excess of plan assets:



	December 31, 2019					December 31, 2018
	Pension Benefits					Pension Benefits
	Funded Plans		Unfunded Plans		Other Postretirement Benefits	Funded Plans		Unfunded Plans		Other Postretirement Benefits
Projected benefit obligation	$	51	$	34	N/A	$	—	$	37	N/A
Accumulated benefit obligation	52		34		208	1		37		198
Fair value of plan assets	43		—		270	1		—		241

Components of Net Periodic Benefit Cost



	December 31, 2019						December 31, 2018
	Pension Benefits			Other Postretirement Benefits			Pension Benefits		Other Postretirement Benefits
Net periodic benefit cost:
Service cost	$	—		$	1		$	—	$	1
Interest cost	3			7			1		5
Expected return on plan assets	(2		)	(10		)	—		(10		)
Prior service cost amortization	—			26			—		16
Net periodic benefit cost	$	1		$	24		$	1	$	12

Assumptions

The weighted-average assumptions used in determining benefit obligations at the dates indicated are shown in the table below:



	December 31, 2019				December 31, 2018
	Pension Benefits		Other Postretirement Benefits		Pension Benefits		Other Postretirement Benefits
Discount rate	4.00	%	2.71	%	4.02	%	3.40	%
Rate of compensation increase	—		—		N/A		N/A

The weighted-average assumptions used in determining net periodic benefit cost for the periods presented are shown in the table below:



	December 31, 2019				December 31, 2018
	Pension Benefits		Other Postretirement Benefits		Pension Benefits		Other Postretirement Benefits
Discount rate	3.33	%	3.76	%	3.52	%	3.51	%
Expected return on assets:
Tax exempt accounts	3.37	%	7.00	%	3.26	%	6.63	%
Taxable accounts	—		4.75	%	N/A		4.50	%
Rate of compensation increase	—		—		N/A		N/A

The long-term expected rate of return on plan assets was estimated based on a variety of factors including the historical investment return achieved over a long-term period, the targeted allocation of plan assets and expectations concerning future returns in the marketplace for both equity and fixed income securities. Current market factors such as inflation and interest rates are evaluated before long-term market assumptions are determined. Peer data and historical returns are reviewed to ensure reasonableness and appropriateness.

The assumed health care cost trend weighted-average rates used to measure the expected cost of benefits covered by the plans are shown in the table below:



	December 31,
	2019		2018
Health care cost trend rate	7.25	%	7.15	%
Rate to which the cost trend is assumed to decline (the ultimate trend rate)	4.83	%	4.82	%
Year that the rate reaches the ultimate trend rate	2026		2024

Changes in the health care cost trend rate assumptions are not expected to have a significant impact on postretirement benefits.

Plan Assets

For the Panhandle plans, the overall investment strategy is to maintain an appropriate balance of actively managed investments with the objective of optimizing longer-term returns while maintaining a high standard of portfolio quality and achieving proper diversification. To achieve diversity within its other postretirement plan asset portfolio, Panhandle has targeted the following asset allocations: equity of 25% to 35%, fixed income of 65% to 75%.

The investment strategy of ETC Sunoco funded defined benefit plans is to achieve consistent positive returns, after adjusting for inflation, and to maximize long-term total return within prudent levels of risk through a combination of income and capital appreciation. The objective of this strategy is to reduce the volatility of investment returns and maintain a sufficient funded status of the plans. In anticipation of the pension plan termination, ETC Sunoco targeted the asset allocations to a more stable position by investing in growth assets and liability hedging assets.

The fair value of the pension plan assets by asset category at the dates indicated is as follows:



			Fair Value Measurements at December 31, 2019
	Fair Value Total		Level 1		Level 2		Level 3
Asset Category:
Cash and cash equivalents	$	1	$	1	$	—	$	—
Mutual funds ⁽¹⁾	19		19		—		—
Fixed income securities	23		—		23		—
Total	$	43	$	20	$	23	$	—


⁽¹⁾	Comprised of approximately 100% equities as of December 31, 2019.



			Fair Value Measurements at December 31, 2018
	Fair Value Total		Level 1		Level 2		Level 3
Mutual funds ⁽¹⁾	$	1	$	1	$	—	$	—


⁽¹⁾	Comprised of approximately 100% equities as of December 31, 2018.

The fair value of other postretirement plan assets by asset category at the dates indicated is as follows:



			Fair Value Measurements at December 31, 2019
	Fair Value Total		Level 1		Level 2		Level 3
Asset category:
Cash and cash equivalents	$	14	$	14	$	—	$	—
Mutual funds⁽¹⁾	177		177		—		—
Fixed income securities	79		—		79		—
Total	$	270	$	191	$	79	$	—


⁽¹⁾	Primarily comprised of approximately 59% equities, 40% fixed income securities and 1% cash as of December 31, 2019.



			Fair Value Measurements at December 31, 2018
	Fair Value Total		Level 1		Level 2		Level 3
Asset category:
Cash and cash equivalents	$	20	$	20	$	—	$	—
Mutual funds⁽¹⁾	144		144		—		—
Fixed income securities	77		—		77		—
Total	$	241	$	164	$	77	$	—


⁽¹⁾	Primarily comprised of approximately 53% equities, 46% fixed income securities and 1% cash as of December 31, 2018.

The Level 1 plan assets are valued based on active market quotes. The Level 2 plan assets are valued based on the net asset value per share (or its equivalent) of the investments, which was not determinable through publicly published sources but was calculated consistent with authoritative accounting guidelines.

Contributions

We expect to contribute $7 million to pension plans and $8 million to other postretirement plans in 2020. The cost of the plans are funded in accordance with federal regulations, not to exceed the amounts deductible for income tax purposes.

Benefit Payments

Panhandle and ETC Sunoco’s estimate of expected benefit payments, which reflect expected future service, as appropriate, in each of the next five years and in the aggregate for the five years thereafter are shown in the table below:



Years	Pension Benefits - Unfunded Plans ⁽¹⁾		Other Postretirement Benefits (Gross, Before Medicare Part D)
2020	$	7	$	20
2021	8		20
2022	8		19
2023	8		18
2024	7		15
2025 – 2029	22		67

⁽¹⁾ Expected benefit payments of funded pension plans are less than $1 million for the next ten years.

The Medicare Prescription Drug Act provides for a prescription drug benefit under Medicare (“Medicare Part D”) as well as a federal subsidy to sponsors of retiree health care benefit plans that provide a prescription drug benefit that is at least actuarially equivalent to Medicare Part D.

Panhandle does not expect to receive any Medicare Part D subsidies in any future periods.

Related Party Transactions

12 Months Ended

Dec. 31, 2019

Related Party Transactions

RELATED PARTY TRANSACTIONS:

In June 2017, the Partnership acquired all of the publicly held PennTex common units through a tender offer and exercise of a limited call right, as further discussed in Note 8.

ET previously paid ETO to provide services on its behalf and on behalf of other subsidiaries of ET, which included the reimbursement of various operating and general and administrative expenses incurred by ETO on behalf of ET and its subsidiaries. These agreements expired in 2016.

The Partnership also has related party transactions with several of its equity method investees. In addition to commercial transactions, these transactions include the provision of certain management services and leases of certain assets.

The following table summarizes the revenues from related companies on our consolidated statements of operations:



	Years Ended December 31,
	2019		2018		2017
Affiliated revenues	$	492	$	431	$	303

The following table summarizes the related company accounts receivable and accounts payable balances on our consolidated balance sheets:



	December 31,
	2019		2018
Accounts receivable from related companies:
FGT	$	50	$	25
Phillips 66	36		42
Traverse Rover LLC	42		—
Other	31		44
Total accounts receivable from related companies	$	159	$	111

As of December 31, 2019 and 2018, accounts payable with related companies in the Partnership’s consolidated balance sheets totaled $31 million and $59 million, respectively.

Reportable Segments

12 Months Ended

Dec. 31, 2019

Reportable Segments [Abstract]

Reportable Segments

REPORTABLE SEGMENTS:

Our reportable segments currently reflect the following segments, which conduct their business primarily in the United States:

•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.

The investment in USAC segment reflects the results of USAC beginning April 2018, the date that the Partnership obtained control of USAC.

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.

We report Segment Adjusted EBITDA as a measure of segment performance. We define Segment 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. Segment 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:



	Years Ended December 31,
	2019			2018			2017
Revenues:
Intrastate transportation and storage:
Revenues from external customers	$	2,749		$	3,428		$	2,891
Intersegment revenues	350			309			192
	3,099			3,737			3,083
Interstate transportation and storage:
Revenues from external customers	1,941			1,664			1,112
Intersegment revenues	22			18			19
	1,963			1,682			1,131
Midstream:
Revenues from external customers	2,280			2,090			2,510
Intersegment revenues	3,751			5,432			4,433
	6,031			7,522			6,943
NGL and refined products transportation and services:
Revenues from external customers	9,920			10,119			7,885
Intersegment revenues	1,721			1,004			763
	11,641			11,123			8,648
Crude oil transportation and services:
Revenues from external customers	18,447			17,236			11,672
Intersegment revenues	—			96			31
	18,447			17,332			11,703
Investment in Sunoco LP:
Revenues from external customers	16,590			16,982			11,713
Intersegment revenues	6			12			10
	16,596			16,994			11,723
Investment in USAC:
Revenues from external customers	678			495			—
Intersegment revenues	20			13			—
	698			508			—
All other:
Revenues from external customers	1,608			2,073			2,740
Intersegment revenues	81			155			161
	1,689			2,228			2,901
Eliminations	(5,951		)	(7,039		)	(5,609		)
Total revenues	$	54,213		$	54,087		$	40,523



	Years Ended December 31,
	2019			2018			2017
Cost of products sold:
Intrastate transportation and storage	$	1,909		$	2,665		$	2,327
Midstream	3,577			5,145			4,761
NGL and refined products transportation and services	8,393			8,462			6,508
Crude oil transportation and services	14,758			14,439			9,826
Investment in Sunoco LP	15,380			15,872			10,615
Investment in USAC	91			67			—
All other	1,504			2,006			2,509
Eliminations	(5,885		)	(6,998		)	(5,580		)
Total cost of products sold	$	39,727		$	41,658		$	30,966



	Years Ended December 31,
	2019		2018		2017
Depreciation, depletion and amortization:
Intrastate transportation and storage	$	184	$	169	$	147
Interstate transportation and storage	387		334		254
Midstream	1,066		1,006		954
NGL and refined products transportation and services	613		466		401
Crude oil transportation and services	437		445		402
Investment in Sunoco LP	181		167		169
Investment in USAC	231		169		—
All other	48		103		227
Total depreciation, depletion and amortization	$	3,147	$	2,859	$	2,554



	Years Ended December 31,
	2019			2018		2017
Equity in earnings (losses) of unconsolidated affiliates:
Intrastate transportation and storage	$	18		$	19	$	(156	)
Interstate transportation and storage	222			227		236
Midstream	20			26		20
NGL and refined products transportation and services	53			64		33
Crude oil transportation and services	(1		)	6		4
All other	(10		)	2		7
Total equity in earnings of unconsolidated affiliates	$	302		$	344	$	144



	Years Ended December 31,
	2019			2018			2017
Segment Adjusted EBITDA:
Intrastate transportation and storage	$	999		$	927		$	626
Interstate transportation and storage	1,792			1,680			1,274
Midstream	1,602			1,627			1,481
NGL and refined products transportation and services	2,666			1,979			1,641
Crude oil transportation and services	2,972			2,330			1,379
Investment in Sunoco LP	665			638			732
Investment in USAC	420			289			—
All Other	98			40			187
Total Segment Adjusted EBITDA	11,214			9,510			7,320
Depreciation, depletion and amortization	(3,147		)	(2,859		)	(2,554		)
Interest expense, net of interest capitalized	(2,331		)	(2,055		)	(1,922		)
Impairment losses	(74		)	(431		)	(1,039		)
Gains (losses) on interest rate derivatives	(241		)	47			(37		)
Non-cash compensation expense	(113		)	(105		)	(99		)
Unrealized gains (losses) on commodity risk management activities	(5		)	(11		)	59
Inventory valuation adjustments	79			(85		)	24
Losses on extinguishments of debt	(18		)	(112		)	(89		)
Adjusted EBITDA related to unconsolidated affiliates	(626		)	(655		)	(716		)
Equity in earnings of unconsolidated affiliates	302			344			144
Impairment of investments in unconsolidated affiliates	—			—			(313		)
Adjusted EBITDA related to discontinued operations	—			25			(223		)
Other, net	54			21			155
Income from continuing operations before income tax (expense) benefit	5,094			3,634			710
Income tax (expense) benefit from continuing operations	(195		)	(4		)	1,833
Income from continuing operations	4,899			3,630			2,543
Loss from discontinued operations, net of income taxes	—			(265		)	(177		)
Net income	$	4,899		$	3,365		$	2,366



	December 31,
	2019		2018		2017
Segment assets:
Intrastate transportation and storage	$	6,648	$	6,365	$	5,020
Interstate transportation and storage	18,111		15,081		15,316
Midstream	20,332		19,745		20,004
NGL and refined products transportation and services	19,145		18,267		17,600
Crude oil transportation and services	22,840		18,022		17,730
Investment in Sunoco LP	5,438		4,879		8,344
Investment in USAC	3,730		3,775		—
All other and eliminations	2,636		2,112		2,232
Total segment assets	$	98,880	$	88,246	$	86,246



	Years Ended December 31,
	2019		2018		2017
Additions to property, plant and equipment ⁽¹⁾:
Intrastate transportation and storage	$	124	$	344	$	175
Interstate transportation and storage	375		812		728
Midstream	827		1,161		1,308
NGL and refined products transportation and services	2,976		2,381		2,971
Crude oil transportation and services	403		474		453
Investment in Sunoco LP	148		103		103
Investment in USAC	200		205		—
All other	215		150		268
Total additions to property, plant and equipment ⁽¹⁾	$	5,268	$	5,630	$	6,006


⁽¹⁾	Excluding acquisitions, net of contributions in aid of construction costs (capital expenditures related to the Partnership’s proportionate ownership on an accrual basis).



	December 31,
	2019		2018		2017
Advances to and investments in affiliates:
Intrastate transportation and storage	$	88	$	83	$	85
Interstate transportation and storage	2,524		2,070		2,118
Midstream	112		124		126
NGL and refined products transportation and services	461		243		234
Crude oil transportation and services	242		28		22
All other	33		94		120
Total advances to and investments in affiliates	$	3,460	$	2,642	$	2,705

Quarterly Financial Data (Unaudited)

12 Months Ended

Dec. 31, 2019

Quarterly Financial Information Disclosure [Abstract]

Quarterly Financial Data (Unaudited)

QUARTERLY FINANCIAL DATA (UNAUDITED):

Summarized unaudited quarterly financial data is presented below. Earnings per unit are computed on a stand-alone basis for each quarter and total year.



	Quarters Ended
	March 31		June 30		September 30		December 31		Total Year
2019:
Revenues	$	13,121	$	13,877	$	13,495	$	13,720	$	54,213
Operating income	1,927		1,819		1,830		1,701		7,277
Net income	1,180		1,208		1,161		1,350		4,899
Limited Partners’ interest in net income	869		877		831		1,011		3,588
Income from continuing operations per limited partner unit:
Basic	$	0.33	$	0.33	$	0.32	$	0.38	$	1.37
Diluted	$	0.33	$	0.33	$	0.32	$	0.38	$	1.36
Net income per limited partner unit:
Basic	$	0.33	$	0.33	$	0.32	$	0.38	$	1.37
Diluted	$	0.33	$	0.33	$	0.32	$	0.38	$	1.36



	Quarters Ended
	March 31		June 30		September 30		December 31		Total Year
2018:
Revenues	$	11,882	$	14,118	$	14,514	$	13,573	$	54,087
Operating income	1,100		1,126		1,703		1,419		5,348
Income from continuing operations	726		659		1,393		852		3,630
Net income	489		633		1,391		852		3,365
Limited Partners’ interest in net income	341		330		370		617		1,658
Income from continuing operations per limited partner unit:
Basic	$	0.32	$	0.30	$	0.32	$	0.26	$	1.17
Diluted	$	0.32	$	0.30	$	0.32	$	0.26	$	1.16
Net income per limited partner unit:
Basic	$	0.31	$	0.30	$	0.32	$	0.26	$	1.16
Diluted	$	0.31	$	0.30	$	0.32	$	0.26	$	1.15

Operations And Organization Operations and Organization (Policies)

12 Months Ended

Dec. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Accounting, Policy [Policy Text Block]

The consolidated financial statements of Energy Transfer LP presented herein for the years ended December 31, 2019, 2018 and 2017, have been prepared in accordance with GAAP and pursuant to the rules and regulations of the SEC. We consolidate all majority-owned subsidiaries and limited partnerships, which we control as the general partner or owner of the general partner. All significant intercompany transactions and accounts are eliminated in consolidation.

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


•	the Parent Company;


•	our controlled subsidiary, Energy Transfer Operating, L.P.; and


•	Energy Transfer Partners GP, L.P. (“ETP GP”), the general partner of ETO, and Energy Transfer Partners, L.L.C. (“ETP LLC”), the general partner of ETP GP.

Estimates, Significant Accounting Policies and Balance Sheet Detail (Policy)

12 Months Ended

Dec. 31, 2019

Accounting Policies [Abstract]

Use of Estimates

Revenue Recognition

Disaggregation of revenue

The major types of revenue within our reportable segments, 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;


•	fuel distribution and marketing;


•	all other;

•investment in USAC;


•	contract operations;


•	retail parts and services; and

•all other.

Note 17 depicts the disaggregation of revenue by segment, with revenue amounts reflected in accordance with ASC Topic 606 for 2019 and 2018 and ASC Topic 605 for 2017.

Intrastate transportation and storage revenue

Interstate transportation and storage revenue

Midstream revenue


•	In-Kind POP: We retain our POP percentage (non-cash consideration) and also any additional cash fees in exchange for providing the services. We recognize revenue for the non-cash consideration and cash fees at the time the services are performed.


•	Mixed POP: We purchase NGLs from the producer and retain a portion of the residue gas as non-cash consideration for services provided. We may also receive cash fees for such services. Under Topic 606, these agreements were determined

Payment for services under these contracts are typically due the month after the services have been performed.

Our midstream segment also generates revenues from the sale of residue gas and NGLs at the tailgate of our processing facilities primarily to affiliates and some third-party customers.

NGL and refined products transportation and services revenue

Crude oil transportation and services revenue

The performance obligation with respect to interruptible contracts is also a promise to provide a single type of service, but such promise is made on a case-by-case basis at the time the customer requests the service and/or product and we accept the customer’s request. Revenue is recognized for interruptible contracts at the time the services are performed.

Acquisition and marketing contracts are in most cases short-term agreements involving purchase and/or sale of crude oil at market rates. These contracts were not affected by ASC 606.

Sunoco LP’s fuel distribution and marketing revenue

Sunoco LP receives rental income from leased or subleased properties. Revenue from leasing arrangements for which Sunoco LP is the lessor are recognized ratably over the term of the underlying lease.

Sunoco LP’s all other revenue

USAC’s contract operations revenue

Variable consideration exists in select contracts when billing rates vary based on actual equipment availability or volume of total installed horsepower.

There are typically no material obligations for returns or refunds. USAC’s standard contracts do not usually include material non-cash consideration.

USAC’s retail parts and services revenue

All other revenue

Regulatory Accounting - Regulatory Assets and Liabilities

Regulatory Accounting – Regulatory Assets and Liabilities

Cash, Cash Equivalents and Supplemental Cash Flow Information

Accounts Receivable

Inventories

Inventories consisted of the following:



	December 31,
	2019		2018
Natural gas, NGLs and refined products ⁽¹⁾	$	833	$	833
Crude oil	654		506
Spare parts and other	448		338
Total inventories	$	1,935	$	1,677


⁽¹⁾	Due to changes in fuel prices, Sunoco LP recorded a write-down on the value of its fuel inventory of $85 million as of December 31, 2018.

Property, Plant and Equipment

In 2018, USAC recognized a $9 million fixed asset impairment related to certain idle compressor assets.

Equity and Cost Method Investments, Policy [Policy Text Block]

Advances to and Investments in Unconsolidated Affiliates

Other Non-Current Assets, net

Other non-current assets, net are stated at cost less accumulated amortization.

Intangible Assets

Components and useful lives of intangible assets were as follows:



	December 31, 2019					December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Gross Carrying Amount		Accumulated Amortization
Amortizable intangible assets:
Customer relationships, contracts and agreements (3 to 46 years)	$	7,535	$	(1,743	)	$	7,106	$	(1,493	)
Patents (10 years)	48		(35		)	48		(30		)
Trade names (20 years)	66		(31		)	66		(28		)
Other (5 to 20 years)	19		(12		)	33		(9		)
Total amortizable intangible assets	7,668		(1,821		)	7,253		(1,560		)
Non-amortizable intangible assets:
Trademarks	295		—			295		—
Other	12		—			12		—
Total non-amortizable intangible assets	307		—			307		—
Total intangible assets	$	7,975	$	(1,821	)	$	7,560	$	(1,560	)

Aggregate amortization expense of intangible assets was as follows:



	Years Ended December 31,
	2019		2018		2017
Reported in depreciation, depletion and amortization expense	$	308	$	321	$	344

Estimated aggregate amortization expense of intangible assets for the next five years was as follows:



Years Ending December 31:
2020	$	394
2021	390
2022	360
2023	320
2024	307

Goodwill

Goodwill is tested for impairment annually or more frequently if circumstances indicate that goodwill might be impaired. The annual impairment test is performed during the fourth quarter.

Changes in the carrying amount of goodwill were 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		All Other			Total
Balance, December 31, 2017	$	10	$	196		$	870		$	693	$	1,167	$	1,430		$	—	$	402		$	4,768
Acquired	—		—			—			—		—		129			366		—			495
CDM Contribution	—		—			—			—		—		—			253		(253		)	—
Impaired	—		—			(378		)	—		—		—			—		—			(378		)
Other	—		—			—			—		—		—			—		—			—
Balance, December 31, 2018	10		196			492			693		1,167		1,559			619		149			4,885
Acquired	—		42			—			—		230		—			—		35			307
Impaired	—		(12		)	(9		)	—		—		—			—		—			(21		)
Other	—		—			—			—		—		(4		)	—		—			(4		)
Balance, December 31, 2019	$	10	$	226		$	483		$	693	$	1,397	$	1,555		$	619	$	184		$	5,167

control premium representing the incremental value that accrues to the majority owner from the opportunity to dictate the strategic and operational actions of the business.

Asset Retirement Obligation

Asset Retirement Obligations

Accrued and Other Current Liabilities Policy [Text Block]

Redeemable Noncontrolling Interest [Text Block]

Redeemable Noncontrolling Interests

Environmental Costs, Policy [Policy Text Block]

Environmental Remediation

Fair Value of Financial Instruments

The carrying amounts of cash and cash equivalents, accounts receivable and accounts payable approximate their fair value.

Contributions In Aid Of Construction Costs Policy Text Block

Contributions in Aid of Construction Costs

Shipping and Handling Costs

Costs and Expenses

Issuances of Subsidiary Units

Income Taxes

Accounting for Derivative Instruments and Hedging Activities

Cash flows from derivatives accounted for as cash flow hedges are reported as cash flows from operating activities, in the same category as the cash flows from the items being hedged.

Share-based Payment Arrangement [Policy Text Block]

Pension and Other Postretirement Plans, Policy [Policy Text Block]

Pensions and Other Postretirement Benefit Plans

Allocation of Income (Loss)

Allocation of Income

Revenue (Policies)

12 Months Ended

Dec. 31, 2019

Revenue from Contract with Customer [Abstract]

Revenue Recognition

Disaggregation of revenue

The major types of revenue within our reportable segments, 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;


•	fuel distribution and marketing;


•	all other;

•investment in USAC;


•	contract operations;


•	retail parts and services; and

•all other.

Note 17 depicts the disaggregation of revenue by segment, with revenue amounts reflected in accordance with ASC Topic 606 for 2019 and 2018 and ASC Topic 605 for 2017.

Intrastate transportation and storage revenue

Interstate transportation and storage revenue

Midstream revenue


•	In-Kind POP: We retain our POP percentage (non-cash consideration) and also any additional cash fees in exchange for providing the services. We recognize revenue for the non-cash consideration and cash fees at the time the services are performed.


•	Mixed POP: We purchase NGLs from the producer and retain a portion of the residue gas as non-cash consideration for services provided. We may also receive cash fees for such services. Under Topic 606, these agreements were determined

Payment for services under these contracts are typically due the month after the services have been performed.

Our midstream segment also generates revenues from the sale of residue gas and NGLs at the tailgate of our processing facilities primarily to affiliates and some third-party customers.

NGL and refined products transportation and services revenue

Crude oil transportation and services revenue

The performance obligation with respect to interruptible contracts is also a promise to provide a single type of service, but such promise is made on a case-by-case basis at the time the customer requests the service and/or product and we accept the customer’s request. Revenue is recognized for interruptible contracts at the time the services are performed.

Acquisition and marketing contracts are in most cases short-term agreements involving purchase and/or sale of crude oil at market rates. These contracts were not affected by ASC 606.

Sunoco LP’s fuel distribution and marketing revenue

Sunoco LP receives rental income from leased or subleased properties. Revenue from leasing arrangements for which Sunoco LP is the lessor are recognized ratably over the term of the underlying lease.

Sunoco LP’s all other revenue

USAC’s contract operations revenue

Variable consideration exists in select contracts when billing rates vary based on actual equipment availability or volume of total installed horsepower.

There are typically no material obligations for returns or refunds. USAC’s standard contracts do not usually include material non-cash consideration.

USAC’s retail parts and services revenue

All other 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, January 1, 2018	$	221
Additions	765
Revenue recognized	(592		)
Balance, December 31, 2018	394
Additions	664
Revenue recognized	(681		)
Balance, December 31, 2019	$	377

Lease Accounting (Policies)	12 Months Ended
Lease Accounting (Policies)	Dec. 31, 2019
Leases [Abstract]
Lessor, Leases [Policy Text Block]	Lessor Accounting The Partnership leases or subleases a portion of its real estate portfolio to third-party companies as a stable source of long-term revenue. Our lessor and sublease portfolio consists mainly of operating leases with convenience store operators. At this time, most lessor agreements contain five-year terms with renewal options to extend and early termination options based on established terms specific to the individual agreement. Rental income included in other revenue in our consolidated statement of operations for the year ended December 31, 2019 was $149 million.
Lessee, Leases [Policy Text Block]	Lessee Accounting The Partnership leases terminal facilities, tank cars, office space, land and equipment under non-cancelable operating leases whose initial terms are typically five to 15 years, with some real estate leases having terms of 40 years or more, along with options that permit renewals for additional periods. At the inception of each, we determine if the arrangement is a lease or contains an embedded lease and review the facts and circumstances of the arrangement to classify lease assets as operating or finance leases under Topic 842. The Partnership has elected not to record any leases with terms of 12 months or less on the balance sheet. At present, the majority of the Partnership’s active leases are classified as operating in accordance with Topic 842. Balances related to operating leases are included in operating lease ROU assets, accrued and other current liabilities, operating lease current liabilities and non-current operating lease liabilities in our consolidated balance sheets. Finance leases represent a small portion of the active lease agreements and are included in finance lease ROU assets, current maturities of long-term debt and long-term debt, less current maturities in our consolidated balance sheets. The ROU assets represent the Partnership’s right to use an underlying asset for the lease term and lease liabilities represent the obligation of the Partnership to make minimum lease payments arising from the lease for the duration of the lease term. Most leases include one or more options to renew, with renewal terms that can extend the lease term from one to 20 years or greater. The exercise of lease renewal options is typically at the sole discretion of the Partnership and lease extensions are evaluated on a lease-by-lease basis. Leases containing early termination clauses typically require the agreement of both parties to the lease. At the inception of a lease, all renewal options reasonably certain to be exercised are considered when determining the lease term. Presently, the Partnership does not have leases that include options to purchase or automatic transfer of ownership of the leased property to the Partnership. The depreciable life of lease assets and leasehold improvements are limited by the expected lease term. To determine the present value of future minimum lease payments, we use the implicit rate when readily determinable. Presently, because many of our leases do not provide an implicit rate, the Partnership applies its incremental borrowing rate based on the information available at the lease commencement date to determine the present value of minimum lease payments. The operating and finance lease ROU assets include any lease payments made and exclude lease incentives. Minimum rent payments are expensed on a straight-line basis over the term of the lease. In addition, some leases require additional contingent or variable lease payments, which are based on the factors specific to the individual agreement. Variable lease payments the Partnership is typically responsible for include payment of real estate taxes, maintenance expenses and insurance. For short-term leases (leases that have term of twelve months or less upon commencement), lease payments are recognized on a straight-line basis and no ROU assets are recorded.

Estimates, Significant Accounting Policies and Balance Sheet Detail (Tables)

12 Months Ended

Dec. 31, 2019

Accounting Policies [Abstract]

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

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



	Years Ended December 31,
	2019			2018			2017
Accounts receivable	$	(473	)	$	541		$	(948	)
Accounts receivable from related companies	(69		)	162			24
Inventories	(117		)	282			58
Other current assets	117			7			38
Other non-current assets, net	(78		)	(92		)	84
Accounts payable	146			(766		)	712
Accounts payable to related companies	(32		)	(202		)	(178		)
Accrued and other current liabilities	(44		)	382			(97		)
Other non-current liabilities	(186		)	28			106
Derivative assets and liabilities, net	218			(53		)	9
Net change in operating assets and liabilities, net of effects of acquisitions	$	(518	)	$	289		$	(192	)

Schedule Of Non-Cash Investing And Financing Activities

Non-cash investing and financing activities and supplemental cash flow information are as follows:



	Years Ended December 31,
	2019		2018			2017
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures	$	1,334	$	1,030		$	1,060
Lease assets obtained in exchange for new lease liabilities	68		—			—
Net losses from subsidiary common unit transactions	—		(126		)	(56		)
NON-CASH FINANCING ACTIVITIES:
Contribution of assets from noncontrolling interests	$	—	$	—		$	988
SUPPLEMENTAL CASH FLOW INFORMATION:
Cash paid for interest, net of interest capitalized	$	1,932	$	1,870		$	1,914
Cash paid for income taxes	31		508			50

Schedule of Inventory

Inventories consisted of the following:



	December 31,
	2019		2018
Natural gas, NGLs and refined products ⁽¹⁾	$	833	$	833
Crude oil	654		506
Spare parts and other	448		338
Total inventories	$	1,935	$	1,677

⁽¹⁾

Due to changes in fuel prices, Sunoco LP recorded a write-down on the value of its fuel inventory of $85 million as of December 31, 2018.

Other Current Assets

Other current assets consisted of the following:



	December 31,
	2019		2018
Deposits paid to vendors	$	95	$	141
Prepaid expenses and other	180		209
Total other current assets	$	275	$	350

Property, Plant and Equipment

Components and useful lives of property, plant and equipment were as follows:



	December 31,
	2019			2018
Land and improvements	$	1,264		$	1,168
Buildings and improvements (1 to 45 years)	2,632			2,664
Pipelines and equipment (5 to 83 years)	64,678			58,783
Product storage and related facilities (2 to 83 years)	5,898			4,978
Right of way (20 to 83 years)	4,859			4,533
Other (1 to 48 years)	1,964			1,583
Construction work-in-process	8,495			6,067
	89,790			79,776
Less – Accumulated depreciation and depletion	(15,597		)	(12,813		)
Property, plant and equipment, net	$	74,193		$	66,963

Schedule Of Property, Plant And Equipment Depreciation And Capitalized Interest Expense

We recognized the following amounts for the periods presented:



	Years Ended December 31,
	2019		2018		2017
Depreciation, depletion and amortization expense	$	2,839	$	2,538	$	2,204
Capitalized interest	166		294		286

Schedule of Other Non-Current Assets, net

Other non-current assets, net are stated at cost less accumulated amortization. Other non-current assets, net consisted of the following:



	December 31,
	2019		2018
Regulatory assets	$	42	$	43
Pension assets	84		68
Deferred charges	178		173
Restricted funds	178		178
Other	593		544
Total other non-current assets, net	$	1,075	$	1,006

Components And Useful Lives Of Intangibles And Other Assets

Components and useful lives of intangible assets were as follows:



	December 31, 2019					December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Gross Carrying Amount		Accumulated Amortization
Amortizable intangible assets:
Customer relationships, contracts and agreements (3 to 46 years)	$	7,535	$	(1,743	)	$	7,106	$	(1,493	)
Patents (10 years)	48		(35		)	48		(30		)
Trade names (20 years)	66		(31		)	66		(28		)
Other (5 to 20 years)	19		(12		)	33		(9		)
Total amortizable intangible assets	7,668		(1,821		)	7,253		(1,560		)
Non-amortizable intangible assets:
Trademarks	295		—			295		—
Other	12		—			12		—
Total non-amortizable intangible assets	307		—			307		—
Total intangible assets	$	7,975	$	(1,821	)	$	7,560	$	(1,560	)

Aggregate Amortization Expense Of Intangibles And Other Assets

Aggregate amortization expense of intangible assets was as follows:



	Years Ended December 31,
	2019		2018		2017
Reported in depreciation, depletion and amortization expense	$	308	$	321	$	344

Estimated Aggregate Amortization Expense

Estimated aggregate amortization expense of intangible assets for the next five years was as follows:



Years Ending December 31:
2020	$	394
2021	390
2022	360
2023	320
2024	307

Schedule of Goodwill

Changes in the carrying amount of goodwill were 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		All Other			Total
Balance, December 31, 2017	$	10	$	196		$	870		$	693	$	1,167	$	1,430		$	—	$	402		$	4,768
Acquired	—		—			—			—		—		129			366		—			495
CDM Contribution	—		—			—			—		—		—			253		(253		)	—
Impaired	—		—			(378		)	—		—		—			—		—			(378		)
Other	—		—			—			—		—		—			—		—			—
Balance, December 31, 2018	10		196			492			693		1,167		1,559			619		149			4,885
Acquired	—		42			—			—		230		—			—		35			307
Impaired	—		(12		)	(9		)	—		—		—			—		—			(21		)
Other	—		—			—			—		—		(4		)	—		—			(4		)
Balance, December 31, 2019	$	10	$	226		$	483		$	693	$	1,397	$	1,555		$	619	$	184		$	5,167

Accrued and Other Current Liabilities

Accrued and other current liabilities consisted of the following:



	December 31,
	2019		2018
Interest payable	$	579	$	571
Customer advances and deposits	123		128
Accrued capital expenditures	1,334		1,030
Accrued wages and benefits	217		283
Taxes payable other than income taxes	263		256
Exchanges payable	67		112
Other	759		538
Total accrued and other current liabilities	$	3,342	$	2,918

Fair Value Of Financial Assets And Liabilities Measured On Recurring Basis



	Fair Value Total			Fair Value Measurements at December 31, 2019
				Level 1			Level 2
Assets:
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	$	17		$	17		$	—
Swing Swaps IFERC	1			—			1
Fixed Swaps/Futures	65			65			—
Forward Physical Contracts	3			—			3
Power:
Forwards	11			—			11
Futures	4			4			—
Options – Puts	1			1			—
Options – Calls	1			1			—
NGLs – Forwards/Swaps	260			260			—
Refined Products – Futures	8			8			—
Crude – Forwards/Swaps	13			13			—
Total commodity derivatives	384			369			15
Other non-current assets	31			20			11
Total assets	$	415		$	389		$	26
Liabilities:
Interest rate derivatives	$	(399	)	$	—		$	(399	)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(49		)	(49		)	—
Swing Swaps IFERC	(1		)	—			(1		)
Fixed Swaps/Futures	(43		)	(43		)	—
Power:
Forwards	(5		)	—			(5		)
Futures	(3		)	(3		)	—
NGLs – Forwards/Swaps	(278		)	(278		)	—
Refined Products – Futures	(10		)	(10		)	—
Total commodity derivatives	(389		)	(383		)	(6		)
Total liabilities	$	(788	)	$	(383	)	$	(405	)



	Fair Value Total			Fair Value Measurements at December 31, 2018
				Level 1			Level 2
Assets:
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	$	42		$	42		$	—
Swing Swaps IFERC	52			8			44
Fixed Swaps/Futures	97			97			—
Forward Physical Contracts	20			—			20
Power:
Power – Forwards	48			—			48
Futures	1			1			—
Options – Calls	1			1			—
NGLs – Forwards/Swaps	291			291			—
Refined Products – Futures	7			7			—
Crude - Forwards/Swaps	1			1			—
Total commodity derivatives	560			448			112
Other non-current assets	26			17			9
Total assets	$	586		$	465		$	121
Liabilities:
Interest rate derivatives	$	(163	)	$	—		$	(163	)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(91		)	(91		)	—
Swing Swaps IFERC	(40		)	—			(40		)
Fixed Swaps/Futures	(88		)	(88		)	—
Forward Physical Contracts	(21		)	—			(21		)
Power:
Forwards	(42		)	—			(42		)
Futures	(1		)	(1		)	—
NGLs – Forwards/Swaps	(224		)	(224		)	—
Refined Products – Futures	(15		)	(15		)	—
Crude - Forwards/Swaps	(61		)	(61		)	—
Total commodity derivatives	(583		)	(480		)	(103		)
Total liabilities	$	(746	)	$	(480	)	$	(266	)

Acquisitions and Related Transactions (Tables)

12 Months Ended

Dec. 31, 2019

Disposal Groups, Including Discontinued Operations [Table Text Block]



	Years Ended December 31,
	2018			2017
REVENUES	$	349		$	6,964

COSTS AND EXPENSES
Cost of products sold	305			5,806
Operating expenses	61			763
Depreciation, depletion and amortization	—			34
Selling, general and administrative	7			168
Impairment losses	—			285
Total costs and expenses	373			7,056
OPERATING LOSS	(24		)	(92		)
OTHER EXPENSE
Interest expense, net	2			36
Loss on extinguishment of debt	20			—
Other, net	61			1
LOSS FROM DISCONTINUED OPERATIONS BEFORE INCOME TAX EXPENSE	(107		)	(129		)
Income tax expense	158			48
LOSS FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES	$	(265	)	$	(177	)
LOSS FROM DISCONTINUED OPERATIONS, NET OF INCOME TAXES ATTRIBUTABLE TO ET	$	(10	)	$	(6	)

SemGroup [Member]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]

Summary of Assets Acquired and Liabilities Assumed

The total purchase price was allocated as follows:



	At December 5, 2019
Total current assets	$	794
Property, plant and equipment	3,914
Other non-current assets	623
Goodwill⁽¹⁾	265
Intangible assets	460
Total assets	6,056

Total current liabilities	629
Long-term debt, less current maturities ⁽²⁾	2,576
Other non-current liabilities	196
SemCAMS Preferred shares	241
Total liabilities	3,642

Noncontrolling interest	822

Total consideration ⁽³⁾	1,592
Cash received⁽⁴⁾	153
Total consideration, net of cash received	$	1,439


⁽¹⁾	None of the goodwill is expected to be deductible for tax purposes. Goodwill recognized from the business combination primarily relates to the value attributed to additional growth opportunities, synergies and operating leverage within SemGroup’s operations.


⁽²⁾	Long-term debt at December 5, 2019 includes SemGroup senior notes with an aggregate principal amount of $1.375 billion and SemGroup subsidiary debt of $593 million, all of which were redeemed in total in December 2019, subsequent to the close of the SemGroup Transaction, utilizing proceeds from an intercompany promissory note from ETO.


⁽³⁾	Total consideration includes (i) cash paid to SemGroup shareholders, (ii) fair value of ET Common Units issued in the acquisition and (iii) cash paid to redeem SemGroup’s preferred shares.

⁽⁴⁾

Cash received represents cash and cash equivalents held by SemGroup as of the acquisition date.

USA Compression Partners, LP [Member]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]

The total purchase price was allocated as follows:



	At April 2, 2018
Total current assets	$	786
Property, plant and equipment	1,332
Other non-current assets	15
Goodwill⁽¹⁾	366
Intangible assets	222
Total assets	2,721

Total current liabilities	110
Long-term debt, less current maturities	1,527
Other non-current liabilities	2
Total liabilities	1,639

Noncontrolling interest	832

Total consideration	250
Cash received⁽²⁾	711
Total consideration, net of cash received⁽²⁾	$	(461	)


⁽¹⁾	None of the goodwill is expected to be deductible for tax purposes. Goodwill recognized from the business combination primarily relates to the value attributed to additional growth opportunities, synergies and operating leverage within USAC’s operations.

⁽²⁾

Cash received represents cash and cash equivalents held by USAC as of the acquisition date.

- Definition

Tabular disclosure of information related to a disposal group. Includes, but is not limited to, a discontinued operation, disposal classified as held-for-sale or disposed of by means other than sale or disposal of an individually significant component.

+ References

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 360
-SubTopic 10
-Section 50
-Paragraph 3A
-URI http://asc.fasb.org/extlink&oid=109226691&loc=SL51724579-110230

Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=109222650&loc=d3e1474-107760

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5D
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721677-107760

Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 45
-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=109222160&loc=SL51721533-107759

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 3A
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721659-107760

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721665-107760

Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 360
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=109226691&loc=d3e2941-110230

Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5C
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721675-107760

Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721683-107760

Reference 10: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=109222650&loc=d3e1361-107760

Reference 11: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5A
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721671-107760

Reference 12: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5B
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721673-107760

Reference 13: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 4A
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721663-107760

+ Details

Advances to and Investments in Unconsolidated Affiliates (Tables)

12 Months Ended

Dec. 31, 2019

Investment In Affiliates [Abstract]

Schedule Of Aggregated Selected Balance Sheet And Income Statement Data For Our Unconsolidated Affiliates

The carrying values of the Partnership’s investments advances to and in unconsolidated affiliates as of December 31, 2019 and 2018 were as follows:



	December 31,
	2019		2018
Citrus	$	1,876	$	1,737
FEP	218		107
MEP	429		225
Others	937		573
Total	$	3,460	$	2,642

The following table presents equity in earnings (losses) of unconsolidated affiliates:



	Years Ended December 31,
	2019		2018		2017
Citrus	$	148	$	141	$	144
FEP	59		55		53
MEP	15		31		38
Other	80		117		(91		)
Total equity in earnings of unconsolidated affiliates	$	302	$	344	$	144

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



	December 31,
	2019		2018
Current assets	$	247	$	212
Property, plant and equipment, net	7,680		7,800
Other assets	40		39
Total assets	$	7,967	$	8,051

Current liabilities	$	738	$	1,534
Non-current liabilities	3,242		3,439
Equity	3,987		3,078
Total liabilities and equity	$	7,967	$	8,051



	Years Ended December 31,
	2019		2018 ⁽¹⁾		2017
Revenue	$	1,192	$	1,249	$	1,358
Operating income	683		723		407
Net income	443		460		145

⁽¹⁾

Selected income data related to HPC for the year ended December 31, 2018 reflects HPC’s results for January 1, 2018 through March 31, 2018. HPC was fully consolidated beginning April 1, 2018 as discussed above.

Net Income Per Limited Partner Unit (Tables)

12 Months Ended

Dec. 31, 2019

Earnings Per Share [Abstract]

Reconciliation Of Net Income (Loss) And Weighted Average Units

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



	Years Ended December 31,
	2019			2018			2017
Income from continuing operations	$	4,899		$	3,630		$	2,543
Less: Net income attributable to redeemable noncontrolling interests	51			39			—
Less: Income (loss) from continuing operations attributable to noncontrolling interests	1,256			1,888			1,583
Income from continuing operations, net of noncontrolling interests	3,592			1,703			960
Less: General Partner’s interest in income from continuing operations	4			3			2
Less: ET Series A Convertible Preferred Unitholders’ interest in net income from continuing operations	—			33			38
Income from continuing operations available to Limited Partners	$	3,588		$	1,667		$	920
Basic Income from Continuing Operations per Limited Partner Unit:
Weighted average limited partner units	2,628.0			1,423.8			1,078.2
Basic income from continuing operations per Limited Partner unit	$	1.37		$	1.17		$	0.86
Basic loss from discontinued operations per Limited Partner unit	$	—		$	(0.01	)	$	(0.01	)
Diluted Income from Continuing Operations per Limited Partner Unit:
Income from continuing operations available to Limited Partners	$	3,588		$	1,667		$	920
Dilutive effect of equity-based compensation of subsidiaries and distributions to convertible units	(1		)	33			38
Diluted income from continuing operations available to Limited Partners	3,587			1,700			958
Weighted average limited partner units	2,628.0			1,423.8			1,078.2
Dilutive effect of unconverted unit awards and ET Series A Convertible Preferred Units	—			30.3			72.6
Dilutive effect of unvested unit awards	9.6			7.3			—
Weighted average limited partner units, assuming dilutive effect of unvested unit awards	2,637.6			1,461.4			1,150.8
Diluted income from continuing operations per Limited Partner unit	$	1.36		$	1.16		$	0.84
Diluted loss from discontinued operations per Limited Partner unit	$	—		$	(0.01	)	$	(0.01	)

Debt Obligations Debt Obligations (Tables)

12 Months Ended

Dec. 31, 2019

Debt Obligations [Abstract]

Schedule of debt obligations

Our debt obligations consist of the following:



	December 31,
	2019		2018
Parent Company Indebtedness:
7.50% Senior Notes due October 15, 2020 ⁽¹⁾	$	52	$	1,187
4.25% Senior Notes due March 15, 2023	5		1,000
5.875% Senior Notes due January 15, 2024	23		1,150
5.50% Senior Notes due June 1, 2027	44		1,000
ET Senior Secured Term Loan	—		1,220
Unamortized premiums, discounts and fair value adjustments, net	—		(10		)
Deferred debt issuance costs	—		(27		)
	124		5,520

Subsidiary Indebtedness:
ETO Debt
9.70% Senior Notes due March 15, 2019	—		400
9.00% Senior Notes due April 15, 2019	—		450
5.50% Senior Notes due February 15, 2020 ⁽¹⁾	250		250
5.75% Senior Notes due September 1, 2020 ⁽¹⁾	400		400
4.15% Senior Notes due October 1, 2020 ⁽¹⁾	1,050		1,050
7.50% Senior Notes due October 15, 2020 ⁽¹⁾	1,135		—
4.40% Senior Notes due April 1, 2021	600		600
4.65% Senior Notes due June 1, 2021	800		800
5.20% Senior Notes due February 1, 2022	1,000		1,000
4.65% Senior Notes due February 15, 2022	300		300
5.875% Senior Notes due March 1, 2022	900		900
5.00% Senior Notes due October 1, 2022	700		700
3.45% Senior Notes due January 15, 2023	350		350
3.60% Senior Notes due February 1, 2023	800		800
4.25% Senior Notes due March 15, 2023	995		—
4.20% Senior Notes due September 15, 2023	500		500
4.50% Senior Notes due November 1, 2023	600		600
5.875% Senior Notes due January 15, 2024	1,127		—
4.90% Senior Notes due February 1, 2024	350		350
7.60% Senior Notes due February 1, 2024	277		277
4.25% Senior Notes due April 1, 2024	500		500
4.50% Senior Notes due April 15, 2024	750		—
9.00% Debentures due November 1, 2024	65		65
4.05% Senior Notes due March 15, 2025	1,000		1,000
5.95% Senior Notes due December 1, 2025	400		400
4.75% Senior Notes due January 15, 2026	1,000		1,000
3.90% Senior Notes due July 15, 2026	550		550
4.20% Senior Notes due April 15, 2027	600		600
5.50% Senior Notes due June 1, 2027	956		—
4.00% Senior Notes due October 1, 2027	750		750
4.95% Senior Notes due June 15, 2028	1,000		1,000
5.25% Senior Notes due April 15, 2029	1,500		—
8.25% Senior Notes due November 15, 2029	267		267



4.90% Senior Notes due March 15, 2035	500		500
6.625% Senior Notes due October 15, 2036	400		400
5.80% Senior Notes due June 15, 2038	500		500
7.50% Senior Notes due July 1, 2038	550		550
6.85% Senior Notes due February 15, 2040	250		250
6.05% Senior Notes due June 1, 2041	700		700
6.50% Senior Notes due February 1, 2042	1,000		1,000
6.10% Senior Notes due February 15, 2042	300		300
4.95% Senior Notes due January 15, 2043	350		350
5.15% Senior Notes due February 1, 2043	450		450
5.95% Senior Notes due October 1, 2043	450		450
5.30% Senior Notes due April 1, 2044	700		700
5.15% Senior Notes due March 15, 2045	1,000		1,000
5.35% Senior Notes due May 15, 2045	800		800
6.125% Senior Notes due December 15, 2045	1,000		1,000
5.30% Senior Notes due April 15, 2047	900		900
5.40% Senior Notes due October 1, 2047	1,500		1,500
6.00% Senior Notes due June 15, 2048	1,000		1,000
6.25% Senior Notes due April 15, 2049	1,750		—
Floating Rate Junior Subordinated Notes due November 1, 2066	546		546
ETO $2.00 billion Term Loan facility due October 2022	2,000		—
ETO $5.00 billion Revolving Credit Facility due December 2023	4,214		3,694
Unamortized premiums, discounts and fair value adjustments, net	(5	)	17
Deferred debt issuance costs	(207	)	(178	)
	42,120		32,288

Transwestern Debt
5.36% Senior Notes due December 9, 2020 ⁽¹⁾	175		175
5.89% Senior Notes due May 24, 2022	150		150
5.66% Senior Notes due December 9, 2024	175		175
6.16% Senior Notes due May 24, 2037	75		75
Deferred debt issuance costs	(1	)	(1	)
	574		574

Panhandle Debt
8.125% Senior Notes due June 1, 2019	—		150
7.60% Senior Notes due February 1, 2024	82		82
7.00% Senior Notes due July 15, 2029	66		66
8.25% Senior Notes due November 15, 2029	33		33
Floating Rate Junior Subordinated Notes due November 1, 2066	54		54
Unamortized premiums, discounts and fair value adjustments, net	11		14
	246		399




Bakken Project Debt
3.625% Senior Notes due April 1, 2022	650			—
3.90% Senior Notes due April 1, 2024	1,000			—
4.625% Senior Notes due April 1, 2029	850			—
Bakken $2.50 billion Credit Facility due August 2019	—			2,500
Unamortized premiums, discounts and fair value adjustments, net	(3		)	—
Deferred debt issuance costs	(16		)	(3		)
	2,481			2,497

Sunoco LP Debt
4.875% Senior Notes Due January 15, 2023	1,000			1,000
5.50% Senior Notes Due February 15, 2026	800			800
6.00% Senior Notes Due April 15, 2027	600			—
5.875% Senior Notes Due March 15, 2028	400			400
Sunoco LP $1.50 billion Revolving Credit Facility due July 2023	162			700
Lease-related obligations	135			107
Deferred debt issuance costs	(26		)	(23		)
	3,071			2,984

USAC Debt
6.875% Senior Notes due April 1, 2026	725			725
6.875% Senior Notes due September 1, 2027	750			—
USAC $1.60 billion Revolving Credit Facility due April 2023	403			1,050
Deferred debt issuance costs	(26		)	(16		)
	1,852			1,759

SemGroup Debt
HFOTCO Tax Exempt Notes due 2050	225			—
SemCAMS Revolver due February 25, 2024	92			—
SemCAMS Term Loan A due February 25, 2024	269			—
Unamortized premiums, discounts and fair value adjustments, net	1			—
Deferred debt issuance costs	(3		)	—
	584			—

Other	2			7
Total debt	51,054			46,028
Less: Current maturities of long-term debt	26			2,655
Long-term debt, less current maturities	$	51,028		$	43,373

Future maturities of long-term debt



2020	$	3,086
2021	1,412
2022	5,792
2023	8,965
2024	4,708
Thereafter	27,366
Total	$	51,329

- Definition

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

+ References

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=114775744&loc=d3e28541-108399

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21506-112644

Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(e),(f))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=114775744&loc=d3e28551-108399

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21521-112644

Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21538-112644

Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=75038535&loc=d3e64711-112823

Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=114775985&loc=d3e28878-108400

Reference 10: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21475-112644

+ Details

Equity (Tables)

12 Months Ended

Dec. 31, 2019

Change In ETE Common Units

The change in ET Common Units during the years ended December 31, 2019, 2018 and 2017 was as follows:



	Years Ended December 31,
	2019		2018	2017
Number of Common Units, beginning of period	2,619.4		1,079.1	1,046.9
Conversion of ET Series A Convertible Preferred Units to common units	—		79.1	—
Common Units issued in mergers and acquisitions	57.6		1,458.9	—
Common Units repurchased	(1.9	)	—	—
Issuance of Common Units	14.5		2.3	32.2
Number of Common Units, end of period	2,689.6		2,619.4	1,079.1

In October 2018, ET issued 1.46 billion ET Common Units in connection with the Energy Transfer Merger.

Accumulated Other Comprehensive Income (Loss)

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



	December 31,
	2019			2018
Available-for-sale securities	$	13		$	2
Foreign currency translation adjustment	2			(5		)
Actuarial loss related to pensions and other postretirement benefits	(25		)	(48		)
Investments in unconsolidated affiliates, net	(1		)	9
Total AOCI, net of tax	$	(11	)	$	(42	)

Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]

The table below sets forth the tax amounts included in the respective components of other comprehensive income:



	December 31,
	2019			2018
Available-for-sale securities	$	(1	)	$	(1	)
Foreign currency translation adjustment	2			2
Actuarial loss relating to pension and other postretirement benefits	8			12
Total	$	9		$	13

Parent Company [Member]

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

Our distributions declared and paid with respect to our common units were as follows:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2016 ⁽¹⁾	February 7, 2017	February 21, 2017	$	0.2850
March 31, 2017 ⁽¹⁾	May 10, 2017	May 19, 2017	0.2850
June 30, 2017 ⁽¹⁾	August 7, 2017	August 21, 2017	0.2850
September 30, 2017 ⁽¹⁾	November 7, 2017	November 20, 2017	0.2950
December 31, 2017 ⁽¹⁾	February 8, 2018	February 20, 2018	0.3050
March 31, 2018	May 7, 2018	May 21, 2018	0.3050
June 30, 2018	August 6, 2018	August 20, 2018	0.3050
September 30, 2018	November 8, 2018	November 19, 2018	0.3050
December 31, 2018	February 8, 2019	February 19, 2019	0.3050
March 31, 2019	May 7, 2019	May 20, 2019	0.3050
June 30, 2019	August 6, 2019	August 19, 2019	0.3050
September 30, 2019	November 5, 2019	November 19, 2019	0.3050
December 31, 2019	February 7, 2020	February 19, 2020	0.3050

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 were as follows:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2016	February 13, 2017	February 21, 2017	$	0.8255
March 31, 2017	May 9, 2017	May 16, 2017	0.8255
June 30, 2017	August 7, 2017	August 15, 2017	0.8255
September 30, 2017	November 7, 2017	November 14, 2017	0.8255
December 31, 2017	February 6, 2018	February 14, 2018	0.8255
March 31, 2018	May 7, 2018	May 15, 2018	0.8255
June 30, 2018	August 7, 2018	August 15, 2018	0.8255
September 30, 2018	November 6, 2018	November 14, 2018	0.8255
December 31, 2018	February 6, 2019	February 14, 2019	0.8255
March 31, 2019	May 7, 2019	May 15, 2019	0.8255
June 30, 2019	August 6, 2019	August 14, 2019	0.8255
September 30, 2019	November 5, 2019	November 19, 2019	0.8255
December 31, 2019	February 7, 2020	February 19, 2020	0.8255

Schedule of Incentive Distributions Made to Managing Members or General Partners by Distribution [Table Text Block]



		Marginal Percentage Interest in Distributions
	Total Quarterly Distribution Target Amount	Common Unitholders	Holder of IDRs
Minimum Quarterly Distribution	$0.4375	100%	—%
First Target Distribution	$0.4375 to $0.503125	100%	—%
Second Target Distribution	$0.503125 to $0.546875	85%	15%
Third Target Distribution	$0.546875 to $0.656250	75%	25%
Thereafter	Above $0.656250	50%	50%

USAC [Member]

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

USAC Cash Distributions

Distributions on USAC’s units declared and/or paid by USAC subsequent to the USAC transaction on April 2, 2018 were as follows:



Quarter Ended	Record Date	Payment Date	Rate
March 31, 2018	May 1, 2018	May 11, 2018	$	0.5250
June 30, 2018	July 30, 2018	August 10, 2018	0.5250
September 30, 2018	October 29, 2018	November 09, 2018	0.5250
December 31, 2018	January 28, 2019	February 8, 2019	0.5250
March 31, 2019	April 29, 2019	May 10, 2019	0.5250
June 30, 2019	July 29, 2019	August 9, 2019	0.5250
September 30, 2019	October 28, 2019	November 8, 2019	0.5250
December 31, 2019	January 27, 2020	February 7, 2020	0.5250

Preferred Units [Member] | Parent Company [Member]

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

Our distributions declared and paid with respect to ET Series A Convertible Preferred Unit were as follows:



Quarter Ended	Record Date	Payment Date	Rate
December 31, 2016	February 7, 2017	February 21, 2017	$	0.1100
March 31, 2017	May 10, 2017	May 19, 2017	0.1100
June 30, 2017	August 7, 2017	August 21, 2017	0.1100
September 30, 2017	November 7, 2017	November 20, 2017	0.1100
December 31, 2017	February 8, 2018	February 20, 2018	0.1100
March 31, 2018	May 7, 2018	May 21, 2018	0.1100

Preferred Units [Member] | ETO [Member]

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



Period Ended	Record Date	Payment Date	Series A⁽¹⁾			Series B⁽¹⁾			Series C			Series D			Series E
December 31, 2017	February 1, 2018	February 15, 2018	$	15.4510	^*	$	16.3780	^*	$	—		$	—		$	—
June 30, 2018	August 1, 2018	August 15, 2018	31.2500			33.1250			0.5634		^*	—			—
September 30, 2018	November 1, 2018	November 15, 2018	—			—			0.4609			0.5931		^*	—
December 31, 2018	February 1, 2019	February 15, 2019	31.2500			33.1250			0.4609			0.4766			—
March 31, 2019	May 1, 2019	May 15, 2019	—			—			0.4609			0.4766			—
June 30, 2019	August 1, 2019	August 15, 2019	31.2500			33.1250			0.4609			0.4766			0.5806		^*
September 30, 2019	November 1, 2019	November 15, 2019	—			—			0.4609			0.4766			0.4750
December 31, 2019	February 3, 2020	February 18, 2020	31.2500			33.1250			0.4609			0.4766			0.4750


^*	Represent prorated initial distributions. Prorated initial distributions on the recently issued ETO Series F Preferred Units and ETO Series G Preferred Units will be payable in May 2020.

⁽¹⁾ ETO Series A Preferred Units and ETO Series B Preferred Unit distributions are paid on a semi-annual basis.

Non-Cash Compensation Plans Unit-Based Compensation Plans (Tables)

12 Months Ended

Dec. 31, 2019

Schedule Of ETP Awards Granted To Employees And Non-Employee Directos

The following table shows the activity of the awards granted to employees and non-employee directors:



	Number of Units		Weighted Average Grant-Date Fair Value Per Unit
Unvested awards as of December 31, 2018	22.4		$	15.94
Replacement awards issued in the SemGroup Transaction	1.4		11.60
Awards granted	8.9		12.51
Awards vested	(4.0	)	21.09
Awards forfeited	(0.7	)	15.70
Unvested awards as of December 31, 2019	28.0		13.89

Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value [Table Text Block]

The following table summarizes the weighted average grant-date fair value per unit award granted:



	Years Ended December 31,
	2019		2018		2017
Sunoco LP	$	30.70	$	27.67	$	28.31
USAC	15.88		15.47		N/A

Subsidiaries [Member]

Schedule Of ETP Awards Granted To Employees And Non-Employee Directos

The following table summarizes the activity of the Subsidiary Unit Awards:



	Sunoco LP				USAC
	Number of Units		Weighted Average Grant-Date Fair Value Per Unit		Number of Units		Weighted Average Grant-Date Fair Value Per Unit
Unvested awards as of December 31, 2018	2.1		$	29.15	1.4		$	14.98
Awards granted	0.7		30.70		0.7		15.88
Awards vested	(0.5	)	30.04		(0.3	)	13.06
Awards forfeited	(0.2	)	28.16		—		16.78
Unvested awards as of December 31, 2019	2.1		29.21		1.8		15.09

Income Taxes Income Taxes (Tables)

12 Months Ended

Dec. 31, 2019

Federal and State Income Taxes [Abstract]

Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]

The components of the federal and state income tax expense (benefit) of our taxable subsidiaries were summarized as follows:



	Years Ended December 31,
	2019			2018			2017
Current expense (benefit):
Federal	$	(20	)	$	(8	)	$	54
State	(2		)	19			(16		)
Total	(22		)	11			38
Deferred expense (benefit):
Federal	174			181			(2,055		)
State	43			(188		)	184
Total	217			(7		)	(1,871		)
Total income tax expense (benefit) from continuing operations	$	195		$	4		$	(1,833	)

Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]



	Years Ended December 31,
	2019			2018			2017
Income tax expense at United States statutory rate	$	1,070		$	763		$	248
Increase (reduction) in income taxes resulting from:
Partnership earnings not subject to tax	(882		)	(635		)	(477		)
Goodwill impairment	—			—			207
State tax, net of federal tax benefit	12			(125		)	124
Dividend received deduction	(3		)	(5		)	(14		)
Federal rate change	—			—			(1,812		)
Change in tax status of subsidiary	—			—			(124		)
Other	(2		)	6			15
Income tax expense (benefit) from continuing operations	$	195		$	4		$	(1,833	)

Schedule of Deferred Tax Assets and Liabilities [Table Text Block]



	December 31,
	2019			2018
Deferred income tax assets:
Net operating losses, alternative minimum tax credit and other carryforwards	$	936		$	768
Pension and other postretirement benefits	7			34
Long-term debt	—			13
Other	85			181
Total deferred income tax assets	1,028			996
Valuation allowance	(95		)	(96		)
Net deferred income tax assets	933			900

Deferred income tax liabilities:
Property, plant and equipment	(501		)	(782		)
Investments in affiliates	(3,547		)	(2,872		)
Trademarks	(72		)	(63		)
Other	(21		)	(109		)
Total deferred income tax liabilities	(4,141		)	(3,826		)
Net deferred income taxes	$	(3,208	)	$	(2,926	)

ScheduleOfUnrecognizedTaxBenefits [Table Text Block]



	Years Ended December 31,
	2019			2018		2017
Balance at beginning of year	$	624		$	609	$	615
Additions attributable to tax positions taken in the current year	—			8		—
Additions attributable to tax positions taken in prior years	11			7		28
Reduction attributable to tax positions taken in prior years	(541		)	—		(25		)
Lapse of statute	—			—		(9		)
Balance at end of year	$	94		$	624	$	609

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

12 Months Ended

Dec. 31, 2019

Environmental Exit Costs by Cost [Table Text Block]



	December 31,
	2019		2018
Current	$	46	$	42
Non-current	274		295
Total environmental liabilities	$	320	$	337

Right Of Way [Member]

Lessee, Operating Lease, Disclosure [Table Text Block]



	Years Ended December 31,
	2019		2018		2017
ROW expense	$	45	$	46	$	46

Revenue (Tables)

12 Months Ended

Dec. 31, 2019

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

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



	Contract Liabilities
Balance, January 1, 2018	$	221
Additions	765
Revenue recognized	(592		)
Balance, December 31, 2018	394
Additions	664
Revenue recognized	(681		)
Balance, December 31, 2019	$	377

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]



	Years Ending December 31,
	2020		2021		2022		Thereafter		Total
Revenue expected to be recognized on contracts with customers existing as of December 31, 2019	$	6,232	$	5,300	$	4,899	$	27,158	$	43,589

Sunoco LP [Member]

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

The balances of Sunoco LP’s contract assets and contract liabilities as of December 31, 2019 and 2018 were as follows:



	December 31, 2019		December 31, 2018
Contract Balances
Contract asset	$	117	$	75
Accounts receivable from contracts with customers	366		347
Contract liability	—		1

Lease Accounting (Tables)

12 Months Ended

Dec. 31, 2019

Leases [Abstract]

Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]

Future minimum operating lease payments receivable as of December 31, 2019 are as follows:



	Lease Payments
2020	$	138
2021	112
2022	75
2023	20
2024	15
Thereafter	12
Total undiscounted cash flows	$	372

Schedule of Property Subject to or Available for Operating Lease [Table Text Block]

The components of operating and finance lease amounts recognized in the accompanying consolidated balance sheet as of December 31, 2019 were as follows:



	December 31, 2019
Operating leases:
Lease right-of-use assets, net	$	935
Operating lease current liabilities	60
Accrued and other current liabilities	1
Non-current operating lease liabilities	901
Finance leases:
Property, plant and equipment, net	$	1
Lease right-of-use assets, net	29
Accrued and other current liabilities	1
Current maturities of long-term debt	6
Long-term debt, less current maturities	26
Other non-current liabilities	2

Lease, Cost [Table Text Block]

The components of lease expense for the year ended December 31, 2019 were as follows:



	Income Statement Location	Year Ended December 31, 2019
Operating lease costs:
Operating lease cost	Cost of goods sold	$	28
Operating lease cost	Operating expenses	73
Operating lease cost	Selling, general and administrative	16
Total operating lease costs		117
Finance lease costs:
Amortization of lease assets	Depreciation, depletion and amortization	6
Interest on lease liabilities	Interest expense, net of capitalized interest	1
Total finance lease costs		7
Short-term lease cost	Operating expenses	42
Variable lease cost	Operating expenses	17
Lease costs, gross		183
Less: Sublease income	Other revenue	47
Lease costs, net		$	136

Lessee, Operating Lease, Liability, Maturity [Table Text Block]

Maturities of lease liabilities as of December 31, 2019 are as follows:



	Operating leases		Finance leases		Total
2020	$	104	$	8	$	112
2021	96		8		104
2022	83		8		91
2023	77		7		84
2024	74		4		78
Thereafter	1,342		5		1,347
Total lease payments	1,776		40		1,816
Less: present value discount	815		5		820
Present value of lease liabilities	$	961	$	35	$	996

The weighted average remaining lease terms and weighted average discount rates as of December 31, 2019 were as follows:



	December 31, 2019
Weighted-average remaining lease term (years):
Operating leases	24
Finance leases	5
Weighted-average discount rate (%):
Operating leases	5	%
Finance leases	5	%

Schedule of additional lease information [Table Text Block]

Cash flows and non-cash activity related to leases for the year ended December 31, 2019 were as follows:



	Year Ended December 31, 2019
Operating cash flows from operating leases	$	(159	)
Lease assets obtained in exchange for new finance lease liabilities	28
Lease assets obtained in exchange for new operating lease liabilities	40

Derivative Assets And Liabilities (Tables)

12 Months Ended

Dec. 31, 2019

General Discussion of Derivative Instruments and Hedging Activities [Abstract]

Offsetting Assets [Table Text Block]



		Asset Derivatives						Liability Derivatives
	Balance Sheet Location	December 31, 2019			December 31, 2018			December 31, 2019			December 31, 2018
Derivatives without offsetting agreements	Derivative liabilities	$	—		$	—		$	(399	)	$	(163	)
Derivatives in offsetting agreements:
OTC contracts	Derivative assets (liabilities)	41			158			(39		)	(173		)
Broker cleared derivative contracts	Other current assets (liabilities)	343			402			(350		)	(410		)
		384			560			(788		)	(746		)
Offsetting agreements:
Counterparty netting	Derivative assets (liabilities)	(18		)	(47		)	18			47
Counterparty netting	Other current assets (liabilities)	(318		)	(397		)	318			397
Total net derivatives		$	48		$	116		$	(452	)	$	(302	)

Outstanding Commodity-Related Derivatives

The following table details our outstanding commodity-related derivatives:



	December 31, 2019			December 31, 2018
	Notional Volume		Maturity	Notional Volume		Maturity
Mark-to-Market Derivatives
(Trading)
Natural Gas (BBtu):
Fixed Swaps/Futures	1,483		2020	468		2019
Basis Swaps IFERC/NYMEX⁽¹⁾	(35,208	)	2020-2024	16,845		2019-2020
Options – Puts	—		—	10,000		2019
Power (Megawatt):
Forwards	3,213,450		2020-2029	3,141,520		2019
Futures	(353,527	)	2020	56,656		2019-2021
Options – Puts	51,615		2020	18,400		2019
Options – Calls	(2,704,330	)	2020-2021	284,800		2019
(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(18,923	)	2020-2022	(30,228	)	2019-2021
Swing Swaps IFERC	(9,265	)	2020	54,158		2019-2020
Fixed Swaps/Futures	(3,085	)	2020-2021	(1,068	)	2019-2021
Forward Physical Contracts	(13,364	)	2020-2021	(123,254	)	2019-2020
NGL (MBbls) – Forwards/Swaps	(1,300	)	2020-2021	(2,135	)	2019
Crude (MBbls) – Forwards/Swaps	4,465		2020	20,888		2019
Refined Products (MBbls) – Futures	(2,473	)	2020-2021	(1,403	)	2019
Corn (thousand bushels)	(1,210	)	2020	(1,920	)	2019
Fair Value Hedging Derivatives
(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(31,780	)	2020	(17,445	)	2019
Fixed Swaps/Futures	(31,780	)	2020	(17,445	)	2019
Hedged Item – Inventory	31,780		2020	17,445		2019

⁽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
Term	Type ⁽¹⁾	December 31, 2019		December 31, 2018
March 2019	Pay a floating rate and receive a fixed rate of 1.42%	$	—	$	300
July 2019 ⁽²⁾	Forward-starting to pay a fixed rate of 3.56% and receive a floating rate	—		400
July 2020 ⁽²⁾⁽³⁾	Forward-starting to pay a fixed rate of 3.52% and receive a floating rate	400		400
July 2021 ⁽²⁾	Forward-starting to pay a fixed rate of 3.55% and receive a floating rate	400		400
July 2022 ⁽²⁾	Forward-starting to pay a fixed rate of 3.80% and receive a floating rate	400		—

⁽¹⁾

Floating rates are based on 3-month LIBOR.

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
	December 31, 2019		December 31, 2018		December 31, 2019			December 31, 2018
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	24	$	—	$	—		$	(13	)
	24		—		—			(13		)
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	319		402		(350		)	(397		)
Commodity derivatives	41		158		(39		)	(173		)
Interest rate derivatives	—		—		(399		)	(163		)
	360		560		(788		)	(733		)
Total derivatives	$	384	$	560	$	(788	)	$	(746	)

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

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



	Location of Gain (Loss) Recognized in Income on Derivatives	Amount of Gain (Loss) Recognized in Income Representing Hedge Ineffectiveness and Amount Excluded from the Assessment of Effectiveness
		Years Ended December 31,
		2019		2018			2017
Derivatives in fair value hedging relationships (including hedged item):
Commodity derivatives	Cost of products sold	$	—	$	(3	)	$	26

Derivatives Not Designated as Hedging Instruments [Table Text Block]



	Location of Gain (Loss) Recognized in Income on Derivatives	Amount of Gain (Loss) Recognized in Income on Derivatives
		Years Ended December 31,
		2019			2018			2017
Derivatives not designated as hedging instruments:
Commodity derivatives – Trading	Revenues	$	(3	)	$	—		$	—
Commodity derivatives – Trading	Cost of products sold	21			32			31
Commodity derivatives – Non-trading	Cost of products sold	(78		)	(102		)	5
Interest rate derivatives	Gains (losses) on interest rate derivatives	(241		)	47			(37		)
Embedded derivatives	Other, net	—			—			1
Total		$	(301	)	$	(23	)	$	—

- 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=109980867&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=109980867&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=109980867&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=109980867&loc=SL5579245-113959

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=109980867&loc=d3e41638-113959

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=109980867&loc=d3e41678-113959

Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=109980867&loc=d3e41641-113959

Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4C
-URI http://asc.fasb.org/extlink&oid=109980867&loc=SL5624171-113959

Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n)(2))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 10: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=109980867&loc=SL5579240-113959

+ Details

Retirement Benefits Retirement Benefits (Tables)

12 Months Ended

Dec. 31, 2019

Retirement Benefits [Abstract]

Schedule of Defined Benefit Plans Disclosures [Table Text Block]

Obligations and Funded Status

Pension and other postretirement benefit liabilities are accrued on an actuarial basis during the years an employee provides services.

The following table contains information at the dates indicated about the obligations and funded status of pension and other postretirement plans on a combined basis:



	December 31, 2019									December 31, 2018
	Pension Benefits									Pension Benefits
	Funded Plans			Unfunded Plans			Other Postretirement Benefits			Funded Plans		Unfunded Plans			Other Postretirement Benefits
Change in benefit obligation:
Benefit obligation at beginning of period	$	1		$	37		$	198		$	1	$	47		$	156
Service cost	—			—			1			—		—			1
Interest cost	2			1			7			—		1			5
Amendments	—			—			—			—		—			60
Benefits paid, net	(1		)	(7		)	(16		)	—		(7		)	(17		)
Actuarial (gain) loss and other	4			—			18			—		(4		)	(7		)
Settlements	(4		)	—			—			—		—			—
SemGroup Acquisition	50			3			—			—		—			—
Benefit obligation at end of period	52			34			208			1		37			198

Change in plan assets:
Fair value of plan assets at beginning of period	1			—			241			1		—			257
Return on plan assets and other	6			—			35			—		—			(8		)
Employer contributions	1			—			10			—		—			9
Benefits paid, net	(1		)	—			(16		)	—		—			(17		)
Settlements	(4		)	—			—			—		—			—
SemGroup Acquisition	40			—			—			—		—			—
Fair value of plan assets at end of period	43			—			270			1		—			241

Amount underfunded (overfunded) at end of period	$	9		$	34		$	(62	)	$	—	$	37		$	(43	)

Amounts recognized in the consolidated balance sheets consist of:
Non-current assets	$	—		$	—		$	88		$	—	$	—		$	68
Current liabilities	—			(5		)	(2		)	—		(6		)	(2		)
Non-current liabilities	(9		)	(29		)	(24		)	—		(31		)	(23		)
	$	(9	)	$	(34	)	$	62		$	—	$	(37	)	$	43

Amounts recognized in accumulated other comprehensive income (loss) (pre-tax basis) consist of:
Net actuarial gain (loss)	$	—		$	1		$	(5	)	$	—	$	1		$	(7	)
Prior service cost	—			—			40			—		—			66
	$	—		$	1		$	35		$	—	$	1		$	59

Defined Benefit Plan, Plan with Projected Benefit Obligation in Excess of Plan Assets [Table Text Block]

The following table summarizes information at the dates indicated for plans with an accumulated benefit obligation in excess of plan assets:



	December 31, 2019					December 31, 2018
	Pension Benefits					Pension Benefits
	Funded Plans		Unfunded Plans		Other Postretirement Benefits	Funded Plans		Unfunded Plans		Other Postretirement Benefits
Projected benefit obligation	$	51	$	34	N/A	$	—	$	37	N/A
Accumulated benefit obligation	52		34		208	1		37		198
Fair value of plan assets	43		—		270	1		—		241

Schedule of Health Care Cost Trend Rates [Table Text Block]

The assumed health care cost trend weighted-average rates used to measure the expected cost of benefits covered by the plans are shown in the table below:



	December 31,
	2019		2018
Health care cost trend rate	7.25	%	7.15	%
Rate to which the cost trend is assumed to decline (the ultimate trend rate)	4.83	%	4.82	%
Year that the rate reaches the ultimate trend rate	2026		2024

Fair Value of Plan Assets [Table Text Block]

The fair value of the pension plan assets by asset category at the dates indicated is as follows:



			Fair Value Measurements at December 31, 2019
	Fair Value Total		Level 1		Level 2		Level 3
Asset Category:
Cash and cash equivalents	$	1	$	1	$	—	$	—
Mutual funds ⁽¹⁾	19		19		—		—
Fixed income securities	23		—		23		—
Total	$	43	$	20	$	23	$	—


⁽¹⁾	Comprised of approximately 100% equities as of December 31, 2019.



			Fair Value Measurements at December 31, 2018
	Fair Value Total		Level 1		Level 2		Level 3
Mutual funds ⁽¹⁾	$	1	$	1	$	—	$	—


⁽¹⁾	Comprised of approximately 100% equities as of December 31, 2018.

The fair value of other postretirement plan assets by asset category at the dates indicated is as follows:



			Fair Value Measurements at December 31, 2019
	Fair Value Total		Level 1		Level 2		Level 3
Asset category:
Cash and cash equivalents	$	14	$	14	$	—	$	—
Mutual funds⁽¹⁾	177		177		—		—
Fixed income securities	79		—		79		—
Total	$	270	$	191	$	79	$	—


⁽¹⁾	Primarily comprised of approximately 59% equities, 40% fixed income securities and 1% cash as of December 31, 2019.



			Fair Value Measurements at December 31, 2018
	Fair Value Total		Level 1		Level 2		Level 3
Asset category:
Cash and cash equivalents	$	20	$	20	$	—	$	—
Mutual funds⁽¹⁾	144		144		—		—
Fixed income securities	77		—		77		—
Total	$	241	$	164	$	77	$	—


⁽¹⁾	Primarily comprised of approximately 53% equities, 46% fixed income securities and 1% cash as of December 31, 2018.

Schedule of Expected Benefit Payments [Table Text Block]

Benefit Payments



Years	Pension Benefits - Unfunded Plans ⁽¹⁾		Other Postretirement Benefits (Gross, Before Medicare Part D)
2020	$	7	$	20
2021	8		20
2022	8		19
2023	8		18
2024	7		15
2025 – 2029	22		67

⁽¹⁾ Expected benefit payments of funded pension plans are less than $1 million for the next ten years.

Schedule of Net Benefit Costs [Table Text Block]

Components of Net Periodic Benefit Cost



	December 31, 2019						December 31, 2018
	Pension Benefits			Other Postretirement Benefits			Pension Benefits		Other Postretirement Benefits
Net periodic benefit cost:
Service cost	$	—		$	1		$	—	$	1
Interest cost	3			7			1		5
Expected return on plan assets	(2		)	(10		)	—		(10		)
Prior service cost amortization	—			26			—		16
Net periodic benefit cost	$	1		$	24		$	1	$	12

Defined Benefit Plan, Assumptions [Table Text Block]

The weighted-average assumptions used in determining benefit obligations at the dates indicated are shown in the table below:



	December 31, 2019				December 31, 2018
	Pension Benefits		Other Postretirement Benefits		Pension Benefits		Other Postretirement Benefits
Discount rate	4.00	%	2.71	%	4.02	%	3.40	%
Rate of compensation increase	—		—		N/A		N/A

The weighted-average assumptions used in determining net periodic benefit cost for the periods presented are shown in the table below:



	December 31, 2019				December 31, 2018
	Pension Benefits		Other Postretirement Benefits		Pension Benefits		Other Postretirement Benefits
Discount rate	3.33	%	3.76	%	3.52	%	3.51	%
Expected return on assets:
Tax exempt accounts	3.37	%	7.00	%	3.26	%	6.63	%
Taxable accounts	—		4.75	%	N/A		4.50	%
Rate of compensation increase	—		—		N/A		N/A

Related Party Transactions Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2019

The following table summarizes the revenues from related companies on our consolidated statements of operations:



	Years Ended December 31,
	2019		2018		2017
Affiliated revenues	$	492	$	431	$	303

The following table summarizes the related company accounts receivable and accounts payable balances on our consolidated balance sheets:



	December 31,
	2019		2018
Accounts receivable from related companies:
FGT	$	50	$	25
Phillips 66	36		42
Traverse Rover LLC	42		—
Other	31		44
Total accounts receivable from related companies	$	159	$	111

As of December 31, 2019 and 2018, accounts payable with related companies in the Partnership’s consolidated balance sheets totaled $31 million and $59 million, respectively.

Reportable Segments (Tables)

12 Months Ended

Dec. 31, 2019

Financial Information By Segment

The following tables present financial information by segment:



	Years Ended December 31,
	2019			2018			2017
Revenues:
Intrastate transportation and storage:
Revenues from external customers	$	2,749		$	3,428		$	2,891
Intersegment revenues	350			309			192
	3,099			3,737			3,083
Interstate transportation and storage:
Revenues from external customers	1,941			1,664			1,112
Intersegment revenues	22			18			19
	1,963			1,682			1,131
Midstream:
Revenues from external customers	2,280			2,090			2,510
Intersegment revenues	3,751			5,432			4,433
	6,031			7,522			6,943
NGL and refined products transportation and services:
Revenues from external customers	9,920			10,119			7,885
Intersegment revenues	1,721			1,004			763
	11,641			11,123			8,648
Crude oil transportation and services:
Revenues from external customers	18,447			17,236			11,672
Intersegment revenues	—			96			31
	18,447			17,332			11,703
Investment in Sunoco LP:
Revenues from external customers	16,590			16,982			11,713
Intersegment revenues	6			12			10
	16,596			16,994			11,723
Investment in USAC:
Revenues from external customers	678			495			—
Intersegment revenues	20			13			—
	698			508			—
All other:
Revenues from external customers	1,608			2,073			2,740
Intersegment revenues	81			155			161
	1,689			2,228			2,901
Eliminations	(5,951		)	(7,039		)	(5,609		)
Total revenues	$	54,213		$	54,087		$	40,523



	Years Ended December 31,
	2019			2018			2017
Cost of products sold:
Intrastate transportation and storage	$	1,909		$	2,665		$	2,327
Midstream	3,577			5,145			4,761
NGL and refined products transportation and services	8,393			8,462			6,508
Crude oil transportation and services	14,758			14,439			9,826
Investment in Sunoco LP	15,380			15,872			10,615
Investment in USAC	91			67			—
All other	1,504			2,006			2,509
Eliminations	(5,885		)	(6,998		)	(5,580		)
Total cost of products sold	$	39,727		$	41,658		$	30,966



	Years Ended December 31,
	2019		2018		2017
Depreciation, depletion and amortization:
Intrastate transportation and storage	$	184	$	169	$	147
Interstate transportation and storage	387		334		254
Midstream	1,066		1,006		954
NGL and refined products transportation and services	613		466		401
Crude oil transportation and services	437		445		402
Investment in Sunoco LP	181		167		169
Investment in USAC	231		169		—
All other	48		103		227
Total depreciation, depletion and amortization	$	3,147	$	2,859	$	2,554



	Years Ended December 31,
	2019			2018		2017
Equity in earnings (losses) of unconsolidated affiliates:
Intrastate transportation and storage	$	18		$	19	$	(156	)
Interstate transportation and storage	222			227		236
Midstream	20			26		20
NGL and refined products transportation and services	53			64		33
Crude oil transportation and services	(1		)	6		4
All other	(10		)	2		7
Total equity in earnings of unconsolidated affiliates	$	302		$	344	$	144



	Years Ended December 31,
	2019			2018			2017
Segment Adjusted EBITDA:
Intrastate transportation and storage	$	999		$	927		$	626
Interstate transportation and storage	1,792			1,680			1,274
Midstream	1,602			1,627			1,481
NGL and refined products transportation and services	2,666			1,979			1,641
Crude oil transportation and services	2,972			2,330			1,379
Investment in Sunoco LP	665			638			732
Investment in USAC	420			289			—
All Other	98			40			187
Total Segment Adjusted EBITDA	11,214			9,510			7,320
Depreciation, depletion and amortization	(3,147		)	(2,859		)	(2,554		)
Interest expense, net of interest capitalized	(2,331		)	(2,055		)	(1,922		)
Impairment losses	(74		)	(431		)	(1,039		)
Gains (losses) on interest rate derivatives	(241		)	47			(37		)
Non-cash compensation expense	(113		)	(105		)	(99		)
Unrealized gains (losses) on commodity risk management activities	(5		)	(11		)	59
Inventory valuation adjustments	79			(85		)	24
Losses on extinguishments of debt	(18		)	(112		)	(89		)
Adjusted EBITDA related to unconsolidated affiliates	(626		)	(655		)	(716		)
Equity in earnings of unconsolidated affiliates	302			344			144
Impairment of investments in unconsolidated affiliates	—			—			(313		)
Adjusted EBITDA related to discontinued operations	—			25			(223		)
Other, net	54			21			155
Income from continuing operations before income tax (expense) benefit	5,094			3,634			710
Income tax (expense) benefit from continuing operations	(195		)	(4		)	1,833
Income from continuing operations	4,899			3,630			2,543
Loss from discontinued operations, net of income taxes	—			(265		)	(177		)
Net income	$	4,899		$	3,365		$	2,366



	December 31,
	2019		2018		2017
Segment assets:
Intrastate transportation and storage	$	6,648	$	6,365	$	5,020
Interstate transportation and storage	18,111		15,081		15,316
Midstream	20,332		19,745		20,004
NGL and refined products transportation and services	19,145		18,267		17,600
Crude oil transportation and services	22,840		18,022		17,730
Investment in Sunoco LP	5,438		4,879		8,344
Investment in USAC	3,730		3,775		—
All other and eliminations	2,636		2,112		2,232
Total segment assets	$	98,880	$	88,246	$	86,246



	Years Ended December 31,
	2019		2018		2017
Additions to property, plant and equipment ⁽¹⁾:
Intrastate transportation and storage	$	124	$	344	$	175
Interstate transportation and storage	375		812		728
Midstream	827		1,161		1,308
NGL and refined products transportation and services	2,976		2,381		2,971
Crude oil transportation and services	403		474		453
Investment in Sunoco LP	148		103		103
Investment in USAC	200		205		—
All other	215		150		268
Total additions to property, plant and equipment ⁽¹⁾	$	5,268	$	5,630	$	6,006


⁽¹⁾	Excluding acquisitions, net of contributions in aid of construction costs (capital expenditures related to the Partnership’s proportionate ownership on an accrual basis).



	December 31,
	2019		2018		2017
Advances to and investments in affiliates:
Intrastate transportation and storage	$	88	$	83	$	85
Interstate transportation and storage	2,524		2,070		2,118
Midstream	112		124		126
NGL and refined products transportation and services	461		243		234
Crude oil transportation and services	242		28		22
All other	33		94		120
Total advances to and investments in affiliates	$	3,460	$	2,642	$	2,705

Quarterly Financial Data (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2019

Quarterly Financial Information Disclosure [Abstract]

Schedule of Quarterly Financial Information



	Quarters Ended
	March 31		June 30		September 30		December 31		Total Year
2019:
Revenues	$	13,121	$	13,877	$	13,495	$	13,720	$	54,213
Operating income	1,927		1,819		1,830		1,701		7,277
Net income	1,180		1,208		1,161		1,350		4,899
Limited Partners’ interest in net income	869		877		831		1,011		3,588
Income from continuing operations per limited partner unit:
Basic	$	0.33	$	0.33	$	0.32	$	0.38	$	1.37
Diluted	$	0.33	$	0.33	$	0.32	$	0.38	$	1.36
Net income per limited partner unit:
Basic	$	0.33	$	0.33	$	0.32	$	0.38	$	1.37
Diluted	$	0.33	$	0.33	$	0.32	$	0.38	$	1.36



	Quarters Ended
	March 31		June 30		September 30		December 31		Total Year
2018:
Revenues	$	11,882	$	14,118	$	14,514	$	13,573	$	54,087
Operating income	1,100		1,126		1,703		1,419		5,348
Income from continuing operations	726		659		1,393		852		3,630
Net income	489		633		1,391		852		3,365
Limited Partners’ interest in net income	341		330		370		617		1,658
Income from continuing operations per limited partner unit:
Basic	$	0.32	$	0.30	$	0.32	$	0.26	$	1.17
Diluted	$	0.32	$	0.30	$	0.32	$	0.26	$	1.16
Net income per limited partner unit:
Basic	$	0.31	$	0.30	$	0.32	$	0.26	$	1.16
Diluted	$	0.31	$	0.30	$	0.32	$	0.26	$	1.15

Operations And Organization (Narrative) (Details)	1 Months Ended	3 Months Ended	12 Months Ended
Operations And Organization (Narrative) (Details)	Oct. 31, 2018 shares	Dec. 31, 2018 shares	Dec. 31, 2019 shares	Jul. 30, 2019 shares
Limited Partner interest in the Partnership, percentage			99.90%
Sunoco LP [Member]
Incentive Distribution Rights			100.00%
Number of common units of a subsidiary partnership that are held by a wholly-owned subsidiary of the Parent.			28,500,000
USAC [Member]
Number of common units of a subsidiary partnership that are held by a wholly-owned subsidiary of the Parent.		39,700,000		46,100,000
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest			100.00%
ETE Merger [Member]
Sale of Stock, Number of Shares Issued in Transaction	1,460,000,000
Stockholders' Equity Note, Stock Split, Conversion Ratio	1.28
ETE Merger [Member] \| Sunoco LP [Member]
Sale of Stock, Number of Shares Issued in Transaction	2,263,158	2,263,158
ETE Merger [Member] \| Sunoco GP [Member]
Limited Partner interest in the Partnership, percentage	100.00%	100.00%
ETE Merger [Member] \| USAC [Member]
Sale of Stock, Number of Shares Issued in Transaction	12,466,912	12,466,912
Limited Partner interest in the Partnership, percentage	100.00%	100.00%
ETE Merger [Member] \| Lake Charles LNG [Member]
Limited Partner interest in the Partnership, percentage	100.00%	100.00%
ETE Merger [Member] \| Energy Transfer LNG Export LLC, ET Crude Oil Terminals LLC, & ETC Illinois LLC [Member]
Limited Partner interest in the Partnership, percentage	60.00%	60.00%
IDRs [Member] \| ETE Merger [Member]
Sale of Stock, Number of Shares Issued in Transaction	1,168,205,710
General Partner [Member] \| ETE Merger [Member]
Sale of Stock, Number of Shares Issued in Transaction	18,448,341
ETO [Member] \| ETE Merger [Member] \| Sunoco LP [Member]
Sale of Stock, Number of Shares Issued in Transaction	2,874,275	2,874,275
ETO [Member] \| ETE Merger [Member] \| Sunoco GP [Member]
Sale of Stock, Number of Shares Issued in Transaction	42,812,389	42,812,389
ETO [Member] \| ETE Merger [Member] \| USAC [Member]
Sale of Stock, Number of Shares Issued in Transaction	16,134,903	16,134,903
ETO [Member] \| ETE Merger [Member] \| Lake Charles LNG [Member]
Sale of Stock, Number of Shares Issued in Transaction	37,557,815	37,557,815

Estimates, Significant Accounting Policies and Balance Sheet Detail (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended			12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jan. 01, 2019
Impairment losses				$ 74	$ 431	$ 1,039
Operating Lease, Liability				961
Operating Lease, Right-of-Use Asset		$ 0		1,000	0		$ 889
Asset Retirement Obligation		193		247	193
Costs Incurred, Asset Retirement Obligation Incurred				5	13	9
Tangible Asset Impairment Charges				9	127
Asset Retirement Obligation, Legally Restricted Assets, Fair Value		26		31	26
Long-term Debt, Fair Value		45,060		54,790	45,060
Impairment losses	$ (12)	(9)		(21)	(378)
Goodwill acquired				307	495
Goodwill		4,885	$ 4,768	5,167	4,885	4,768
Long-term Debt		46,028		51,054	46,028
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net				0
Midstream [Member]
Impairment losses		378		(9)	(378)
Goodwill acquired				0	0
Goodwill		492	870	483	492	870
Other Segments [Member]
Impairment losses			(452)	0	0
Goodwill acquired				35	0
Goodwill		149	402	184	149	402
Investment In Sunoco LP [Member]
Impairment losses			(387)	0	0
Goodwill acquired				0	129
Goodwill		1,559	1,430	1,555	1,559	1,430
Retail Marketing [Member]
Excise Taxes Collected				386	370	$ 234
Sunoco LP [Member]
Impairment losses				47
Inventory Write-down					85
Long-term Debt		2,984		3,071	$ 2,984
USAC [Member]
Impairment losses				6
SemGroup [Member]
Goodwill acquired				265
Fair value exceeding carrying value by less than 20% [Member]
Goodwill				380
Customer relationships, contracts and agreements (3 to 46 years)
Impairment of Intangible Assets (Excluding Goodwill)		$ 30		$ 17
Continuing Operations [Member] \| Investment In Sunoco LP [Member]
Impairment losses			$ (102)

Estimates, Significant Accounting Policies and Balance Sheet Detail Estimates (Schedule of Accounting Change) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jan. 01, 2019
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Other current assets	$ 275	$ 350
Increase (Decrease) in Operating Capital	(518)	289	$ (192)
Inventories	1,935	1,677
Noncontrolling interests	12,018	10,291
Property, Plant and Equipment, Net	74,193	66,963		$ 66,962
Intangible assets, net	6,154	6,000
Other non-current assets, net	1,075	1,006
Other non-current liabilities	1,162	1,184		1,172
Cost of Goods and Services Sold	39,727	41,658	30,966
Operating expenses	3,294	3,089	2,644
Depreciation, depletion and amortization	3,147	2,859	2,554
Operating Lease, Right-of-Use Asset	1,000	0		889
Operating Lease, Liability, Current	60	0		71
Accrued and other current liabilities	3,342	2,918		2,917
Current maturities of long-term debt	26	2,655		2,656
Long-term debt, less current maturities	51,028	43,373		43,379
Operating Lease, Liability, Noncurrent	901	0		823
Natural gas sales
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	3,295	4,452	4,172
NGL sales
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	8,290	9,986	7,781
Crude sales
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	15,917	14,425	10,706
Gathering, transportation and other fees
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	9,086	6,797	4,435
Refined product sales
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	16,752	17,458	11,166
Other
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	$ 873	$ 969	$ 2,263
Accounting Standards Update 2016-02 [Member]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Property, Plant and Equipment, Net				(1)
Other non-current liabilities				(12)
Operating Lease, Right-of-Use Asset				889
Operating Lease, Liability, Current				71
Accrued and other current liabilities				(1)
Current maturities of long-term debt				1
Long-term debt, less current maturities				6
Operating Lease, Liability, Noncurrent				$ 823

Estimates (Schedule Of Net Changes In Operating Assets And Liabilities Included Cash Flows From Operating Activities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Accounting Policies [Abstract]
Accounts receivable	$ (473)	$ 541	$ (948)
Accounts receivable from related companies	(69)	162	24
Inventories	(117)	282	58
Other current assets	(117)	(7)	(38)
Other non-current assets, net	(78)	(92)	84
Accounts payable	146	(766)	712
Accounts payable to related companies	(32)	(202)	(178)
Accrued and other current liabilities	(44)	382	(97)
Other non-current liabilities	(186)	28	106
Derivative assets and liabilities, net	218	(53)	9
Net change in operating assets and liabilities, net of effects of acquisitions	$ (518)	$ 289	$ (192)

Estimates (Schedule Of Non-Cash Investing And Financing Activities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures	$ 1,334	$ 1,030	$ 1,060
Right-of-Use Assets Obtained in Exchange for Liabilities	68	0	0
Right-of-Use Asset Obtained in Exchange for Finance Lease Liability	28
Contribution of assets from noncontrolling interests	0	0	988
Net losses from subsidiary common unit transactions	0	(126)	(56)
SUPPLEMENTAL CASH FLOW INFORMATION:
Cash paid for interest, net of interest capitalized	1,932	1,870	1,914
Cash paid for income taxes	$ 31	$ 508	$ 50

Estimates (Schedule of Inventory) (Details) - USD ($)
$ in Millions

Dec. 31, 2019

Dec. 31, 2018

Inventory, Net [Abstract]

Natural gas, NGLs and refined products (1)

^[1]

$ 833

Crude oil

654

506

Spare parts and other

448

338

Total inventories

$ 1,935

$ 1,677

[1]	Due to changes in fuel prices, Sunoco LP recorded a write-down on the value of its fuel inventory of $85 million as of December 31, 2018.

Estimates (Other Current Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Other Information [Abstract]
Deposits paid to vendors	$ 95	$ 141
Prepaid expenses and other	180	209
Total other current assets	$ 275	$ 350

Estimates (Property, Plant and Equipment) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Jan. 01, 2019	Dec. 31, 2018
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	$ 89,790		$ 79,776
Less - Accumulated depreciation	(15,597)		(12,813)
Property, Plant and Equipment, Net	74,193	$ 66,962	66,963
Land and Land Improvements [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	1,264		1,168
Building and Building Improvements [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	2,632		2,664
Pipelines [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	64,678		58,783
Natural gas and NGL storage facilities (5 to 46 years)
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	5,898		4,978
Right Of Way [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	4,859		4,533
Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	1,964		1,583
Construction Work-In-Process [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	$ 8,495		$ 6,067

Estimates (Schedule Of Property, Plant And Equipment Depreciation And Capitalized Interest Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization expense	$ 2,839	$ 2,538	$ 2,204
Capitalized interest	$ 166	$ 294	$ 286

Estimates (Schedule of Other Non-Current Assets, net) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Accounting Policies [Abstract]
Regulatory assets	$ 42	$ 43
Defined Benefit Plan, Pension Plan with Projected Benefit Obligation in Excess of Plan Assets, Plan Assets	84	68
Deferred charges	178	173
Restricted funds	178	178
Other	593	544
Total other non-current assets, net	$ 1,075	$ 1,006

Estimates (Components Of Intangibles And Other Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Gross Carrying Amount	$ 7,975	$ 7,560
Accumulated Amortization	(1,821)	(1,560)
Customer relationships, contracts and agreements (3 to 46 years)
Gross Carrying Amount	7,535	7,106
Accumulated Amortization	(1,743)	(1,493)
Patents (10 years)
Gross Carrying Amount	48	48
Accumulated Amortization	(35)	(30)
Trade names (20 years)
Gross Carrying Amount	66	66
Accumulated Amortization	(31)	(28)
Total Amortizable Intangible Assets [Member]
Gross Carrying Amount	7,668	7,253
Accumulated Amortization	(1,821)	(1,560)
Trademarks [Member]
Gross Carrying Amount	295	295
Accumulated Amortization	0	0
Other non-amortizable intangible assets [Member]
Gross Carrying Amount	12	12
Accumulated Amortization	0	0
Other Amortizable Intangible Assets [Member]
Gross Carrying Amount	19	33
Accumulated Amortization	(12)	(9)
Non-amortizable intangible assets [Member]
Gross Carrying Amount	307	307
Accumulated Amortization	$ 0	$ 0

Estimates, Significant Accounting Policies and Balance Sheet Detail Estimates (Schedule of Useful Lives) (Details) (Details)	12 Months Ended
	Dec. 31, 2019
Minimum [Member] \| Customer relationships, contracts and agreements (3 to 46 years)
Intangible assets, useful life, minimum (years)	3 years
Minimum [Member] \| Other (5 to 20 years)
Intangible assets, useful life, minimum (years)	5 years
Maximum [Member] \| Customer relationships, contracts and agreements (3 to 46 years)
Intangible assets, useful life, minimum (years)	46 years
Maximum [Member] \| Patents (10 years)
Intangible assets, useful life, minimum (years)	20 years
Maximum [Member] \| Trade names (20 years)
Intangible assets, useful life, minimum (years)	10 years
Maximum [Member] \| Other (5 to 20 years)
Intangible assets, useful life, minimum (years)	20 years
Buildings and improvements [Member] \| Minimum [Member]
Property, plant and equipment, useful life, minimum (years)	1 year
Buildings and improvements [Member] \| Maximum [Member]
Property, plant and equipment, useful life, minimum (years)	45 years
Pipelines And Equipment [Member] \| Minimum [Member]
Property, plant and equipment, useful life, minimum (years)	5 years
Pipelines And Equipment [Member] \| Maximum [Member]
Property, plant and equipment, useful life, minimum (years)	83 years
Natural gas and NGL storage facilities (5 to 46 years) \| Minimum [Member]
Property, plant and equipment, useful life, minimum (years)	2 years
Natural gas and NGL storage facilities (5 to 46 years) \| Maximum [Member]
Property, plant and equipment, useful life, minimum (years)	83 years
Right Of Way [Member] \| Minimum [Member]
Property, plant and equipment, useful life, minimum (years)	20 years
Right Of Way [Member] \| Maximum [Member]
Property, plant and equipment, useful life, minimum (years)	83 years
Property, Plant and Equipment, Other Types [Member] \| Minimum [Member]
Property, plant and equipment, useful life, minimum (years)	1 year
Property, Plant and Equipment, Other Types [Member] \| Maximum [Member]
Property, plant and equipment, useful life, minimum (years)	48 years

Estimates (Aggregate Amortization Expense Of Intangibles And Other Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Depreciation And Amortization [Member]
Reported in depreciation and amortization	$ 308	$ 321	$ 344

Estimates (Estimated Aggregate Amortization Expense) (Details) $ in Millions	Dec. 31, 2019 USD ($)
Goodwill and Intangible Assets Disclosure [Abstract]
2019	$ 394
2020	390
2021	360
2022	320
2023	$ 307

Estimates (Schedule Of Goodwill) (Details) - USD ($) $ in Millions	3 Months Ended			12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Goodwill [Roll Forward]
Goodwill				$ 4,885	$ 4,768
Goodwill acquired				307	495
Goodwill, Transfers					0
Goodwill		$ 4,885	$ 4,768	5,167	4,885
Goodwill impairment	$ (12)	(9)		(21)	(378)
Goodwill, Other Changes				(4)	0
Intrastate Transportation And Storage [Member]
Goodwill [Roll Forward]
Goodwill				10	10
Goodwill acquired				0	0
Goodwill, Transfers					0
Goodwill		10	10	10	10
Goodwill impairment				0	0
Goodwill, Other Changes				0	0
Interstate Transportation and Storage [Member]
Goodwill [Roll Forward]
Goodwill				196	196
Goodwill acquired				42	0
Goodwill, Transfers					0
Goodwill		196	196	226	196
Goodwill impairment			(262)	(12)	0
Goodwill, Other Changes				0	0
Midstream [Member]
Goodwill [Roll Forward]
Goodwill				492	870
Goodwill acquired				0	0
Goodwill, Transfers					0
Goodwill		492	870	483	492
Goodwill impairment		378		(9)	(378)
Goodwill, Other Changes				0	0
NGL and refined products transportation and services [Member]
Goodwill [Roll Forward]
Goodwill				693	693
Goodwill acquired				0	0
Goodwill, Transfers					0
Goodwill		693	693	693	693
Goodwill impairment			(79)	0	0
Goodwill, Other Changes				0	0
Crude oil transportation and services [Member]
Goodwill [Roll Forward]
Goodwill				1,167	1,167
Goodwill acquired				230	0
Goodwill, Transfers					0
Goodwill		1,167	1,167	1,397	1,167
Goodwill impairment				0	0
Goodwill, Other Changes				0	0
Investment In Sunoco LP [Member]
Goodwill [Roll Forward]
Goodwill				1,559	1,430
Goodwill acquired				0	129
Goodwill, Transfers					0
Goodwill		1,559	1,430	1,555	1,559
Goodwill impairment			(387)	0	0
Goodwill, Other Changes				(4)	0
Investment In USAC [Member]
Goodwill [Roll Forward]
Goodwill				619	0
Goodwill acquired				0	366
Goodwill, Transfers					253
Goodwill		619	0	619	619
Goodwill impairment				0	0
Goodwill, Other Changes				0	0
Other Segments [Member]
Goodwill [Roll Forward]
Goodwill				149	402
Goodwill acquired				35	0
Goodwill, Transfers					(253)
Goodwill		$ 149	402	184	149
Goodwill impairment			$ (452)	0	0
Goodwill, Other Changes				$ 0	$ 0

Estimates (Accrued And Other Current Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Jan. 01, 2019	Dec. 31, 2018
Other Information [Abstract]
Interest payable	$ 579		$ 571
Customer advances and deposits	123		128
Accrued capital expenditures	1,334		1,030
Accrued wages and benefits	217		283
Taxes payable other than income taxes	263		256
Exchanges payable	67		112
Other	759		538
Accrued and other current liabilities	$ 3,342	$ 2,917	$ 2,918

Estimates (Fair Value Of Financial Assets And Liabilities Measured On Recurring Basis) (Details) - Fair Value, Recurring [Member] - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Commodity derivatives:	$ 384	$ 560
Other Assets, Fair Value Disclosure	31	26
Total assets	415	586
Interest rate derivatives	(399)	(163)
Commodity derivatives:	(389)	(583)
Financial and Nonfinancial Liabilities, Fair Value Disclosure	788	746
Level 1 [Member]
Commodity derivatives:	369	448
Other Assets, Fair Value Disclosure	20	17
Total assets	389	465
Interest rate derivatives	0	0
Commodity derivatives:	(383)	(480)
Financial and Nonfinancial Liabilities, Fair Value Disclosure	383	480
Level 2 [Member]
Commodity derivatives:	15	112
Other Assets, Fair Value Disclosure	11	9
Total assets	26	121
Interest rate derivatives	(399)	(163)
Commodity derivatives:	(6)	(103)
Financial and Nonfinancial Liabilities, Fair Value Disclosure	405	266
Commodity Derivatives - Power [Member] \| Options - Calls [Member]
Commodity derivatives:	1	1
Commodity Derivatives - Power [Member] \| Forwards Swaps [Member]
Commodity derivatives:	11	48
Commodity derivatives:	(5)	(42)
Commodity Derivatives - Power [Member] \| Future [Member]
Commodity derivatives:	4	1
Commodity derivatives:	(3)	(1)
Commodity Derivatives - Power [Member] \| Options - Puts [Member]
Commodity derivatives:	1
Commodity Derivatives - Power [Member] \| Level 1 [Member] \| Options - Calls [Member]
Commodity derivatives:	1	1
Commodity Derivatives - Power [Member] \| Level 1 [Member] \| Forwards Swaps [Member]
Commodity derivatives:	0	0
Commodity derivatives:	0	0
Commodity Derivatives - Power [Member] \| Level 1 [Member] \| Future [Member]
Commodity derivatives:	4	1
Commodity derivatives:	(3)	(1)
Commodity Derivatives - Power [Member] \| Level 1 [Member] \| Options - Puts [Member]
Commodity derivatives:	1
Commodity Derivatives - Power [Member] \| Level 2 [Member] \| Options - Calls [Member]
Commodity derivatives:	0	0
Commodity Derivatives - Power [Member] \| Level 2 [Member] \| Forwards Swaps [Member]
Commodity derivatives:	11	48
Commodity derivatives:	(5)	(42)
Commodity Derivatives - Power [Member] \| Level 2 [Member] \| Future [Member]
Commodity derivatives:	0	0
Commodity derivatives:	0	0
Commodity Derivatives - Power [Member] \| Level 2 [Member] \| Options - Puts [Member]
Commodity derivatives:	0
Commodity Derivatives - Refined Products [Member] \| Future [Member]
Commodity derivatives:	8	7
Commodity derivatives:	(10)	(15)
Commodity Derivatives - Refined Products [Member] \| Level 1 [Member] \| Future [Member]
Commodity derivatives:	8	7
Commodity derivatives:	(10)	(15)
Commodity Derivatives - Refined Products [Member] \| Level 2 [Member] \| Future [Member]
Commodity derivatives:	0	0
Commodity derivatives:	0	0
Commodity Derivatives - Crude [Member] \| Forwards Swaps [Member]
Commodity derivatives:	13	1
Commodity Derivatives - Crude [Member] \| Future [Member]
Commodity derivatives:		(61)
Commodity Derivatives - Crude [Member] \| Level 1 [Member] \| Forwards Swaps [Member]
Commodity derivatives:	13	1
Commodity Derivatives - Crude [Member] \| Level 1 [Member] \| Future [Member]
Commodity derivatives:		(61)
Commodity Derivatives - Crude [Member] \| Level 2 [Member] \| Forwards Swaps [Member]
Commodity derivatives:	0	0
Commodity Derivatives - Crude [Member] \| Level 2 [Member] \| Future [Member]
Commodity derivatives:		0
Commodity Derivatives - Natural Gas [Member] \| Basis Swaps IFERC NYMEX [Member]
Commodity derivatives:	17	42
Commodity derivatives:	(49)	(91)
Commodity Derivatives - Natural Gas [Member] \| Swing Swaps IFERC [Member]
Commodity derivatives:	1	52
Commodity derivatives:	(1)	(40)
Commodity Derivatives - Natural Gas [Member] \| Fixed Swaps/Futures [Member]
Commodity derivatives:	65	97
Commodity derivatives:	(43)	(88)
Commodity Derivatives - Natural Gas [Member] \| Forward Physical Contracts [Member]
Commodity derivatives:		(21)
Commodity Derivatives - Natural Gas [Member] \| Forward Physical Swaps [Member]
Commodity derivatives:	3	20
Commodity Derivatives - Natural Gas [Member] \| Level 1 [Member] \| Basis Swaps IFERC NYMEX [Member]
Commodity derivatives:	17	42
Commodity derivatives:	(49)	(91)
Commodity Derivatives - Natural Gas [Member] \| Level 1 [Member] \| Swing Swaps IFERC [Member]
Commodity derivatives:	0	8
Commodity derivatives:	0	0
Commodity Derivatives - Natural Gas [Member] \| Level 1 [Member] \| Fixed Swaps/Futures [Member]
Commodity derivatives:	65	97
Commodity derivatives:	(43)	(88)
Commodity Derivatives - Natural Gas [Member] \| Level 1 [Member] \| Forward Physical Contracts [Member]
Commodity derivatives:		0
Commodity Derivatives - Natural Gas [Member] \| Level 1 [Member] \| Forward Physical Swaps [Member]
Commodity derivatives:	0	0
Commodity Derivatives - Natural Gas [Member] \| Level 2 [Member] \| Basis Swaps IFERC NYMEX [Member]
Commodity derivatives:	0	0
Commodity derivatives:	0	0
Commodity Derivatives - Natural Gas [Member] \| Level 2 [Member] \| Swing Swaps IFERC [Member]
Commodity derivatives:	1	44
Commodity derivatives:	(1)	(40)
Commodity Derivatives - Natural Gas [Member] \| Level 2 [Member] \| Fixed Swaps/Futures [Member]
Commodity derivatives:	0	0
Commodity derivatives:	0	0
Commodity Derivatives - Natural Gas [Member] \| Level 2 [Member] \| Forward Physical Contracts [Member]
Commodity derivatives:		(21)
Commodity Derivatives - Natural Gas [Member] \| Level 2 [Member] \| Forward Physical Swaps [Member]
Commodity derivatives:	3	20
Commodity Derivatives - NGLs [Member] \| Forwards Swaps [Member]
Commodity derivatives:	260	291
Commodity derivatives:	(278)	(224)
Commodity Derivatives - NGLs [Member] \| Level 1 [Member] \| Forwards Swaps [Member]
Commodity derivatives:	260	291
Commodity derivatives:	(278)	(224)
Commodity Derivatives - NGLs [Member] \| Level 2 [Member] \| Forwards Swaps [Member]
Commodity derivatives:	0	0
Commodity derivatives:	$ 0	$ 0

Acquisitions and Related Transactions Acquisitions (2019 Transactions) (Details) - USD ($)

Dec. 05, 2019

Dec. 31, 2019

Dec. 31, 2018

Business Acquisition [Line Items]

Long-term Debt

$ 51,054,000,000

$ 46,028,000,000

SemGroup [Member]

Business Acquisition [Line Items]

Senior Notes

$ 1,375,000,000

Preferred Stock, No Par Value

$ 0.01

Business Acquisition, Share Price

$ 6.80

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets

$ 794,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment

3,914,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets

623,000,000

Business Acquisition, Purchase Price Allocation, Goodwill Expected to be Not Tax Deductible, Amount

^[1]

265,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill

460,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets

6,056,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities

629,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt

^[2]

2,576,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other

196,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Financial Liabilities

241,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities

3,642,000,000

Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest

822,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net

^[3]

1,592,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents

^[4]

153,000,000

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net

$ 1,439,000,000

Conversion of Stock, Shares Issued

0.7275

SemGroup Subsidiary [Member] | SemGroup [Member]

Business Acquisition [Line Items]

Long-term Debt

$ 593,000,000

[1]	None of the goodwill is expected to be deductible for tax purposes. Goodwill recognized from the business combination primarily relates to the value attributed to additional growth opportunities, synergies and operating leverage within SemGroup’s operations.
[2]	Long-term debt at December 5, 2019 includes SemGroup senior notes with an aggregate principal amount of $1.375 billion and SemGroup subsidiary debt of $593 million, all of which were redeemed in total in December 2019, subsequent to the close of the SemGroup Transaction, utilizing proceeds from an intercompany promissory note from ETO.
[3]	Total consideration includes (i) cash paid to SemGroup shareholders, (ii) fair value of ET Common Units issued in the acquisition and (iii) cash paid to redeem SemGroup’s preferred shares
[4]	Cash received represents cash and cash equivalents held by SemGroup as of the acquisition date.

Acquisitions and Related Transactions Acquisitions (2018 Transactions) (Details) gal in Millions, $ in Millions	1 Months Ended			3 Months Ended								12 Months Ended
	Oct. 31, 2018 shares	Apr. 30, 2018 USD ($) shares	Jan. 22, 2018 USD ($)	Dec. 31, 2019 USD ($)	Sep. 30, 2019 USD ($)	Jun. 30, 2019 USD ($)	Mar. 31, 2019 USD ($)	Dec. 31, 2018 USD ($) shares	Sep. 30, 2018 USD ($)	Jun. 30, 2018 USD ($)	Mar. 31, 2018 USD ($)	Dec. 31, 2019 USD ($) shares gal	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)
Business Acquisition [Line Items]
Impairment losses \| $					$ (12)			$ (9)				$ (21)	$ (378)
Limited Partner interest in the Partnership, percentage												99.90%
Long-term Purchase Commitment, Minimum Volume Required \| gal												2,000
Revenues \| $				$ 13,720	$ 13,495	$ 13,877	$ 13,121	$ 13,573	$ 14,514	$ 14,118	$ 11,882	$ 54,213	54,087	$ 40,523
ETE Merger [Member]
Business Acquisition [Line Items]
Sale of Stock, Number of Shares Issued in Transaction	1,460,000,000
USAC Transaction [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred \| $		$ 1,700
Payments to Acquire Businesses, Gross \| $		$ 1,230
7-Eleven [Member]
Business Acquisition [Line Items]
Revenues \| $			$ 199										3,200
Trade Receivables Held-for-sale, Reconciliation to Cash Flow, Period Increase (Decrease) \| $												$ 3,700	$ 3,400
Sunoco LP [Member] \| ETE Merger [Member]
Business Acquisition [Line Items]
Sale of Stock, Number of Shares Issued in Transaction	2,263,158							2,263,158
USA Compression Partners, LP [Member] \| USAC Transaction [Member]
Business Acquisition [Line Items]
Sale of Stock, Number of Shares Issued in Transaction		19,191,351
USA Compression Partners, LP [Member] \| USAC Transaction [Member] \| Class B Units [Member]
Business Acquisition [Line Items]
Sale of Stock, Number of Shares Issued in Transaction												6,397,965
Sunoco GP [Member] \| ETE Merger [Member]
Business Acquisition [Line Items]
Limited Partner interest in the Partnership, percentage	100.00%							100.00%
USAC [Member] \| ETE Merger [Member]
Business Acquisition [Line Items]
Sale of Stock, Number of Shares Issued in Transaction	12,466,912							12,466,912
Limited Partner interest in the Partnership, percentage	100.00%							100.00%
Lake Charles LNG [Member] \| ETE Merger [Member]
Business Acquisition [Line Items]
Limited Partner interest in the Partnership, percentage	100.00%							100.00%
Energy Transfer LNG Export LLC, ET Crude Oil Terminals LLC, & ETC Illinois LLC [Member] \| ETE Merger [Member]
Business Acquisition [Line Items]
Limited Partner interest in the Partnership, percentage	60.00%							60.00%
ETO [Member] \| Sunoco LP [Member] \| ETE Merger [Member]
Business Acquisition [Line Items]
Sale of Stock, Number of Shares Issued in Transaction	2,874,275							2,874,275
ETO [Member] \| Sunoco GP [Member] \| ETE Merger [Member]
Business Acquisition [Line Items]
Sale of Stock, Number of Shares Issued in Transaction	42,812,389							42,812,389
ETO [Member] \| USAC [Member] \| ETE Merger [Member]
Business Acquisition [Line Items]
Sale of Stock, Number of Shares Issued in Transaction	16,134,903							16,134,903
ETO [Member] \| Lake Charles LNG [Member] \| ETE Merger [Member]
Business Acquisition [Line Items]
Sale of Stock, Number of Shares Issued in Transaction	37,557,815							37,557,815
ET [Member] \| USA Compression Partners, LP [Member] \| USAC Transaction [Member]
Business Acquisition [Line Items]
Sale of Stock, Number of Shares Issued in Transaction		12,466,912
Equity Issued in Business Combination, Fair Value Disclosure \| $		$ 250
USAC GP [Member] \| USA Compression Partners, LP [Member]
Business Acquisition [Line Items]
Sale of Stock, Number of Shares Issued in Transaction		8,000,000
Additional aggregate volumes [Member]
Business Acquisition [Line Items]
Long-term Purchase Commitment, Minimum Volume Required \| gal												500

Acquisitions and Related Transactions Acquisitions (2017 Transactions) (Details) - USD ($) $ in Millions	1 Months Ended			12 Months Ended
	Oct. 31, 2017	Jul. 31, 2017	Feb. 28, 2017	Dec. 31, 2019	Jan. 01, 2019	Dec. 31, 2018	Feb. 01, 2017
Business Acquisition [Line Items]
Noncontrolling Interest, Increase from Sale of Parent Equity Interest		$ 988		$ 93
Intangible assets, net				6,154		$ 6,000
Property, Plant and Equipment, Net				$ 74,193	$ 66,962	$ 66,963
ETO [Member] \| Rover Contribution [Member]
Business Acquisition [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	50.10%
ETO [Member] \| Holdco [Member] \| Rover Contribution [Member]
Business Acquisition [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest		49.90%
Permian Express Partners LLC [Member]
Business Acquisition [Line Items]
Percent of total equity ownership of a subsidiary		88.00%
Intangible assets, net							$ 547
Property, Plant and Equipment, Net							$ 435
Holdco [Member] \| Rover Pipeline LLC [Member] \| Rover Contribution [Member]
Business Acquisition [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest		65.00%
Blackstone [Member] \| Rover Contribution [Member]
Business Acquisition [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	49.90%
Dakota Access and ETCOC [Member]
Business Acquisition [Line Items]
Percent of total equity ownership of a subsidiary		15.00%
Phillips 66 Company [Member] \| Dakota Access and ETCOC [Member]
Business Acquisition [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest			25.00%
Bakken Holdings Company LLC [Member] \| ETO [Member]
Business Acquisition [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest			100.00%
Bakken Holdings Company LLC [Member] \| Sunoco Logistics [Member]
Business Acquisition [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest			49.00%
Bakken Holdings Company LLC [Member] \| Bakken Pipeline Investments LLC [Member]
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired							200000000000.00%
Bakken Pipeline Investments LLC [Member] \| Dakota Access and ETCOC [Member]
Business Acquisition [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest			75.00%

Acquisitions (Schedule Of Assets Acquired And Liabilities Assumed In Acquisition Table) (Details) - USD ($)
$ in Millions

1 Months Ended

Dec. 05, 2019

Apr. 30, 2018

SemGroup [Member]

Business Acquisition [Line Items]

Current assets

$ 794

Property, plant and equipment

3,914

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets

623

Goodwill(1)

^[1]

265

Intangible assets

460

Total assets acquired

6,056

Current liabilities

629

Long-term debt obligations, less current maturities

^[2]

2,576

Other non-current liabilities

196

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Financial Liabilities

241

Total liabilities assumed

3,642

Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest

822

Total consideration

^[3]

1,592

Cash received

^[4]

153

Total consideration, net of cash received

$ 1,439

USA Compression Partners, LP [Member]

Business Acquisition [Line Items]

Current assets

$ 786

Property, plant and equipment

1,332

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Assets

Goodwill(1)

^[5]

366

Intangible assets

222

Total assets acquired

2,721

Current liabilities

110

Long-term debt obligations, less current maturities

1,527

Other non-current liabilities

Noncontrolling interest

832

Total liabilities assumed

1,639

Total consideration

250

Cash received

^[6]

711

Total consideration, net of cash received

^[6]

$ (461)

[1]	None of the goodwill is expected to be deductible for tax purposes. Goodwill recognized from the business combination primarily relates to the value attributed to additional growth opportunities, synergies and operating leverage within SemGroup’s operations.
[2]	Long-term debt at December 5, 2019 includes SemGroup senior notes with an aggregate principal amount of $1.375 billion and SemGroup subsidiary debt of $593 million, all of which were redeemed in total in December 2019, subsequent to the close of the SemGroup Transaction, utilizing proceeds from an intercompany promissory note from ETO.
[3]	Total consideration includes (i) cash paid to SemGroup shareholders, (ii) fair value of ET Common Units issued in the acquisition and (iii) cash paid to redeem SemGroup’s preferred shares
[4]	Cash received represents cash and cash equivalents held by SemGroup as of the acquisition date.
[5]	None of the goodwill is expected to be deductible for tax purposes. Goodwill recognized from the business combination primarily relates to the value attributed to additional growth opportunities, synergies and operating leverage within USAC’s operations.
[6]	Cash received represents cash and cash equivalents held by USAC as of the acquisition date.

Acquisitions and Related Transactions Acquisitions (Schedule of Discontinued Operations) (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Disposal Group, Including Discontinued Operations, Loss on Debt Extinguishment				$ 20	$ 0
Disposal Group, Including Discontinued Operation, Revenue				349	6,964
Disposal Group, Including Discontinued Operation, Costs of Goods Sold				305	5,806
Disposal Group, Including Discontinued Operation, Operating Expense				61	763
Disposal Group, Including Discontinued Operation, Depreciation and Amortization				0	34
Disposal Group, Including Discontinued Operation, General and Administrative Expense				7	168
Impairment of Long-Lived Assets to be Disposed of				0	285
Goodwill impairment	$ 12	$ 9	$ 21	378
Disposal Group, Including Discontinued Operations, Total Costs and Expenses				373	7,056
Disposal Group, Including Discontinued Operation, Operating Income (Loss)				(24)	(92)
Disposal Group, Including Discontinued Operation, Interest Expense				2	36
Disposal Group, Including Discontinued Operation, Other Expense				61	1
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax				(107)	(129)
Discontinued Operation, Tax Effect of Discontinued Operation				158	48
Loss from discontinued operations			$ 0	(265)	(177)
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent				$ (10)	$ (6)

Advances to and Investments in Unconsolidated Affiliates Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Impairment of investments in unconsolidated affiliates	$ 0	$ 0	$ 313
Impairment losses	74	431	1,039
Advances to and investments in unconsolidated affiliates	3,460	2,642	2,705
Equity in earnings of unconsolidated affiliates	$ 302	$ 344	$ 144
Citrus [Member]
Interest ownership	50.00%
Business Acquisition, Percentage of Voting Interests Acquired	50.00%
FGT [Member]
Percentage Ownership Operating Facility	100.00%
FEP [Member]
Interest ownership	50.00%
Impairment of investments in unconsolidated affiliates	$ 141
Midcontinent Express Pipeline, LLC [Member]
Interest ownership	50.00%

Advances to and Investments in Unconsolidated Affiliates Investment in Affiliates (Carrying Values) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Equity in earnings of unconsolidated affiliates	$ 302	$ 344	$ 144
Advances to and investments in unconsolidated affiliates	3,460	2,642	2,705
Citrus [Member]
Equity in earnings of unconsolidated affiliates	148	141	144
Advances to and investments in unconsolidated affiliates	1,876	1,737
FEP [Member]
Equity in earnings of unconsolidated affiliates	59	55	53
Advances to and investments in unconsolidated affiliates	218	107
MEP [Member]
Equity in earnings of unconsolidated affiliates	15	31	38
Advances to and investments in unconsolidated affiliates	429	225
Other Affiliates [Member]
Equity in earnings of unconsolidated affiliates	80	117	$ (91)
Advances to and investments in unconsolidated affiliates	$ 937	$ 573

Investments in Affiliates (Summarized Balance Sheet Information) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Investment In Affiliates [Abstract]
Current assets	$ 247	$ 212
Property, plant and equipment, net	7,680	7,800
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	40	39
Total assets	7,967	8,051
Current Liabilities	738	1,534
Non-current liabilities	3,242	3,439
Equity	3,987	3,078
Total liabilities and equity	$ 7,967	$ 8,051

Investments in Affiliates (Summarized Income Statement Information) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Schedule of Equity Method Investments [Line Items]

Revenues

$ 1,192

$ 1,249

^[1]

$ 1,358

Equity Method Investments Summarized Financial Information, Operating Income

683

723

^[1]

407

Net income

443

460

^[1]

145

Equity in earnings of unconsolidated affiliates

302

344

144

Citrus [Member]

Schedule of Equity Method Investments [Line Items]

Equity in earnings of unconsolidated affiliates

148

141

144

FEP [Member]

Schedule of Equity Method Investments [Line Items]

Equity in earnings of unconsolidated affiliates

MEP [Member]

Schedule of Equity Method Investments [Line Items]

Equity in earnings of unconsolidated affiliates

Other Affiliates [Member]

Schedule of Equity Method Investments [Line Items]

Equity in earnings of unconsolidated affiliates

$ 80

$ 117

$ (91)

[1]	Selected income data related to HPC for the year ended December 31, 2018 reflects HPC’s results for January 1, 2018 through March 31, 2018. HPC was fully consolidated beginning April 1, 2018 as discussed above.

Net Income Per Limited Partner Unit (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Earnings Per Share [Abstract]
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent					$ 852	$ 1,393	$ 659	$ 726	$ 4,899	$ 3,630	$ 2,543
Less: Net income attributable to redeemable noncontrolling interests									51	39	0
Less: Income (loss) from continuing operations attributable to noncontrolling interests									1,256	1,888	1,583
Income from continuing operations, net of noncontrolling interests									3,592	1,703	960
Less: General Partner’s interest in income from continuing operations									4	3	2
Convertible Unitholders’ interest in net income									0	33	38
Income from continuing operations available to Limited Partners									3,588	1,667	920
Dilutive effect of equity-based compensation of subsidiaries and distributions to convertible units									(1)	33	38
Diluted income from continuing operations available to Limited Partners									$ 3,587	$ 1,700	$ 958
Weighted average limited partner units									2,628.0	1,423.8	1,078.2
Incremental Common Shares Attributable to Dilutive Effect of Conversion of Preferred Stock									0.0	30.3	72.6
Basic income from continuing operations per Limited Partner unit	$ 0.38	$ 0.32	$ 0.33	$ 0.33	$ 0.26	$ 0.32	$ 0.30	$ 0.32	$ 1.37	$ 1.17	$ 0.86
Basic loss from discontinued operations per Limited Partner unit									$ 0	$ (0.01)	$ (0.01)
Dilutive effect of unconverted unit awards and ET Series A Convertible Preferred Units									9.6	7.3	0.0
Weighted average limited partner units, assuming dilutive effect of unvested unit awards									2,637.6	1,461.4	1,150.8
Diluted income from continuing operations per Limited Partner unit	$ 0.38	$ 0.32	$ 0.33	$ 0.33	$ 0.26	$ 0.32	$ 0.30	$ 0.32	$ 1.36	$ 1.16	$ 0.84
Diluted loss from discontinued operations per Limited Partner unit									$ 0	$ (0.01)	$ (0.01)

Debt Obligations Debt Obligations (Schedule Of Debt Obligations) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Jun. 30, 2019

Mar. 31, 2019

Jan. 31, 2019

Jan. 01, 2019

Dec. 31, 2018

Debt Instrument [Line Items]

Debt Instrument, Unamortized Discount (Premium), Net

$ 279

Other Long-term Debt

$ 7

Long-term Debt

51,054

46,028

Current maturities of long-term debt

$ 2,656

2,655

Long-term debt, less current maturities

51,028

$ 43,379

43,373

Parent Company [Member]

Debt Instrument [Line Items]

Debt Instrument, Unamortized Discount (Premium), Net

Deferred Finance Costs, Noncurrent, Net

(27)

Long-term Debt

$ 124

5,520

Parent Company [Member] | ETE 7.5% Senior Notes due 2020 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

7.50%

Debt Instrument, Maturity Date

Oct. 15, 2020

Senior Notes

^[1]

$ 52

1,187

Parent Company [Member] | 5.875% Senior Notes due January 15, 2024 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.88%

Debt Instrument, Maturity Date

Jan. 15, 2024

Senior Notes

$ 23

1,150

Parent Company [Member] | 5.5% Senior Notes due June 1, 2027 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.50%

Debt Instrument, Maturity Date

Jun. 01, 2027

Senior Notes

$ 44

1,000

Parent Company [Member] | 4.25% Senior Notes due March 15, 2023 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.25%

Debt Instrument, Maturity Date

Mar. 15, 2023

Senior Notes

$ 5

1,000

Parent Company [Member] | ETE Senior Secured Term Loan due February 2, 2024 [Member]

Debt Instrument [Line Items]

Secured Debt

1,220

ETO [Member]

Debt Instrument [Line Items]

Debt Instrument, Unamortized Discount (Premium), Net

(5)

Deferred Finance Costs, Noncurrent, Net

(207)

(178)

Long-term Debt

$ 42,120

32,288

ETO [Member] | 5.875% Senior Notes due January 15, 2024 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.88%

5.875%

Debt Instrument, Maturity Date

Jan. 15, 2024

Senior Notes

$ 1,127

$ 1,130

ETO [Member] | 5.5% Senior Notes due June 1, 2027 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.50%

Debt Instrument, Maturity Date

Jun. 01, 2027

Senior Notes

$ 956

ETO [Member] | 4.25% Senior Notes due March 15, 2023 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.25%

Debt Instrument, Maturity Date

Mar. 15, 2023

Senior Notes

$ 995

ETO [Member] | 7.60% Senior Notes, due February 1, 2024 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

7.60%

Debt Instrument, Maturity Date

Feb. 01, 2024

Senior Notes

$ 277

277

ETO [Member] | 4.05% Senior Notes due March 2025 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.05%

Debt Instrument, Maturity Date

Mar. 15, 2025

Senior Notes

$ 1,000

1,000

ETO [Member] | 4.75% Senior Notes due January 2026 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.75%

Debt Instrument, Maturity Date

Jan. 15, 2026

Senior Notes

$ 1,000

1,000

ETO [Member] | 8.25% Senior Notes, due November 14, 2029 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

8.25%

Debt Instrument, Maturity Date

Nov. 15, 2029

Senior Notes

$ 267

267

ETO [Member] | 4.90% Senior Notes due March 2035 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.90%

Debt Instrument, Maturity Date

Mar. 15, 2035

Senior Notes

$ 500

500

ETO [Member] | 6.625% Senior Notes, due October 15, 2036 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.63%

Debt Instrument, Maturity Date

Oct. 15, 2036

Senior Notes

$ 400

400

ETO [Member] | 5.80% Senior Notes due 2038 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.80%

Debt Instrument, Maturity Date

Jul. 01, 2038

Senior Notes

$ 500

500

ETO [Member] | 7.5% Senior Notes, due July 1, 2038 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

7.50%

Debt Instrument, Maturity Date

Jul. 01, 2038

Senior Notes

$ 550

550

ETO [Member] | Senior Notes 6.05% Due June 1, 2041 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.85%

Debt Instrument, Maturity Date

Jun. 01, 2041

Senior Notes

$ 700

700

ETO [Member] | Senior Notes 6.50% Due February 1, 2042 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.05%

Debt Instrument, Maturity Date

Feb. 01, 2042

Senior Notes

$ 1,000

1,000

ETO [Member] | 5.15% Senior Notes due February 1, 2043 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.95%

Debt Instrument, Maturity Date

Feb. 01, 2043

Senior Notes

$ 450

450

ETO [Member] | 5.95% Senior Notes due October 1, 2043 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.15%

Debt Instrument, Maturity Date

Oct. 01, 2043

Senior Notes

$ 450

450

ETO [Member] | 5.15% Senior Notes due March 2045 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.30%

Debt Instrument, Maturity Date

Mar. 15, 2045

Senior Notes

$ 1,000

1,000

ETO [Member] | 6.125% Senior Notes due December 2045 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.35%

Debt Instrument, Maturity Date

May 15, 2045

Senior Notes

$ 1,000

1,000

ETO [Member] | 5.30% Senior Notes due April 2047 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.13%

Debt Instrument, Maturity Date

Apr. 01, 2047

Senior Notes

$ 900

900

ETO [Member] | 5.40% Senior Notes due October 1, 2047 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.30%

Debt Instrument, Maturity Date

Oct. 01, 2047

Senior Notes

$ 1,500

1,500

ETO [Member] | 6.0% Senior Notes due 2048 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.00%

Debt Instrument, Maturity Date

Jun. 15, 2048

Senior Notes

$ 1,000

1,000

ETO [Member] | 6.25% Senior Notes due 2049 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.25%

Debt Instrument, Maturity Date

Apr. 15, 2049

Senior Notes

$ 1,750

ETO [Member] | 7.2% Junior Subordinated Notes due November 21, 2066 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.40%

Junior Subordinated Notes

$ 546

546

ETO [Member] | ETO Term Loan [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

2,000

ETO [Member] | ETO Credit Facility due December 2022 [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

$ 4,214

3,694

ETO [Member] | 9.00% Debentures, due 2024 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

9.00%

Debt Instrument, Maturity Date

Nov. 01, 2024

Subordinated Debt

$ 65

ETO [Member] | 5.50% Senior Notes, due February 15, 2020 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.50%

Debt Instrument, Maturity Date

Feb. 15, 2020

Senior Notes

^[1]

$ 250

250

ETO [Member] | Senior Note 4.65% Due February 15, 2022 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.65%

Debt Instrument, Maturity Date

Feb. 15, 2022

Senior Notes

$ 300

300

ETO [Member] | 3.45% Senior Notes due January 2023 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

3.45%

Debt Instrument, Maturity Date

Feb. 01, 2023

Senior Notes

$ 350

350

ETO [Member] | 6.85% Senior Notes, due February 15, 2040 [Member]

Debt Instrument [Line Items]

Debt Instrument, Maturity Date

Feb. 15, 2040

Senior Notes

$ 250

250

ETO [Member] | 4.25% Senior Notes due April 1, 2024 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.25%

Debt Instrument, Maturity Date

Apr. 01, 2024

Senior Notes

$ 500

500

ETO [Member] | 4.5% Senior Notes due 2024 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.50%

Senior Notes

$ 750

ETO [Member] | 5.95% Senior Notes due December 2025 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.95%

Debt Instrument, Maturity Date

Dec. 01, 2025

Senior Notes

$ 400

400

ETO [Member] | 3.90% Senior Notes due July 15, 2026 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

3.90%

Debt Instrument, Maturity Date

Jul. 15, 2026

Senior Notes

$ 550

550

ETO [Member] | 4.20% Senior Notes due April 2027 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.20%

Debt Instrument, Maturity Date

Apr. 15, 2027

Senior Notes

$ 600

600

ETO [Member] | 4.00% Senior Notes due October 1, 2027 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.00%

Debt Instrument, Maturity Date

Oct. 01, 2027

Senior Notes

$ 750

750

ETO [Member] | 4.95% Senior Notes due 2028 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.95%

Debt Instrument, Maturity Date

Jun. 15, 2028

Senior Notes

$ 1,000

1,000

ETO [Member] | 5.25% Senior Notes due 2029 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.25%

Debt Instrument, Maturity Date

Apr. 15, 2029

Senior Notes

$ 1,500

ETO [Member] | Senior Note 6.10%, due February 15, 2042 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.50%

Debt Instrument, Maturity Date

Feb. 15, 2042

Senior Notes

$ 300

300

ETO [Member] | 5.30% Senior Notes due April 1, 2044 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.95%

Debt Instrument, Maturity Date

Apr. 01, 2044

Senior Notes

$ 700

700

ETO [Member] | 5.35% Senior Notes due May 15, 2045 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.15%

Debt Instrument, Maturity Date

Dec. 15, 2045

Senior Notes

$ 800

800

ETO [Member] | 4.95% Senior Notes due January 2043 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.10%

Debt Instrument, Maturity Date

Jan. 15, 2043

Senior Notes

$ 350

350

ETO [Member] | 9.7% Senior Notes, due March 15, 2019 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

9.70%

Debt Instrument, Maturity Date

Mar. 15, 2019

Senior Notes

$ 0

400

ETO [Member] | 9.0% Senior Notes due April 15, 2019 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

9.00%

Debt Instrument, Maturity Date

Apr. 15, 2019

Senior Notes

$ 0

450

ETO [Member] | 5.75% Senior Notes due September 1, 2020 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.75%

Debt Instrument, Maturity Date

Sep. 01, 2020

Senior Notes

^[1]

$ 400

400

ETO [Member] | 4.15% Senior Notes due October 1, 2020 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.15%

Debt Instrument, Maturity Date

Oct. 01, 2020

Senior Notes

^[1]

$ 1,050

1,050

ETO [Member] | 5.875% Senior Notes due April 1, 2022 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.88%

Debt Instrument, Maturity Date

Mar. 01, 2022

Senior Notes

$ 900

900

ETO [Member] | 4.5% Senior Notes due November 1, 2023 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.50%

Debt Instrument, Maturity Date

Nov. 01, 2023

Senior Notes

$ 600

600

ETO [Member] | 4.9% Senior Notes due February 1, 2024 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.90%

Debt Instrument, Maturity Date

Feb. 01, 2024

Senior Notes

$ 350

350

ETO [Member] | Senior Notes 4.65% Due June 1, 2021 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.65%

Debt Instrument, Maturity Date

Jun. 01, 2021

Senior Notes

$ 800

800

ETO [Member] | Senior Notes 5.20% Due February 1, 2022 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.20%

Debt Instrument, Maturity Date

Feb. 01, 2022

Senior Notes

$ 1,000

1,000

ETO [Member] | 5.0% Senior Notes due October 1, 2022 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.00%

Debt Instrument, Maturity Date

Oct. 01, 2022

Senior Notes

$ 700

700

ETO [Member] | 3.6% Senior Notes due February 1, 2023 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

3.60%

Debt Instrument, Maturity Date

Feb. 01, 2023

Senior Notes

$ 800

800

ETO [Member] | 4.20% Senior Notes due 2023 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

4.20%

Debt Instrument, Maturity Date

Sep. 15, 2023

Senior Notes

$ 500

500

ETO [Member] | ETO 364-day Credit Facility due November 2019 [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

ETO [Member] | 7.5% Senior Notes due October 15, 2020 [Member]

Debt Instrument [Line Items]

Senior Notes

^[1]

1,135

Bakken Project [Member]

Debt Instrument [Line Items]

Deferred Finance Costs, Noncurrent, Net

(16)

(3)

Long-term Debt

2,481

2,497

Bakken Project [Member] | Bakken Project $2.50 billion Credit Facility due August 2019 [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

2,500

Debt Instrument, Unamortized Discount (Premium), Net

(3)

Bakken Project [Member] | 3.625% Senior Notes due 2022 [Member]

Debt Instrument [Line Items]

Senior Notes

650

Bakken Project [Member] | 3.90% Senior Notes due 2024 [Member]

Debt Instrument [Line Items]

Senior Notes

1,000

Bakken Project [Member] | 4.625% Senior Notes due 2029 [Member]

Debt Instrument [Line Items]

Senior Notes

850

Sunoco LP [Member]

Debt Instrument [Line Items]

Capital Lease Obligations

135

107

Deferred Finance Costs, Noncurrent, Net

(26)

(23)

Long-term Debt

$ 3,071

2,984

Sunoco LP [Member] | 6.00% Senior Notes due April 15, 2027 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.00%

Debt Instrument, Maturity Date

Apr. 15, 2027

Senior Notes

$ 600

Sunoco LP [Member] | 5.5% Senior Notes due August 2020 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.50%

Debt Instrument, Maturity Date

Feb. 15, 2026

Sunoco LP [Member] | Sunoco LP $1.5 billion Revolving Credit Facility due July 2023 [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

$ 162

700

Sunoco LP [Member] | 5.875% senior notes due 2028 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.88%

Debt Instrument, Maturity Date

Mar. 15, 2028

Senior Notes

$ 400

400

Transwestern [Member]

Debt Instrument [Line Items]

Deferred Finance Costs, Noncurrent, Net

(1)

Long-term Debt

$ 574

574

Transwestern [Member] | 5.36% Senior Unsecured Notes, due December 9, 2020 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.36%

Debt Instrument, Maturity Date

Dec. 09, 2020

Senior Notes

^[1]

$ 175

175

Transwestern [Member] | 5.89% Senior Unsecured Notes, due May 24, 2022 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.89%

Debt Instrument, Maturity Date

May 24, 2022

Senior Notes

$ 150

150

Transwestern [Member] | 5.66% Senior Unsecured Notes, due December 9, 2024 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

5.66%

Debt Instrument, Maturity Date

Dec. 09, 2024

Senior Notes

$ 175

175

Transwestern [Member] | 6.16% Senior Unsecured Notes, due May 24, 2037 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.16%

Debt Instrument, Maturity Date

May 24, 2037

Senior Notes

$ 75

Transwestern [Member] | 6.875% Senior notes due April 2026 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.88%

Debt Instrument, Maturity Date

Apr. 01, 2026

Transwestern [Member] | 6.875% Senior Notes due September 2027 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

6.88%

Debt Instrument, Maturity Date

Sep. 01, 2027

Panhandle [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

8.125%

Debt Instrument, Unamortized Discount (Premium), Net

$ 11

Long-term Debt

$ 246

399

Panhandle [Member] | 7.60% Senior Notes, due February 1, 2024 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

7.60%

Debt Instrument, Maturity Date

Feb. 01, 2024

Senior Notes

$ 82

Panhandle [Member] | 8.25% Senior Notes, due November 14, 2029 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

8.20%

Debt Instrument, Maturity Date

Nov. 15, 2029

Senior Notes

$ 33

Panhandle [Member] | 7.2% Junior Subordinated Notes due November 21, 2066 [Member]

Debt Instrument [Line Items]

Junior Subordinated Notes

$ 54

Panhandle [Member] | 8.125% Senior Notes, due June 1, 2019 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

8.13%

8.125%

Debt Instrument, Maturity Date

Jun. 01, 2019

Senior Notes

$ 0

150

Panhandle [Member] | 7.00% Senior Notes, due July 15, 2029 [Member]

Debt Instrument [Line Items]

Debt Instrument, Interest Rate, Stated Percentage

7.00%

Debt Instrument, Maturity Date

Jul. 15, 2029

Senior Notes

$ 66

USA Compression Partners, LP [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

403

1,050

Deferred Finance Costs, Noncurrent, Net

(26)

(16)

Long-term Debt

1,852

1,759

USA Compression Partners, LP [Member] | 6.875% Senior notes due April 2026 [Member]

Debt Instrument [Line Items]

Senior Notes

725

USA Compression Partners, LP [Member] | 6.875% Senior Notes due September 2027 [Member]

Debt Instrument [Line Items]

Senior Notes

750

SemGroup [Member]

Debt Instrument [Line Items]

Debt Instrument, Unamortized Discount (Premium), Net

Deferred Finance Costs, Noncurrent, Net

(3)

Long-term Debt

584

SemGroup [Member] | HFOTCO Tax Exempt Notes due 2050 [Member]

Debt Instrument [Line Items]

Senior Notes

225

SemGroup [Member] | SemCAMS Revolver due February 25, 2024 [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

SemGroup [Member] | SemCAMS Term Loan A due February 25, 2024 [Member]

Debt Instrument [Line Items]

Long-term Line of Credit

$ 269

$ 0

[1]	As of December 31, 2019, these notes were classified as long-term as management had the intent and ability to refinance the borrowings on a long-term basis. The notes were redeemed in January 2020.

Debt Obligations Debt Obligations (Future Maturities of Long-Term Debt) (Details) $ in Millions	Dec. 31, 2019 USD ($)
Debt Obligations [Abstract]
2020	$ 3,086
2021	1,412
2022	5,792
2023	8,965
2024	4,708
Thereafter	27,366
Long-term Debt	$ 51,329

Debt Obligations (Debt Narrative) (Details)
$ in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Jun. 30, 2019

USD ($)

Mar. 31, 2019

USD ($)

Jan. 31, 2019

USD ($)

Mar. 31, 2019

USD ($)

Dec. 31, 2019

USD ($)

Dec. 31, 2018

USD ($)

Dec. 31, 2017

USD ($)

Jan. 31, 2020

USD ($)

Dec. 31, 2019

CAD ($)

Oct. 31, 2019

USD ($)

Noncontrolling interests

$ 12,018,000,000

$ 10,291,000,000

Less: Net income attributable to noncontrolling interests

1,256,000,000

1,632,000,000

$ 1,412,000,000

Repayments of Long-term Debt

20,101,000,000

28,948,000,000

31,268,000,000

Proceeds from Issuance of Senior Long-term Debt

$ 3,960,000,000

4,210,000,000

Long-term Debt

51,054,000,000

46,028,000,000

Proceeds from borrowings

$ 22,583,000,000

29,001,000,000

$ 31,608,000,000

Sunoco LP $1.5 billion Revolving Credit Facility due July 2023 [Member]

Debt Instrument, Covenant Description

Sunoco LP’s Credit Facility requires Sunoco LP to maintain a Net Leverage Ratio of not more than 5.5 to 1. The maximum Net Leverage Ratio is subject to upwards adjustment of not more than 6.0 to 1 for a period not to exceed three fiscal quarters in the event Sunoco LP engages in certain specified acquisitions of not less than $50 million (as permitted under Sunoco LP’s Credit Facility agreement). The Sunoco LP Credit Facility also requires Sunoco LP to maintain an Interest Coverage Ratio (as defined in the Sunoco LP’s Credit Facility agreement) of not less than 2.25 to 1.

USAC Credit Facility, due 2023 [Member]

Debt Instrument, Covenant Description

Parent Company [Member]

Long-term Debt

$ 124,000,000

5,520,000,000

Parent Company [Member] | ETE 7.5% Senior Notes due 2020 [Member]

Senior Notes

^[1]

$ 52,000,000

1,187,000,000

Debt instrument, interest rate, stated percentage

7.50%

Debt Instrument, Maturity Date

Oct. 15, 2020

Parent Company [Member] | ETE Senior Secured Term Loan due February 2, 2024 [Member]

Line of Credit Facility, Maximum Borrowing Capacity

$ 2,200,000,000

Parent Company [Member] | 4.25% Senior Notes due March 15, 2023 [Member]

Senior Notes

$ 5,000,000

1,000,000,000

Debt instrument, interest rate, stated percentage

4.25%

Debt Instrument, Maturity Date

Mar. 15, 2023

Parent Company [Member] | 5.5% Senior Notes due June 1, 2027 [Member]

Senior Notes

$ 44,000,000

1,000,000,000

Debt instrument, interest rate, stated percentage

5.50%

Debt Instrument, Maturity Date

Jun. 01, 2027

Parent Company [Member] | 5.875% Senior Notes due January 15, 2024 [Member]

Senior Notes

$ 23,000,000

1,150,000,000

Debt instrument, interest rate, stated percentage

5.88%

Debt Instrument, Maturity Date

Jan. 15, 2024

ET [Member]

Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed

97.00%

USA Compression Partners, LP [Member]

Long-term Debt

$ 1,852,000,000

1,759,000,000

Outstanding borrowings

403,000,000

1,050,000,000

USA Compression Partners, LP [Member] | 6.875% Senior notes due April 2026 [Member]

Senior Notes

725,000,000

USA Compression Partners, LP [Member] | USAC Credit Facility, due 2023 [Member]

Line of Credit Facility, Current Borrowing Capacity

1,600,000,000

USAC [Member]

Line of Credit Facility, Increase (Decrease), Net

$ 750,000,000

Line of Credit Facility, Maximum Borrowing Capacity

0.06875

$ 0.06875

USAC [Member] | USAC Credit Facility, due 2023 [Member]

Letters of Credit Outstanding, Amount

Line of Credit Facility, Remaining Borrowing Capacity

$ 1,200,000,000

Line of Credit Facility, Interest Rate at Period End

4.31%

Outstanding borrowings

$ 403,000,000

SemCAMS [Member]

Line of Credit Facility, Remaining Borrowing Capacity

193,000,000

Line of Credit Facility, Maximum Borrowing Capacity

404,000,000

Long-term Construction Loan

231,000,000

SemCAMS [Member] | SemCAMS Senior secured term loan [Member]

Senior Notes

270,000,000

ETO [Member]

Long-term Debt

42,120,000,000

32,288,000,000

ETO [Member] | 5.75% Senior Notes due September 1, 2020 [Member]

Senior Notes

^[1]

$ 400,000,000

400,000,000

Debt instrument, interest rate, stated percentage

5.75%

Debt Instrument, Maturity Date

Sep. 01, 2020

ETO [Member] | 9.7% Senior Notes, due March 15, 2019 [Member]

Senior Notes

$ 0

400,000,000

Repayments of Senior Debt

$ 400,000,000

Debt instrument, interest rate, stated percentage

9.70%

Debt Instrument, Maturity Date

Mar. 15, 2019

ETO [Member] | 9.0% Senior Notes due April 15, 2019 [Member]

Senior Notes

$ 0

450,000,000

Repayments of Senior Debt

$ 450,000,000

Debt instrument, interest rate, stated percentage

9.00%

Debt Instrument, Maturity Date

Apr. 15, 2019

ETO [Member] | ETO Term Loan [Member]

Line of Credit Facility, Interest Rate at Period End

2.78%

Outstanding borrowings

$ 2,000,000,000

Line of Credit Facility, Maximum Borrowing Capacity

$ 2,000,000,000.00

ETO [Member] | ETO Credit Facility due December 2022 [Member]

Line of Credit Facility, Current Borrowing Capacity

5,000,000,000.00

Letters of Credit Outstanding, Amount

77,000,000

Line of Credit Facility, Remaining Borrowing Capacity

$ 709,000,000

Line of Credit Facility, Interest Rate at Period End

2.88%

Outstanding borrowings

$ 4,214,000,000

3,694,000,000

Long-term Commercial Paper, Noncurrent

1,640,000,000

ETO [Member] | 4.25% Senior Notes due March 15, 2023 [Member]

Senior Notes

$ 995,000,000

Debt instrument, interest rate, stated percentage

4.25%

Debt Instrument, Maturity Date

Mar. 15, 2023

ETO [Member] | 5.5% Senior Notes due June 1, 2027 [Member]

Senior Notes

$ 956,000,000

Debt instrument, interest rate, stated percentage

5.50%

Debt Instrument, Maturity Date

Jun. 01, 2027

ETO [Member] | 7.50% Senior Notes Due 2020 [Member]

Senior Notes

$ 1,140,000,000

Debt instrument, interest rate, stated percentage

7.50%

Debt Instrument, Maturity Date

Oct. 15, 2020

ETO [Member] | 5.35% Senior Notes due May 15, 2045 [Member]

Senior Notes

$ 800,000,000

800,000,000

Debt instrument, interest rate, stated percentage

5.15%

Debt Instrument, Maturity Date

Dec. 15, 2045

ETO [Member] | 3.26% Junior Subordinated Notes due November 1, 2066 [Member]

Junior Subordinated Notes

$ 546,000,000

546,000,000

Debt instrument, interest rate, stated percentage

5.40%

ETO [Member] | 4.25% Senior Notes due April 1, 2024 [Member]

Senior Notes

$ 500,000,000

500,000,000

Debt instrument, interest rate, stated percentage

4.25%

Debt Instrument, Maturity Date

Apr. 01, 2024

ETO [Member] | 5.875% Senior Notes due April 1, 2022 [Member]

Senior Notes

$ 900,000,000

900,000,000

Debt instrument, interest rate, stated percentage

5.88%

Debt Instrument, Maturity Date

Mar. 01, 2022

ETO [Member] | 5.875% Senior Notes due January 15, 2024 [Member]

Senior Notes

$ 1,130,000,000

$ 1,127,000,000

Debt instrument, interest rate, stated percentage

5.875%

5.88%

Debt Instrument, Maturity Date

Jan. 15, 2024

ETO [Member] | 5.0% Senior Notes due October 1, 2022 [Member]

Senior Notes

$ 700,000,000

700,000,000

Debt instrument, interest rate, stated percentage

5.00%

Debt Instrument, Maturity Date

Oct. 01, 2022

ETO [Member] | 4.40% Senior Notes due April 2021 [Member]

Senior Notes

$ 600,000,000

600,000,000

Debt instrument, interest rate, stated percentage

4.40%

Debt Instrument, Maturity Date

Apr. 01, 2021

ETO [Member] | 3.90% Senior Notes due July 15, 2026 [Member]

Senior Notes

$ 550,000,000

550,000,000

Debt instrument, interest rate, stated percentage

3.90%

Debt Instrument, Maturity Date

Jul. 15, 2026

ETO [Member] | ETO 364-day Credit Facility due November 2019 [Member]

Outstanding borrowings

$ 0

Line of Credit Facility, Maximum Borrowing Capacity

1,000,000,000.00

ETO [Member] | 4.5% Senior Notes due 2024 [Member]

Senior Notes

$ 750,000,000

750,000,000

Debt instrument, interest rate, stated percentage

4.50%

ETO [Member] | 6.25% Senior Notes due 2049 [Member]

Senior Notes

$ 1,750,000,000

Debt instrument, interest rate, stated percentage

6.25%

Debt Instrument, Maturity Date

Apr. 15, 2049

ETO [Member] | 5.25% Senior Notes due 2029 [Member]

Senior Notes

$ 1,500,000,000

Debt instrument, interest rate, stated percentage

5.25%

Debt Instrument, Maturity Date

Apr. 15, 2029

ETO [Member] | 4.20% Senior Notes due 2023 [Member]

Senior Notes

$ 500,000,000

500,000,000

Debt instrument, interest rate, stated percentage

4.20%

Debt Instrument, Maturity Date

Sep. 15, 2023

ETO [Member] | 4.95% Senior Notes due 2028 [Member]

Senior Notes

$ 1,000,000,000

1,000,000,000

Debt instrument, interest rate, stated percentage

4.95%

Debt Instrument, Maturity Date

Jun. 15, 2028

ETO [Member] | 5.80% Senior Notes due 2038 [Member]

Senior Notes

$ 500,000,000

500,000,000

Debt instrument, interest rate, stated percentage

5.80%

Debt Instrument, Maturity Date

Jul. 01, 2038

ETO [Member] | 6.0% Senior Notes due 2048 [Member]

Senior Notes

$ 1,000,000,000

1,000,000,000

Debt instrument, interest rate, stated percentage

6.00%

Debt Instrument, Maturity Date

Jun. 15, 2048

ETO [Member] | 4.15% Senior Notes due October 1, 2020 [Member]

Senior Notes

^[1]

$ 1,050,000,000

1,050,000,000

Debt instrument, interest rate, stated percentage

4.15%

Debt Instrument, Maturity Date

Oct. 01, 2020

ETO [Member] | 7.5% Senior Notes due October 15, 2020 [Member]

Senior Notes

^[1]

$ 1,135,000,000

ETO [Member] | 5.50% Senior Notes, due February 15, 2020 [Member]

Senior Notes

^[1]

$ 250,000,000

250,000,000

Debt instrument, interest rate, stated percentage

5.50%

Debt Instrument, Maturity Date

Feb. 15, 2020

ETO [Member] | Minimum [Member] | ETO Credit Facility due December 2022 [Member]

Line of Credit Facility, Commitment Fee Percentage

0.125%

ETO [Member] | Minimum [Member] | ETO 364-day Credit Facility due November 2019 [Member]

Line of Credit Facility, Commitment Fee Percentage

0.125%

ETO [Member] | Maximum [Member] | ETO Credit Facility due December 2022 [Member]

Line of Credit Facility, Commitment Fee Percentage

0.30%

ETO [Member] | Maximum [Member] | ETO 364-day Credit Facility due November 2019 [Member]

Line of Credit Facility, Commitment Fee Percentage

0.225%

Transwestern [Member]

Long-term Debt

$ 574,000,000

574,000,000

Transwestern [Member] | 5.36% Senior Unsecured Notes, due December 9, 2020 [Member]

Senior Notes

^[1]

$ 175,000,000

175,000,000

Debt instrument, interest rate, stated percentage

5.36%

Debt Instrument, Maturity Date

Dec. 09, 2020

Transwestern [Member] | 6.875% Senior notes due April 2026 [Member]

Debt instrument, interest rate, stated percentage

6.88%

Debt Instrument, Maturity Date

Apr. 01, 2026

Panhandle [Member]

Repayments of Senior Debt

$ 150,000,000

Long-term Debt

$ 246,000,000

399,000,000

Debt instrument, interest rate, stated percentage

8.125%

Panhandle [Member] | 3.26% Junior Subordinated Notes due November 1, 2066 [Member]

Junior Subordinated Notes

54,000,000

Panhandle [Member] | 8.125% Senior Notes, due June 1, 2019 [Member]

Senior Notes

$ 0

150,000,000

Repayments of Senior Debt

$ 150,000,000

Debt instrument, interest rate, stated percentage

8.125%

8.13%

Debt Instrument, Maturity Date

Jun. 01, 2019

Dakota Access, LLC [Member]

Proceeds from Issuance of Senior Long-term Debt

$ 2,480,000,000

Dakota Access, LLC [Member] | 3.625% Senior Notes due 2022 [Member]

Senior Notes

$ 650,000,000

Debt instrument, interest rate, stated percentage

3.625%

Dakota Access, LLC [Member] | 3.90% Senior Notes due 2024 [Member]

Senior Notes

$ 1,000,000,000.00

Debt instrument, interest rate, stated percentage

3.90%

Dakota Access, LLC [Member] | 4.625% Senior Notes due 2029 [Member]

Senior Notes

$ 850,000,000

Debt instrument, interest rate, stated percentage

4.625%

Bakken Project [Member]

Long-term Debt

$ 2,481,000,000

2,497,000,000

Bakken Project [Member] | Bakken Project $2.50 billion Credit Facility due August 2019 [Member]

Outstanding borrowings

2,500,000,000

Bakken Project [Member] | 3.625% Senior Notes due 2022 [Member]

Senior Notes

650,000,000

Bakken Project [Member] | 3.90% Senior Notes due 2024 [Member]

Senior Notes

1,000,000,000

Bakken Project [Member] | 4.625% Senior Notes due 2029 [Member]

Senior Notes

850,000,000

Sunoco LP [Member]

Line of Credit Facility, Increase (Decrease), Net

$ 600,000,000

Long-term Debt

$ 3,071,000,000

2,984,000,000

Line of Credit Facility, Maximum Borrowing Capacity

$ 0.0600

Sunoco LP [Member] | 5.5% Senior Notes due August 2020 [Member]

Debt instrument, interest rate, stated percentage

5.50%

Debt Instrument, Maturity Date

Feb. 15, 2026

Sunoco LP [Member] | 4.875% senior notes due 2023 [Member]

Senior Notes

$ 1,000,000,000

1,000,000,000

Debt instrument, interest rate, stated percentage

4.88%

Debt Instrument, Maturity Date

Jan. 15, 2023

Sunoco LP [Member] | 5.500% senior notes due 2026 [Member]

Senior Notes

$ 800,000,000

800,000,000

Sunoco LP [Member] | 5.875% senior notes due 2028 [Member]

Senior Notes

$ 400,000,000

400,000,000

Debt instrument, interest rate, stated percentage

5.88%

Debt Instrument, Maturity Date

Mar. 15, 2028

Sunoco LP [Member] | Sunoco LP $1.5 billion Revolving Credit Facility due July 2023 [Member]

Line of Credit Facility, Current Borrowing Capacity

$ 1,500,000,000

Letters of Credit Outstanding, Amount

8,000,000

Line of Credit Facility, Remaining Borrowing Capacity

$ 1,330,000,000

Line of Credit Facility, Interest Rate at Period End

3.75%

Outstanding borrowings

$ 162,000,000

$ 700,000,000

Accordion feature [Member] | USA Compression Partners, LP [Member] | USAC Credit Facility, due 2023 [Member]

Outstanding borrowings

400,000,000

Accordion feature [Member] | ETO [Member] | ETO Credit Facility due December 2022 [Member]

Line of Credit Facility, Current Borrowing Capacity

$ 6,000,000,000.00

Eurodollar [Member] | Maximum [Member]

Debt Instrument, Basis Spread on Variable Rate

2.00%

Eurodollar [Member] | ETO [Member] | Minimum [Member] | ETO Credit Facility due December 2022 [Member]

Debt Instrument, Basis Spread on Variable Rate

1.125%

Eurodollar [Member] | ETO [Member] | Minimum [Member] | ETO 364-day Credit Facility due November 2019 [Member]

Debt Instrument, Basis Spread on Variable Rate

1.25%

Eurodollar [Member] | ETO [Member] | Maximum [Member] | ETO 364-day Credit Facility due November 2019 [Member]

Debt Instrument, Basis Spread on Variable Rate

1.75%

Base Rate Loans [Member] | ETO [Member] | Minimum [Member] | ETO Credit Facility due December 2022 [Member]

Debt Instrument, Basis Spread on Variable Rate

0.125%

Base Rate Loans [Member] | ETO [Member] | Minimum [Member] | ETO 364-day Credit Facility due November 2019 [Member]

Debt Instrument, Basis Spread on Variable Rate

0.25%

Base Rate Loans [Member] | ETO [Member] | Maximum [Member] | ETO Credit Facility due December 2022 [Member]

Debt Instrument, Basis Spread on Variable Rate

1.00%

Base Rate Loans [Member] | ETO [Member] | Maximum [Member] | ETO 364-day Credit Facility due November 2019 [Member]

Debt Instrument, Basis Spread on Variable Rate

0.75%

Canada, Dollars | SemCAMS [Member]

Line of Credit Facility, Remaining Borrowing Capacity

$ 250

Line of Credit Facility, Maximum Borrowing Capacity

525

Long-term Construction Loan

300

Canada, Dollars | SemCAMS [Member] | SemCAMS Senior secured term loan [Member]

Senior Notes

$ 350

Subsequent Event [Member] | 2.9% Senior Notes due 2025 [Member]

Senior Notes

$ 1,000,000,000

Subsequent Event [Member] | 3.75% Senior Notes due 2030 [Member]

Senior Notes

1,500,000,000

Subsequent Event [Member] | 5.0% Senior Notes due 2050 [Member]

Senior Notes

$ 2,000,000,000

[1]	As of December 31, 2019, these notes were classified as long-term as management had the intent and ability to refinance the borrowings on a long-term basis. The notes were redeemed in January 2020.

Debt Obligations Debt Obligations (Covenants Related To Credit Agrrements) (Narrative) (Details)	12 Months Ended
	Dec. 31, 2019
Debt Instrument [Line Items]
Leverage Ratio Maximum	6.0
Maximum Leverage Ratio Permitted	7
Supplementary Leverage Ratio	404.00%
Debt instrument covenant minimum fixed charge coverage ratio	1.5
ETO [Member]
Debt Instrument [Line Items]
Leverage Ratio Maximum	5.0
Maximum Leverage Ratio Permitted	5.5
Sunoco LP $1.5 billion Revolving Credit Facility due July 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Covenant Description	Sunoco LP’s Credit Facility requires Sunoco LP to maintain a Net Leverage Ratio of not more than 5.5 to 1. The maximum Net Leverage Ratio is subject to upwards adjustment of not more than 6.0 to 1 for a period not to exceed three fiscal quarters in the event Sunoco LP engages in certain specified acquisitions of not less than $50 million (as permitted under Sunoco LP’s Credit Facility agreement). The Sunoco LP Credit Facility also requires Sunoco LP to maintain an Interest Coverage Ratio (as defined in the Sunoco LP’s Credit Facility agreement) of not less than 2.25 to 1.
USAC Credit Facility, due 2023 [Member]
Debt Instrument [Line Items]
Minimum interest coverage ratio	2.5
Debt Instrument, Covenant Description	a maximum funded debt to EBITDA ratio, determined as of the last day of each fiscal quarter, for the annualized trailing three months of (i) 5.5 to 1 through the end of the fiscal quarter ending December 31, 2019 and (ii) 5.0 to 1.0 thereafter, in each case subject to a provision for increases to such thresholds by 0.50 in connection with certain future acquisitions for the six consecutive month period following the period in which any such acquisition occurs.
Eurodollar [Member] \| Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.00%

Debt Obligations Debt Obligations (Interest Rates & Maturities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Jun. 30, 2019	Mar. 31, 2019	Jan. 31, 2019	Dec. 31, 2018
Parent Company [Member]
Deferred Finance Costs, Noncurrent, Net	$ 0				$ 27
ETO [Member]
Deferred Finance Costs, Noncurrent, Net	207				178
Panhandle [Member]
Debt Instrument, Interest Rate, Stated Percentage		8.125%
Sunoco LP [Member]
Deferred Finance Costs, Noncurrent, Net	26				23
Transwestern [Member]
Deferred Finance Costs, Noncurrent, Net	$ 1				$ 1
5.80% Senior Notes due 2038 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.80%
Debt Instrument, Maturity Date	Jul. 01, 2038
ETE 7.5% Senior Notes due 2020 [Member] \| Parent Company [Member]
Debt Instrument, Interest Rate, Stated Percentage	7.50%
Debt Instrument, Maturity Date	Oct. 15, 2020
5.875% Senior Notes due January 15, 2024 [Member] \| Parent Company [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.88%
Debt Instrument, Maturity Date	Jan. 15, 2024
5.875% Senior Notes due January 15, 2024 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.88%		5.875%
Debt Instrument, Maturity Date	Jan. 15, 2024
5.5% Senior Notes due June 1, 2027 [Member] \| Parent Company [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.50%
Debt Instrument, Maturity Date	Jun. 01, 2027
5.5% Senior Notes due June 1, 2027 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.50%		5.50%
Debt Instrument, Maturity Date	Jun. 01, 2027
4.25% Senior Notes due March 15, 2023 [Member] \| Parent Company [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.25%
Debt Instrument, Maturity Date	Mar. 15, 2023
4.25% Senior Notes due March 15, 2023 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.25%		4.25%
Debt Instrument, Maturity Date	Mar. 15, 2023
4.20% Senior Notes due 2023 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.20%
Debt Instrument, Maturity Date	Sep. 15, 2023
9.7% Senior Notes, due March 15, 2019 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	9.70%			9.70%
Debt Instrument, Maturity Date	Mar. 15, 2019
9.0% Senior Notes due April 15, 2019 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	9.00%			9.00%
Debt Instrument, Maturity Date	Apr. 15, 2019
4.15% Senior Notes due October 1, 2020 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.15%
Debt Instrument, Maturity Date	Oct. 01, 2020
7.50% Senior Notes Due 2020 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	7.50%		7.50%
Debt Instrument, Maturity Date	Oct. 15, 2020
Senior Notes 4.65% Due June 1, 2021 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.65%
Debt Instrument, Maturity Date	Jun. 01, 2021
Senior Notes 5.20% Due February 1, 2022 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.20%
Debt Instrument, Maturity Date	Feb. 01, 2022
3.6% Senior Notes due February 1, 2023 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	3.60%
Debt Instrument, Maturity Date	Feb. 01, 2023
4.9% Senior Notes due February 1, 2024 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.90%
Debt Instrument, Maturity Date	Feb. 01, 2024
4.90% Senior Notes due March 2035 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.90%
Debt Instrument, Maturity Date	Mar. 15, 2035
7.5% Senior Notes, due July 1, 2038 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	7.50%
Debt Instrument, Maturity Date	Jul. 01, 2038
Senior Notes 6.05% Due June 1, 2041 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	6.85%
Debt Instrument, Maturity Date	Jun. 01, 2041
Senior Notes 6.50% Due February 1, 2042 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	6.05%
Debt Instrument, Maturity Date	Feb. 01, 2042
5.15% Senior Notes due February 1, 2043 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.95%
Debt Instrument, Maturity Date	Feb. 01, 2043
5.95% Senior Notes due October 1, 2043 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.15%
Debt Instrument, Maturity Date	Oct. 01, 2043
5.15% Senior Notes due March 2045 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.30%
Debt Instrument, Maturity Date	Mar. 15, 2045
6.125% Senior Notes due December 2045 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.35%
Debt Instrument, Maturity Date	May 15, 2045
5.30% Senior Notes due April 2047 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	6.13%
Debt Instrument, Maturity Date	Apr. 01, 2047
5.40% Senior Notes due October 1, 2047 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.30%
Debt Instrument, Maturity Date	Oct. 01, 2047
6.0% Senior Notes due 2048 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	6.00%
Debt Instrument, Maturity Date	Jun. 15, 2048
6.25% Senior Notes due 2049 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	6.25%			6.25%
Debt Instrument, Maturity Date	Apr. 15, 2049
8.125% Senior Notes, due June 1, 2019 [Member] \| Panhandle [Member]
Debt Instrument, Interest Rate, Stated Percentage	8.13%			8.125%
Debt Instrument, Maturity Date	Jun. 01, 2019
7.00% Senior Notes, due July 15, 2029 [Member] \| Panhandle [Member]
Debt Instrument, Interest Rate, Stated Percentage	7.00%
Debt Instrument, Maturity Date	Jul. 15, 2029
5.75% Senior Notes due September 1, 2020 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.75%
Debt Instrument, Maturity Date	Sep. 01, 2020
5.875% Senior Notes due April 1, 2022 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.88%
Debt Instrument, Maturity Date	Mar. 01, 2022
4.5% Senior Notes due November 1, 2023 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.50%
Debt Instrument, Maturity Date	Nov. 01, 2023
5.0% Senior Notes due October 1, 2022 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.00%
Debt Instrument, Maturity Date	Oct. 01, 2022
7.60% Senior Notes, due February 1, 2024 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	7.60%
Debt Instrument, Maturity Date	Feb. 01, 2024
7.60% Senior Notes, due February 1, 2024 [Member] \| Panhandle [Member]
Debt Instrument, Interest Rate, Stated Percentage	7.60%
Debt Instrument, Maturity Date	Feb. 01, 2024
4.05% Senior Notes due March 2025 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.05%
Debt Instrument, Maturity Date	Mar. 15, 2025
4.75% Senior Notes due January 2026 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.75%
Debt Instrument, Maturity Date	Jan. 15, 2026
8.25% Senior Notes, due November 14, 2029 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	8.25%
Debt Instrument, Maturity Date	Nov. 15, 2029
8.25% Senior Notes, due November 14, 2029 [Member] \| Panhandle [Member]
Debt Instrument, Interest Rate, Stated Percentage	8.20%
Debt Instrument, Maturity Date	Nov. 15, 2029
7.2% Junior Subordinated Notes due November 21, 2066 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.40%
9.00% Debentures, due 2024 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	9.00%
Debt Instrument, Maturity Date	Nov. 01, 2024
5.50% Senior Notes, due February 15, 2020 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.50%
Debt Instrument, Maturity Date	Feb. 15, 2020
4.40% Senior Notes due April 2021 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.40%
Debt Instrument, Maturity Date	Apr. 01, 2021
Senior Note 4.65% Due February 15, 2022 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.65%
Debt Instrument, Maturity Date	Feb. 15, 2022
3.45% Senior Notes due January 2023 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	3.45%
Debt Instrument, Maturity Date	Feb. 01, 2023
4.25% Senior Notes due April 1, 2024 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.25%
Debt Instrument, Maturity Date	Apr. 01, 2024
5.95% Senior Notes due December 2025 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.95%
Debt Instrument, Maturity Date	Dec. 01, 2025
3.90% Senior Notes due July 15, 2026 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	3.90%
Debt Instrument, Maturity Date	Jul. 15, 2026
4.20% Senior Notes due April 2027 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.20%
Debt Instrument, Maturity Date	Apr. 15, 2027
4.00% Senior Notes due October 1, 2027 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.00%
Debt Instrument, Maturity Date	Oct. 01, 2027
4.95% Senior Notes due 2028 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.95%
Debt Instrument, Maturity Date	Jun. 15, 2028
5.25% Senior Notes due 2029 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.25%			5.25%
Debt Instrument, Maturity Date	Apr. 15, 2029
6.85% Senior Notes, due February 15, 2040 [Member] \| ETO [Member]
Debt Instrument, Maturity Date	Feb. 15, 2040
Senior Note 6.10%, due February 15, 2042 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	6.50%
Debt Instrument, Maturity Date	Feb. 15, 2042
4.95% Senior Notes due January 2043 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	6.10%
Debt Instrument, Maturity Date	Jan. 15, 2043
5.30% Senior Notes due April 1, 2044 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.95%
Debt Instrument, Maturity Date	Apr. 01, 2044
5.35% Senior Notes due May 15, 2045 [Member] \| ETO [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.15%
Debt Instrument, Maturity Date	Dec. 15, 2045
5.36% Senior Unsecured Notes, due December 9, 2020 [Member] \| Transwestern [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.36%
Debt Instrument, Maturity Date	Dec. 09, 2020
5.89% Senior Unsecured Notes, due May 24, 2022 [Member] \| Transwestern [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.89%
Debt Instrument, Maturity Date	May 24, 2022
5.66% Senior Unsecured Notes, due December 9, 2024 [Member] \| Transwestern [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.66%
Debt Instrument, Maturity Date	Dec. 09, 2024
6.16% Senior Unsecured Notes, due May 24, 2037 [Member] \| Transwestern [Member]
Debt Instrument, Interest Rate, Stated Percentage	6.16%
Debt Instrument, Maturity Date	May 24, 2037
6.875% Senior notes due April 2026 [Member] \| Transwestern [Member]
Debt Instrument, Interest Rate, Stated Percentage	6.88%
Debt Instrument, Maturity Date	Apr. 01, 2026
3.625% Senior Notes due 2022 [Member] \| Bakken Pipeline [Member]
Debt Instrument, Interest Rate, Stated Percentage	3.63%
Debt Instrument, Maturity Date	Apr. 01, 2022
3.90% Senior Notes due 2024 [Member] \| Bakken Pipeline [Member]
Debt Instrument, Interest Rate, Stated Percentage	3.90%
Debt Instrument, Maturity Date	Apr. 01, 2024
4.625% Senior Notes due 2029 [Member] \| Bakken Pipeline [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.63%
Debt Instrument, Maturity Date	Apr. 01, 2029
4.875% senior notes due 2023 [Member] \| Sunoco LP [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.88%
Debt Instrument, Maturity Date	Jan. 15, 2023
5.5% Senior Notes due August 2020 [Member] \| Sunoco LP [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.50%
Debt Instrument, Maturity Date	Feb. 15, 2026
6.00% Senior Notes due April 15, 2027 [Member] \| Sunoco LP [Member]
Debt Instrument, Interest Rate, Stated Percentage	6.00%
Debt Instrument, Maturity Date	Apr. 15, 2027
5.875% senior notes due 2028 [Member] \| Sunoco LP [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.88%
Debt Instrument, Maturity Date	Mar. 15, 2028
6.875% Senior Notes due September 2027 [Member] \| Transwestern [Member]
Debt Instrument, Interest Rate, Stated Percentage	6.88%
Debt Instrument, Maturity Date	Sep. 01, 2027

Redeemable Preferred Units (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended
	Apr. 30, 2018	Dec. 31, 2019	Jan. 31, 2021	Dec. 31, 2018	Apr. 02, 2018
Redeemable noncontrolling interests		$ 739		$ 499
USAC [Member]
Redeemable noncontrolling interests		477
ETO [Member]
Redeemable noncontrolling interests		15
SemCAMS [Member]
Redeemable noncontrolling interests		$ 247
Preferred Stock, Shares Outstanding		300,000
Preferred Units [Member] \| USAC [Member]
Preferred Units, Issued					500,000
Shares Issued, Price Per Share					$ 1,000
Proceeds from Issuance of Preferred Limited Partners Units	$ 500
Distribution Made to Limited Partner, Distributions Declared, Per Unit	$ 24.375
Preferred Stock, Redemption Terms		In addition, at any time on or after the tenth anniversary of the issue date, 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 the Partnership may elect to pay up to 50% of such redemption amount in USAC common units.
Preferred Units [Member] \| SemCAMS [Member]
Preferred Units, Issued		315,859
Subsequent Event [Member]
Preferred Stock, Redemption Price Per Share			$ 845
Canada, Dollars \| Subsequent Event [Member]
Preferred Stock, Redemption Price Per Share			$ 1,100

Equity (Narrative) (Details) - USD ($)
$ / shares in Units, $ in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Jan. 01, 2020

Jul. 31, 2019

Apr. 30, 2019

Oct. 31, 2018

Jul. 31, 2018

May 31, 2018

Apr. 30, 2018

Feb. 28, 2018

Jan. 31, 2018

Nov. 30, 2017

Feb. 28, 2017

Dec. 31, 2019

Sep. 30, 2019

Jun. 30, 2019

Mar. 31, 2019

Dec. 31, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2017

Sep. 30, 2017

Jun. 30, 2017

Mar. 31, 2017

Dec. 31, 2016

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Jan. 31, 2021

Jan. 31, 2020

Jul. 30, 2019

Apr. 02, 2018

Stock Issued During Period, Shares, New Issues

14,500,000

2,300,000

32,200,000

Stock Repurchase Program, Authorized Amount

$ 2,000.0

Partners' Capital Account, Unit-based Payment Arrangement, Number of Units

57,600,000

1,458,900,000

Stock Repurchase Program, Remaining Authorized Repurchase Amount

$ 911.0

Minimum beneficial percentage ownership, other than the Partnership's General Partner and its affiliates, no voting rights, not considered outstanding

20.00%

Limited Partners' Capital Account, Units Outstanding

2,689,600,000

2,619,368,605

1,079,100,000

1,046,900,000

2,689,600,000

2,619,368,605

1,079,100,000

Stock Issued During Period, Shares, Conversion of Units

79,100,000

Limited Partner interest in the Partnership, percentage

99.90%

Units repurchased under buyback program

$ 25.0

$ 0.0

Equity Distribution Agreements, Value of Units Available to be Issued

$ 1,000.0

1,000.0

Stock Issued During Period, Value, Dividend Reinvestment Plan

$ 148.0

Common Units Remaining Available to be Issued Under Distribution Reinvestment Plan

29,000,000

Proceeds from Issuance of Common Limited Partners Units

$ 0.0

$ 568.0

Parent Company [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.3050

^[1]

$ 0.2950

^[1]

$ 0.2850

^[1]

$ 0.2850

^[1]

$ 0.2850

^[1]

PennTex [Member]

Sale of Stock, Price Per Share

20.00

Phillips 66 Company [Member] | Dakota Access and ETCOC [Member]

Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest

25.00%

Sunoco LP [Member]

Number of common units of a subsidiary partnership that are held by a wholly-owned subsidiary of the Parent.

28,500,000

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.8255

0.8255

$ 0.8255

0.8255

$ 0.8255

0.8255

Stock Repurchased During Period, Shares

17,286,859

Units repurchased under buyback program

$ 540.0

USAC [Member]

Number of common units of a subsidiary partnership that are held by a wholly-owned subsidiary of the Parent.

39,700,000

46,100,000

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.5250

0.5250

Limited Partners' Capital Account, Units Outstanding

96,600,000

Stock Issued During Period, Value, Dividend Reinvestment Plan

$ 1.0

$ 0.6

Stock Issued During Period, Shares, Dividend Reinvestment Plan

60,584

39,280

Bakken Holdings Company LLC [Member] | Sunoco Logistics [Member]

Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest

49.00%

Bakken Pipeline Investments LLC [Member] | Dakota Access and ETCOC [Member]

Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest

75.00%

Convertible Preferred Stock [Member]

Limited Partners' Capital Account, Units Outstanding

329,300,000

Series A Preferred Units [Member]

Preferred Stock, Shares Issued

950,000

Preferred Stock, Dividend Rate, Percentage

6.25%

Shares Issued, Price Per Share

$ 1,000

Preferred Units, Liquidation Spread, Percent

4.028%

Series A Preferred Units [Member] | Sunoco LP [Member]

Payments for Repurchase of Preferred Stock and Preference Stock

$ 300.0

Stock Repurchased and Retired During Period, Shares

12,000,000.0

Preferred Stock, Dividend Rate, Percentage

10.00%

Preferred Stock, Liquidation Preference Per Share

$ 25.00

Preferred Units, Liquidation Spread, Percent

8.00%

Preferred Stock Redemption Premium

$ 313.0

Call premium on preferred units.

1.00%

Series C Preferred Units [Member]

Preferred Stock, Shares Issued

18,000,000

Preferred Stock, Dividend Rate, Percentage

7.375%

Shares Issued, Price Per Share

$ 25

Preferred Units, Liquidation Spread, Percent

4.53%

Preferred Stock, Redemption Price Per Share

$ 25

Series B Preferred Units [Member]

Preferred Stock, Shares Issued

550,000

Preferred Stock, Dividend Rate, Percentage

6.625%

Shares Issued, Price Per Share

$ 1,000

Preferred Units, Liquidation Spread, Percent

4.155%

Series D Preferred Units [Member]

Preferred Stock, Dividend Rate, Percentage

7.625%

Shares Issued, Price Per Share

$ 25

Preferred Stock, Liquidation Preference Per Share

$ 17,800,000

Preferred Units, Liquidation Spread, Percent

4.738%

Preferred Stock, Redemption Price Per Share

$ 25

Series E Preferred Units [Member]

Preferred Stock, Dividend Rate, Percentage

7.60%

Shares Issued, Price Per Share

$ 25

Preferred Units, Liquidation Spread, Percent

5.161%

Preferred Stock, Redemption Price Per Share

$ 25

Preferred Units, Outstanding

32,000,000

Class B Units [Member] | USAC [Member]

Number of common units of a subsidiary partnership that are held by a wholly-owned subsidiary of the Parent.

6,400,000

Partners' Capital Account, Units, Converted

6,397,965

Class K Units [Member]

Number of common units of a subsidiary partnership that are held by a wholly-owned subsidiary of the Parent.

101,500,000

Distribution Made to Limited Partner, Distributions Declared, Per Unit

0.67275

Cash Distributions, Percent

1.50%

Class L Units [Member]

Cash Distributions, Percent

7.65%

Class M Units [Member]

Preferred Stock, Dividend Rate, Percentage

8.00%

ETE Merger [Member]

Sale of Stock, Number of Shares Issued in Transaction

1,460,000,000

ETE Merger [Member] | Sunoco LP [Member]

Sale of Stock, Number of Shares Issued in Transaction

2,263,158

ETE Merger [Member] | USAC [Member]

Limited Partner interest in the Partnership, percentage

100.00%

Sale of Stock, Number of Shares Issued in Transaction

12,466,912

USAC [Member]

Stock Issued During Period, Shares, Conversion of Units

6,397,965

Class D Units [Member]

Stock Issued During Period, Shares, New Issues

79,100,000

Series A Convertible Preferred Units [Member]

Units repurchased under buyback program

$ 0.0

ETE Class A Units [Member] | ETE Merger [Member]

Sale of Stock, Number of Shares Issued in Transaction

647,745,099

Series A Convertible Preferred Units [Member] | Parent Company [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.1100

$ 0.11

Strike price of $17.03 [Member] | USAC [Member]

Class of Warrant or Right, Number of Securities Called by Warrants or Rights

5,000,000

Class of Warrant or Right, Exercise Price of Warrants or Rights

$ 17.03

Strike price of $19.59 [Member] | USAC [Member]

Class of Warrant or Right, Number of Securities Called by Warrants or Rights

10,000,000

Class of Warrant or Right, Exercise Price of Warrants or Rights

$ 19.59

Equity Distribution Program [Member] | Sunoco LP [Member]

Equity Distribution Agreements, Value of Units Available to be Issued

$ 295.0

Partners' Capital Account, Units, Sale of Units

1,300,000

Proceeds from Issuance of Common Limited Partners Units

$ 33.0

Payments for Commissions

$ 0.3

Subsequent Event [Member]

Preferred Stock, Redemption Price Per Share

$ 845

Subsequent Event [Member] | Series F Preferred Units [Member]

Preferred Stock, Dividend Rate, Percentage

6.75%

Shares Issued, Price Per Share

$ 1,000

Preferred Units, Issued

500,000

Preferred Units, Liquidation Spread, Percent

5.134%

Subsequent Event [Member] | Series G Preferred Units [Member]

Preferred Stock, Dividend Rate, Percentage

7.125%

Shares Issued, Price Per Share

$ 1,000

Preferred Units, Issued

1,100,000

Preferred Units, Liquidation Spread, Percent

5.306%

[1]

Equity (Change In ETE Common Units) (Details) - shares	12 Months Ended
Equity (Change In ETE Common Units) (Details) - shares	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Stock Issued During Period, Shares, New Issues	14,500,000	2,300,000	32,200,000
Outstanding	2,689,600,000	2,619,368,605	1,079,100,000	1,046,900,000
Issuance of restricted Common Units under long-term incentive plans	(57,600,000)	(1,458,900,000)	0
Partners' Capital Account, Units, Treasury Units Purchased	(1,900,000)	0	0
Number of Common Units, end of period	2,689,600,000	2,619,368,605	1,079,100,000
Class D Units [Member]
Stock Issued During Period, Shares, New Issues	0	79,100,000	0

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

3 Months Ended

Dec. 31, 2019

Sep. 30, 2019

Jun. 30, 2019

Mar. 31, 2019

Dec. 31, 2018

Sep. 30, 2018

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2017

Sep. 30, 2017

Jun. 30, 2017

Mar. 31, 2017

Dec. 31, 2016

Parent Company [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.3050

^[1]

$ 0.2950

^[1]

$ 0.2850

^[1]

$ 0.2850

^[1]

$ 0.2850

^[1]

USAC [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

0.5250

Sunoco LP [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

0.8255

$ 0.8255

0.8255

Series A Convertible Preferred Units [Member] | Parent Company [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.1100

0.1100

$ 0.1100

$ 0.11

Minimum Quarterly Distribution [Member]

Distribution Payment Targets

$0.4375

First Target Distribution [Member]

Distribution Payment Targets

$0.4375 to $0.503125

Second Target Distribution [Member]

Distribution Payment Targets

$0.503125 to $0.546875

Third Target Distribution [Member]

Distribution Payment Targets

$0.546875 to $0.656250

Thereafter [Member]

Distribution Payment Targets

Above $0.656250

IDRs [Member] | Minimum Quarterly Distribution [Member]

Distribution Payment Targets

—%

IDRs [Member] | First Target Distribution [Member]

Distribution Payment Targets

—%

IDRs [Member] | Second Target Distribution [Member]

Distribution Payment Targets

15%

IDRs [Member] | Third Target Distribution [Member]

Distribution Payment Targets

25%

IDRs [Member] | Thereafter [Member]

Distribution Payment Targets

50%

Limited Partner [Member] | Minimum Quarterly Distribution [Member]

Distribution Payment Targets

100%

Limited Partner [Member] | First Target Distribution [Member]

Distribution Payment Targets

100%

Limited Partner [Member] | Second Target Distribution [Member]

Distribution Payment Targets

85%

Limited Partner [Member] | Third Target Distribution [Member]

Distribution Payment Targets

75%

Limited Partner [Member] | Thereafter [Member]

Distribution Payment Targets

50%

Series A Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

^[2]

31.2500

$ 31.2500

31.2500

15.4510

^[3]

Series B Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

^[2]

33.1250

16.3780

Series C Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

0.4609

0.5634

^[3]

Series D Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

0.4766

0.5931

^[3]

Series E Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.4750

$ 0.5806

^[3]

$ 0

[1]	Certain common unitholders elected to participate in a plan pursuant to which those unitholders elected to forego their cash distributions on all or a portion of their common units for a period of up to nine quarters commencing with the distribution for the quarter ended March 31, 2016 and, in lieu of receiving cash distributions on these common units for each such quarter, each said unitholder received ET Series A Convertible Preferred Units (on a one-for-one basis for each common unit as to which the participating unitholder elected be subject to this plan) that entitled them to receive a cash distribution of up to $0.11 per unit. See additional information below.
[2]	⁽¹⁾ ETO Series A Preferred Units and ETO Series B Preferred Unit distributions are paid on a semi-annual basis.
[3]	^* Represent prorated initial distributions. Prorated initial distributions on the recently issued ETO Series F Preferred Units and ETO Series G Preferred Units will be payable in May 2020.

Equity (Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Partners' Capital Notes [Abstract]
Unrealized gains on available-for-sale securities	$ 13	$ 2
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Gain (Loss) Arising During Period, Net of Tax	2	(5)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss) Arising During Period, after Tax	(25)	(48)
AOCI attributable to equity method investments	(1)	9
AOCI Including Portion Attributable to Noncontrolling Interest, Tax	(11)	(42)
Total AOCI included in partners' capital, net of tax	$ (11)	$ (42)

Equity Tax amounts in components of other comprehensive income (loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Other Comprehensive Income Loss Commodity Hedges Tax	$ (1)	$ (1)
Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Tax	2	2
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized (Gain) Loss Arising During Period, Tax	8	12
Other Comprehensive Income (Loss), Tax	$ 9	$ 13

ETE Unit-Based Compensation Plans (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		12 Months Ended
	Dec. 05, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Stock Issued During Period, Shares, New Issues		14.5	2.3	32.2
ETE Long-Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant		6.5
Sunoco LP Unit Based Compensation Plans [Member]
Awards granted		8.9
Weighted Average Grant-Date Fair Value Per Unit, Awards granted		$ 12.51	$ 13.00	$ 17.01
Unvested awards		28.0	22.4
Weighted Average Grant-Date Fair Value Per Unit		$ 13.89	$ 15.94
Units Vested In Period		(4.0)
Weighted Average Grant-Date Fair Value Per Unit, Awards vested		$ 21.09
Fair Value Of Units As Of The Vesting Date		$ 47	$ 49	$ 40
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount		$ 258
Equity Instruments Other than Options, Outstanding, Weighted Average Remaining Contractual Term		2 years 7 months 6 days
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period		(0.7)
Weighted Average Grant-Date Fair Value Per Unit, Awards forfeited		$ 15.70
SemGroup Compensation Plans [Member] [Member]
Awards granted	1.4
Weighted Average Grant-Date Fair Value Per Unit, Awards granted	$ 11.60

Non-Cash Compensation Plans Subsidiary Unit-Based Compensation Plans (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Subsidiary Unit Based Compensation [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair Value Of Units As Of The Vesting Date	$ 17	$ 22	$ 9
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount	$ 57
Equity Instruments Other than Options, Outstanding, Weighted Average Remaining Contractual Term	3 years 7 months 6 days
Sunoco LP Unit Based Compensation Plans [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unvested awards	2.1	2.1
Weighted Average Grant-Date Fair Value Per Unit	$ 29.21	$ 29.15
Awards granted	0.7
Weighted Average Grant-Date Fair Value Per Unit, Awards granted	$ 30.70	$ 27.67	$ 28.31
Awards vested	(0.5)
Weighted Average Grant-Date Fair Value Per Unit, Awards vested	$ 30.04
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	0.2
Weighted Average Grant-Date Fair Value Per Unit, Awards forfeited	$ 28.16
USAC Unit Based Compensation Plans [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unvested awards	1.8	1.4
Weighted Average Grant-Date Fair Value Per Unit	$ 15.09	$ 14.98
Awards granted	0.7
Weighted Average Grant-Date Fair Value Per Unit, Awards granted	$ 15.88	$ 15.47
Awards vested	(0.3)
Weighted Average Grant-Date Fair Value Per Unit, Awards vested	$ 13.06
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	0.0
Weighted Average Grant-Date Fair Value Per Unit, Awards forfeited	$ 16.78

Non-Cash Compensation Plans Unit-based compensation Narrative (Details) $ / shares in Units, shares in Millions, $ in Millions	1 Months Ended	12 Months Ended
	Oct. 31, 2018	Dec. 31, 2019 USD ($) $ / shares shares	Dec. 31, 2018 USD ($) $ / shares shares	Dec. 31, 2017 USD ($) $ / shares
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount		$ 0	$ 0	$ (1,812)
ET Unit Based Compensation Plans [Member]
Weighted Average Grant-Date Fair Value Per Unit, Awards granted \| $ / shares		$ 12.51	$ 13.00	$ 17.01
Fair Value Of Units As Of The Vesting Date		$ 47	$ 49	$ 40
Unvested awards \| shares		28.0	22.4
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount		$ 258
Equity Instruments Other than Options, Outstanding, Weighted Average Remaining Contractual Term		2 years 7 months 6 days
Subsidiary Unit Based Compensation [Member]
Fair Value Of Units As Of The Vesting Date		$ 17	$ 22	$ 9
Share-based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount		$ 57
Equity Instruments Other than Options, Outstanding, Weighted Average Remaining Contractual Term		3 years 7 months 6 days
ETE Merger [Member]
Stockholders' Equity Note, Stock Split, Conversion Ratio	1.28

Income Taxes Narrative (Details) - USD ($) $ in Millions	12 Months Ended
Income Taxes Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Oct. 31, 2019
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	$ 1,100
Deferred Tax Liabilities, Gross	4,141	$ 3,826
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	90
Net operating losses, alternative minimum tax credit and other carryforwards	936	768
Valuation allowance	(95)	(96)
Unrecognized Tax Benefits That Would Impact Effective Tax Rate, Ater Tax	72
State	(2)	19	$ (16)
Unrecognized Tax Benefits, Interest on Income Taxes Expense	1
Income Tax Examination, Penalties and Interest Accrued	3
Deferred Income Tax Expense (Benefit)	217	(7)	(1,871)
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount	0	$ 0	$ (1,812)
Tax Credit Carryforward, Valuation Allowance	49
ETP Holdco and other corporate subsidiaries [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	2,650
SemGroup [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	766
Corporate Subsidiaries [Member]
Operating Loss Carryforwards [Line Items]
Net operating losses, alternative minimum tax credit and other carryforwards	15
Deferred Tax Asset, Interest Carryforward	$ 35
Holdco [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Jan. 01, 2031
Sunoco, Inc. [Member]
Operating Loss Carryforwards [Line Items]
Estimated Litigation Liability				$ 530
Net of federal tax [Member]
Operating Loss Carryforwards [Line Items]
State	$ 53
Maximum [Member] \| Corporate Subsidiaries [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2037
Minimum [Member] \| Corporate Subsidiaries [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Expiration Date	Jan. 01, 2020
Expiring between 2031 and 2037 [Member] \| SemGroup [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 185
Reclassed to current income tax receivable within 12 months [Member]
Operating Loss Carryforwards [Line Items]
Net operating losses, alternative minimum tax credit and other carryforwards	8
Expiring between 2020 and 2038 [Member] \| Corporate Subsidiaries [Member]
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Operating Loss Carryforwards, State and Local	118
Expiring in 2033 [Member] \| Corporate Subsidiaries [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	68
Expiring in 2020 [Member] \| Corporate Subsidiaries [Member]
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Tax Credit Carryforwards, Foreign	45
Pennsylvania Constitution [Member]
Operating Loss Carryforwards [Line Items]
State	67
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Contingencies	34
Pennsylvania Constitution [Member] \| Net of federal tax [Member]
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Contingencies	27
Canada, Dollars \| Corporate Subsidiaries [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Valuation Allowance	$ 46

Income Taxes Components of Income Tax (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Current expense (benefit):
Federal	$ (20)	$ (8)	$ 54
State	(2)	19	(16)
Total	(22)	11	38
Deferred expense (benefit):
Federal	174	181	(2,055)
State	43	(188)	184
Total	217	(7)	(1,871)
Total income tax expense (benefit) from continuing operations	$ 195	$ 4	$ (1,833)

Income Taxes Reconciliation of Income Tax Satutory Rate (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Effective Income Tax Rate Reconciliation, Change in Tax Status of Subsidiary	$ 0	$ 0	$ (124)
Income tax expense at United States statutory rate	1,070	763	248
Increase (reduction) in income taxes resulting from:
Goodwill impairment	0	0	207
Partnership earnings not subject to tax	(882)	(635)	(477)
State tax, net of federal tax benefit	12	(125)	124
Dividend received deduction	(3)	(5)	(14)
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, Amount	0	0	(1,812)
Other	(2)	6	15
Total income tax expense (benefit) from continuing operations	$ 195	$ 4	$ (1,833)

Income Taxes Effects of Temporary Differences That Comprise Net Deffered Income Tax Liability (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Deferred income tax assets:
Net operating losses, alternative minimum tax credit and other carryforwards	$ 936	$ 768
Pension and other postretirement benefits	7	34
Long-term debt	0	13
Other	85	181
Deferred Tax Assets, Gross	1,028	996
Valuation allowance	(95)	(96)
Net deferred income tax assets	933	900
Deferred income tax liabilities:
Property, plant and equipment	(501)	(782)
Investments in affiliates	(3,547)	(2,872)
Trademarks	(72)	(63)
Other	(21)	(109)
Deferred Tax Liabilities, Gross	4,141	3,826
Deferred Tax Liabilities	$ (3,208)	$ (2,926)

Income Taxes Components of Net Deferred Tax Liability (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Components of Net Deferred Income Tax [Abstract]
Total deferred income tax assets	$ 1,028	$ 996
Deferred Tax Liabilities, Net	(3,208)	(2,926)
Valuation allowance	95	96
Net deferred income tax assets	$ 933	$ 900

Income Taxes Changes in Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Changes in Unrecognized Tax Benefits [Abstract]
Balance at beginning of year	$ 624	$ 609	$ 615
Additions attributable to tax positions taken in the current year	0	8	0
Additions attributable to tax positions taken in prior years	11	7	28
Reduction attributable to tax positions taken in prior years	(541)	0	(25)
Lapse of statute	0	0	9
Balance at end of year	$ 94	$ 624	$ 609

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Limited Partner interest in the Partnership, percentage	99.90%
Operating Leases, Rent Expense	$ 45,000,000	$ 46,000,000	$ 46,000,000
Payments for Environmental Liabilities	39,000,000	48,000,000
Accrual for loss contingency	0
Loss Contingency, Estimate of Possible Loss	80,000,000
Total environmental liabilities	$ 320,000,000	337,000,000
Site Contingency, Number of Sites Needing Remediation	40
Long-term Debt	$ 51,054,000,000	46,028,000,000
PES [Member]
Limited Partner interest in the Partnership, percentage	7.40%
Debt Instrument, Debt Default, Amount	$ 75,000,000
Sunoco LP [Member]
Long-term Debt	3,071,000,000	2,984,000,000
Rover Pipeline LLC [Member]
Proposed Environmental Penalty	2,600,000
SPLP and Mid-Valley Pipeline [Member]
Loss Contingency, Damages Awarded, Value	5,400,000
Related To Deductibles [Member]
Accrual for loss contingency	$ 120,000,000	56,000,000
4.875% senior notes due 2023 [Member] \| Sunoco LP [Member]
Debt Instrument, Interest Rate, Stated Percentage	4.88%
Senior Notes	$ 1,000,000,000	1,000,000,000
5.500% senior notes due 2026 [Member] \| Sunoco LP [Member]
Senior Notes	$ 800,000,000	800,000,000
5.875% senior notes due 2028 [Member] \| Sunoco LP [Member]
Debt Instrument, Interest Rate, Stated Percentage	5.88%
Senior Notes	$ 400,000,000	$ 400,000,000
Final Judgement [Member]
Gain Contingency, Unrecorded Amount	536,000,000
Expense Reimbursement [Member]
Gain Contingency, Unrecorded Amount	1,000,000
Disgorgement [Member]
Gain Contingency, Unrecorded Amount	595,000,000
Compensatory Damages [Member]
Gain Contingency, Unrecorded Amount	$ 319,000,000

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Regulatory Matters, Commitments, Contingencies And Environemental Liabilities (Environmental Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Environmental Remediation Obligations [Abstract]
Current		$ 42
Non-current		295
Total environmental liabilities	$ 320	$ 337

Revenue Narrative (Details) - USD ($) $ in Millions	12 Months Ended
Revenue Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Sunoco LP [Member]
Capitalized Contract Cost, Amortization	$ 17	$ 14

Revenue Contracts with customers (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Jan. 01, 2019	Jan. 01, 2018
Contract with Customer, Liability	$ 377	$ 394		$ 221
Deferred Revenue, Additions	664	765
Contract with Customer, Liability, Revenue Recognized	$ (681)	(592)
Sunoco LP [Member]
Contract with Customer, Liability		1	$ 0
Receivables from Customers		347	366
Contract with Customer, Asset, after Allowance for Credit Loss		$ 75	$ 117

Revenue Revenue, future obligations (Details) $ in Millions	Dec. 31, 2019 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-12-31
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 6,232
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	5,300
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-12-31
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	4,899
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-12-31
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	27,158
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 43,589

Lease Accounting Leasee Accounting(Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jan. 01, 2019
Rental Income, Nonoperating	$ 149
Operating Lease, Weighted Average Remaining Lease Term	24 years
Lessee, Operating Lease, Liability, Payments, Remainder of Fiscal Year	$ 104
Operating Lease, Cost	117
Operating Lease, Right-of-Use Asset	1,000	$ 0		$ 889
Operating Lease, Liability, Current	60	0		71
Accrued and other current liabilities	3,342	2,918		2,917
Operating Lease, Liability, Noncurrent	901	0		823
Property, Plant and Equipment, Net	74,193	66,963		66,962
Current maturities of long-term debt	26	2,655		2,656
Long-term debt, less current maturities	51,028	43,373		43,379
Other non-current liabilities	1,162	1,184		$ 1,172
Finance Lease, Interest Expense	1
Lease, Cost	136
Lease, Cost, Gross	183
Net Cash Provided by (Used in) Financing Activities	(1,197)	$ (3,082)	$ 953
Finance Lease, Liability, Payments, Remainder of Fiscal Year	8
Lease Liabilities, Remainder of Year	112
Lessee, Operating Lease, Liability, Payments, Due Year Two	96
Finance Lease, Liability, Payments, Due Year Two	8
Lease Liabilities, Due Year Two	104
Lessee, Operating Lease, Liability, Payments, Due Year Three	83
Finance Lease, Liability, Payments, Due Year Three	8
Lease Liabilities, Due Year Three	91
Lessee, Operating Lease, Liability, Payments, Due Year Four	77
Finance Lease, Liability, Payments, Due Year Four	7
Lease Liabilities, Due Year Four	84
Lessee, Operating Lease, Liability, Payments, Due Year Five	74
Finance Lease, Liability, Payments, Due Year Five	4
Lease Liabilities, Due Year Five	78
Lessee, Operating Lease, Liability, Payments, Due after Year Five	1,342
Finance Lease, Liability, Payments, Due after Year Five	5
Lease Liabilities, Due After Five Years	1,347
Lessee, Operating Lease, Liability, Payments, Due	1,776
Finance Lease, Liability, Payment, Due	40
Lease Liabilities, Due	1,816
Lessee, Operating Lease, Liability, Undiscounted Excess Amount	815
Finance Lease, Liability, Undiscounted Excess Amount	5
Lease Liability, Undiscounted Excess Amount	820
Operating Lease, Liability	961
Finance Lease, Liability	35
Lease, Liabilities	$ 996
Finance Lease, Weighted Average Remaining Lease Term	5 years
Right-of-Use Asset Obtained in Exchange for Finance Lease Liability	$ 28
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	40
Operating Leases [Member]
Net Cash Provided by (Used in) Operating Activities	(159)
Operating Lease, Right-of-Use Asset	935
Operating Lease, Liability, Current	60
Accrued and other current liabilities	1
Operating Lease, Liability, Noncurrent	901
Finance Leases [Member]
Accrued and other current liabilities	1
Property, Plant and Equipment, Net	1
Finance Lease, Right-of-Use Asset	29
Current maturities of long-term debt	6
Long-term debt, less current maturities	26
Other non-current liabilities	2
Lease, Cost	7
Cost of Goods and Service Benchmark [Member]
Operating Lease, Cost	28
Operating Expense [Member]
Operating Lease, Cost	73
Short-term Lease, Cost	42
Variable Lease, Cost	17
Selling, General and Administrative Expenses [Member]
Operating Lease, Cost	16
Depreciation And Amortization [Member]
Finance Lease, Right-of-Use Asset, Amortization	6
Other Revenue [Member]
Sublease Income	$ 47
ETO [Member]
Operating Lease, Weighted Average Discount Rate, Percent	5.00%
Finance Lease, Weighted Average Discount Rate, Percent	5.00%
Real Estate [Member]
Lessee, Operating Lease, Term of Contract	40 years
Minimum [Member]
Lessee, Operating Lease, Renewal Term	1 year
Minimum [Member] \| Equipment [Member]
Lessee, Operating Lease, Term of Contract	5 years
Maximum [Member]
Lessee, Operating Lease, Renewal Term	20 years
Maximum [Member] \| Equipment [Member]
Lessee, Operating Lease, Term of Contract	15 years

Lease Accounting Lessor Accounting (Details) $ in Millions	12 Months Ended
Lease Accounting Lessor Accounting (Details) $ in Millions	Dec. 31, 2019 USD ($)
Leases [Abstract]
Rental Income, Nonoperating	$ 149
Lessor, Operating Lease, Payments to be Received, Next Twelve Months	138
Lessor, Operating Lease, Payments to be Received, Two Years	112
Lessor, Operating Lease, Payments to be Received, Three Years	75
Lessor, Operating Lease, Payments to be Received, Four Years	20
Lessor, Operating Lease, Payments to be Received, Five Years	15
Lessor, Operating Lease, Payments to be Received, Thereafter	12
Lessor, Operating Lease, Payments to be Received	$ 372

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

Dec. 31, 2019

barrels

BBtu

MB_bls

bushels

Dec. 31, 2018

MMbtu

barrels

BBtu

bushels

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

Derivative, Nonmonetary Notional Amount

(9,265)

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

Derivative, Nonmonetary Notional Amount

(3,085)

(1,068)

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

Derivative, Nonmonetary Notional Amount

(18,923)

(30,228)

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

Derivative, Nonmonetary Notional Amount

(13,364)

(123,254)

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

Derivative, Nonmonetary Notional Amount

^[1]

(35,208)

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

Derivative, Nonmonetary Notional Amount

(31,780)

(17,445)

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

Derivative, Nonmonetary Notional Amount

(31,780)

(17,445)

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

Derivative, Nonmonetary Notional Amount

(54,158)

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

Derivative, Nonmonetary Notional Amount

(1,483)

(468)

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

Derivative, Nonmonetary Notional Amount

^[1]

(16,845)

Natural Gas [Member] | Long [Member] | Mark-To-Market Derivatives [Member] | Trading [Member] | Options - Calls [Member]

Derivative, Nonmonetary Notional Amount

(10,000)

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

Derivative, Nonmonetary Notional Amount

(31,780)

(17,445)

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

Derivative, Nonmonetary Notional Amount | MW

(2,704,330)

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

Derivative, Nonmonetary Notional Amount | MW

(353,527)

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

Derivative, Nonmonetary Notional Amount | MW

(284,800)

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

Derivative, Nonmonetary Notional Amount | MW

(3,213,450)

(3,141,520)

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

Derivative, Nonmonetary Notional Amount | MW

(56,656)

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

Derivative, Nonmonetary Notional Amount | MW

(51,615)

(18,400)

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

Derivative, Nonmonetary Notional Amount

(1,300)

(2,135)

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

Derivative, Nonmonetary Notional Amount

(2,473)

(1,403)

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

Derivative, Nonmonetary Notional Amount | bushels

(1,210)

(1,920)

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

Derivative, Nonmonetary Notional Amount | barrels

(4,465)

(20,888)

[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 (Interest Rate Swaps Outstanding) (Details) - Derivatives Not Designated As Hedging Instruments - Interest Rate Derivatives [Member] - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

March 2019 [Member]

Notional Amount

$ 0

$ 300

Type

^[1]

Pay a floating rate and receive a fixed rate of 1.42%

July 2019 [Member] | Forward-Starting Swaps [Member]

Notional Amount

^[2],[3]

$ 400

400

Type

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

Forward-starting to pay a fixed rate of 3.52% and receive a floating rate

July 2021 [Member] | Forward-Starting Swaps [Member]

Notional Amount

^[3]

$ 400

400

Type

^[1],[3]

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

July 2018 [Member] | Forward-Starting Swaps [Member]

Notional Amount

^[3]

$ 0

400

Type

^[1],[3]

Forward-starting to pay a fixed rate of 3.56% and receive a floating rate

July 2022 [Member] | Forward-Starting Swaps [Member]

Notional Amount

^[3]

$ 400

$ 0

Type

^[1],[3]

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

[1]	Floating rates are based on 3-month LIBOR.
[2]	The July 2020 interest rate swaps were terminated in January 2020.
[3]	Represents the effective date. These forward-starting swaps have terms of 30 years with a mandatory termination date the same as the effective date.

Derivative Assets And Liabilities (Fair Value Of Derivative Instruments) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Asset Derivatives	$ 384	$ 560
Liability Derivatives	(788)	(746)
Designated as Hedging Instrument [Member]
Asset Derivatives	24	0
Liability Derivatives	0	(13)
Not Designated as Hedging Instrument [Member]
Asset Derivatives	360	560
Liability Derivatives	(788)	(733)
Broker cleared derivative contracts [Member]
Asset Derivatives	343	402
Liability Derivatives	(350)	(410)
Commodity Derivatives [Member] \| Not Designated as Hedging Instrument [Member]
Asset Derivatives	41	158
Liability Derivatives	(39)	(173)
Commodity Derivatives (Margin Deposits) [Member] \| Designated as Hedging Instrument [Member]
Asset Derivatives	24	0
Liability Derivatives	0	(13)
Commodity Derivatives (Margin Deposits) [Member] \| Not Designated as Hedging Instrument [Member]
Asset Derivatives	319	402
Liability Derivatives	(350)	(397)
Interest Rate Derivatives [Member] \| Not Designated as Hedging Instrument [Member]
Asset Derivatives	0	0
Liability Derivatives	$ (399)	$ (163)

Derivative Assets And Liabilities Derivative Assets and Lianilities (Offsetting Agreements Netting Table) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Asset Derivatives	$ 384	$ 560
Derivative Liability, Fair Value, Gross Liability	(788)	(746)
Derivative Asset, Fair Value, Amount Offset Against Collateral	(18)	(47)
Derivative Liability, Fair Value, Amount Offset Against Collateral	18	47
Derivative Asset, Collateral, Obligation to Return Cash, Offset	(318)	(397)
Derivative Liability, Collateral, Right to Reclaim Cash, Offset	318	397
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	48	116
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	452	302
Without offsetting agreements [Member]
Asset Derivatives	0	0
Derivative Liability, Fair Value, Gross Liability	(399)	(163)
OTC Contracts [Member]
Asset Derivatives	41	158
Derivative Liability, Fair Value, Gross Liability	(39)	(173)
Broker cleared derivative contracts [Member]
Asset Derivatives	343	402
Derivative Liability, Fair Value, Gross Liability	$ (350)	$ (410)

Derivative Assets And Liabilities (Derivatives Recognized OCI On Derivatives) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cost of Sales [Member] \| Commodity Derivatives [Member]
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	$ 0	$ (3)	$ 26

Derivative Assets And Liabilities (Derivative Amount Of Gain (Loss) Recognized) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Amount of Gain/(Loss) Recognized in Income on Derivatives	$ (301)	$ (23)	$ 0
Gains (losses) on interest rate derivatives	(241)	47	(37)
Commodity Derivatives [Member] \| Cost of Sales [Member]
Amount of Gain/(Loss) Recognized in Income Representing Hedge Ineffectiveness and Amount Excluded from the Assessment of Effectiveness	0	(3)	26
Embedded Derivatives in Preferred Units [Member] \| Other Income (Expenses) [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	0	0	1
Non Trading [Member] \| Commodity Derivatives [Member] \| Cost of Sales [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	(78)	(102)	5
Trading [Member] \| Commodity Derivatives [Member] \| Trading Revenue [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	(3)	0	0
Trading [Member] \| Commodity Derivatives [Member] \| Cost of Sales [Member]
Amount of Gain/(Loss) Recognized in Income on Derivatives	$ 21	$ 32	$ 31

Retirement Benefits (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Retirement Benefits [Line Items]
Defined Contribution Plan, Cost	$ 66	$ 62	$ 59
Sunoco [Member]
Retirement Benefits [Line Items]
Liability, Other Postretirement Defined Benefit Plan, Noncurrent	$ 200
Pension Benefits
Retirement Benefits [Line Items]
Large Cap US Equitiies	100.00%	100.00%
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year	$ 7
Other Postretirement Benefits
Retirement Benefits [Line Items]
Large Cap US Equitiies	59.00%	53.00%
Fixed Income Securities	40.00%	46.00%
Cash Fund Investments	1.00%	1.00%
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year	$ 8
Minimum [Member] \| Other Postretirement Benefits \| Equity [Member]
Retirement Benefits [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Percentage	25.00%
Minimum [Member] \| Other Postretirement Benefits \| Fixed Income Investments [Member]
Retirement Benefits [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Percentage	65.00%
Maximum [Member] \| Other Postretirement Benefits \| Equity [Member]
Retirement Benefits [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Percentage	35.00%
Maximum [Member] \| Other Postretirement Benefits \| Fixed Income Investments [Member]
Retirement Benefits [Line Items]
Defined Benefit Plan, Plan Assets, Investment within Plan Asset Category, Percentage	75.00%
Funded Plans [Member] \| Pension Benefits
Retirement Benefits [Line Items]
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months	$ 1

Retirement Benefits (Obligations and Funded Status) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Change in benefit obligation:
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	$ 0	$ 0
Change in plan assets:
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	0	0
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	0	0
Change in benefit obligation:
Defined Benefit Plan, Interest Cost	3	1
Change in plan assets:
Defined Benefit Plan, Plan Assets, Amount	43
Amounts recognized in the consolidated balance sheets consist of:
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position		0
Amounts recognized in accumulated other comprehensive loss (pre-tax basis) consist of:
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, after Tax		0
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	1	1
Change in benefit obligation:
Defined Benefit Plan, Benefit Obligation	198	156
Defined Benefit Plan, Interest Cost	7	5
Defined Benefit Plan, Benefit Obligation, Increase (Decrease) for Plan Amendment	0	60
Defined Benefit Plan, Benefits Paid (Deprecated 2017-01-31)	(16)	(17)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	18	(7)
Defined Benefit Plan, Benefit Obligation	208	198
Change in plan assets:
Defined Benefit Plan, Plan Assets, Amount	241	257
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss)	35	(8)
Defined Benefit Plan, Plan Assets, Contributions by Employer	10	9
Defined Benefit Plan, Plan Assets, Amount	270	241
Defined Benefit Plan, Funded (Unfunded) Status of Plan	(62)	(43)
Amounts recognized in the consolidated balance sheets consist of:
Assets for Plan Benefits, Defined Benefit Plan	88	68
Liability, Defined Benefit Plan, Current	(2)	(2)
Liability, Defined Benefit Plan, Noncurrent	(24)	(23)
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position	62	43
Amounts recognized in accumulated other comprehensive loss (pre-tax basis) consist of:
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), after Reclassification Adjustment, before Tax	(5)	(7)
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), before Tax	40	66
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, after Tax	35	59
Defined Benefit Plan, Plan Assets, Benefits Paid	(16)	(17)
Funded Plans [Member]
Change in benefit obligation:
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	(4)
Change in plan assets:
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	(4)
Funded Plans [Member] \| Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	0
Change in benefit obligation:
Defined Benefit Plan, Benefit Obligation	1	1
Defined Benefit Plan, Interest Cost	2	0
Defined Benefit Plan, Benefit Obligation, Increase (Decrease) for Plan Amendment	0	0
Defined Benefit Plan, Benefits Paid (Deprecated 2017-01-31)	(1)	0
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	4	0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement		0
Defined Benefit Plan, Benefit Obligation	52	1
Change in plan assets:
Defined Benefit Plan, Plan Assets, Amount	1	1
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss)	6	0
Defined Benefit Plan, Plan Assets, Contributions by Employer	1	0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement		0
Defined Benefit Plan, Plan Assets, Amount	43	1
Defined Benefit Plan, Funded (Unfunded) Status of Plan	9	0
Amounts recognized in the consolidated balance sheets consist of:
Assets for Plan Benefits, Defined Benefit Plan	0	0
Liability, Defined Benefit Plan, Current	0	0
Liability, Defined Benefit Plan, Noncurrent	(9)	0
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position	(9)
Amounts recognized in accumulated other comprehensive loss (pre-tax basis) consist of:
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), after Reclassification Adjustment, before Tax	0	0
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), before Tax	0	0
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, after Tax	0
Defined Benefit Plan, Plan Assets, Benefits Paid	(1)	0
Unfunded Plans [Member]
Change in benefit obligation:
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	0	0
Change in plan assets:
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	0	0
Unfunded Plans [Member] \| Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	0	0
Change in benefit obligation:
Defined Benefit Plan, Benefit Obligation	37	47
Defined Benefit Plan, Interest Cost	1	1
Defined Benefit Plan, Benefit Obligation, Increase (Decrease) for Plan Amendment	0	0
Defined Benefit Plan, Benefits Paid (Deprecated 2017-01-31)	(7)	(7)
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	0	(4)
Defined Benefit Plan, Benefit Obligation	34	37
Change in plan assets:
Defined Benefit Plan, Plan Assets, Amount	0	0
Defined Benefit Plan, Plan Assets, Increase (Decrease) for Actual Return (Loss)	0	0
Defined Benefit Plan, Plan Assets, Contributions by Employer	0	0
Defined Benefit Plan, Plan Assets, Amount	0	0
Defined Benefit Plan, Funded (Unfunded) Status of Plan	34	37
Amounts recognized in the consolidated balance sheets consist of:
Assets for Plan Benefits, Defined Benefit Plan	0	0
Liability, Defined Benefit Plan, Current	(5)	(6)
Liability, Defined Benefit Plan, Noncurrent	(29)	(31)
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position	(34)	(37)
Amounts recognized in accumulated other comprehensive loss (pre-tax basis) consist of:
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), after Reclassification Adjustment, before Tax	1	1
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), before Tax	0	0
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, after Tax	1	1
Defined Benefit Plan, Plan Assets, Benefits Paid	0	0
SemGroup Compensation Plans [Member] [Member]
Change in benefit obligation:
Defined Benefit Plan, Benefit Obligation	0
Defined Benefit Plan, Benefit Obligation	0	0
SemGroup Compensation Plans [Member] [Member] \| Other Postretirement Benefits
Change in plan assets:
Defined Benefit Plan, Plan Assets, Amount	0
Defined Benefit Plan, Plan Assets, Amount	0	0
SemGroup Compensation Plans [Member] [Member] \| Funded Plans [Member]
Change in benefit obligation:
Defined Benefit Plan, Benefit Obligation	50
SemGroup Compensation Plans [Member] [Member] \| Funded Plans [Member] \| Pension Benefits
Change in benefit obligation:
Defined Benefit Plan, Benefit Obligation	0
Defined Benefit Plan, Benefit Obligation		0
Change in plan assets:
Defined Benefit Plan, Plan Assets, Amount	0
Defined Benefit Plan, Plan Assets, Amount	40	0
SemGroup Compensation Plans [Member] [Member] \| Unfunded Plans [Member]
Change in benefit obligation:
Defined Benefit Plan, Benefit Obligation	0
Defined Benefit Plan, Benefit Obligation	3	0
SemGroup Compensation Plans [Member] [Member] \| Unfunded Plans [Member] \| Pension Benefits
Change in plan assets:
Defined Benefit Plan, Plan Assets, Amount	0
Defined Benefit Plan, Plan Assets, Amount	$ 0	$ 0

Retirement Benefits (Accumulated Benefit Obligation In Excess of Plan Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Plan Assets		$ 241
Funded Plans [Member] \| Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Pension Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Projected Benefit Obligation	$ 51	0
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Plan Assets		1
Unfunded Plans [Member] \| Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Pension Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Projected Benefit Obligation	$ 34	37
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Plan Assets		$ 0

Retirement Benefits (Net Periodic Benefit Costs Schedule) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	$ 0	$ 0
Defined Benefit Plan, Interest Cost	3	1
Defined Benefit Plan, Expected Return (Loss) on Plan Assets	2	0
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	0	0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)	1	1
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Service Cost	1	1
Defined Benefit Plan, Interest Cost	7	5
Defined Benefit Plan, Expected Return (Loss) on Plan Assets	10	10
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	26	16
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)	$ 24	$ 12

Retirement Benefits (Benefit Assumptions) (Details)	12 Months Ended
Retirement Benefits (Benefit Assumptions) (Details)	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed, Next Fiscal Year	7.25%	7.15%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	4.83%	4.82%
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.00%	4.02%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.33%	3.52%
Expected long term return on assets, tax exempt accounts	3.37%	3.26%
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	2.71%	3.40%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.76%	3.51%
Expected long term return on assets, tax exempt accounts	7.00%	6.63%
Expected long term return on assets, taxable accounts	4.75%	4.50%

Retirement Benefits (Fair Value of Plan Assets) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Benefit Obligation	$ 208	$ 198	$ 156
Defined Benefit Plan, Plan Assets, Amount	270	241	257
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Plan Assets		241
Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	43
Cash and Cash Equivalents [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	14	20
Cash and Cash Equivalents [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	1
Mutual Fund [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	177	144
Mutual Fund [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	19	1
Fixed Income Securities [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	79	77
Fixed Income Securities [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	23
Level 1 [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	191	164
Level 1 [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	20
Level 1 [Member] \| Cash and Cash Equivalents [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	14	20
Level 1 [Member] \| Cash and Cash Equivalents [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	1
Level 1 [Member] \| Mutual Fund [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	177	144
Level 1 [Member] \| Mutual Fund [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	19	1
Level 1 [Member] \| Fixed Income Securities [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0	0
Level 1 [Member] \| Fixed Income Securities [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0
Level 2 [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	79	77
Level 2 [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	23
Level 2 [Member] \| Cash and Cash Equivalents [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0	0
Level 2 [Member] \| Cash and Cash Equivalents [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0
Level 2 [Member] \| Mutual Fund [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0	0
Level 2 [Member] \| Mutual Fund [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0	0
Level 2 [Member] \| Fixed Income Securities [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	79	77
Level 2 [Member] \| Fixed Income Securities [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	23
Level 3 [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0	0
Level 3 [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0
Level 3 [Member] \| Cash and Cash Equivalents [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0	0
Level 3 [Member] \| Cash and Cash Equivalents [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0
Level 3 [Member] \| Mutual Fund [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0	0
Level 3 [Member] \| Mutual Fund [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0	0
Level 3 [Member] \| Fixed Income Securities [Member] \| Other Postretirement Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0	0
Level 3 [Member] \| Fixed Income Securities [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Plan Assets, Amount	0
Funded Plans [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Pension Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Projected Benefit Obligation	51	0
Defined Benefit Plan, Benefit Obligation	52	1	1
Defined Benefit Plan, Plan Assets, Amount	43	1	1
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Plan Assets		1
Unfunded Plans [Member] \| Pension Benefits
Fair Value of Plan Assets [Line Items]
Defined Benefit Plan, Pension Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Projected Benefit Obligation	34	37
Defined Benefit Plan, Benefit Obligation	34	37	47
Defined Benefit Plan, Plan Assets, Amount	$ 0	0	$ 0
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Plan Assets		$ 0

Retirement Benefits (Benefit Payments) (Details)
$ in Millions

Dec. 31, 2019

USD ($)

Other Postretirement Benefits (Gross, Before Medicare Part D) [Member]

Defined Benefit Plan Disclosure [Line Items]

2020

$ 20

^[1]

Unfunded Plans [Member] | Pension Benefits

Defined Benefit Plan Disclosure [Line Items]

^[1]

$ 22

[1]	Expected benefit payments of funded pension plans are less than $1 million for the next ten years.

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Accounts payable to related companies	$ 31	$ 59
Revenue	492	431	$ 303
Accounts Receivable, Related Parties, Current	159	111
FGT [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	50	25
Other Related Parties [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	31	44
Phillips 66 Company [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	36	42
Traverse Rover LLC [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	$ 42	$ 0

Reportable Segments Revenue (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenue from External Customer [Line Items]
Revenues	$ 13,720	$ 13,495	$ 13,877	$ 13,121	$ 13,573	$ 14,514	$ 14,118	$ 11,882	$ 54,213	$ 54,087	$ 40,523
Investment In USAC [Member]
Revenue from External Customer [Line Items]
Revenues									698	508	0
Intersegment Eliminations [Member]
Revenue from External Customer [Line Items]
Revenues									(5,951)	(7,039)	(5,609)
Other Segments [Member]
Revenue from External Customer [Line Items]
Revenues									1,689	2,228	2,901
Crude oil transportation and services [Member]
Revenue from External Customer [Line Items]
Revenues									18,447	17,332	11,703
NGL and refined products transportation and services [Member]
Revenue from External Customer [Line Items]
Revenues									11,641	11,123	8,648
Midstream [Member]
Revenue from External Customer [Line Items]
Revenues									6,031	7,522	6,943
Interstate Transportation and Storage [Member]
Revenue from External Customer [Line Items]
Revenues									1,963	1,682	1,131
Intrastate Transportation And Storage [Member]
Revenue from External Customer [Line Items]
Revenues									3,099	3,737	3,083
Investment In Sunoco LP [Member]
Revenue from External Customer [Line Items]
Revenues									16,596	16,994	11,723
Intersegment [Member] \| Investment In USAC [Member]
Revenue from External Customer [Line Items]
Revenues									20	13	0
Intersegment [Member] \| Other Segments [Member]
Revenue from External Customer [Line Items]
Revenues									81	155	161
Intersegment [Member] \| Crude oil transportation and services [Member]
Revenue from External Customer [Line Items]
Revenues									0	96	31
Intersegment [Member] \| NGL and refined products transportation and services [Member]
Revenue from External Customer [Line Items]
Revenues									1,721	1,004	763
Intersegment [Member] \| Midstream [Member]
Revenue from External Customer [Line Items]
Revenues									3,751	5,432	4,433
Intersegment [Member] \| Interstate Transportation and Storage [Member]
Revenue from External Customer [Line Items]
Revenues									22	18	19
Intersegment [Member] \| Intrastate Transportation And Storage [Member]
Revenue from External Customer [Line Items]
Revenues									350	309	192
Intersegment [Member] \| Investment In Sunoco LP [Member]
Revenue from External Customer [Line Items]
Revenues									6	12	10
External Customers [Member] \| Investment In USAC [Member]
Revenue from External Customer [Line Items]
Revenues									678	495	0
External Customers [Member] \| Other Segments [Member]
Revenue from External Customer [Line Items]
Revenues									1,608	2,073	2,740
External Customers [Member] \| Crude oil transportation and services [Member]
Revenue from External Customer [Line Items]
Revenues									18,447	17,236	11,672
External Customers [Member] \| NGL and refined products transportation and services [Member]
Revenue from External Customer [Line Items]
Revenues									9,920	10,119	7,885
External Customers [Member] \| Midstream [Member]
Revenue from External Customer [Line Items]
Revenues									2,280	2,090	2,510
External Customers [Member] \| Interstate Transportation and Storage [Member]
Revenue from External Customer [Line Items]
Revenues									1,941	1,664	1,112
External Customers [Member] \| Intrastate Transportation And Storage [Member]
Revenue from External Customer [Line Items]
Revenues									2,749	3,428	2,891
External Customers [Member] \| Investment In Sunoco LP [Member]
Revenue from External Customer [Line Items]
Revenues									$ 16,590	$ 16,982	$ 11,713

Reportable Segments (Operating Segments) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cost of Goods and Services Sold	$ 39,727	$ 41,658	$ 30,966
Depreciation, depletion and amortization	3,147	2,859	2,554
Equity in earnings of unconsolidated affiliates	302	344	144
Intrastate Transportation And Storage [Member]
Cost of Goods and Services Sold	1,909	2,665	2,327
Depreciation, depletion and amortization	184	169	147
Equity in earnings of unconsolidated affiliates	18	19	(156)
Investment In Sunoco LP [Member]
Cost of Goods and Services Sold	15,380	15,872	10,615
Depreciation, depletion and amortization	181	167	169
Interstate Transportation and Storage [Member]
Depreciation, depletion and amortization	387	334	254
Equity in earnings of unconsolidated affiliates	222	227	236
Midstream [Member]
Cost of Goods and Services Sold	3,577	5,145	4,761
Depreciation, depletion and amortization	1,066	1,006	954
Equity in earnings of unconsolidated affiliates	20	26	20
NGL and refined products transportation and services [Member]
Cost of Goods and Services Sold	8,393	8,462	6,508
Depreciation, depletion and amortization	613	466	401
Equity in earnings of unconsolidated affiliates	53	64	33
Crude oil transportation and services [Member]
Cost of Goods and Services Sold	14,758	14,439	9,826
Depreciation, depletion and amortization	437	445	402
Equity in earnings of unconsolidated affiliates	(1)	6	4
Other Segments [Member]
Cost of Goods and Services Sold	1,504	2,006	2,509
Depreciation, depletion and amortization	48	103	227
Equity in earnings of unconsolidated affiliates	(10)	2	7
Investment In USAC [Member]
Cost of Goods and Services Sold	91	67	0
Depreciation, depletion and amortization	231	169	0
Intersegment Eliminations [Member]
Cost of Goods and Services Sold	$ (5,885)	$ (6,998)	$ (5,580)

Reportable Segments Reportable Segments (Segment Adjusted EBITDA) (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA									$ 11,214	$ 9,510	$ 7,320
Depreciation, depletion and amortization									(3,147)	(2,859)	(2,554)
Interest expense, net of interest capitalized									(2,331)	(2,055)	(1,922)
Impairment losses									(74)	(431)	(1,039)
Gains (losses) on interest rate derivatives									(241)	47	(37)
Unrealized gains (losses) on commodity risk management activities									(113)	(105)	(99)
Non-cash compensation expense									5	11	(59)
Losses on extinguishments of debt									(18)	(112)	(89)
Adjusted EBITDA related to unconsolidated affiliates									79	(85)	24
Equity in earnings of unconsolidated affiliates									0	25	(223)
Impairment of investments in unconsolidated affiliates									0	0	(313)
Impairment of investments in unconsolidated affiliates									(626)	(655)	(716)
Equity in earnings of unconsolidated affiliates									302	344	144
Other, net									54	21	155
Income from continuing operations before income tax (expense) benefit									5,094	3,634	710
Income tax expense (benefit) from continuing operations									(195)	(4)	1,833
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent					$ 852	$ 1,393	$ 659	$ 726	4,899	3,630	2,543
Loss from discontinued operations									0	(265)	(177)
Net income	$ 1,350	$ 1,161	$ 1,208	$ 1,180	$ 852	$ 1,391	$ 633	$ 489	4,899	3,365	2,366
Intrastate Transportation And Storage [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA									999	927	626
Depreciation, depletion and amortization									(184)	(169)	(147)
Equity in earnings of unconsolidated affiliates									18	19	(156)
Investment In Sunoco LP [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA									665	638	732
Depreciation, depletion and amortization									(181)	(167)	(169)
Investment In USAC [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA									420	289	0
Depreciation, depletion and amortization									(231)	(169)	0
Corporate and Other [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA									98	40	187
Interstate Transportation and Storage [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA									1,792	1,680	1,274
Depreciation, depletion and amortization									(387)	(334)	(254)
Equity in earnings of unconsolidated affiliates									222	227	236
Midstream [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA									1,602	1,627	1,481
Depreciation, depletion and amortization									(1,066)	(1,006)	(954)
Equity in earnings of unconsolidated affiliates									20	26	20
NGL and refined products transportation and services [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA									2,666	1,979	1,641
Depreciation, depletion and amortization									(613)	(466)	(401)
Equity in earnings of unconsolidated affiliates									53	64	33
Crude oil transportation and services [Member]
Segment Reporting Information [Line Items]
Segment Adjusted EBITDA									2,972	2,330	1,379
Depreciation, depletion and amortization									(437)	(445)	(402)
Equity in earnings of unconsolidated affiliates									$ (1)	$ 6	$ 4

Reportable Segments (Assets Segments) (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Assets	$ 98,880	$ 88,246	$ 86,246
Intrastate Transportation And Storage [Member]
Assets	6,648	6,365	5,020
Interstate Transportation and Storage [Member]
Assets	18,111	15,081	15,316
Midstream [Member]
Assets	20,332	19,745	20,004
NGL and refined products transportation and services [Member]
Assets	19,145	18,267	17,600
Crude oil transportation and services [Member]
Assets	22,840	18,022	17,730
Investment In Sunoco LP [Member]
Assets	5,438	4,879	8,344
Investment In USAC [Member]
Assets	3,730	3,775	0
Corporate and Other [Member]
Assets	$ 2,636	$ 2,112	$ 2,232

Reporting Segments (Additions To Property Plant And Equipment Including Acquisitions Net Of Contributions In Aid Of Construction Costs Segments) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Segment Reporting Information [Line Items]

Property, Plant and Equipment, Additions

^[1]

$ 5,268

$ 5,630

$ 6,006

Investment In Sunoco LP [Member]

Segment Reporting Information [Line Items]

Property, Plant and Equipment, Additions

^[1]

$ 148

$ 103

[1]	Excluding acquisitions, net of contributions in aid of construction costs (capital expenditures related to the Partnership’s proportionate ownership on an accrual basis).

Reportable Segments (Advances to and investments in affiliates) (Details) - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Segment Reporting Information [Line Items]

Property, Plant and Equipment, Additions

^[1]

$ 5,268

$ 5,630

$ 6,006

Advances to and investments in unconsolidated affiliates

3,460

2,642

2,705

Intrastate Transportation And Storage [Member]

Segment Reporting Information [Line Items]

Property, Plant and Equipment, Additions

^[1]

124

344

175

Advances to and investments in unconsolidated affiliates

Interstate Transportation and Storage [Member]

Segment Reporting Information [Line Items]

Property, Plant and Equipment, Additions

^[1]

375

812

728

Advances to and investments in unconsolidated affiliates

2,524

2,070

2,118

Midstream [Member]

Segment Reporting Information [Line Items]

Property, Plant and Equipment, Additions

^[1]

827

1,161

1,308

Advances to and investments in unconsolidated affiliates

112

124

126

NGL and refined products transportation and services [Member]

Segment Reporting Information [Line Items]

Property, Plant and Equipment, Additions

^[1]

2,976

2,381

2,971

Advances to and investments in unconsolidated affiliates

461

243

234

Crude oil transportation and services [Member]

Segment Reporting Information [Line Items]

Property, Plant and Equipment, Additions

^[1]

403

474

453

Advances to and investments in unconsolidated affiliates

242

Investment In Sunoco LP [Member]

Segment Reporting Information [Line Items]

Property, Plant and Equipment, Additions

^[1]

148

103

Investment In USAC [Member]

Segment Reporting Information [Line Items]

Property, Plant and Equipment, Additions

^[1]

200

205

Other Segments [Member]

Segment Reporting Information [Line Items]

Property, Plant and Equipment, Additions

^[1]

215

150

268

Advances to and investments in unconsolidated affiliates

$ 33

$ 94

$ 120

[1]	Excluding acquisitions, net of contributions in aid of construction costs (capital expenditures related to the Partnership’s proportionate ownership on an accrual basis).

Quarterly Financial Data (Unaudited) (Schedule of Quarterly Financial Information) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Revenues	$ 13,720	$ 13,495	$ 13,877	$ 13,121	$ 13,573	$ 14,514	$ 14,118	$ 11,882	$ 54,213	$ 54,087	$ 40,523
Operating income	1,701	1,830	1,819	1,927	1,419	1,703	1,126	1,100	7,277	5,348	2,721
Income (Loss) from Continuing Operations, Net of Tax, Attributable to Parent					852	1,393	659	726	4,899	3,630	2,543
Net income	1,350	1,161	1,208	1,180	852	1,391	633	489	4,899	3,365	2,366
Limited Partners’ interest in net income	$ 1,011	$ 831	$ 877	$ 869	$ 617	$ 370	$ 330	$ 341	$ 3,588	$ 1,658	$ 915
Basic	$ 0.38	$ 0.32	$ 0.33	$ 0.33	$ 0.26	$ 0.32	$ 0.30	$ 0.31	$ 1.37	$ 1.16	$ 0.85
Diluted	0.38	0.32	0.33	0.33	0.26	0.32	0.30	0.31	1.36	1.15	0.83
Basic	0.38	0.32	0.33	0.33	0.26	0.32	0.30	0.32	1.37	1.17	0.86
Diluted	$ 0.38	$ 0.32	$ 0.33	$ 0.33	$ 0.26	$ 0.32	$ 0.30	$ 0.32	$ 1.36	$ 1.16	$ 0.84

Quarterly Financial Data (Unaudited) Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Statement [Abstract]
Impairment losses	$ 74	$ 431	$ 1,039
Impairment of investments in unconsolidated affiliates	$ 0	$ 0	$ 313