0001276187-20-000046 | 10-Q | XBRL Viewer

Property, plant and equipment

1,723

1,532

Income taxes receivable

146

Derivative assets

Other current assets

235

275

Total current assets

6,150

7,464

93,239

89,790

Accumulated depreciation and depletion

(18,111)

(15,597)

Property, Plant and Equipment, Net

75,128

74,193

Advances to and investments in unconsolidated affiliates

3,068

3,460

Lease, Right of Use Asset, Net

934

964

1,582

1,571

Intangible assets, net

5,915

6,154

Accounts payable to related companies

2,418

5,167

Total assets

95,195

98,973

LIABILITIES AND EQUITY

Accounts payable

2,765

4,118

Derivative liabilities

264

147

Operating lease current liabilities

Accrued and other current liabilities

2,913

3,342

Current maturities of long-term debt

Total current liabilities

6,047

7,724

Long-term debt, less current maturities

51,424

51,028

Non-current derivative liabilities

275

273

Non-current operating lease liabilities

901

Deferred income taxes

3,349

3,208

Other non-current liabilities

1,152

1,162

Commitments and contingencies

Accumulated other comprehensive loss

756

739

Limited Partners:

Common Unitholders

18,296

21,935

General Partner

(8)

(4)

(4)

(11)

Total partners’ capital

18,284

21,920

Noncontrolling interests

13,007

12,018

Total equity

31,291

33,938

Total liabilities and equity

$ 95,195

$ 98,973

[1]	*As adjusted. See Note 1.

Consolidated Statements Of Operations - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2020

Sep. 30, 2019

^[1]

Sep. 30, 2020

Sep. 30, 2019

^[1]

REVENUES:

Total revenues

$ 9,955

$ 13,495

$ 28,920

$ 40,493

COSTS AND EXPENSES:

6,376

9,864

29,642

Operating expenses

773

806

2,406

Selling, general and administrative

912

784

2,715

2,343

176

173

499

Interest expense, net of interest capitalized

1,474

2,803

Total costs and expenses

9,711

11,639

34,952

OPERATING INCOME

244

1,856

5,541

OTHER INCOME (EXPENSE):

(569)

(579)

(1,750)

(1,747)

Equity in earnings (losses) of unconsolidated affiliates

(32)

224

Equity Method Investment, Other than Temporary Impairment

(129)

(62)

(18)

(175)

(277)

(371)

INCOME (LOSS) BEFORE INCOME TAX EXPENSE

(360)

1,241

(525)

3,728

Income tax expense

168

214

NET INCOME (LOSS)

(401)

1,187

(693)

3,514

Less: Net income attributable to noncontrolling interests

369

317

554

931

Less: Net income attributable to redeemable noncontrolling interests

NET INCOME (LOSS) ATTRIBUTABLE TO PARTNERS

(782)

858

(1,284)

2,545

General Partner’s interest in net income (loss)

(1)

Limited Partners’ interest in net income (loss)

$ (782)

$ 857

$ (1,283)

$ 2,542

INCOME FROM CONTINUING OPERATIONS PER LIMITED PARTNER UNIT:

NET INCOME (LOSS) PER LIMITED PARTNER UNIT:

$ (0.29)

$ 0.33

$ (0.48)

$ 0.97

Diluted

(0.29)

0.33

(0.48)

0.97

(0.29)

0.33

(0.48)

0.97

Diluted

$ (0.29)

$ 0.33

$ (0.48)

$ 0.97

Refined product sales

REVENUES:

$ 2,720

$ 4,311

$ 7,952

$ 12,514

COSTS AND EXPENSES:

18,784

Operating expenses

2,422

Selling, general and administrative

2,715

555

Interest expense, net of interest capitalized

2,803

Total costs and expenses

27,279

OPERATING INCOME

1,641

OTHER INCOME (EXPENSE):

(1,750)

Equity in earnings (losses) of unconsolidated affiliates

(62)

(277)

INCOME (LOSS) BEFORE INCOME TAX EXPENSE

(525)

Crude sales

REVENUES:

2,298

3,971

7,170

11,842

NGL sales

REVENUES:

Gathering, transportation and other fees

1,808

1,723

4,751

6,121

REVENUES:

2,283

2,466

6,805

6,768

Natural gas sales

REVENUES:

681

822

1,783

2,549

Other

REVENUES:

Statement of Comprehensive Income [Abstract]

$ 165

$ 202

$ 459

$ 699

[1]	*As adjusted. See Note 1.

Consolidated Statements Of Comprehensive Income - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2020

Sep. 30, 2019

^[1]

Sep. 30, 2020

Sep. 30, 2019

^[1]

Other comprehensive income (loss), net of tax:

$ (401)

$ 1,187

$ (693)

$ 3,514

Change in value of available-for-sale securities

Actuarial gain (loss) related to pension and other postretirement benefit plans

(3)

Foreign currency translation adjustments

(16)

Change in other comprehensive income (loss) from unconsolidated affiliates

(4)

(15)

(13)

Other comprehensive income (loss), net of tax

(7)

(13)

Less: Comprehensive income attributable to noncontrolling interests

(375)

1,180

(706)

3,516

369

317

554

931

Less: Net income attributable to redeemable noncontrolling interests

Comprehensive income (loss) attributable to partners

$ (756)

$ 851

$ (1,297)

$ 2,547

[1]	*As adjusted. See Note 1.

Consolidated Statement Of Equity - USD ($)
$ in Millions

Total

Limited Partner [Member]

General Partner

Noncontrolling Interest

AOCI Attributable to Parent [Member]

Balance, Beginning of Period at Dec. 31, 2018

^[1]

$ 31,017

$ 20,773

$ (5)

$ 10,291

$ (42)

(800)

(799)

(1)

Capital contributions from noncontrolling interests

(425)

140

Sale of noncontrolling interest in subsidiary

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

3,420

1,105

807

297

Balance, End of Period at Mar. 31, 2019

^[1]

31,167

20,798

(5)

10,408

(34)

Balance, Beginning of Period at Dec. 31, 2018

^[1]

31,017

20,773

(5)

10,291

(42)

^[1]

Balance, End of Period at Sep. 30, 2019

^[1]

3,514

32,174

21,094

(4)

11,124

(40)

Balance, Beginning of Period at Mar. 31, 2019

^[1]

31,167

20,798

(5)

10,408

(34)

(749)

(748)

(1)

Capital contributions from noncontrolling interests

(388)

Subsidiary units issued

780

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

1,196

878

317

Balance, End of Period at Jun. 30, 2019

^[1]

32,123

20,978

(5)

11,183

(33)

(800)

Capital contributions from noncontrolling interests

(457)

(7)

^[1]

(7)

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

^[1]

1,187

1,175

857

317

Balance, End of Period at Sep. 30, 2019

32,174

21,094

(4)

11,124

(40)

Partners' Capital Account, Sale of Units

Balance, Beginning of Period at Dec. 31, 2019

^[1]

33,938

21,935

(4)

12,018

(11)

(1,592)

(1,591)

(1)

Capital contributions from noncontrolling interests

(444)

Subsidiary units issued

1,580

(86)

(38)

(48)

(7)

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

4,825

(976)

(854)

(1)

(121)

Balance, End of Period at Mar. 31, 2020

32,530

19,512

(6)

13,083

(59)

Balance, Beginning of Period at Dec. 31, 2019

^[1]

33,938

21,935

(4)

12,018

(11)

(13)

Balance, End of Period at Sep. 30, 2020

(693)

31,291

18,296

(8)

13,007

(4)

Balance, Beginning of Period at Mar. 31, 2020

32,530

19,512

(6)

13,083

(59)

(1)

Capital contributions from noncontrolling interests

(408)

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

(27)

(31)

659

353

306

Balance, End of Period at Jun. 30, 2020

32,892

19,843

(7)

13,077

(21)

Partners' Capital Account, Sale of Units

(813)

(812)

(1)

Capital contributions from noncontrolling interests

(430)

(43)

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

(401)

(413)

(782)

369

Balance, End of Period at Sep. 30, 2020

$ 31,291

$ 18,296

$ (8)

$ 13,007

$ (4)

[1]	*As adjusted. See Note 1.

Consolidated Statements Of Cash Flows - USD ($)
$ in Millions

9 Months Ended

Sep. 30, 2020

Sep. 30, 2019

$ (0.48)

$ 0.97

^[1]

OPERATING ACTIVITIES:

Reconciliation of net income (loss) to net cash provided by operating activities:

$ (693)

$ 3,514

^[1]

Non-cash compensation expense

2,715

2,343

^[1]

Deferred income taxes

159

191

^[1]

^[1]

2,803

^[1]

Equity in earnings of unconsolidated affiliates

(62)

(18)

^[1]

(46)

(224)

^[1]

Distributions from unconsolidated affiliates

176

254

^[1]

Inventory valuation adjustments

126

(71)

^[1]

Distributions on unvested awards

(33)

(27)

^[1]

Other non-cash

(130)

^[1]

Net change in operating assets and liabilities, net of effects of acquisitions

(212)

^[1]

Net Cash Provided by (Used in) Operating Activities, Continuing Operations

5,455

5,966

^[1]

INVESTING ACTIVITIES:

Proceeds from Divestiture of Businesses and Interests in Affiliates

^[1]

Cash paid for all other acquisitions, net of cash received

(7)

^[1]

Capital expenditures, excluding allowance for equity funds used during construction

(4,030)

(4,181)

^[1]

Contributions in aid of construction costs

^[1]

Contributions to unconsolidated affiliate

481

^[1]

Distributions from unconsolidated affiliates in excess of cumulative earnings

144

^[1]

Proceeds from the sale of other assets

^[1]

Other

^[1]

Net Cash Provided by (Used in) Investing Activities, Continuing Operations

(3,861)

(4,423)

^[1]

FINANCING ACTIVITIES:

Proceeds from borrowings

20,651

18,125

^[1]

Repayments of debt

(20,293)

(17,247)

^[1]

Subsidiary equity offerings, net of issue costs

1,580

780

^[1]

(2,397)

(2,300)

^[1]

Debt issuance costs

(53)

(114)

^[1]

(3)

^[1]

Preferred Units, Cumulative Cash Distributions

(1,282)

(1,270)

^[1]

(37)

^[1]

Capital contributions from noncontrolling interest

203

278

^[1]

Net cash used in financing activities

(1,610)

(1,751)

^[1]

Decrease in cash and cash equivalents

(16)

(208)

^[1]

Cash and cash equivalents, beginning of period

^[1]

291

419

Cash and cash equivalents, end of period

275

211

^[1]

Equity Method Investment, Other than Temporary Impairment

$ 129

$ 0

^[1]

Revision of Prior Period, Change in Accounting Principle, Adjustment [Member]

Operations And Organization [Abstract]

$ 0.10

[1]	*As adjusted. See Note 1.

Operations And Organization

3 Months Ended

Sep. 30, 2020

Operations And Organization

ORGANIZATION AND BASIS OF PRESENTATION

Organization

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

In December 2019, we completed the acquisition of SemGroup. In connection with the transaction, a wholly-owned subsidiary of ET merged with and into SemGroup, with SemGroup surviving the merger. During the first and second quarters of 2020, ET contributed SemGroup and its former subsidiaries to ETO through sale and contribution transactions (together, the “SemGroup Transaction”).

Substantially all of the Partnership’s cash flows are derived from distributions related to its investment in ETO, which derives its cash flows 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.

Basis of Presentation

The unaudited financial information included in this Form 10-Q has been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2019, filed with the SEC on February 21, 2020. In the opinion of the Partnership’s management, such financial information reflects all adjustments necessary for a fair presentation of the financial position and the results of operations for such interim periods in accordance with GAAP. All intercompany items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.

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

•the Parent Company;

•our controlled subsidiary, ETO; and

•ETP GP, the general partner of ETO, and Energy Transfer Partners, L.L.C., the general partner of ETP GP.

Our subsidiaries also own varying undivided interests in certain pipelines. Ownership of these pipelines has been structured as an ownership of an undivided interest in assets, not as an ownership interest in a partnership, limited liability company, joint venture or other forms of entities. Each owner controls marketing and invoices separately, and each owner is

responsible for any loss, damage or injury that may occur to their own customers. As a result, we apply proportionate consolidation for our interests in these entities.

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

Change in Accounting Policy

Effective January 1, 2020, the Partnership elected to change its accounting policy related to certain barrels of crude oil that were previously accounted for as inventory. Under the revised accounting policy, certain amounts of crude oil that are not available for sale have been reclassified from inventory to non-current assets. These crude oil barrels, which are owned by the Partnership’s crude oil acquisition and marketing business, include pipeline linefill and tank bottoms and are not considered to be available for sale because the volumes must be maintained in order to continue normal operation of the related pipelines or tanks and because there is no expectation of liquidation or sale of these volumes in the near term.

Under the previous accounting policy, all crude oil barrels were recorded as inventory under the weighted average cost method. Under the revised accounting policy, barrels related to pipeline linefill and tank bottoms are accounted for as long-lived assets and reflected as non-current assets on the consolidated balance sheet. These crude oil barrels will be tested for impairment consistent with the Partnership’s existing accounting policy for impairments of long-lived assets. The Partnership’s management believes that the change in accounting policy is preferable as it more closely aligns the accounting policies across the consolidated entity, given that similar assets in the Partnership’s natural gas, NGLs and refined products businesses are accounted for as non-current assets. In addition, management believes that reflecting these crude oil barrels as non-current assets better represents the economic results of the Partnership’s crude oil acquisition and marketing business by reducing volatility resulting from market price adjustments to crude oil barrels that are not expected to be sold or liquidated in the near term.

The impact of this accounting policy change on the Partnership’s net income for the nine months ended September 30, 2020 was $265 million, or $0.10 per limited partner unit. As a result of this change in accounting policy, the Partnership’s consolidated balance sheets for prior periods have been retrospectively adjusted as follows:


	December 31, 2019						December 31, 2018
	As Originally Reported		Effect of Change		As Adjusted		As Originally Reported		Effect of Change		As Adjusted
Inventories	$	1,935	$	(403)	$	1,532	$	1,677	$	(305)	$	1,372
Total current assets	7,867		(403)		7,464		6,750		(305)		6,445
Other non-current assets, net	1,075		496		1,571		1,006		472		1,478
Total assets	98,880		93		98,973		88,246		167		88,413
Total partners’ capital	21,827		93		21,920		20,559		167		20,726

In addition, the Partnership’s consolidated statements of operations, comprehensive income and cash flows for prior periods have been retrospectively adjusted as follows:


	Year Ended December 31,				Three Months Ended September 30,		Nine Months Ended September 30,
	2019		2018		2019		2019
As originally reported:
Consolidated Statements of Operations and Comprehensive Income
Cost of products sold	$	39,727	$	41,658	$	9,890	$	29,607
Operating income	7,277		5,348		1,830		5,576
Income from continuing operations before income tax expense (benefit)	5,094		3,634		1,215		3,763
Net income	4,899		3,365		1,161		3,549
Net income per limited partner unit	1.37		1.16		0.32		0.98
Comprehensive income	4,930		3,322		1,154		3,551
Comprehensive income attributable to partners	3,623		1,651		825		2,582

Consolidated Statements of Cash Flows
Net income	4,899		3,365		1,161		3,549

Net change in operating assets and liabilities	(518)		289		27		(247)

Effect of change:
Consolidated Statements of Operations and Comprehensive Income
Cost of products sold	74		(55)		(26)		35
Operating income	(74)		55		26		(35)
Income from continuing operations before income tax expense (benefit)	(74)		55		26		(35)
Net income	(74)		55		26		(35)
Net income per limited partner unit	(0.03)		0.04		0.01		(0.01)
Comprehensive income	(74)		55		26		(35)
Comprehensive income attributable to partners	(74)		55		26		(35)

Consolidated Statements of Cash Flows
Net income	(74)		55		26		(35)

Net change in operating assets and liabilities	74		(55)		(26)		35

As adjusted:
Consolidated Statements of Operations and Comprehensive Income
Cost of products sold	39,801		41,603		9,864		29,642
Operating income	7,203		5,403		1,856		5,541
Income from continuing operations before income tax expense (benefit)	5,020		3,689		1,241		3,728
Net income	4,825		3,420		1,187		3,514
Net income per limited partner unit	1.34		1.20		0.33		0.97
Comprehensive income	4,856		3,377		1,180		3,516
Comprehensive income attributable to partners	3,549		1,706		851		2,547

Consolidated Statements of Cash Flows
Net income	4,825		3,420		1,187		3,514

Net change in operating assets and liabilities	(444)		234		1		(212)

Use of Estimates

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

Recent Accounting Pronouncements

Effective January 1, 2020, the Partnership adopted Accounting Standards Update (“ASU”) 2016-13 “Financial Instruments - Credit Losses (Topic 326) Measurement of Credit Losses on Financial Instruments.” ASU 2016-13 requires an entity to utilize a new impairment model known as the current expected credit loss (“CECL”) model to estimate its lifetime “expected credit loss” and record an allowance that, when deducted from the amortized cost basis of the financial asset, presents the net amount expected to be collected on the financial asset. The CECL model is expected to result in more timely recognition of credit losses. The impact of adoption was immaterial to the Partnership. However, due in large part to the global economic impacts of COVID-19, the Partnership and its subsidiaries recorded an aggregate $16 million of current expected credit losses for the nine months ended September 30, 2020.

Goodwill

During the first quarter of 2020, due to the impacts of the COVID-19 pandemic, the decline in commodity prices and the decreases in the Partnership’s market capitalization, we determined that interim impairment testing should be performed on certain reporting units. We performed the interim impairment tests consistent with our approach for annual impairment testing, including using similar models, inputs and assumptions. As a result of the interim impairment test, the Partnership recognized a goodwill impairment of $483 million related to our Arklatex and South Texas operations within the midstream segment, a goodwill impairment of $183 million related to our Lake Charles LNG regasification operations within the interstate transportation and storage segment due to contractually scheduled reductions in payments for the remainder of the contract term, and a goodwill impairment of $40 million related to our all other operations primarily due to decreases in projected future revenues and cash flows as a result of the overall market demand decline. In addition, USAC recognized a goodwill impairment of $619 million during the three months ended March 31, 2020, which is included in the Partnership’s consolidated results of operations.

During the three months ended September 30, 2020, the Partnership performed interim impairment testing on certain reporting units within its midstream, interstate, crude, NGL and all other operations. As a result, the Partnership recognized a goodwill impairment of $1.28 billion related to our crude operations, a goodwill impairment of $132 million related to our SemCAMS operations within the all other segment and a goodwill impairment of $43 million related to our interstate operations primarily due to decreases in projected future cash flow as a result of the overall market demand decline. No other impairments of the Partnership’s goodwill were identified.

In connection with aforementioned impairments, the Partnership determined the fair value of our reporting units using the income approach. The income approach is based on the present value of future cash flows, which are derived from our long-term financial forecasts, and requires significant assumptions including, among others, revenue growth rates, operating margins, weighted average costs of capital and future market conditions. 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. Cash flow projections are derived from one-year budgeted amounts and three-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.

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, 2019	$	10	$	226	$	483	$	693	$	1,397	$	1,555	$	619	$	184	$	5,167


Impaired	—		(183)		(483)		—		—		—		(619)		(40)		(1,325)
Other	—		—		—		—		—		—		—		(7)		(7)
Balance, March 31, 2020	10		43		—		693		1,397		1,555		—		137		3,835

Other	—		—		—		—		—		—		—		33		33
Balance, June 30, 2020	10		43		—		693		1,397		1,555		—		170		3,868
Impaired	—		(43)		—		—		(1,279)		—		—		(132)		(1,454)
Other	—		—		—		—		(66)		—		—		70		4
Balance, September 30, 2020	$	10	$	—	$	—	$	693	$	52	$	1,555	$	—	$	108	$	2,418

Cash And Cash Equivalents

9 Months Ended

Sep. 30, 2020

Supplemental Cash Flow Information [Abstract]

Cash And Cash Equivalents

CASH AND CASH EQUIVALENTS

Cash and cash equivalents include all cash on hand, demand deposits, and investments with original maturities of three months or less. We consider cash equivalents to include short-term, highly liquid investments that are readily convertible to known amounts of cash and that are subject to an insignificant risk of changes in value. The Partnership’s consolidated balance sheets did not include any material amounts of restricted cash as of September 30, 2020 or December 31, 2019.

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

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


	Nine Months Ended September 30,
	2020		2019
Accounts receivable	$	1,307	$	(353)
Accounts receivable from related companies	(258)		(36)
Inventories	(298)		(7)
Other current assets	108		14
Other non-current assets, net	(26)		(151)
Accounts payable	(1,354)		25
Accounts payable to related companies	370		(37)
Accrued and other current liabilities	127		129
Other non-current liabilities	(5)		(103)
Derivative assets and liabilities, net	123		307
Net change in operating assets and liabilities, net of effects of acquisitions	$	94	$	(212)

Non-cash activities were as follows:


	Nine Months Ended September 30,
	2020		2019
NON-CASH INVESTING AND FINANCING ACTIVITIES:
Accrued capital expenditures	$	684	$	1,202

Lease assets obtained in exchange for new lease liabilities	130		73
Distribution reinvestment	72		100

Inventories (Notes)

9 Months Ended

Sep. 30, 2020

Inventory, Net [Abstract]

INVENTORIES

As further discussed in Note 1, the Partnership elected to change its accounting policy related to certain barrels of crude oil that were previously accounted for as inventory. As a result of this change in accounting policy, the Partnership’s inventory balance for the prior period has been retrospectively adjusted.

Inventories consisted of the following:


	September 30, 2020		December 31, 2019
Natural gas, NGLs and refined products	$	914	$	833
Crude oil	352		251
Spare parts and other	457		448
Total inventories	$	1,723	$	1,532

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.

Sunoco LP’s fuel inventories are stated at the lower of cost or market using the last-in, first-out (“LIFO”) method. As of September 30, 2020 and December 31, 2019, the carrying value of Sunoco LP’s fuel inventory included lower of cost or market reserves of $360 million and $229 million, respectively, and the inventory carrying value equaled or exceeded its replacement cost. For the three and nine months ended September 30, 2020 and 2019, the Partnership’s consolidated income statements did not include any material amounts of income from the liquidation of LIFO fuel inventory.

Fair Value Measurements

9 Months Ended

Sep. 30, 2020

Fair Value Measurements [Abstract]

Fair Value Measurements

FAIR VALUE MEASURESWe have commodity derivatives and interest rate derivatives that are accounted for as assets and liabilities at fair value in our consolidated balance sheets. We determine the fair value of our assets and liabilities subject to fair value measurement by using the highest possible “level” of inputs. Level 1 inputs are observable quotes in an active market for identical assets and liabilities. We consider the valuation of marketable securities and commodity derivatives transacted through a clearing broker with a published price from the appropriate exchange as a Level 1 valuation. Level 2 inputs are inputs observable for similar assets and liabilities. We consider OTC commodity derivatives entered into directly with third parties as a Level 2 valuation since the values of these derivatives are quoted on an exchange for similar transactions. Additionally, we consider our options transacted through our clearing broker as having Level 2 inputs due to the level of activity of these contracts on the exchange in which they trade. We consider the valuation of our interest rate derivatives as Level 2 as the primary input, the LIBOR curve, is based on quotes from an active exchange of Eurodollar futures for the same period as the future interest swap settlements. Level 3 inputs are unobservable. During the nine months ended September 30, 2020, no transfers were made between any levels within the fair value hierarchy.

The following tables summarize the gross fair value of our financial assets and liabilities measured and recorded at fair value on a recurring basis as of September 30, 2020 and December 31, 2019 based on inputs used to derive their fair values:


			Fair Value Measurements at September 30, 2020
	Fair Value Total		Level 1		Level 2
Assets:

Commodity derivatives:

Natural Gas:
Basis Swaps IFERC/NYMEX	$	13	$	13	$	—
Swing Swaps IFERC	2		—		2
Fixed Swaps/Futures	5		5		—


Forward Physical Contracts	6		—		6
Power:
Forwards	8		—		8
Futures	2		2		—
Options – Puts	—		—		—
Options – Calls	1		1		—
NGLs – Forwards/Swaps	103		103		—
Refined Products – Futures	5		5		—
Crude – Forwards/Swaps	2		2		—

Total commodity derivatives	147		131		16
Other non-current assets	31		20		11
Total assets	$	178	$	151	$	27
Liabilities:
Interest rate derivatives	$	(522)	$	—	$	(522)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(9)		(9)		—
Swing Swaps IFERC	(4)		(1)		(3)
Fixed Swaps/Futures	(29)		(29)		—



Power:
Forwards	(3)		—		(3)
Futures	(2)		(2)		—


NGLs – Forwards/Swaps	(153)		(153)		—
Refined Products – Futures	(4)		(4)		—

Total commodity derivatives	(204)		(198)		(6)
Total liabilities	$	(726)	$	(198)	$	(528)


			Fair Value Measurements at December 31, 2019
	Fair Value Total		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)

Based on the estimated borrowing rates currently available to us and our subsidiaries for loans with similar terms and average maturities, the aggregate fair value and carrying amount of our consolidated debt obligations as of September 30, 2020 were $52.28 billion and $51.45 billion, respectively. As of December 31, 2019, the aggregate fair value and carrying amount of our consolidated debt obligations were $54.79 billion and $51.05 billion, respectively. The fair value of our consolidated debt obligations is a Level 2 valuation based on the respective debt obligations’ observable inputs used for similar liabilities.

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

Net Income Per Limited Partner Unit

Net Income per Limited Partner Unit

9 Months Ended

Sep. 30, 2020

Earnings Per Share [Abstract]

NET INCOME (LOSS) PER LIMITED PARTNER UNIT

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019*		2020		2019*
Net income (loss)	$	(401)	$	1,187	$	(693)	$	3,514
Less: Net income attributable to noncontrolling interests	369		317		554		931
Less: Net income attributable to redeemable noncontrolling interests	12		12		37		38
Net income (loss), net of noncontrolling interests	(782)		858		(1,284)		2,545
Less: General Partner’s interest in income (loss)	—		1		(1)		3
Income (loss) available to Limited Partners	$	(782)	$	857	$	(1,283)	$	2,542
Basic Income (Loss) per Limited Partner Unit:
Weighted average limited partner units	2,696.6		2,624.9		2,694.4		2,621.9
Basic income (loss) per Limited Partner unit	$	(0.29)	$	0.33	$	(0.48)	$	0.97

Diluted Income (Loss) per Limited Partner Unit:
Income (loss) available to Limited Partners	$	(782)	$	857	$	(1,283)	$	2,542
Dilutive effect of equity-based compensation of subsidiaries (1)	—		—		—		—
Diluted income (loss) available to Limited Partners	$	(782)	$	857	$	(1,283)	$	2,542
Weighted average limited partner units	2,696.6		2,624.9		2,694.4		2,621.9
Dilutive effect of unvested unit awards (1)	—		10.6		—		11.0
Weighted average limited partner units, assuming dilutive effect of unvested unit awards	2,696.6		2,635.5		2,694.4		2,632.9
Diluted income (loss) from per Limited Partner unit	$	(0.29)	$	0.33	$	(0.48)	$	0.97

*As adjusted. See Note 1.

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

Debt Obligations	9 Months Ended
Debt Obligations	Sep. 30, 2020
Debt Obligations [Abstract]
Debt Obligations	DEBT OBLIGATIONS Parent Company Indebtedness ET Term Loan Facility On January 15, 2019, ET 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. Subsidiary Indebtedness ETO January 2020 Senior Notes Offering and Redemption On January 22, 2020, ETO completed a registered offering (the “January 2020 Senior Notes Offering”) of $1.00 billion aggregate principal amount of ETO’s 2.900% Senior Notes due 2025, $1.50 billion aggregate principal amount of the Partnership’s 3.750% Senior Notes due 2030 and $2.00 billion aggregate principal amount of ETO’s 5.000% Senior Notes due 2050 (collectively, the “Notes”). The Notes are fully and unconditionally guaranteed by ETO’s wholly-owned subsidiary, Sunoco Logistics Operations, on a senior unsecured basis. Using 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. HFOTCO Long-Term Debt In connection with the contribution transactions discussed in Note 1, HFOTCO became a wholly-owned subsidiary of ETO in February 2020. As of September 30, 2020, HFOTCO had $225 million outstanding principal amount of tax exempt notes due 2050 (the “Ike Bonds”). The Ike Bonds are fully and unconditionally guaranteed by ETO, on a senior unsecured basis. The indentures under which the Ike Bonds were issued are subject to customary representations and warranties and affirmative and negative covenants, the majority of which are substantially similar to those found in ETO’s revolving credit facility, as further discussed below. Credit Facilities and Commercial Paper ETO Term Loan ETO’s term loan credit agreement provides for a $2 billion three-year term loan credit facility (the “ETO Term Loan”). Borrowings under the term loan agreement mature on October 17, 2022 and are available for working capital purposes and for general partnership purposes. The ETO Term Loan is unsecured and is guaranteed by ETO’s subsidiary, Sunoco Logistics Operations. As of September 30, 2020, the ETO Term Loan had $2 billion outstanding and was fully drawn. The weighted average interest rate on the total amount outstanding as of September 30, 2020 was 1.15%. 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 September 30, 2020, the ETO Five-Year Credit Facility had $3.23 billion of outstanding borrowings, $1.63 billion of which was commercial paper. The amount available for future borrowings was $1.65 billion, after taking into account letters of credit of $117 million. The weighted average interest rate on the total amount outstanding as of September 30, 2020 was 1.16%. 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 September 30, 2020, the ETO 364-Day Facility had no outstanding borrowings. Sunoco LP Credit Facility Sunoco LP maintains a $1.50 billion senior secured revolving credit facility (the “Sunoco LP Credit Facility”), which matures in July 2023. As of September 30, 2020, the Sunoco LP Credit Facility had $87 million of outstanding borrowings and $8 million in standby letters of credit. As of September 30, 2020, Sunoco LP had $1.41 billion of availability under the Sunoco LP Credit Facility. The weighted average interest rate on the total amount outstanding as of September 30, 2020 was 2.15%. USAC Credit Facility USAC maintains a $1.60 billion senior secured revolving credit facility (the “USAC Credit Facility”), with a further potential increase of $400 million, which matures in April 2023. As of September 30, 2020, the USAC Credit Facility had $497 million of outstanding borrowings and no outstanding letters of credit. As of September 30, 2020, USAC had $1.10 billion of borrowing base availability and, subject to compliance with the applicable financial covenants, available borrowing capacity of $412 million under the USAC Credit Facility. The weighted average interest rate on the total amount outstanding as of September 30, 2020 was 3.03%. SemCAMS Credit Facilities SemCAMS is party to a credit agreement providing for a C$350 million (US$262 million at the September 30, 2020 exchange rate) senior secured term loan facility, a C$525 million (US$394 million at the September 30, 2020 exchange rate) senior secured revolving credit facility, and a C$300 million (US$225 million at the September 30, 2020 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$187 million at the September 30, 2020 exchange rate), subject to receiving commitments for such additional term loans or revolving commitments from either new lenders or increased commitments from existing lenders. As of September 30, 2020, the SemCAMS senior secured term loan facility and senior secured revolving credit facility had $253 million and $74 million, respectively, of outstanding borrowings. As of September 30, 2020, the KAPS Facility had no outstanding borrowings. Compliance with Our Covenants We and our subsidiaries were in compliance with all requirements, tests, limitations, and covenants related to our debt agreements as of September 30, 2020.

Redeemable Noncontrolling Interest (Notes)	9 Months Ended
Redeemable Noncontrolling Interest (Notes)	Sep. 30, 2020
Temporary Equity Disclosure [Abstract]
Redeemable Noncontrolling Interest [Text Block]	REDEEMABLE NONCONTROLLING INTERESTS Certain redeemable noncontrolling interests in the Partnership’s subsidiaries are reflected as mezzanine equity on the consolidated balance sheets. Redeemable noncontrolling interests as of September 30, 2020 included a balance of $477 million related to the USAC Preferred Units described below, 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, and a balance of $264 million related to the SemCAMS preferred stock described below. USAC Preferred Units As of September 30, 2020, USAC had 500,000 USAC Preferred Units issued and outstanding. The holders of these 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 April 2, 2023, 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 April 2, 2028, the holders of the USAC Preferred Units will have the right to require USAC to redeem all or any portion of the USAC Preferred Units, and the Partnership may elect to pay up to 50% of such redemption amount in USAC common units. SemCAMS Redeemable Preferred Stock As of September 30, 2020, SemCAMS had 337,046 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$825 at the September 30, 2020 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. Dividends on the preferred stock may be paid in-kind through June 30, 2021.

Equity

9 Months Ended

Sep. 30, 2020

Partners' Capital Notes [Abstract]

Equity

EQUITY

The change in ET Common Units during the nine months ended September 30, 2020 was as follows:


			Nine Months Ended September 30, 2020
Number of Common Units, beginning of period			2,689.6
Common Units issued in connection with the distribution reinvestment plan			6.9

Common Units vested under equity incentive plans and other			1.2
Number of Common Units, end of period			2,697.7

ET Repurchase Program

During the nine months ended September 30, 2020, ET did not repurchase any ET common units under its current buyback program. As of September 30, 2020, $911 million remained available to repurchase under the current program.

ET Distribution Reinvestment Program

During the nine months ended September 30, 2020, distributions of $72 million were reinvested under the distribution reinvestment program. As of September 30, 2020, a total of 22 million ET common units remain available to be issued under the existing registration statement in connection with the distribution reinvestment program.

Subsidiary Equity

ETO Preferred Units

As of September 30, 2020 and December 31, 2019, ETO’s outstanding preferred units included 950,000 ETO Series A Preferred Units, 550,000 ETO Series B Preferred Units, 18,000,000 ETO Series C Preferred Units, 17,800,000 ETO Series D Preferred Units and 32,000,000 ETO Series E Preferred Units. As of September 30, 2020, ETO’s outstanding preferred units also included 500,000 ETO Series F Preferred Units and 1,100,000 ETO Series G Preferred Units.

Sunoco LP Equity Distribution Program

For the nine months ended September 30, 2020, Sunoco LP issued no additional units under its at-the-market equity distribution program. As of September 30, 2020, $295 million of Sunoco LP common units remained available to be issued under the currently effective equity distribution agreement.

USAC Distribution Reinvestment Program

During the nine months ended September 30, 2020, distributions of $1.4 million were reinvested under the USAC distribution reinvestment program resulting in the issuance of approximately 140,318 USAC common units.

Parent Company Cash Distributions

Distributions declared and/or paid subsequent to December 31, 2019 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2019

February 7, 2020

February 19, 2020

0.3050

March 31, 2020

May 7, 2020

May 19, 2020

0.3050

June 30, 2020

August 7, 2020

August 19, 2020

0.3050

September 30, 2020

November 6, 2020

November 19, 2020

0.1525

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

ETO Cash Distributions

Distributions declared and/or paid by ETO to its preferred unitholders subsequent to December 31, 2019 were as follows:


Period Ended	Record Date	Payment Date	Series A (1)		Series B (1)		Series C		Series D		Series E		Series F (2)		Series G (2)
December 31, 2019	February 3, 2020	February 18, 2020	$	31.25	$	33.125	$	0.4609	$	0.4766	$	0.4750	$	—	$	—
March 31, 2020	May 1, 2020	May 15, 2020	—		—		0.4609		0.4766		0.4750		21.19		22.36
June 30, 2020	August 3, 2020	August 17, 2020	31.25		33.125		0.4609		0.4766		0.4750		—		—
September 30, 2020	November 2, 2020	November 16, 2020	—		—		0.4609		0.4766		0.4750		33.75		35.625

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

(2) ETO Series F and G Preferred Unit distributions related to the period ended March 31, 2020 represent a prorated initial distribution. Distributions are paid on a semi-annual basis.

Sunoco LP Cash Distributions

Distributions declared and/or paid by Sunoco LP to its common unitholders subsequent to December 31, 2019 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2019

February 7, 2020

February 19, 2020

0.8255

March 31, 2020

May 7, 2020

May 19, 2020

0.8255

June 30, 2020

August 7, 2020

August 19, 2020

0.8255

September 30, 2020

November 6, 2020

November 19, 2020

0.8255

USAC Cash Distributions

Distributions declared and/or paid by USAC to its common unitholders subsequent to December 31, 2019 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2019

January 27, 2020

February 7, 2020

0.5250

March 31, 2020

April 27, 2020

May 8, 2020

0.5250

June 30, 2020

July 31, 2020

August 10, 2020

0.5250

September 30, 2020

October 26, 2020

November 6, 2020

0.5250

Accumulated Other Comprehensive Income (Loss)

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


	September 30, 2020		December 31, 2019
Available-for-sale securities	$	16	$	13
Foreign currency translation adjustment	(14)		2
Actuarial loss related to pensions and other postretirement benefits	(10)		(25)
Investments in unconsolidated affiliates, net	(16)		(1)

Total AOCI, net of tax	(24)		(11)
Amounts attributable to noncontrolling interest	20		—
Total AOCI included in partners’ capital, net of tax	$	(4)	$	(11)

Income Taxes (Notes)	9 Months Ended
Income Taxes (Notes)	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Income Tax Disclosure [Text Block]	INCOME TAXESThe Partnership’s effective tax rate differs 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.

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

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

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities

9 Months Ended

Sep. 30, 2020

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 commenced on August 25, 2020 and adjourned on September 15, 2020. An initial decision is expected in early 2021.

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.

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

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019		2020		2019
ROW expense	$	13	$	5	$	32	$	17

PES Refinery Fire and Bankruptcy

We previously owned an approximately 7.4% indirect non-operating interest in PES, which owned a former refinery in Philadelphia. In addition, the Partnership previously provided logistics services to PES under commercial contracts and Sunoco LP previously 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. In June 2020, the Partnership received $12 million from PES on the note payable and recorded a reserve for the remaining $63 million note balance.

In addition, the Partnership’s subsidiaries retained certain environmental remediation liabilities when the refinery was sold to PES. As of September 30, 2020, 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.” It may be necessary for the Partnership to record additional environmental remediation liabilities in the future depending upon the use of such property by the buyer; 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 (“District Court”) 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”). On March 25, 2020, the court remanded the case back to the USACE for preparation of an Environment Impact Statement. On July 6, 2020, the court vacated the easement and ordered Dakota Access to be shut down and emptied of oil by August 5, 2020. Dakota Access and USACE appealed to the United States Court of Appeals for the District of Columbia (“Court of Appeals”) which granted an administrative stay of the District Court’s July 6 order and ordered further briefing on whether to fully stay the July 6 order. On August 5, 2020, the Court of Appeals granted a stay of the portion of the District Court order that required Dakota Access to shut the pipeline down and empty it of oil. The Court of Appeals also denied a motion to stay the March 25 order pending a decision on the merits by the Court of Appeals as to whether USACE will be required to prepare an Environmental Impact Statement. In addition, the Court of Appeals denied a motion to stay the District Court’s order to vacate the easement during this appeal process. The August 5 order also states that the Court of Appeals expects USACE to clarify its position with respect to whether USACE intends to allow the continued operation of the pipeline notwithstanding the vacator of the easement and that the District Court may consider additional relief if necessary.

On August 10, 2020, the District Court ordered USACE to submit a status report by August 31, 2020 clarifying its position with regard to its decision making process with respect to the continued operation of the pipeline. On August 31, 2020, USACE submitted a status report that indicated that it considers the presence of the pipeline at the Lake Oahe crossing without an easement to constitute an encroachment on federal land, and that it was still considering whether to exercise its enforcement discretion regarding this encroachment. Following the filing of this status report, the District Court ordered briefing on whether to enjoin the operation of the pipeline, with briefing scheduled to conclude by December 18, 2020.

Briefing on the merits of the appeal to the Court of Appeals has been completed, and oral argument has been scheduled by the Court of Appeals to occur on November 4, 2020. As a result of the ruling by the Court of Appeals related to the motions to stay and the District Court’s briefing schedule related to the injunction issue, it is expected that the pipeline will continue to operate during the pendency of the appeals process with the Court of Appeals.

ET cannot determine when or how these lawsuits will be resolved or the impact they may have on the Dakota Access pipelines; however, ET expects after the law and complete record are fully considered, the issues in this litigation will be resolved in a manner that will allow the pipeline to continue to operate.

Mont Belvieu Incident

On June 26, 2016, a hydrocarbon storage well located on another operator’s facility adjacent to Lone Star NGL LLC’s (“Lone Star”) 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 Defendants”) are defendants in lawsuits alleging MTBE contamination of groundwater. The plaintiffs, state-level governmental entities, assert product liability, nuisance, trespass, negligence, violation of environmental laws, and/or deceptive business practices claims. The plaintiffs seek to recover compensatory damages, and in some cases also seek natural resource damages, injunctive relief, punitive damages, and attorneys’ fees.

As of September 30, 2020, Sunoco Defendants are defendants in five cases, including one case each initiated by the States of Maryland and Rhode Island, one by the Commonwealth of Pennsylvania and two by the Commonwealth of Puerto Rico. The more recent Puerto Rico action is a companion case alleging damages for additional sites beyond those at issue in the initial Puerto Rico action. The actions brought by the State of Maryland and Commonwealth of Pennsylvania have also named as defendants ETO, ETP Holdco Corporation, and Sunoco Partners Marketing & Terminals L.P. (“SPMT”).

It is reasonably possible that a loss may be realized in the remaining cases; however, we are unable to estimate the possible loss or range of loss in excess of amounts accrued. An adverse determination with respect to one or more of the MTBE cases could have a significant impact on results of operations during the period in which any such adverse determination occurs, but such an adverse determination likely would not have a material adverse effect on the Partnership’s consolidated financial position.

Regency Merger Litigation

On June 10, 2015, Adrian Dieckman (“Dieckman”), 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 a post-trial hearing was held on May 6, 2020.

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.

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.

In July 2020, the Court denied Defendant’s Motion for Summary Judgment and Williams’ Motion for Partial Summary Judgment. Trial is set for December 14-18, 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.

Rover

On November 3, 2017, the State of Ohio and the Ohio Environmental Protection Agency (“Ohio EPA”) filed suit against Rover and other defendants seeking to recover civil penalties allegedly owed and certain injunctive relief related to permit compliance. The defendants filed several motions to dismiss, which were granted on all counts. The Ohio EPA appealed, and on December 9, 2019, the Fifth District Court of Appeals entered a unanimous judgment affirming the trial court. The Ohio EPA sought review from the Ohio Supreme Court, which the defendants opposed in briefs filed in February 2020. On April 22, 2020, the Ohio Supreme Court granted the Ohio EPA’s request for review. Briefing has concluded. The Ohio Supreme Court has not yet scheduled oral argument.

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 PADEP 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 prescribed 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. On June 25, 2020, a preliminary hearing was held on the charges against the employee, and the judge dismissed all charges.

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. On March 16, 2020, the Pennsylvania Attorney General Office served a Statewide Investigating Grand Jury subpoena for documents relating to inadvertent returns and water supplies related to the Mariner East pipelines. While the Partnership will cooperate with the subpoena, it intends to vigorously defend itself.

Recently Filed Litigation Involving Energy Transfer LP

Four purported unitholders of ET filed derivative actions against various past and current members of ET’s Board of Directors, LE GP, and ET, as a nominal defendant that assert claims for breach of fiduciary duties, unjust enrichment,

waste of corporate assets, breach of ET’s limited partnership agreement, tortious interference, abuse of control, and gross mismanagement related primarily to matters involving the construction of pipelines in Pennsylvania. They also seek damages and changes to ET’s corporate governance structure. See Bettiol v. LE GP, Case No. 3:19-cv-02890-X (N.D. Tex.); Davidson v. Kelcy L. Warren, Cause No. DC-20-02322 (44th Judicial District of Dallas County, Texas); Harris v. Kelcy L. Warren, Case No. 2:20-cv-00364-GAM (E.D. Pa.); and King v. LE GP, Case No. 3:20-cv-00719-X (N.D. Tex.). Another purported unitholder of ET, Allegheny County Employees’ Retirement System (“ACERS”), individually and on behalf of all others similarly situated, filed a suit under the federal securities laws purportedly on behalf of a class, against ET and three of ET’s directors, Kelcy L. Warren, John W. McReynolds, and Thomas E. Long. See Allegheny County Emps.’ Ret. Sys. v. Energy Transfer LP, Case No. 2:20-00200-GAM (E.D. Pa.). On June 15, 2020, ACERS filed an amended complaint and added as additional defendants ET directors Marshall McCrea and Matthew Ramsey, as well as Michael J. Hennigan and Joseph McGinn. The amended complaint asserts claims for violations of Sections 10(b) and 20(a) of the Exchange Act and Rule 10b-5 promulgated thereunder related primarily to matters involving the construction of pipelines in Pennsylvania. On August 14, 2020, the defendants filed a motion to dismiss ACERS’ amended complaint. The Court has not yet ruled on the motion to dismiss. 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 September 30, 2020 and December 31, 2019, accruals of approximately $86 million and $120 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 September 30, 2020 or 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 our results of operations for any single period, we believe that such costs will not have a material adverse effect on our financial position.

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

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 Pipeline Company (“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 the 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, the Pipeline and 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 polychlorinated biphenyls (“PCBs”). PCB assessments are ongoing and, in some cases, our subsidiaries could be contractually responsible for contamination caused by other parties.

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

•Legacy sites related to Sunoco 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 September 30, 2020, Sunoco had been named as a PRP at approximately 31 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 require disclosure in our consolidated financial statements.


	September 30, 2020		December 31, 2019
Current	$	46	$	46
Non-current	252		274
Total environmental liabilities	$	298	$	320

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 three months ended September 30, 2020 and 2019, the Partnership recorded $7 million and $16 million, respectively, of expenditures related to environmental cleanup programs. During the nine months ended September 30, 2020 and 2019, the Partnership recorded $22 million and $31 million, respectively, of expenditures related to environmental cleanup programs.

Our pipeline operations are subject to regulation by the United States Department of Transportation under PHMSA, pursuant to which PHMSA has established requirements relating to the design, installation, testing, construction, operation, replacement and management of pipeline facilities. Moreover, PHMSA, through the Office of Pipeline Safety, has promulgated a rule requiring pipeline operators to develop integrity management programs to comprehensively evaluate their pipelines, and take measures to protect pipeline segments located in what the rule refers to as “high consequence areas.” Activities under these integrity management programs involve the performance of internal pipeline inspections, pressure testing or other effective means to assess the integrity of these regulated pipeline segments, and the regulations require prompt action to address integrity issues raised by the assessment and analysis. Integrity testing and assessment of all of these assets will continue, and the potential exists that results of such testing and assessment could cause us to incur future capital and operating expenditures for repairs or upgrades deemed necessary to ensure the continued safe and reliable operation of our pipelines; however, no estimate can be made at this time of the likely range of such expenditures.

Our operations are also subject to the requirements of OSHA, and comparable state laws that regulate the protection of the health and safety of employees. In addition, the Occupational Safety and Health Administration’s hazardous communication standard requires that information be maintained about hazardous materials used or produced in our operations and that this information be provided to employees, state and local government authorities and citizens. We believe that our past costs for OSHA required activities, including general industry standards, record keeping requirements, and monitoring of occupational exposure to regulated substances have not had a material adverse effect on our results of operations, but there is no assurance that such costs will not be material in the future.

Revenue (Notes)

9 Months Ended

Sep. 30, 2020

Revenue [Abstract]

Revenue from Contract with Customer [Text Block]

REVENUE

Disaggregation of Revenue

The Partnership’s consolidated financial statements reflect eight reportable segments, which also represent the level at which the Partnership aggregates revenue for disclosure purposes. Note 14 depicts the disaggregation of revenue by segment.

Contract Balances with Customers

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

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

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

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


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

Balance, December 31, 2018	$	394
Additions	448
Revenue recognized	(491)
Balance, September 30, 2019	$	351

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 expected credit losses. The allowance for expected credit losses represents Sunoco LP's best estimate of the probable losses associated with potential customer defaults. Sunoco LP estimates the expected credit losses based on historical write-off experience by industry and current expectations of future credit losses.

The balances of Sunoco LP’s contract assets as of September 30, 2020 and December 31, 2019 were as follows:


	September 30, 2020		December 31, 2019
Contract balances:
Contract assets	$	123	$	117
Accounts receivable from contracts with customers	225		366

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 the 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 three months ended September 30, 2020 and 2019 was $4 million and $4 million, respectively. The amount of amortization expense that Sunoco LP recognized for the nine months ended September 30, 2020 and 2019 was $14 million and $12 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 expected contract consideration to each distinct performance obligation based on a standalone-selling price basis. Revenue is recognized when (or as) the performance obligations are satisfied, that is, when the customer obtains control of the good or service. Certain of our contracts contain variable components, which, when combined with the fixed component are considered a single performance obligation. For these types of contacts, only the fixed component of the contracts are included in the table below.

As of September 30, 2020, the aggregate amount of transaction price allocated to unsatisfied (or partially satisfied) performance obligations is $39.50 billion, and the Partnership expects to recognize this amount as revenue within the time bands illustrated below:


	Years Ending December 31,
	2020 (remainder)		2021		2022		Thereafter		Total
Revenue expected to be recognized on contracts with customers existing as of September 30, 2020	$	1,633	$	5,674	$	5,180	$	27,016	$	39,503

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

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-Paragraph 12
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=121604090&loc=SL49130554-203045

General Discussion of Derivative Instruments and Hedging Activities [Abstract]

Derivative Assets And Liabilities

9 Months Ended

Sep. 30, 2020

Derivative Assets And Liabilities

DERIVATIVE ASSETS AND LIABILITIES

Commodity Price Risk

We are exposed to market risks related to the volatility of commodity prices. To manage the impact of volatility from these prices, we utilize various exchange-traded and OTC commodity financial instrument contracts. These contracts consist primarily of futures, swaps and options and are recorded at fair value in our consolidated balance sheets.

We use futures and basis swaps, designated as fair value hedges, to hedge our natural gas inventory stored in our Bammel storage facility. At hedge inception, we lock in a margin by purchasing gas in the spot market or off peak season and entering into a financial contract. Changes in the spreads between the forward natural gas prices and the physical inventory spot price result in unrealized gains or losses until the underlying physical gas is withdrawn and the related designated derivatives are settled. Once the gas is withdrawn and the designated derivatives are settled, the previously unrealized gains or losses associated with these positions are realized.

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

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

We utilize swaps, futures and other derivative instruments to mitigate the risk associated with market movements in the price of refined products and NGLs to manage our storage facilities and the purchase and sale of purity NGL. These contracts are not designated as hedges for accounting purposes.

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

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

The following table details our outstanding commodity-related derivatives:


	September 30, 2020		December 31, 2019
	Notional Volume	Maturity	Notional Volume	Maturity
Mark-to-Market Derivatives
(Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX (1)	(91,365)	2020-2021	(35,208)	2020-2024
Fixed Swaps/Futures	4,965	2020-2022	1,483	2020



Power (Megawatt):
Forwards	1,714,800	2020-2029	3,213,450	2020-2029
Futures	(35,313)	2020-2022	(353,527)	2020
Options – Puts	(15)	2020-2021	51,615	2020
Options – Calls	(6,323,560)	2020-2022	(2,704,330)	2020-2021



(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(20,800)	2020-2022	(18,923)	2020-2022
Swing Swaps IFERC	(7,480)	2020-2021	(9,265)	2020
Fixed Swaps/Futures	(43,708)	2020-2022	(3,085)	2020-2021
Forward Physical Contracts	(15,281)	2021	(13,364)	2020-2021

NGLs (MBbls) – Forwards/Swaps	(14,743)	2020-2022	(1,300)	2020-2021
Refined Products (MBbls) – Futures	(3,391)	2020-2022	(2,473)	2020-2021
Crude (MBbls) – Forwards/Swaps	1,929	2020	4,465	2020
Corn (thousand bushels)	—	—	(1,210)	2020
Fair Value Hedging Derivatives
(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(38,490)	2020-2021	(31,780)	2020
Fixed Swaps/Futures	(38,490)	2020-2021	(31,780)	2020
Hedged Item – Inventory	38,490	2020-2021	31,780	2020

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

Interest Rate Risk

We are exposed to market risk for changes in interest rates. To maintain a cost effective capital structure, we borrow funds using a mix of fixed rate debt and variable rate debt. We also manage our interest rate exposure by utilizing interest rate swaps to achieve a desired mix of fixed and variable rate debt. We also utilize forward starting interest rate swaps to lock in the rate on a portion of our anticipated debt issuances.

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


Term	Type(1)	Notional Amount Outstanding
		September 30, 2020		December 31, 2019
July 2020(2)(3)	Forward-starting to pay a fixed rate of 3.52% and receive a floating rate	$	—	$	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		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 our 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, we may at times require collateral under certain circumstances to mitigate credit risk as necessary. We also use industry standard commercial agreements which allow for the netting of positive and negative 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.

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

We have maintenance margin deposits with certain counterparties in the OTC market, primarily independent system operators, and with clearing brokers. Payments on margin deposits are required when the value of a derivative exceeds our pre-established credit limit with the counterparty. Margin deposits are returned to 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
	September 30, 2020		December 31, 2019		September 30, 2020		December 31, 2019
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	32	$	24	$	(52)	$	—
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	68		319		(107)		(350)
Commodity derivatives	47		41		(45)		(39)
Interest rate derivatives	—		—		(522)		(399)
	115		360		(674)		(788)
Total derivatives	$	147	$	384	$	(726)	$	(788)

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


		Asset Derivatives				Liability Derivatives
	Balance Sheet Location	September 30, 2020		December 31, 2019		September 30, 2020		December 31, 2019
Derivatives without offsetting agreements	Derivative liabilities	$	—	$	—	$	(522)	$	(399)
Derivatives in offsetting agreements:
OTC contracts	Derivative assets (liabilities)	47		41		(45)		(39)
Broker cleared derivative contracts	Other current assets (liabilities)	100		343		(159)		(350)
Total gross derivatives		147		384		(726)		(788)
Offsetting agreements:

Counterparty netting	Derivative assets (liabilities)	(28)		(18)		28		18
Counterparty netting	Other current assets (liabilities)	(34)		(318)		34		318



Total net derivatives		$	85	$	48	$	(664)	$	(452)

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 non-current depending on the anticipated settlement date.

The following table summarizes the location and amounts recognized in our consolidated statements of operations with respect to our derivative financial instruments:


	Location	Amount of Gain (Loss) on Derivatives
		Three Months Ended September 30,				Nine Months Ended September 30,
		2020		2019		2020		2019
Derivatives not designated as hedging instruments:
Commodity derivatives – Trading	Cost of products sold	$	4	$	3	$	15	$	15
Commodity derivatives – Non-trading	Cost of products sold	(44)		21		53		(53)

Interest rate derivatives	Gains (losses) on interest rate derivatives	55		(175)		(277)		(371)

Total		$	15	$	(151)	$	(209)	$	(409)

Related Party Transactions

9 Months Ended

Sep. 30, 2020

Related Party Transactions

RELATED PARTY TRANSACTIONS

The Partnership has related party transactions with several of its unconsolidated affiliates. 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:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019		2020		2019
Revenues from related companies	$	100	$	129	$	375	$	374

The following table summarizes the accounts receivable from related companies on our consolidated balance sheets:


	September 30, 2020		December 31, 2019
Accounts receivable from related companies:
FGT	$	13	$	50
Phillips 66	36		36

Various	41		73
Total accounts receivable from related companies	$	90	$	159

As of September 30, 2020 and December 31, 2019, accounts payable with unconsolidated affiliates in the Partnership’s consolidated balance sheets totaled $30 million and $31 million, respectively.

Reportable Segments

9 Months Ended

Sep. 30, 2020

Segment Reporting [Abstract]

Reportable Segments

REPORTABLE SEGMENTS

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

•intrastate transportation and storage;

•interstate transportation and storage;

•midstream;

•NGL and refined products transportation and services;

•crude oil transportation and services;

•investment in Sunoco LP;

•investment in USAC; and

•all other.

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

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

We report Segment Adjusted EBITDA and consolidated Adjusted EBITDA as measures of segment performance. We define Segment Adjusted EBITDA and consolidated Adjusted EBITDA as total partnership earnings before interest, taxes, depreciation, depletion, amortization and other non-cash items, such as non-cash compensation expense, gains and losses on disposals of assets, the allowance for equity funds used during construction, unrealized gains and losses on commodity risk management activities, inventory valuation adjustments, non-cash impairment charges, losses on extinguishments of debt and other non-operating income or expense items. Inventory adjustments that are excluded from the calculation of Adjusted EBITDA represent only the changes in lower of cost or market reserves on inventory that is carried at last-in, first-out (“LIFO”). These amounts are unrealized valuation adjustments applied to Sunoco LP’s fuel volumes remaining in inventory at the end of the period.

Segment Adjusted EBITDA and consolidated Adjusted EBITDA reflect amounts for unconsolidated affiliates based on the same recognition and measurement methods used to record equity in earnings of unconsolidated affiliates. Adjusted EBITDA related to unconsolidated affiliates excludes the same items with respect to the unconsolidated affiliate as those excluded from the calculation of Segment Adjusted EBITDA and consolidated Adjusted EBITDA, such as interest, taxes, depreciation, depletion, amortization and other non-cash items. Although these amounts are excluded from Adjusted EBITDA related to unconsolidated affiliates, such exclusion should not be understood to imply that we have control over the operations and resulting revenues and expenses of such affiliates. We do not control our unconsolidated affiliates; therefore, we do not control the earnings or cash flows of such affiliates. The use of Segment Adjusted EBITDA or Adjusted EBITDA related to unconsolidated affiliates as an analytical tool should be limited accordingly.

The following tables present financial information by segment:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019		2020		2019
Revenues:
Intrastate transportation and storage:
Revenues from external customers	$	614	$	675	$	1,615	$	2,115
Intersegment revenues	40		89		148		270
	654		764		1,763		2,385
Interstate transportation and storage:
Revenues from external customers	466		475		1,365		1,454
Intersegment revenues	5		4		15		16
	471		479		1,380		1,470
Midstream:
Revenues from external customers	585		704		1,477		1,704
Intersegment revenues	792		876		2,088		2,792
	1,377		1,580		3,565		4,496
NGL and refined products transportation and services:
Revenues from external customers	2,207		2,271		5,991		7,340
Intersegment revenues	416		607		1,466		1,181
	2,623		2,878		7,457		8,521
Crude oil transportation and services:
Revenues from external customers	2,849		4,453		8,873		13,685
Intersegment revenues	1		—		4		—
	2,850		4,453		8,877		13,685
Investment in Sunoco LP:
Revenues from external customers	2,801		4,328		8,104		12,494
Intersegment revenues	4		3		53		4
	2,805		4,331		8,157		12,498
Investment in USAC:
Revenues from external customers	158		169		500		505
Intersegment revenues	3		6		9		15
	161		175		509		520
All other:
Revenues from external customers	275		420		995		1,196
Intersegment revenues	92		21		377		80
	367		441		1,372		1,276
Eliminations	(1,353)		(1,606)		(4,160)		(4,358)
Total revenues	$	9,955	$	13,495	$	28,920	$	40,493


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019*		2020		2019*
Segment Adjusted EBITDA:
Intrastate transportation and storage	$	203	$	235	$	630	$	777
Interstate transportation and storage	425		442		1,232		1,358
Midstream	530		411		1,280		1,205
NGL and refined products transportation and services	762		667		2,099		1,923
Crude oil transportation and services	631		726		1,741		2,222
Investment in Sunoco LP	189		192		580		497
Investment in USAC	104		104		315		310
All other	22		35		62		80
Adjusted EBITDA (consolidated)	2,866		2,812		7,939		8,372
Depreciation, depletion and amortization	(912)		(784)		(2,715)		(2,343)
Interest expense, net of interest capitalized	(569)		(579)		(1,750)		(1,747)
Impairment losses	(1,474)		(12)		(2,803)		(62)
Gains (losses) on interest rate derivatives	55		(175)		(277)		(371)
Non-cash compensation expense	(30)		(27)		(93)		(85)
Unrealized gains (losses) on commodity risk management activities	(30)		64		(27)		90
Losses on extinguishments of debt	—		—		(62)		(18)
Inventory valuation adjustments (Sunoco LP)	11		(26)		(126)		71
Adjusted EBITDA related to unconsolidated affiliates	(169)		(161)		(480)		(470)
Equity in earnings (loss) of unconsolidated affiliates	(32)		82		46		224
Impairment of investment in an unconsolidated affiliate	(129)		—		(129)		—
Other, net	53		47		(48)		67
Income (loss) before income tax expense	(360)		1,241		(525)		3,728
Income tax expense	(41)		(54)		(168)		(214)


Net income (loss)	$	(401)	$	1,187	$	(693)	$	3,514

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

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Operations And Organization Accounting policy (Policies)	9 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
Basis of Accounting, Policy [Policy Text Block]	Basis of Presentation The unaudited financial information included in this Form 10-Q has been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2019, filed with the SEC on February 21, 2020. In the opinion of the Partnership’s management, such financial information reflects all adjustments necessary for a fair presentation of the financial position and the results of operations for such interim periods in accordance with GAAP. All intercompany items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been omitted pursuant to the rules and regulations of the SEC.
Use of Estimates, Policy [Policy Text Block]	Use of Estimates The unaudited consolidated financial statements have been prepared in conformity with GAAP, which includes the use of estimates and assumptions made by management that affect the reported amounts of assets, liabilities, revenues, expenses and disclosure of contingent assets and liabilities that exist at the date of the consolidated financial statements. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could be different from those estimates.
New Accounting Pronouncements, Policy [Policy Text Block]	Recent Accounting Pronouncements Effective January 1, 2020, the Partnership adopted Accounting Standards Update (“ASU”) 2016-13 “Financial Instruments - Credit Losses (Topic 326) Measurement of Credit Losses on Financial Instruments.” ASU 2016-13 requires an entity to utilize a new impairment model known as the current expected credit loss (“CECL”) model to estimate its lifetime “expected credit loss” and record an allowance that, when deducted from the amortized cost basis of the financial asset, presents the net amount expected to be collected on the financial asset. The CECL model is expected to result in more timely recognition of credit losses. The impact of adoption was immaterial to the Partnership. However, due in large part to the global economic impacts of COVID-19, the Partnership and its subsidiaries recorded an aggregate $16 million of current expected credit losses for the nine months ended September 30, 2020.
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]	In connection with aforementioned impairments, the Partnership determined the fair value of our reporting units using the income approach. The income approach is based on the present value of future cash flows, which are derived from our long-term financial forecasts, and requires significant assumptions including, among others, revenue growth rates, operating margins, weighted average costs of capital and future market conditions. 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. Cash flow projections are derived from one-year budgeted amounts and three-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.
Inventory, Policy [Policy Text Block]	Change in Accounting Policy Effective January 1, 2020, the Partnership elected to change its accounting policy related to certain barrels of crude oil that were previously accounted for as inventory. Under the revised accounting policy, certain amounts of crude oil that are not available for sale have been reclassified from inventory to non-current assets. These crude oil barrels, which are owned by the Partnership’s crude oil acquisition and marketing business, include pipeline linefill and tank bottoms and are not considered to be available for sale because the volumes must be maintained in order to continue normal operation of the related pipelines or tanks and because there is no expectation of liquidation or sale of these volumes in the near term. Under the previous accounting policy, all crude oil barrels were recorded as inventory under the weighted average cost method. Under the revised accounting policy, barrels related to pipeline linefill and tank bottoms are accounted for as long-lived assets and reflected as non-current assets on the consolidated balance sheet. These crude oil barrels will be tested for impairment consistent with the Partnership’s existing accounting policy for impairments of long-lived assets. The Partnership’s management believes that the change in accounting policy is preferable as it more closely aligns the accounting policies across the consolidated entity, given that similar assets in the Partnership’s natural gas, NGLs and refined products businesses are accounted for as non-current assets. In addition, management believes that reflecting these crude oil barrels as non-current assets better represents the economic results of the Partnership’s crude oil acquisition and marketing business by reducing volatility resulting from market price adjustments to crude oil barrels that are not expected to be sold or liquidated in the near term. 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. Sunoco LP’s fuel inventories are stated at the lower of cost or market using the last-in, first-out (“LIFO”) method. As of September 30, 2020 and December 31, 2019, the carrying value of Sunoco LP’s fuel inventory included lower of cost or market reserves of $360 million and $229 million, respectively, and the inventory carrying value equaled or exceeded its replacement cost. For the three and nine months ended September 30, 2020 and 2019, the Partnership’s consolidated income statements did not include any material amounts of income from the liquidation of LIFO fuel inventory.

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

Cash And Cash Equivalents Cash and Cash Equivalents (Policies)	9 Months Ended
	Sep. 30, 2020
Cash and Cash Equivalents [Abstract]
Cash and Cash Equivalents, Unrestricted Cash and Cash Equivalents, Policy [Policy Text Block]	Cash and cash equivalents include all cash on hand, demand deposits, and investments with original maturities of three months or less. We consider cash equivalents to include short-term, highly liquid investments that are readily convertible to known amounts of cash and that are subject to an insignificant risk of changes in value. The Partnership’s consolidated balance sheets did not include any material amounts of restricted cash as of September 30, 2020 or December 31, 2019. We place our cash deposits and temporary cash investments with high credit quality financial institutions. At times, our cash and cash equivalents may be uninsured or in deposit accounts that exceed the Federal Deposit Insurance Corporation insurance limit.

Inventories Inventories (Policies)	9 Months Ended
Inventories Inventories (Policies)	Sep. 30, 2020
Inventory Disclosure [Abstract]
Inventory, Policy [Policy Text Block]	Change in Accounting Policy Effective January 1, 2020, the Partnership elected to change its accounting policy related to certain barrels of crude oil that were previously accounted for as inventory. Under the revised accounting policy, certain amounts of crude oil that are not available for sale have been reclassified from inventory to non-current assets. These crude oil barrels, which are owned by the Partnership’s crude oil acquisition and marketing business, include pipeline linefill and tank bottoms and are not considered to be available for sale because the volumes must be maintained in order to continue normal operation of the related pipelines or tanks and because there is no expectation of liquidation or sale of these volumes in the near term. Under the previous accounting policy, all crude oil barrels were recorded as inventory under the weighted average cost method. Under the revised accounting policy, barrels related to pipeline linefill and tank bottoms are accounted for as long-lived assets and reflected as non-current assets on the consolidated balance sheet. These crude oil barrels will be tested for impairment consistent with the Partnership’s existing accounting policy for impairments of long-lived assets. The Partnership’s management believes that the change in accounting policy is preferable as it more closely aligns the accounting policies across the consolidated entity, given that similar assets in the Partnership’s natural gas, NGLs and refined products businesses are accounted for as non-current assets. In addition, management believes that reflecting these crude oil barrels as non-current assets better represents the economic results of the Partnership’s crude oil acquisition and marketing business by reducing volatility resulting from market price adjustments to crude oil barrels that are not expected to be sold or liquidated in the near term. 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. Sunoco LP’s fuel inventories are stated at the lower of cost or market using the last-in, first-out (“LIFO”) method. As of September 30, 2020 and December 31, 2019, the carrying value of Sunoco LP’s fuel inventory included lower of cost or market reserves of $360 million and $229 million, respectively, and the inventory carrying value equaled or exceeded its replacement cost. For the three and nine months ended September 30, 2020 and 2019, the Partnership’s consolidated income statements did not include any material amounts of income from the liquidation of LIFO fuel inventory.

Revenue from Contract with Customer [Abstract]

Fair Value Measurements Fair Value Measurements (Policies)	9 Months Ended
	Sep. 30, 2020
Fair Value Disclosures [Abstract]
Fair Value Measurement, Policy [Policy Text Block]	We have commodity derivatives and interest rate derivatives that are accounted for as assets and liabilities at fair value in our consolidated balance sheets. We determine the fair value of our assets and liabilities subject to fair value measurement by using the highest possible “level” of inputs. Level 1 inputs are observable quotes in an active market for identical assets and liabilities. We consider the valuation of marketable securities and commodity derivatives transacted through a clearing broker with a published price from the appropriate exchange as a Level 1 valuation. Level 2 inputs are inputs observable for similar assets and liabilities. We consider OTC commodity derivatives entered into directly with third parties as a Level 2 valuation since the values of these derivatives are quoted on an exchange for similar transactions. Additionally, we consider our options transacted through our clearing broker as having Level 2 inputs due to the level of activity of these contracts on the exchange in which they trade. We consider the valuation of our interest rate derivatives as Level 2 as the primary input, the LIBOR curve, is based on quotes from an active exchange of Eurodollar futures for the same period as the future interest swap settlements. Level 3 inputs are unobservable. During the nine months ended September 30, 2020, no transfers were made between any levels within the fair value hierarchy

Revenue Revenue (Policies)

9 Months Ended

Sep. 30, 2020

Revenue [Policy Text Block]

Disaggregation of Revenue

Revenue Recognition, Deferred Revenue [Policy Text Block]

Contract Balances with Customers

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


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

Balance, December 31, 2018	$	394
Additions	448
Revenue recognized	(491)
Balance, September 30, 2019	$	351

Disclosure of accounting policy for revenue from contract with customer.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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Reference 5: http://www.xbrl.org/2003/role/disclosureRef
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Reference 6: http://www.xbrl.org/2003/role/disclosureRef
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Reference 7: http://www.xbrl.org/2003/role/exampleRef
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Reference 9: http://www.xbrl.org/2003/role/disclosureRef
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Reference 10: http://www.xbrl.org/2003/role/disclosureRef
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Change in Accounting Policy [Abstract]

Derivative Assets And Liabilities Derivative Assets and Liabilities (Policies)	9 Months Ended
	Sep. 30, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Concentration Risk, Credit Risk, Policy [Policy Text Block]	Credit Risk Credit risk refers to the risk that a counterparty may default on its contractual obligations resulting in a loss to the Partnership. Credit policies have been approved and implemented to govern our 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, we may at times require collateral under certain circumstances to mitigate credit risk as necessary. We also use industry standard commercial agreements which allow for the netting of positive and negative 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. Our counterparties consist of a diverse portfolio of customers across the energy industry, including petrochemical companies, commercial and industrials, oil and gas producers, motor fuel distributors, municipalities, utilities and midstream companies. Our overall exposure may be affected positively or negatively by macroeconomic factors or regulatory changes that could impact its counterparties to one extent or another. Currently, management does not anticipate a material adverse effect in our financial position or results of operations as a consequence of counterparty non-performance. We have maintenance margin deposits with certain counterparties in the OTC market, primarily independent system operators, and with clearing brokers. Payments on margin deposits are required when the value of a derivative exceeds our pre-established credit limit with the counterparty. Margin deposits are returned to 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.
Derivatives, Policy [Policy Text Block]	Commodity Price Risk We are exposed to market risks related to the volatility of commodity prices. To manage the impact of volatility from these prices, we utilize various exchange-traded and OTC commodity financial instrument contracts. These contracts consist primarily of futures, swaps and options and are recorded at fair value in our consolidated balance sheets. We use futures and basis swaps, designated as fair value hedges, to hedge our natural gas inventory stored in our Bammel storage facility. At hedge inception, we lock in a margin by purchasing gas in the spot market or off peak season and entering into a financial contract. Changes in the spreads between the forward natural gas prices and the physical inventory spot price result in unrealized gains or losses until the underlying physical gas is withdrawn and the related designated derivatives are settled. Once the gas is withdrawn and the designated derivatives are settled, the previously unrealized gains or losses associated with these positions are realized. We use futures, swaps and options to hedge the sales price of natural gas we retain for fees in our intrastate transportation and storage segment and operational gas sales in our interstate transportation and storage segment. These contracts are not designated as hedges for accounting purposes. We use NGL and crude derivative swap contracts to hedge forecasted sales of NGL and condensate equity volumes we retain for fees in our midstream segment whereby our subsidiaries generally gather and process natural gas on behalf of producers, sell the resulting residue gas and NGL volumes at market prices and remit to producers an agreed upon percentage of the proceeds based on an index price for the residue gas and NGL. These contracts are not designated as hedges for accounting purposes. We utilize swaps, futures and other derivative instruments to mitigate the risk associated with market movements in the price of refined products and NGLs to manage our storage facilities and the purchase and sale of purity NGL. These contracts are not designated as hedges for accounting purposes. We use futures and swaps to achieve ratable pricing of crude oil purchases, to convert certain expected refined product sales to fixed or floating prices, to lock in margins for certain refined products and to lock in the price of a portion of natural gas purchases or sales. These contracts are not designated as hedges for accounting purposes. We use financial commodity derivatives to take advantage of market opportunities in our trading activities which complement our transportation and storage segment’s operations and are netted in cost of products sold in our consolidated statements of operations. We also have trading and marketing activities related to power and natural gas in our all other segment which are also netted in cost of products sold. As a result of our trading activities and the use of derivative financial instruments in our transportation and storage segment, the degree of earnings volatility that can occur may be significant, favorably or unfavorably, from period to period. We attempt to manage this volatility through the use of daily position and profit and loss reports provided to our risk oversight committee, which includes members of senior management, and the limits and authorizations set forth in our commodity risk management policy. We disclose the non-exchange traded financial derivative instruments as derivative assets and liabilities on our consolidated balance sheets at fair value with amounts classified as either current or non-current depending on the anticipated settlement date.

Operations And Organization Operations and Organization (Tables)

9 Months Ended

Sep. 30, 2020

Schedule of Goodwill [Table Text Block]

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, 2019	$	10	$	226	$	483	$	693	$	1,397	$	1,555	$	619	$	184	$	5,167


Impaired	—		(183)		(483)		—		—		—		(619)		(40)		(1,325)
Other	—		—		—		—		—		—		—		(7)		(7)
Balance, March 31, 2020	10		43		—		693		1,397		1,555		—		137		3,835

Other	—		—		—		—		—		—		—		33		33
Balance, June 30, 2020	10		43		—		693		1,397		1,555		—		170		3,868
Impaired	—		(43)		—		—		(1,279)		—		—		(132)		(1,454)
Other	—		—		—		—		(66)		—		—		70		4
Balance, September 30, 2020	$	10	$	—	$	—	$	693	$	52	$	1,555	$	—	$	108	$	2,418

Accounting Standards Update and Change in Accounting Principle [Table Text Block]


	December 31, 2019						December 31, 2018
	As Originally Reported		Effect of Change		As Adjusted		As Originally Reported		Effect of Change		As Adjusted
Inventories	$	1,935	$	(403)	$	1,532	$	1,677	$	(305)	$	1,372
Total current assets	7,867		(403)		7,464		6,750		(305)		6,445
Other non-current assets, net	1,075		496		1,571		1,006		472		1,478
Total assets	98,880		93		98,973		88,246		167		88,413
Total partners’ capital	21,827		93		21,920		20,559		167		20,726

In addition, the Partnership’s consolidated statements of operations, comprehensive income and cash flows for prior periods have been retrospectively adjusted as follows:


	Year Ended December 31,				Three Months Ended September 30,		Nine Months Ended September 30,
	2019		2018		2019		2019
As originally reported:
Consolidated Statements of Operations and Comprehensive Income
Cost of products sold	$	39,727	$	41,658	$	9,890	$	29,607
Operating income	7,277		5,348		1,830		5,576
Income from continuing operations before income tax expense (benefit)	5,094		3,634		1,215		3,763
Net income	4,899		3,365		1,161		3,549
Net income per limited partner unit	1.37		1.16		0.32		0.98
Comprehensive income	4,930		3,322		1,154		3,551
Comprehensive income attributable to partners	3,623		1,651		825		2,582

Consolidated Statements of Cash Flows
Net income	4,899		3,365		1,161		3,549

Net change in operating assets and liabilities	(518)		289		27		(247)

Effect of change:
Consolidated Statements of Operations and Comprehensive Income
Cost of products sold	74		(55)		(26)		35
Operating income	(74)		55		26		(35)
Income from continuing operations before income tax expense (benefit)	(74)		55		26		(35)
Net income	(74)		55		26		(35)
Net income per limited partner unit	(0.03)		0.04		0.01		(0.01)
Comprehensive income	(74)		55		26		(35)
Comprehensive income attributable to partners	(74)		55		26		(35)

Consolidated Statements of Cash Flows
Net income	(74)		55		26		(35)

Net change in operating assets and liabilities	74		(55)		(26)		35

As adjusted:
Consolidated Statements of Operations and Comprehensive Income
Cost of products sold	39,801		41,603		9,864		29,642
Operating income	7,203		5,403		1,856		5,541
Income from continuing operations before income tax expense (benefit)	5,020		3,689		1,241		3,728
Net income	4,825		3,420		1,187		3,514
Net income per limited partner unit	1.34		1.20		0.33		0.97
Comprehensive income	4,856		3,377		1,180		3,516
Comprehensive income attributable to partners	3,549		1,706		851		2,547

Consolidated Statements of Cash Flows
Net income	4,825		3,420		1,187		3,514

Net change in operating assets and liabilities	(444)		234		1		(212)

Cash And Cash Equivalents (Tables)

9 Months Ended

Sep. 30, 2020

Supplemental Cash Flow Information [Abstract]

Cash Flow, Operating Capital [Table Text Block]

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


	Nine Months Ended September 30,
	2020		2019
Accounts receivable	$	1,307	$	(353)
Accounts receivable from related companies	(258)		(36)
Inventories	(298)		(7)
Other current assets	108		14
Other non-current assets, net	(26)		(151)
Accounts payable	(1,354)		25
Accounts payable to related companies	370		(37)
Accrued and other current liabilities	127		129
Other non-current liabilities	(5)		(103)
Derivative assets and liabilities, net	123		307
Net change in operating assets and liabilities, net of effects of acquisitions	$	94	$	(212)

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

Non-cash activities were as follows:


	Nine Months Ended September 30,
	2020		2019
NON-CASH INVESTING AND FINANCING ACTIVITIES:
Accrued capital expenditures	$	684	$	1,202

Lease assets obtained in exchange for new lease liabilities	130		73
Distribution reinvestment	72		100

Inventories (Tables)

9 Months Ended

Sep. 30, 2020

Inventory, Net [Abstract]

Schedule Of Inventory


	September 30, 2020		December 31, 2019
Natural gas, NGLs and refined products	$	914	$	833
Crude oil	352		251
Spare parts and other	457		448
Total inventories	$	1,723	$	1,532

Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2020

Fair Value Measurements [Abstract]

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


			Fair Value Measurements at September 30, 2020
	Fair Value Total		Level 1		Level 2
Assets:

Commodity derivatives:

Natural Gas:
Basis Swaps IFERC/NYMEX	$	13	$	13	$	—
Swing Swaps IFERC	2		—		2
Fixed Swaps/Futures	5		5		—


Forward Physical Contracts	6		—		6
Power:
Forwards	8		—		8
Futures	2		2		—
Options – Puts	—		—		—
Options – Calls	1		1		—
NGLs – Forwards/Swaps	103		103		—
Refined Products – Futures	5		5		—
Crude – Forwards/Swaps	2		2		—

Total commodity derivatives	147		131		16
Other non-current assets	31		20		11
Total assets	$	178	$	151	$	27
Liabilities:
Interest rate derivatives	$	(522)	$	—	$	(522)
Commodity derivatives:
Natural Gas:
Basis Swaps IFERC/NYMEX	(9)		(9)		—
Swing Swaps IFERC	(4)		(1)		(3)
Fixed Swaps/Futures	(29)		(29)		—



Power:
Forwards	(3)		—		(3)
Futures	(2)		(2)		—


NGLs – Forwards/Swaps	(153)		(153)		—
Refined Products – Futures	(4)		(4)		—

Total commodity derivatives	(204)		(198)		(6)
Total liabilities	$	(726)	$	(198)	$	(528)


			Fair Value Measurements at December 31, 2019
	Fair Value Total		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)

Net Income per Limited Partner Unit (Tables)

9 Months Ended

Sep. 30, 2020

Earnings Per Share [Abstract]

Reconciliation Of Net Income And Weighted Average Units

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019*		2020		2019*
Net income (loss)	$	(401)	$	1,187	$	(693)	$	3,514
Less: Net income attributable to noncontrolling interests	369		317		554		931
Less: Net income attributable to redeemable noncontrolling interests	12		12		37		38
Net income (loss), net of noncontrolling interests	(782)		858		(1,284)		2,545
Less: General Partner’s interest in income (loss)	—		1		(1)		3
Income (loss) available to Limited Partners	$	(782)	$	857	$	(1,283)	$	2,542
Basic Income (Loss) per Limited Partner Unit:
Weighted average limited partner units	2,696.6		2,624.9		2,694.4		2,621.9
Basic income (loss) per Limited Partner unit	$	(0.29)	$	0.33	$	(0.48)	$	0.97

Diluted Income (Loss) per Limited Partner Unit:
Income (loss) available to Limited Partners	$	(782)	$	857	$	(1,283)	$	2,542
Dilutive effect of equity-based compensation of subsidiaries (1)	—		—		—		—
Diluted income (loss) available to Limited Partners	$	(782)	$	857	$	(1,283)	$	2,542
Weighted average limited partner units	2,696.6		2,624.9		2,694.4		2,621.9
Dilutive effect of unvested unit awards (1)	—		10.6		—		11.0
Weighted average limited partner units, assuming dilutive effect of unvested unit awards	2,696.6		2,635.5		2,694.4		2,632.9
Diluted income (loss) from per Limited Partner unit	$	(0.29)	$	0.33	$	(0.48)	$	0.97

*As adjusted. See Note 1.

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

Equity (Tables)

9 Months Ended

Sep. 30, 2020

Schedule of Capital Units [Table Text Block]

The change in ET Common Units during the nine months ended September 30, 2020 was as follows:


			Nine Months Ended September 30, 2020
Number of Common Units, beginning of period			2,689.6
Common Units issued in connection with the distribution reinvestment plan			6.9

Common Units vested under equity incentive plans and other			1.2
Number of Common Units, end of period			2,697.7

Accumulated Other Comprehensive Income

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


	September 30, 2020		December 31, 2019
Available-for-sale securities	$	16	$	13
Foreign currency translation adjustment	(14)		2
Actuarial loss related to pensions and other postretirement benefits	(10)		(25)
Investments in unconsolidated affiliates, net	(16)		(1)

Total AOCI, net of tax	(24)		(11)
Amounts attributable to noncontrolling interest	20		—
Total AOCI included in partners’ capital, net of tax	$	(4)	$	(11)

Parent Company [Member]

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

Distributions declared and/or paid subsequent to December 31, 2019 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2019

February 7, 2020

February 19, 2020

0.3050

March 31, 2020

May 7, 2020

May 19, 2020

0.3050

June 30, 2020

August 7, 2020

August 19, 2020

0.3050

September 30, 2020

November 6, 2020

November 19, 2020

0.1525

ETO [Member]

Schedule of Preferred Units [Table Text Block]

Distributions declared and/or paid by ETO to its preferred unitholders subsequent to December 31, 2019 were as follows:


Period Ended	Record Date	Payment Date	Series A (1)		Series B (1)		Series C		Series D		Series E		Series F (2)		Series G (2)
December 31, 2019	February 3, 2020	February 18, 2020	$	31.25	$	33.125	$	0.4609	$	0.4766	$	0.4750	$	—	$	—
March 31, 2020	May 1, 2020	May 15, 2020	—		—		0.4609		0.4766		0.4750		21.19		22.36
June 30, 2020	August 3, 2020	August 17, 2020	31.25		33.125		0.4609		0.4766		0.4750		—		—
September 30, 2020	November 2, 2020	November 16, 2020	—		—		0.4609		0.4766		0.4750		33.75		35.625

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

Sunoco LP [Member]

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

Distributions declared and/or paid by Sunoco LP to its common unitholders subsequent to December 31, 2019 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2019

February 7, 2020

February 19, 2020

0.8255

March 31, 2020

May 7, 2020

May 19, 2020

0.8255

June 30, 2020

August 7, 2020

August 19, 2020

0.8255

September 30, 2020

November 6, 2020

November 19, 2020

0.8255

USA Compression Partners, LP [Member]

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

Distributions declared and/or paid by USAC to its common unitholders subsequent to December 31, 2019 were as follows:

Quarter Ended

Record Date

Payment Date

Rate

December 31, 2019

January 27, 2020

February 7, 2020

0.5250

March 31, 2020

April 27, 2020

May 8, 2020

0.5250

June 30, 2020

July 31, 2020

August 10, 2020

0.5250

September 30, 2020

October 26, 2020

November 6, 2020

0.5250

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

9 Months Ended

Sep. 30, 2020

Environmental Exit Costs by Cost


	September 30, 2020		December 31, 2019
Current	$	46	$	46
Non-current	252		274
Total environmental liabilities	$	298	$	320

Right Of Way [Member]

Lessee, Operating Lease, Disclosure


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019		2020		2019
ROW expense	$	13	$	5	$	32	$	17

Revenue (Tables)

9 Months Ended

Sep. 30, 2020

Revenue [Abstract]

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

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


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

Balance, December 31, 2018	$	394
Additions	448
Revenue recognized	(491)
Balance, September 30, 2019	$	351

The balances of Sunoco LP’s contract assets as of September 30, 2020 and December 31, 2019 were as follows:


	September 30, 2020		December 31, 2019
Contract balances:
Contract assets	$	123	$	117
Accounts receivable from contracts with customers	225		366

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction


	Years Ending December 31,
	2020 (remainder)		2021		2022		Thereafter		Total
Revenue expected to be recognized on contracts with customers existing as of September 30, 2020	$	1,633	$	5,674	$	5,180	$	27,016	$	39,503

Derivative Assets And Liabilities (Tables)

9 Months Ended

Sep. 30, 2020

Outstanding Commodity-Related Derivatives

The following table details our outstanding commodity-related derivatives:


	September 30, 2020		December 31, 2019
	Notional Volume	Maturity	Notional Volume	Maturity
Mark-to-Market Derivatives
(Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX (1)	(91,365)	2020-2021	(35,208)	2020-2024
Fixed Swaps/Futures	4,965	2020-2022	1,483	2020



Power (Megawatt):
Forwards	1,714,800	2020-2029	3,213,450	2020-2029
Futures	(35,313)	2020-2022	(353,527)	2020
Options – Puts	(15)	2020-2021	51,615	2020
Options – Calls	(6,323,560)	2020-2022	(2,704,330)	2020-2021



(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(20,800)	2020-2022	(18,923)	2020-2022
Swing Swaps IFERC	(7,480)	2020-2021	(9,265)	2020
Fixed Swaps/Futures	(43,708)	2020-2022	(3,085)	2020-2021
Forward Physical Contracts	(15,281)	2021	(13,364)	2020-2021

NGLs (MBbls) – Forwards/Swaps	(14,743)	2020-2022	(1,300)	2020-2021
Refined Products (MBbls) – Futures	(3,391)	2020-2022	(2,473)	2020-2021
Crude (MBbls) – Forwards/Swaps	1,929	2020	4,465	2020
Corn (thousand bushels)	—	—	(1,210)	2020
Fair Value Hedging Derivatives
(Non-Trading)
Natural Gas (BBtu):
Basis Swaps IFERC/NYMEX	(38,490)	2020-2021	(31,780)	2020
Fixed Swaps/Futures	(38,490)	2020-2021	(31,780)	2020
Hedged Item – Inventory	38,490	2020-2021	31,780	2020

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

Interest Rate Swaps Outstanding

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


Term	Type(1)	Notional Amount Outstanding
		September 30, 2020		December 31, 2019
July 2020(2)(3)	Forward-starting to pay a fixed rate of 3.52% and receive a floating rate	$	—	$	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		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.

Fair Value Of Derivative Instruments

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


	Fair Value of Derivative Instruments
	Asset Derivatives				Liability Derivatives
	September 30, 2020		December 31, 2019		September 30, 2020		December 31, 2019
Derivatives designated as hedging instruments:
Commodity derivatives (margin deposits)	$	32	$	24	$	(52)	$	—
Derivatives not designated as hedging instruments:
Commodity derivatives (margin deposits)	68		319		(107)		(350)
Commodity derivatives	47		41		(45)		(39)
Interest rate derivatives	—		—		(522)		(399)
	115		360		(674)		(788)
Total derivatives	$	147	$	384	$	(726)	$	(788)

Derivatives, Offsetting Fair Value Amounts [Table Text Block]


		Asset Derivatives				Liability Derivatives
	Balance Sheet Location	September 30, 2020		December 31, 2019		September 30, 2020		December 31, 2019
Derivatives without offsetting agreements	Derivative liabilities	$	—	$	—	$	(522)	$	(399)
Derivatives in offsetting agreements:
OTC contracts	Derivative assets (liabilities)	47		41		(45)		(39)
Broker cleared derivative contracts	Other current assets (liabilities)	100		343		(159)		(350)
Total gross derivatives		147		384		(726)		(788)
Offsetting agreements:

Counterparty netting	Derivative assets (liabilities)	(28)		(18)		28		18
Counterparty netting	Other current assets (liabilities)	(34)		(318)		34		318



Total net derivatives		$	85	$	48	$	(664)	$	(452)

Derivatives Not Designated as Hedging Instruments [Table Text Block]


	Location	Amount of Gain (Loss) on Derivatives
		Three Months Ended September 30,				Nine Months Ended September 30,
		2020		2019		2020		2019
Derivatives not designated as hedging instruments:
Commodity derivatives – Trading	Cost of products sold	$	4	$	3	$	15	$	15
Commodity derivatives – Non-trading	Cost of products sold	(44)		21		53		(53)

Interest rate derivatives	Gains (losses) on interest rate derivatives	55		(175)		(277)		(371)

Total		$	15	$	(151)	$	(209)	$	(409)

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.

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
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Financial Information By Segment

Related Party Transactions Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 2020

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


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019		2020		2019
Revenues from related companies	$	100	$	129	$	375	$	374

The following table summarizes the accounts receivable from related companies on our consolidated balance sheets:


	September 30, 2020		December 31, 2019
Accounts receivable from related companies:
FGT	$	13	$	50
Phillips 66	36		36

Various	41		73
Total accounts receivable from related companies	$	90	$	159

Reportable Segments (Tables)

9 Months Ended

Sep. 30, 2020


	September 30, 2020		December 31, 2019*
Segment assets:
Intrastate transportation and storage	$	7,215	$	6,648
Interstate transportation and storage	17,341		18,111
Midstream	19,056		20,332
NGL and refined products transportation and services	20,944		19,145
Crude oil transportation and services	19,882		22,933
Investment in Sunoco LP	4,986		5,438
Investment in USAC	3,011		3,730
All other	2,760		2,636
Total segment assets	$	95,195	$	98,973

*As adjusted. See Note 1.

Operating Segments [Member]

Financial Information By Segment


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019*		2020		2019*
Segment Adjusted EBITDA:
Intrastate transportation and storage	$	203	$	235	$	630	$	777
Interstate transportation and storage	425		442		1,232		1,358
Midstream	530		411		1,280		1,205
NGL and refined products transportation and services	762		667		2,099		1,923
Crude oil transportation and services	631		726		1,741		2,222
Investment in Sunoco LP	189		192		580		497
Investment in USAC	104		104		315		310
All other	22		35		62		80
Adjusted EBITDA (consolidated)	2,866		2,812		7,939		8,372
Depreciation, depletion and amortization	(912)		(784)		(2,715)		(2,343)
Interest expense, net of interest capitalized	(569)		(579)		(1,750)		(1,747)
Impairment losses	(1,474)		(12)		(2,803)		(62)
Gains (losses) on interest rate derivatives	55		(175)		(277)		(371)
Non-cash compensation expense	(30)		(27)		(93)		(85)
Unrealized gains (losses) on commodity risk management activities	(30)		64		(27)		90
Losses on extinguishments of debt	—		—		(62)		(18)
Inventory valuation adjustments (Sunoco LP)	11		(26)		(126)		71
Adjusted EBITDA related to unconsolidated affiliates	(169)		(161)		(480)		(470)
Equity in earnings (loss) of unconsolidated affiliates	(32)		82		46		224
Impairment of investment in an unconsolidated affiliate	(129)		—		(129)		—
Other, net	53		47		(48)		67
Income (loss) before income tax expense	(360)		1,241		(525)		3,728
Income tax expense	(41)		(54)		(168)		(214)


Net income (loss)	$	(401)	$	1,187	$	(693)	$	3,514

Revenue, Segment Benchmark [Member]

Financial Information By Segment

The following tables present financial information by segment:


	Three Months Ended September 30,				Nine Months Ended September 30,
	2020		2019		2020		2019
Revenues:
Intrastate transportation and storage:
Revenues from external customers	$	614	$	675	$	1,615	$	2,115
Intersegment revenues	40		89		148		270
	654		764		1,763		2,385
Interstate transportation and storage:
Revenues from external customers	466		475		1,365		1,454
Intersegment revenues	5		4		15		16
	471		479		1,380		1,470
Midstream:
Revenues from external customers	585		704		1,477		1,704
Intersegment revenues	792		876		2,088		2,792
	1,377		1,580		3,565		4,496
NGL and refined products transportation and services:
Revenues from external customers	2,207		2,271		5,991		7,340
Intersegment revenues	416		607		1,466		1,181
	2,623		2,878		7,457		8,521
Crude oil transportation and services:
Revenues from external customers	2,849		4,453		8,873		13,685
Intersegment revenues	1		—		4		—
	2,850		4,453		8,877		13,685
Investment in Sunoco LP:
Revenues from external customers	2,801		4,328		8,104		12,494
Intersegment revenues	4		3		53		4
	2,805		4,331		8,157		12,498
Investment in USAC:
Revenues from external customers	158		169		500		505
Intersegment revenues	3		6		9		15
	161		175		509		520
All other:
Revenues from external customers	275		420		995		1,196
Intersegment revenues	92		21		377		80
	367		441		1,372		1,276
Eliminations	(1,353)		(1,606)		(4,160)		(4,358)
Total revenues	$	9,955	$	13,495	$	28,920	$	40,493

Operations And Organization Narrative (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2020

Mar. 31, 2020

Sep. 30, 2019

^[1]

Mar. 31, 2019

Sep. 30, 2020

Sep. 30, 2019

^[1]

Jun. 30, 2020

Dec. 31, 2019

Lease, Right of Use Asset, Net

$ 1,454

$ 1,325

934

$ 934

$ 964

^[1]

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

2,418

3,835

$ 2,418

$ 3,868

5,167

^[1]

Document Period End Date

Sep. 30, 2020

(401)

4,825

$ 1,187

$ 3,420

$ (693)

$ 3,514

COVID-19 [Member]

Accounts Receivable, Credit Loss Expense (Reversal)

483

483

619

619

183

226

132

108

137

108

170

184

1,279

Revision of Prior Period, Change in Accounting Principle, Adjustment [Member]

$ 1,397

$ 52

$ 1,397

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

$ 265

[1]	*As adjusted. See Note 1.

Operations And Organization Accounting Change (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2020

Mar. 31, 2020

Sep. 30, 2019

Mar. 31, 2019

Sep. 30, 2020

Sep. 30, 2019

Dec. 31, 2019

Dec. 31, 2018

Error Corrections and Prior Period Adjustments Restatement [Line Items]

Current maturities of long-term debt

$ 1,723

$ 1,532

^[1]

$ 1,372

^[1]

Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest

6,376

$ 39,801

$ 9,864

^[1]

$ 41,603

$ 29,642

^[1]

Operating Income (Loss)

244

7,203

1,856

^[1]

5,403

5,541

^[1]

(360)

5,020

1,241

^[1]

3,689

(525)

3,728

^[1]

Less: Net income attributable to noncontrolling interests

(401)

4,825

1,187

^[1]

3,420

(693)

3,514

^[1]

369

317

^[1]

554

931

^[1]

Inventory valuation adjustments

(375)

4,856

1,180

^[1]

3,377

(706)

3,516

^[1]

(11)

^[1]

126

(71)

^[1]

Increase (Decrease) in Operating Capital

$ (444)

$ 234

(212)

^[1]

Other current assets

235

275

^[1]

Property, plant and equipment, net

75,128

74,193

^[1]

Lease, Right of Use Asset, Net

934

964

^[1]

Intangible assets, net

5,915

6,154

^[1]

Other non-current liabilities

1,582

1,571

^[1]

1,478

1,152

1,162

^[1]

Noncontrolling interests

13,007

12,018

^[1]

Operating expenses

773

806

^[1]

2,406

^[1]

Non-current operating lease liabilities

912

$ 784

^[1]

2,715

$ 2,343

^[1]

901

^[1]

Long-term debt, less current maturities

51,424

51,028

^[1]

Operating lease current liabilities

^[1]

Accrued and other current liabilities

$ 2,913

3,342

^[1]

Comprehensive Income (Loss), Net of Tax, Attributable to Parent

$ (0.29)

$ 1.34

$ 0.33

^[1]

$ 1.20

$ (0.48)

$ 0.97

^[1]

$ (756)

$ 3,549

$ 851

^[1]

$ 1,706

$ (1,297)

$ 2,547

^[1]

Assets, Current

6,150

7,464

^[1]

6,445

Previously Reported [Member]

95,195

98,973

^[1]

88,413

Partners' Capital

18,284

$ 18,284

21,920

^[1]

20,726

Error Corrections and Prior Period Adjustments Restatement [Line Items]

1,935

1,677

Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest

39,727

9,890

41,658

29,607

Operating Income (Loss)

7,277

1,830

5,348

5,576

5,094

1,215

3,634

3,763

4,899

1,161

3,365

3,549

Increase (Decrease) in Operating Capital

4,930

1,154

3,322

3,551

$ 518

$ (27)

$ (289)

$ 247

1,075

1,006

Comprehensive Income (Loss), Net of Tax, Attributable to Parent

$ 1.37

$ 0.32

$ 1.16

$ 0.98

$ 3,623

$ 825

$ 1,651

$ 2,582

Assets, Current

7,867

6,750

Revision of Prior Period, Change in Accounting Principle, Adjustment [Member]

98,880

88,246

Partners' Capital

21,827

20,559

Error Corrections and Prior Period Adjustments Restatement [Line Items]

(403)

(305)

265

Change in Inventory Accounting Policy [Member]

496

$ 0.10

(403)

$ 93

Error Corrections and Prior Period Adjustments Restatement [Line Items]

Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest

(26)

(55)

Operating Income (Loss)

(74)

(35)

(74)

(35)

(74)

(35)

Increase (Decrease) in Operating Capital

(74)

(35)

$ (74)

$ 26

$ 55

$ (35)

472

Comprehensive Income (Loss), Net of Tax, Attributable to Parent

$ (0.03)

$ 0.01

$ 0.04

$ (0.01)

$ (74)

$ 26

$ 55

$ (35)

(305)

167

$ 167

Error Corrections and Prior Period Adjustments Restatement [Line Items]

Error Corrections and Prior Period Adjustments Restatement [Line Items]

1,808

1,723

^[1]

$ 4,751

6,121

^[1]

Crude sales

Gathering, transportation and other fees

2,298

3,971

^[1]

7,170

11,842

^[1]

Error Corrections and Prior Period Adjustments Restatement [Line Items]

Error Corrections and Prior Period Adjustments Restatement [Line Items]

2,283

2,466

^[1]

6,805

6,768

^[1]

Natural gas sales

Error Corrections and Prior Period Adjustments Restatement [Line Items]

681

822

^[1]

1,783

2,549

^[1]

Other

$ 165

$ 202

^[1]

$ 459

$ 699

^[1]

[1]	*As adjusted. See Note 1.

Operations And Organization Goodwill Impairment (Details) - USD ($)
$ in Millions

3 Months Ended

Sep. 30, 2020

Jun. 30, 2020

Mar. 31, 2020

Dec. 31, 2019

$ 2,418

$ 3,868

$ 3,835

$ 5,167

^[1]

(1,454)

(1,325)

(7)

226

(43)

(183)

483

(483)

NGL and refined products transportation and services [Member]

693

1,397

(1,279)

(66)

1,555

619

(619)

108

170

137

$ 184

(132)

(40)

Supplemental Cash Flow Elements [Abstract]

$ 70

$ 33

$ (7)

[1]	*As adjusted. See Note 1.

Cash And Cash Equivalents Net Change in Operating Assets and Liabilities (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Mar. 31, 2020

Sep. 30, 2019

Mar. 31, 2019

Sep. 30, 2020

Sep. 30, 2019

Accounts receivable

$ 1,307

$ (353)

Accounts receivable from related companies

(258)

(36)

(298)

(7)

Other current assets

108

Accounts payable to related companies

(26)

(151)

Accounts payable

(1,354)

370

(37)

Accrued and other current liabilities

127

129

Other non-current liabilities

(5)

(103)

Derivative assets and liabilities, net

123

307

Net change in operating assets and liabilities, net of effects of acquisitions

$ 444

$ (1)

$ (234)

$ (94)

$ 212

^[1]

[1]	*As adjusted. See Note 1.

Cash And Cash Equivalents Non-Cash Activities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
NON-CASH INVESTING AND FINANCING ACTIVITIES:
Accrued capital expenditures	$ 684	$ 1,202
Right-of-Use Assets Obtained in Exchange for Liabilities	130	73
Stock Issued During Period, Value, Dividend Reinvestment Plan	$ 72	$ 100

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

Sep. 30, 2020

Dec. 31, 2019

Dec. 31, 2018

Inventory, Net [Abstract]

Other Inventory, Supplies, Gross

$ 457

$ 448

Natural gas, NGLs, and refined products

914

833

352

251

Inventory, Net

$ 1,723

$ 1,532

^[1]

$ 1,372

[1]	*As adjusted. See Note 1.

Inventories Inventory Narrative (Details) - USD ($) $ in Millions	Sep. 30, 2020	Dec. 31, 2019
Sunoco LP [Member]
Inventory [Line Items]
Inventory, LIFO Reserve	$ 360	$ 229

Fair Value Measurements Narrative (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2020	Dec. 31, 2019
Fair Value Measurements [Abstract]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net	$ 0
Debt obligations, fair value	52,280	$ 54,790
Long-term Debt	$ 51,450	$ 51,050

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

3 Months Ended

9 Months Ended

Sep. 30, 2020

Mar. 31, 2020

Sep. 30, 2019

^[1]

Mar. 31, 2019

Sep. 30, 2020

Sep. 30, 2019

^[1]

Earnings Per Share [Abstract]

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

$ (401)

$ 4,825

$ 1,187

$ 3,420

$ (693)

$ 3,514

Less: Net income attributable to noncontrolling interests

369

317

554

931

Less: Net income attributable to redeemable noncontrolling interests

Income from continuing operations, net of noncontrolling interest

(782)

858

(1,284)

2,545

Less: General Partner’s interest in income (loss)

(1)

Limited Partners’ interest in net income (loss)

$ (782)

$ 857

$ (1,283)

$ 2,542

Basic Income from Continuing Operations per Limited Partner Unit:

Weighted average limited partner units

2,696.6

2,624.9

2,694.4

2,621.9

Basic income (loss) per Limited Partner unit

$ (0.29)

$ 0.33

$ (0.48)

$ 0.97

Diluted Income from Continuing Operations per Limited Partner Unit:

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

^[2]

$ 0

Net Income (Loss) Available to Common Stockholders, Diluted

$ (782)

$ 857

$ (1,283)

$ 2,542

Dilutive effect of unvested unit awards (1)

^[2]

0.0

10.6

0.0

11.0

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

2,696.6

2,635.5

2,694.4

2,632.9

Diluted income (loss) from per Limited Partner unit

$ (0.29)

$ 0.33

$ (0.48)

$ 0.97

[1]	*As adjusted. See Note 1.
[2]	Dilutive effects are excluded from the calculation for periods where the impact would have been antidilutive.

Debt Obligations Narrative (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2020

Sep. 30, 2019

^[1]

Jan. 31, 2020

Repayments of Long-term Debt

$ 20,293

$ 17,247

Proceeds from Issuance of Long-term Debt

$ 20,651

$ 18,125

Banking Regulation, Leverage Ratio [Abstract]

Banking Regulation, Supplementary Leverage Ratio, Actual

4.24

Distribution Made to Limited Partner, Distributions Declared, Per Unit

$ 0.1525

Annualized [Member]

Banking Regulation, Leverage Ratio [Abstract]

Distribution Made to Limited Partner, Distributions Declared, Per Unit

$ 0.61

USAC [Member]

Line of Credit Facility, Remaining Borrowing Capacity

$ 1,100

2.9% Senior Notes due 2025 [Member]

$ 1,000

ETO Credit Facility due December 2022 [Member]

2.90%

Line of Credit Facility, Current Borrowing Capacity

1,650

Long-term Commercial Paper, Noncurrent

3,230

1,630

Letters of Credit Outstanding, Amount

$ 117

Line of Credit Facility, Interest Rate at Period End

1.16%

Line of Credit Facility, Maximum Borrowing Capacity

$ 5,000

ETO Credit Facility due December 2022 [Member] | Accordion feature [Member]

ETO 364-day Credit Facility due November 2019 [Member]

6,000

Line of Credit Facility, Maximum Borrowing Capacity

1,000

Sunoco LP $1.5 billion Revolving Credit Facility due July 2023 [Member] | Sunoco LP [Member]

Line of Credit Facility, Current Borrowing Capacity

1,500

Letters of Credit Outstanding, Amount

Line of Credit Facility, Remaining Borrowing Capacity

$ 1,410

Line of Credit Facility, Interest Rate at Period End

2.15%

USAC Credit Facility, due 2023 [Member] | USA Compression Partners, LP [Member]

Line of Credit Facility, Current Borrowing Capacity

$ 1,600

Line of Credit Facility, Maximum Borrowing Capacity

400

USAC Credit Facility, due 2023 [Member] | USAC [Member]

Letters of Credit Outstanding, Amount

497

Line of Credit Facility, Remaining Borrowing Capacity

$ 412

Line of Credit Facility, Interest Rate at Period End

3.03%

ETO Term Loan [Member] | ETO [Member]

Line of Credit Facility, Interest Rate at Period End

$ 2,000

1.15%

Line of Credit Facility, Maximum Borrowing Capacity

$ 2,000

3.75% Senior Notes due 2030 [Member]

$ 1,500

5.0% Senior Notes due 2050 [Member]

3.75%

$ 2,000

5.75% Senior Notes due September 1, 2020 [Member] | ETO [Member]

5.00%

$ 400

4.15% Senior Notes due October 1, 2020 [Member] | ETO [Member]

5.75%

$ 1,050

7.5% Senior Notes due October 15, 2020 [Member] | ETO [Member]

4.15%

$ 1,140

5.50% Senior Notes, due February 15, 2020 [Member] | ETO [Member]

7.50%

$ 250

ETE 7.5% Senior Notes due 2020 [Member] | Parent Company [Member]

5.50%

$ 52

5.36% Senior Unsecured Notes, due December 9, 2020 [Member] | Transwestern [Member]

7.50%

$ 175

HFOTCO Tax Exempt Notes due 2050 [Member]

5.36%

SemCAMS C$350 million senior secured term loan facility [Member] | SemCAMS [Member]

225

Line of Credit Facility, Fair Value of Amount Outstanding

262

253

SemCAMS C$525 million senior secured revolving credit facility [Member] | SemCAMS [Member]

SemCAMS C$300 million senior secured construction loan facility [Member] | SemCAMS [Member]

394

Line of Credit Facility, Fair Value of Amount Outstanding

225

KAPS Facility [Member] | SemCAMS [Member]

Line of Credit Facility, Maximum Borrowing Capacity

187

Line of Credit Facility, Fair Value of Amount Outstanding

Canada, Dollars | SemCAMS C$350 million senior secured term loan facility [Member] | SemCAMS [Member]

Canada, Dollars | SemCAMS C$525 million senior secured revolving credit facility [Member] | SemCAMS [Member]

350

Canada, Dollars | SemCAMS C$300 million senior secured construction loan facility [Member] | SemCAMS [Member]

525

Canada, Dollars | KAPS Facility [Member] | SemCAMS [Member]

300

Line of Credit Facility, Maximum Borrowing Capacity

$ 250

[1]	*As adjusted. See Note 1.

Redeemable Noncontrolling Interest (Details) - USD ($)
$ / shares in Units, $ in Millions

1 Months Ended

3 Months Ended

Apr. 30, 2018

Sep. 30, 2020

Dec. 31, 2019

^[1]

Distribution Made to Limited Partner, Distributions Declared, Per Unit

$ 756

$ 739

$ 0.1525

Preferred Stock, Redemption Price Per Share

$ 825

USAC [Member]

$ 477

ETO [Member]

SemCAMS [Member]

Preferred Stock, Shares Outstanding

$ 264

337,046

Preferred Units [Member] | USAC [Member]

Preferred Units, Issued

500,000

Distribution Made to Limited Partner, Distributions Declared, Per Unit

$ 24.375

Canada, Dollars

Preferred Stock, Redemption Price Per Share

$ 1,100

[1]	*As adjusted. See Note 1.

Equity Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2020	Sep. 30, 2019
Distribution Made to Limited Partner, Distributions Declared, Per Unit	$ 0.1525
Stock Repurchase Program, Remaining Authorized Repurchase Amount	$ 911.0	$ 911.0
Stock Issued During Period, Value, Dividend Reinvestment Plan		$ 72.0	$ 100.0
Stock Issued During Period, Shares, Dividend Reinvestment Plan		6,900,000
Common Units Remaining Available to be Issued Under Distribution Reinvestment Plan	22,000,000	22,000,000
USAC [Member]
Stock Issued During Period, Value, Dividend Reinvestment Plan		$ 1.4
Stock Issued During Period, Shares, Dividend Reinvestment Plan		140,318
Equity Distribution Program [Member] \| Sunoco LP [Member]
Equity Distribution Agreements, Value of Units Available to be Issued	$ 295.0	$ 295.0
Partners' Capital Account, Units, Sale of Units		0
Series F Preferred Units [Member]
Preferred Units, Outstanding	500,000	500,000
Series G Preferred Units [Member]
Preferred Units, Outstanding	1,100,000	1,100,000
Series E Preferred Units [Member]
Preferred Units, Outstanding	32,000,000	32,000,000
Series D Preferred Units [Member]
Preferred Units, Outstanding	17,800,000	17,800,000
Series C Preferred Units [Member]
Preferred Units, Outstanding	18,000,000	18,000,000
Series B Preferred Units [Member]
Preferred Units, Outstanding	550,000	550,000
Series A Preferred Units [Member]
Preferred Units, Outstanding	950,000	950,000

Equity Table - Change In ETE Common Units (Details) - shares shares in Millions	9 Months Ended
	Sep. 30, 2020	Dec. 31, 2019
Class of Stock [Line Items]
Limited Partners' Capital Account, Units Outstanding	2,697.7	2,689.6
Stock Issued During Period, Shares, Dividend Reinvestment Plan	6.9
Partners' Capital Account, Unit-based Payment Arrangement, Number of Units	1.2

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

3 Months Ended

Sep. 30, 2020

Jun. 30, 2020

Mar. 31, 2020

Dec. 31, 2019

Distribution Made to Limited Partner, Distributions Paid, Per Unit

$ 0.1525

$ 0.3050

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

Series A Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

^[1]

31.25

Series B Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

^[1]

33.125

Series C Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

0.4609

Series D Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

0.4766

Series E Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

0.4750

Series F Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

^[2]

33.75

21.19

Series G Preferred Units [Member]

Distribution Made to Limited Partner, Distributions Paid, Per Unit

^[2]

$ 35.625

$ 0

$ 22.36

$ 0

[1]	ETO Series A Preferred Unit and ETO Series B Preferred Unit distributions are paid on a semi-annual basis.
[2]	ETO Series F and G Preferred Unit distributions related to the period ended March 31, 2020 represent a prorated initial distribution. Distributions are paid on a semi-annual basis.

Equity Table - Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2020	Dec. 31, 2019
Partners' Capital Notes [Abstract]
Available-for-sale securities	$ 16	$ 13
Foreign currency translation adjustment	(14)	2
Actuarial gain related to pensions and other postretirement benefits	(10)	(25)
AOCI attributable to equity method investments	(16)	(1)
Total AOCI, net of tax	(24)	(11)
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Noncontrolling Interest	$ 20	$ 0

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Narrative (Details) $ in Millions		3 Months Ended		9 Months Ended
	Jan. 01, 2020 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2019 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2019 USD ($)	Dec. 31, 2019 USD ($)
Payments for Environmental Liabilities		$ 7.0	$ 16.0	$ 22.0	$ 31.0
Document Period End Date				Sep. 30, 2020
Loss Contingency Accrual, at Carrying Value		86.0		$ 86.0		$ 120.0
Loss Contingency, Estimate of Possible Loss		80.0		80.0
Accrual for Environmental Loss Contingencies		$ 298.0		$ 298.0		$ 320.0
Sunoco, Inc. [Member]
Loss Contingency, Pending Claims, Number		5		5
Revolution Pipeline [Member]
Payments for Legal Settlements	$ 2.0
SPLP [Member]
Proposed Environmental Penalty				$ 5.4
SPLP and Mid-Valley Pipeline [Member]
Proposed Environmental Penalty				$ 1.0
Sunoco [Member]
Site Contingency, Number of Sites Needing Remediation		31		31
PES [Member]
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest		7.40%
Williams Litigation [Member]
Loss Contingency, Damages Sought, Value				$ 410.0
Civil Penalties [Member] \| Revolution Pipeline [Member]
Payments for Legal Settlements	$ 28.6
PES [Member]
Notes Receivable, Related Parties			$ 75.0		$ 75.0
Repayment of Notes Receivable from Related Parties				12.0
Loans and Leases Receivable, Allowance		$ 63.0		$ 63.0

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Table - Accrued Environmental Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2020	Dec. 31, 2019
Environmental Exit Cost [Line Items]
Current	$ 46	$ 46
Non-current	252	274
Total environmental liabilities	$ 298	$ 320

Regulatory Matters, Commitments, Contingencies And Environmental Liabilities Schedule of Right of Way Expense (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Contractual Right of Way, Expense	$ 13	$ 5	$ 32	$ 17

Revenue (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
Revenue (Details) - USD ($) $ in Millions	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019	Dec. 31, 2018
Contract with Customer, Liability, Revenue Recognized			$ (614)	$ (491)
Increase (Decrease) in Accounts Receivable			(1,307)	353
Contract with Customer, Liability	$ 361	$ 351	361	351	$ 377	$ 394
Revenue, Remaining Performance Obligation, Amount	39,503		39,503
Sunoco LP [Member]
Contract with Customer, Asset, after Allowance for Credit Loss	123		123		117
Capitalized Contract Cost, Amortization	4	$ 4	14	$ 12
Receivables from Customers	$ 225		$ 225		$ 366

Revenue Revenue Contract Liabilities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019	Dec. 31, 2018
Revenue from Contract Liabilities [Abstract]
Contract with Customer, Liability	$ 361	$ 351	$ 377	$ 394
Deferred Revenue, Additions	598	448
Contract with Customer, Liability, Revenue Recognized	$ (614)	$ (491)

Revenue, Remaining performance obligations (Details) $ in Millions	Sep. 30, 2020 USD ($)
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 39,503
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	39,503
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-10-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Amount	1,633
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	1,633
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Amount	5,674
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	5,674
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Amount	5,180
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	5,180
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Amount	27,016
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 27,016

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

Sep. 30, 2020

MMbtu

Megawatt

bbl

barrels

bushels

Dec. 31, 2019

MMbtu

Megawatt

bbl

barrels

bushels

Mark-To-Market Derivatives [Member] | Non Trading [Member] | Future [Member]

Derivative, Nonmonetary Notional Amount | bushels

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

Derivative, Nonmonetary Notional Amount | bbl

(14,743)

(1,300)

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

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

(20,800)

(18,923)

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

(7,480)

(9,265)

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

(43,708)

(3,085)

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

(15,281)

(13,364)

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

^[1]

(91,365)

(35,208)

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

(4,965)

(1,483)

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

(38,490)

(31,780)

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

(38,490)

(31,780)

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

(38,490)

(31,780)

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

(15)

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

(6,323,560)

(2,704,330)

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

(1,714,800)

(3,213,450)

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

(35,313)

(353,527)

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

(51,615)

Derivative, Nonmonetary Notional Amount | bbl

(1,929)

(4,465)

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

Derivative, Nonmonetary Notional Amount | barrels

(3,391)

(2,473)

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

Derivative, Nonmonetary Notional Amount | bushels

(1,210)

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

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

9 Months Ended

Sep. 30, 2020

Dec. 31, 2019

July 2020 [Member]

Description of Interest Rate Derivative Activities

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

Forward-starting to pay a fixed rate of 3.52% and receive a floating rate

Derivative, Notional Amount

^[2],[3]

$ 0

$ 400

July 2021 [Member]

Description of Interest Rate Derivative Activities

^[1],[2]

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

Derivative, Notional Amount

^[2]

$ 400

400

July 2022 [Member]

Description of Interest Rate Derivative Activities

^[1],[2]

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

Derivative, Notional Amount

^[2]

$ 400

[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.

Derivative Assets And Liabilities Table - Fair Value of Derivative Instruments (Details) - USD ($) $ in Millions	Sep. 30, 2020	Dec. 31, 2019
Total derivatives assets	$ 147	$ 384
Total derivatives liabilities	(726)	(788)
Not Designated as Hedging Instrument [Member]
Total derivatives assets	115	360
Total derivatives liabilities	(674)	(788)
Fair Value, Recurring [Member]
Price Risk Derivative Liabilities, at Fair Value	204	389
Level 1 \| Fair Value, Recurring [Member]
Price Risk Derivative Liabilities, at Fair Value	198	383
Level 2 \| Fair Value, Recurring [Member]
Price Risk Derivative Liabilities, at Fair Value	6	6
Commodity Derivatives [Member] \| Not Designated as Hedging Instrument [Member]
Total derivatives assets	47	41
Total derivatives liabilities	(45)	(39)
Commodity Derivatives (Margin Deposits) [Member] \| Designated as Hedging Instrument [Member]
Total derivatives assets	32	24
Total derivatives liabilities	(52)	0
Commodity Derivatives (Margin Deposits) [Member] \| Not Designated as Hedging Instrument [Member]
Total derivatives assets	68	319
Total derivatives liabilities	(107)	(350)
Interest Rate Derivatives [Member] \| Not Designated as Hedging Instrument [Member]
Total derivatives assets	0	0
Total derivatives liabilities	$ (522)	$ (399)

Derivative Assets And Liabilities Table - Gross FV and Netting Offset (Details) - USD ($) $ in Millions	Sep. 30, 2020	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 147	$ 384
Derivative Liability, Fair Value, Gross Liability	(726)	(788)
Counterparty netting	(28)	(18)
Counterparty netting	28	18
Payments on margin deposit	(34)	(318)
Derivative Liability, Collateral, Right to Reclaim Cash, Offset	34	318
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	85	48
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	664	452
Without offsetting agreements [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0
Derivative Liability, Fair Value, Gross Liability	(522)	(399)
OTC Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	47	41
Derivative Liability, Fair Value, Gross Liability	(45)	(39)
Broker cleared derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	100	343
Derivative Liability, Fair Value, Gross Liability	$ (159)	$ (350)

Derivative Assets And Liabilities Table - Partnership's Derivative Assets and Liabilities Amount of Gain (Loss) Recognized (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2020

Sep. 30, 2019

Sep. 30, 2020

Sep. 30, 2019

Amount of Gain/(Loss) Recognized in Income on Derivatives

$ 15

$ (151)

$ (209)

$ (409)

Commodity Derivatives [Member]

(175)

^[1]

(277)

(371)

^[1]

Amount of Gain/(Loss) Recognized in Income on Derivatives

(44)

(53)

Commodity Derivatives - Trading [Member]

Amount of Gain/(Loss) Recognized in Income on Derivatives

$ 4

$ 3

$ 15

[1]	*As adjusted. See Note 1.

Related Party Transactions Related Party Revenue (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2020

Sep. 30, 2019

Sep. 30, 2020

Sep. 30, 2019

Dec. 31, 2019

Contract with Customer, Liability, Revenue Recognized

$ (614)

$ (491)

Accounts payable to related companies

$ 30

$ 31

^[1]

Revenue from Related Parties

100

$ 129

375

$ 374

159

FGT [Member]

Phillips 66 Company [Member]

Other Related Parties [Member]

$ 41

$ 73

[1]	*As adjusted. See Note 1.

Reportable Segments Table - Revenues (External and Intersegment) by Investments (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2020

Sep. 30, 2019

Sep. 30, 2020

Sep. 30, 2019

$ 9,955

$ 13,495

^[1]

$ 28,920

$ 40,493

^[1]

654

764

1,763

2,385

2,805

4,331

8,157

12,498

161

175

509

520

471

479

1,380

1,470

NGL and refined products transportation and services [Member]

1,377

1,580

3,565

4,496

2,623

2,878

7,457

8,521

2,850

4,453

8,877

13,685

Intersegment Eliminations [Member]

367

441

1,372

1,276

Intersegment [Member] | Intrastate Transportation And Storage [Member]

(1,353)

(1,606)

(4,160)

(4,358)

Intersegment [Member] | Investment In Sunoco LP [Member]

148

270

Intersegment [Member] | Investment In USAC [Member]

Intersegment [Member] | Interstate Transportation and Storage [Member]

Intersegment [Member] | Midstream [Member]

Intersegment [Member] | NGL and refined products transportation and services [Member]

792

876

2,088

2,792

Intersegment [Member] | Crude oil transportation and services [Member]

416

607

1,466

1,181

Intersegment [Member] | Other Segments [Member]

External Customers [Member] | Intrastate Transportation And Storage [Member]

377

External Customers [Member] | Investment In Sunoco LP [Member]

614

675

1,615

2,115

External Customers [Member] | Investment In USAC [Member]

2,801

4,328

8,104

12,494

External Customers [Member] | Interstate Transportation and Storage [Member]

158

169

500

505

External Customers [Member] | Midstream [Member]

466

475

1,365

1,454

External Customers [Member] | NGL and refined products transportation and services [Member]

585

704

1,477

1,704

External Customers [Member] | Crude oil transportation and services [Member]

2,207

2,271

5,991

7,340

External Customers [Member] | Other Segments [Member]

2,849

4,453

8,873

13,685

$ 275

$ 420

$ 995

$ 1,196

[1]	*As adjusted. See Note 1.

Reportable Segments Table - Segment Adjusted EBITDA (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2020

Mar. 31, 2020

Sep. 30, 2019

^[1]

Mar. 31, 2019

Sep. 30, 2020

Sep. 30, 2019

$ 2,866

$ 2,812

$ 7,939

$ 8,372

^[1]

(912)

(784)

(2,715)

(2,343)

^[1]

Interest expense, net

(569)

(579)

(1,750)

(1,747)

^[1]

(1,474)

(12)

(2,803)

(62)

^[1]

Non-cash compensation expense

(175)

(277)

(371)

^[1]

(30)

(27)

(93)

(85)

^[1]

Unrealized gains (losses) on commodity risk management activities

(30)

(27)

Inventory valuation adjustments

(62)

(18)

^[1]

(26)

(126)

^[1]

Equity in earnings (losses) of unconsolidated affiliates

(32)

224

^[1]

Adjusted EBITDA related to unconsolidated affiliates

(169)

(161)

(480)

(470)

INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAX EXPENSE

(53)

(47)

(67)

(360)

$ 5,020

1,241

$ 3,689

(525)

3,728

^[1]

Income tax (benefit) expense from continuing operations

(41)

(54)

(168)

(214)

^[1]

Equity Method Investment, Other than Temporary Impairment

(401)

$ 4,825

1,187

$ 3,420

(693)

3,514

^[1]

(129)

^[1]

203

235

630

777

^[1]

189

192

580

497

^[1]

Adjustments And Eliminations [Member]

104

315

310

^[1]

^[1]

425

442

1,232

1,358

^[1]

NGL and refined products transportation and services [Member]

530

411

1,280

1,205

^[1]

762

667

2,099

1,923

^[1]

$ 631

$ 726

$ 1,741

$ 2,222

^[1]

[1]	*As adjusted. See Note 1.

Reportable Segments Table - Assets (Details) - USD ($)
$ in Millions

Sep. 30, 2020

Dec. 31, 2019

^[1]

Dec. 31, 2018

$ 95,195

$ 98,973

$ 88,413

7,215

6,648

17,341

18,111

NGL and refined products transportation and services [Member]

19,056

20,332

20,944

19,145

19,882

22,933

4,986

5,438

3,011

3,730