0000107263-21-000021 | 10-Q | XBRL Viewer

Operating and maintenance expenses

$ 2,283

$ 1,781

$ 4,895

$ 3,694

Costs and expenses:

379

320

739

657

Depreciation and amortization expenses

463

430

901

859

Selling, general, and administrative expenses

114

127

237

240

Impairment of goodwill (Note 10)

187

Other (income) expense – net

Total costs and expenses

1,683

1,169

3,556

2,651

Operating income (loss)

600

612

1,339

1,043

Equity earnings (losses) (Note 4)

135

108

266

130

Impairment of equity-method investments (Note 10)

(938)

Other investing income (loss) – net

Interest incurred

(301)

(299)

(597)

(600)

Interest capitalized

Other income (expense) – net

Income (loss) before income taxes

441

432

1,017

(342)

Less: Provision (benefit) for income taxes

119

117

260

(87)

Net income (loss)

322

315

757

(255)

Less: Net income (loss) attributable to noncontrolling interests

(41)

Net income (loss) attributable to The Williams Companies, Inc.

304

303

730

(214)

Less: Preferred stock dividends

Net income (loss) available to common stockholders

$ 304

$ 303

$ 729

$ (215)

Basic earnings (loss) per common share:

Net income (loss)

$ 0.25

$ 0.60

$ (0.18)

Weighted-average shares (thousands)

1,215,250

1,213,601

1,214,950

1,213,310

Diluted earnings (loss) per common share:

Net income (loss)

$ 0.25

$ 0.60

$ (0.18)

Weighted-average shares (thousands)

1,217,476

1,214,581

1,217,344

1,213,310

^[1]

Service [Member]

Revenues:

NonRegulated Service Commodity Consideration [Member]

$ 1,460

$ 1,446

$ 2,912

$ 2,920

Revenues:

100

Product [Member]

Revenues:

Oil and Gas, Purchased [Member]

772

310

1,883

721

Costs and expenses:

Product costs

697

271

1,629

667

Natural Gas Purchased For Shrink [Member]

Costs and expenses:

Product costs

$ 18

$ 15

$ 39

$ 28

[1]	For the six months ended June 30, 2020, 1.1 million weighted-average nonvested restricted stock units have been excluded from the computation of diluted earnings (loss) per common share as their inclusion would be antidilutive due to our loss available to common stockholders.

Consolidated Statement of Comprehensive Income (Loss) (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Comprehensive income (loss):
Net income (loss)	$ 322	$ 315	$ 757	$ (255)
Cash flow hedging activities:
Net unrealized gain (loss) from derivative instruments, net of taxes of $7 and $9 in 2021 and $— and $— in 2020	(17)	0	(26)	0
Reclassifications into earnings of net derivative instruments (gain) loss, net of taxes of ($2) and ($2) in 2021 and $— and $— in 2020	4	0	6	0
Pension and other postretirement benefits:
Net actuarial gain (loss) arising during the year, net of taxes of $— and $— in 2021 and ($7) and ($3) in 2020	0	23	0	9
Amortization of actuarial (gain) loss and net actuarial loss from settlements included in net periodic benefit cost (credit), net of taxes of ($1) and ($2) in 2021 and ($3) and ($5) in 2020	3	6	6	14
Other comprehensive income (loss)	(10)	29	(14)	23
Comprehensive income (loss)	312	344	743	(232)
Less: Comprehensive income (loss) attributable to noncontrolling interests	18	12	27	(41)
Comprehensive income (loss) attributable to The Williams Companies, Inc.	$ 294	$ 332	$ 716	$ (191)

Consolidated Statement of Comprehensive Income (Loss) (Parenthetical) (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), after Reclassification, Tax [Abstract]
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), before Reclassification, Tax	$ 7	$ 0	$ 9	$ 0
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, Tax	(2)	0	(2)	0
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax [Abstract]
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss) Arising During Period, Tax	0	(7)	0	(3)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Tax	$ (1)	$ (3)	$ (2)	$ (5)

Consolidated Balance Sheet (Unaudited) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 1,201	$ 142
Trade accounts and other receivables	1,000	1,000
Allowance for doubtful accounts	(1)	(1)
Trade accounts and other receivables – net	999	999
Inventories	194	136
Other current assets and deferred charges	231	152
Total current assets	2,625	1,429
Investments	5,124	5,159
Property, plant, and equipment	43,543	42,489
Accumulated depreciation and amortization	(14,244)	(13,560)
Property, plant, and equipment – net	29,299	28,929
Intangible assets – net of accumulated amortization	7,277	7,444
Regulatory assets, deferred charges, and other	1,182	1,204
Total assets	45,507	44,165
Current liabilities:
Accounts payable	611	482
Accrued liabilities	1,005	944
Long-term debt due within one year	2,143	893
Total current liabilities	3,759	2,319
Long-term debt	21,091	21,451
Deferred income tax liabilities	2,179	1,923
Regulatory liabilities, deferred income, and other	4,213	3,889
Contingent liabilities (Note 11)
Stockholders’ equity:
Preferred stock	35	35
Common stock ($1 par value; 1,470 million shares authorized at June 30, 2021 and December 31, 2020; 1,249 million shares issued at June 30, 2021 and 1,248 million shares issued at December 31, 2020)	1,249	1,248
Capital in excess of par value	24,401	24,371
Retained deficit	(13,022)	(12,748)
Accumulated other comprehensive income (loss)	(110)	(96)
Treasury stock, at cost (35 million shares of common stock)	(1,041)	(1,041)
Total stockholders’ equity	11,512	11,769
Noncontrolling interests in consolidated subsidiaries	2,753	2,814
Total equity	14,265	14,583
Total liabilities and equity	$ 45,507	$ 44,165

Consolidated Balance Sheet (Parenthetical) (Unaudited) - USD ($) shares in Millions, $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Stockholders’ equity:
Common stock, par value of shares authorized	$ 1	$ 1
Common stock, shares authorized	1,470	1,470
Common stock, shares issued	1,249	1,248
Treasury stock, shares of common stock	35	35
Inventory, Net	$ 194	$ 136

Consolidated Statement of Changes in Equity (Unaudited) - USD ($) $ in Millions	Total	Total Stockholders’ Equity	Preferred Stock	Common Stock	Capital in Excess of Par Value	Retained Deficit	AOCI*	Treasury Stock	Noncontrolling Interests
Period Start at Dec. 31, 2019	$ 16,364	$ 13,363	$ 35	$ 1,247	$ 24,323	$ (11,002)	$ (199)	$ (1,041)	$ 3,001
Net income (loss)	(255)	(214)	0	0	0	(214)	0	0	(41)
Other comprehensive income (loss)	23	23	0	0	0	0	23	0	0
Cash dividends – common stock	(971)	(971)	0	0	0	(971)	0	0	0
Dividends and distributions to noncontrolling interests	(98)	0	0	0	0	0	0	0	(98)
Stock-based compensation and related common stock issuances, net of tax	21	21	0	1	20	0	0	0	0
Contributions from noncontrolling interests	4	0	0	0	0	0	0	0	4
Other	(8)	(10)	0	0	0	(10)	0	0	2
Net increase (decrease) in equity	(1,284)	(1,151)	0	1	20	(1,195)	23	0	(133)
Period End at Jun. 30, 2020	15,080	12,212	35	1,248	24,343	(12,197)	(176)	(1,041)	2,868
Period Start at Mar. 31, 2020	15,259	12,354	35	1,248	24,330	(12,013)	(205)	(1,041)	2,905
Net income (loss)	315	303	0	0	0	303	0	0	12
Other comprehensive income (loss)	29	29	0	0	0	0	29	0	0
Cash dividends – common stock	(486)	(486)	0	0	0	(486)	0	0	0
Dividends and distributions to noncontrolling interests	(54)	0	0	0	0	0	0	0	(54)
Stock-based compensation and related common stock issuances, net of tax	13	13	0	0	13	0	0	0	0
Contributions from noncontrolling interests	2	0	0	0	0	0	0	0	2
Other	2	(1)	0	0	0	(1)	0	0	3
Net increase (decrease) in equity	(179)	(142)	0	0	13	(184)	29	0	(37)
Period End at Jun. 30, 2020	15,080	12,212	35	1,248	24,343	(12,197)	(176)	(1,041)	2,868
Period Start at Dec. 31, 2020	14,583	11,769	35	1,248	24,371	(12,748)	(96)	(1,041)	2,814
Net income (loss)	757	730	0	0	0	730	0	0	27
Other comprehensive income (loss)	(14)	(14)	0	0	0	0	(14)	0	0
Cash dividends – common stock	(996)	(996)	0	0	0	(996)	0	0	0
Dividends and distributions to noncontrolling interests	(95)	0	0	0	0	0	0	0	(95)
Stock-based compensation and related common stock issuances, net of tax	31	31	0	1	30	0	0	0	0
Contributions from noncontrolling interests	6	0	0	0	0	0	0	0	6
Other	(7)	(8)	0	0	0	(8)	0	0	1
Net increase (decrease) in equity	(318)	(257)	0	1	30	(274)	(14)	0	(61)
Period End at Jun. 30, 2021	14,265	11,512	35	1,249	24,401	(13,022)	(110)	(1,041)	2,753
Period Start at Mar. 31, 2021	14,473	11,702	35	1,249	24,384	(12,825)	(100)	(1,041)	2,771
Net income (loss)	322	304	0	0	0	304	0	0	18
Other comprehensive income (loss)	(10)	(10)	0	0	0	0	(10)	0	0
Cash dividends – common stock	(498)	(498)	0	0	0	(498)	0	0	0
Dividends and distributions to noncontrolling interests	(41)	0	0	0	0	0	0	0	(41)
Stock-based compensation and related common stock issuances, net of tax	20	20	0	0	20	0	0	0	0
Contributions from noncontrolling interests	4	0	0	0	0	0	0	0	4
Other	(5)	(6)	0	0	(3)	(3)	0	0	1
Net increase (decrease) in equity	(208)	(190)	0	0	17	(197)	(10)	0	(18)
Period End at Jun. 30, 2021	$ 14,265	$ 11,512	$ 35	$ 1,249	$ 24,401	$ (13,022)	$ (110)	$ (1,041)	$ 2,753

Amount after tax and reclassification adjustments of other comprehensive income (loss).

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Variable Interest Entity Disclosures [Abstract]

Consolidated Statement of Changes in Equity (Parenthetical) (Unaudited) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Common Stock, Dividends, Per Share, Declared	$ 0.41	$ 0.40	$ 0.82	$ 0.80

Consolidated Statement of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020
OPERATING ACTIVITIES:
Net income (loss)	$ 757	$ (255)
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation and amortization	901	859
Provision (benefit) for deferred income taxes	262	(59)
Equity (earnings) losses	(266)	(130)
Distributions from unconsolidated affiliates	345	323
Impairment of goodwill (Note 10)	0	187
Impairment of equity-method investments (Note 10)	0	938
Amortization of stock-based awards	39	24
Cash provided (used) by changes in current assets and liabilities:
Accounts receivable	(50)	85
Inventories	(58)	(9)
Other current assets and deferred charges	(56)	(13)
Accounts payable	94	236
Accrued liabilities	14	(236)
Other, including changes in noncurrent assets and liabilities	(10)	(20)
Net cash provided (used) by operating activities	1,972	1,930
FINANCING ACTIVITIES:
Proceeds from long-term debt	898	3,896
Payments of long-term debt	(11)	(3,226)
Proceeds from issuance of common stock	3	6
Common dividends paid	(996)	(971)
Dividends and distributions paid to noncontrolling interests	(95)	(98)
Contributions from noncontrolling interests	6	4
Payments for debt issuance costs	(6)	(17)
Other – net	(12)	(10)
Net cash provided (used) by financing activities	(213)	(416)
INVESTING ACTIVITIES:
Capital expenditures (1)	(685)	(613)
Dispositions – net	(5)	(16)
Contributions in aid of construction	36	19
Proceeds from dispositions of equity-method investments	1	0
Purchases of and contributions to equity-method investments	(44)	(66)
Other – net	(3)	6
Net cash provided (used) by investing activities	(700)	(670)
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total	1,059	844
Cash and cash equivalents at beginning of year	142	289
Cash and cash equivalents at end of period	1,201	1,133
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
(1) Increases to property, plant, and equipment	(693)	(581)
Changes in related accounts payable and accrued liabilities	8	(32)
Capital expenditures	$ (685)	$ (613)

General, Description of Business, and Basis of Presentation	6 Months Ended
	Jun. 30, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General, Description of Business, and Basis of Presentation [Text Block]	Note 1 – General, Description of Business, and Basis of Presentation General Our accompanying interim consolidated financial statements do not include all the notes in our annual financial statements and, therefore, should be read in conjunction with the consolidated financial statements and notes thereto for the year ended December 31, 2020, in our Annual Report on Form 10-K. The accompanying unaudited financial statements include all normal recurring adjustments and others that, in the opinion of management, are necessary to present fairly our interim financial statements. The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates. Unless the context clearly indicates otherwise, references in this report to “Williams,” “we,” “our,” “us,” or like terms refer to The Williams Companies, Inc. and its subsidiaries. Unless the context clearly indicates otherwise, references to “Williams,” “we,” “our,” and “us” include the operations in which we own interests accounted for as equity-method investments that are not consolidated in our financial statements. When we refer to our equity investees by name, we are referring exclusively to their businesses and operations. Description of Business We are a Delaware corporation whose common stock is listed and traded on the New York Stock Exchange. Our operations are located in the United States and are presented within the following reportable segments: Transmission & Gulf of Mexico, Northeast G&P, and West, consistent with the manner in which our chief operating decision maker evaluates performance and allocates resources. All remaining business activities, including our recently acquired upstream operations, as well as corporate activities are included in Other. Transmission & Gulf of Mexico is comprised of our interstate natural gas pipelines, Transcontinental Gas Pipe Line Company, LLC (Transco) and Northwest Pipeline LLC (Northwest Pipeline), as well as natural gas gathering and processing and crude oil production handling and transportation assets in the Gulf Coast region, including a 51 percent interest in Gulfstar One LLC (Gulfstar One) (a consolidated variable interest entity, or VIE), which is a proprietary floating production system, a 50 percent equity-method investment in Gulfstream Natural Gas System, L.L.C., and a 60 percent equity-method investment in Discovery Producer Services LLC (Discovery). Northeast G&P is comprised of our midstream gathering, processing, and fractionation businesses in the Marcellus Shale region primarily in Pennsylvania and New York, and the Utica Shale region of eastern Ohio, as well as a 65 percent interest in Ohio Valley Midstream LLC (Northeast JV) (a consolidated VIE) which operates in West Virginia, Ohio, and Pennsylvania, a 66 percent interest in Cardinal Gas Services, L.L.C. (Cardinal) (a consolidated VIE) which operates in Ohio, a 69 percent equity-method investment in Laurel Mountain Midstream, LLC (Laurel Mountain), a 50 percent equity-method investment in Blue Racer Midstream LLC (Blue Racer) (we previously effectively owned a 29 percent indirect interest in Blue Racer through our 58 percent equity-method investment in Caiman Energy II, LLC (Caiman II) until acquiring a controlling interest of Caiman II in November 2020), and Appalachia Midstream Services, LLC, a wholly owned subsidiary that owns equity-method investments with an approximate average 66 percent interest in multiple gas gathering systems in the Marcellus Shale region (Appalachia Midstream Investments). West is comprised of our gas gathering, processing, and treating operations in the Rocky Mountain region of Colorado and Wyoming, the Barnett Shale region of north-central Texas, the Eagle Ford Shale region of south Texas, the Haynesville Shale region of northwest Louisiana, and the Mid-Continent region which includes the Anadarko and Permian basins. This segment also includes our natural gas liquid (NGL) and natural gas marketing business, storage facilities, an undivided 50 percent interest in an NGL fractionator near Conway, Kansas, a 50 percent equity-method investment in Overland Pass Pipeline Company LLC, a 50 percent equity-method investment in Rocky Mountain Midstream Holdings LLC (RMM), a 20 percent equity-method investment in Targa Train 7 LLC (Targa Train 7) (a nonconsolidated VIE), and a 15 percent interest in Brazos Permian II, LLC (Brazos Permian II) (a nonconsolidated VIE). Basis of Presentation Significant risks and uncertainties We believe that the carrying value of certain of our property, plant, and equipment and other identifiable intangible assets, notably certain acquired assets accounted for as business combinations between 2012 and 2014, may be in excess of current fair value. However, the carrying value of these assets, in our judgment, continues to be recoverable. It is reasonably possible that future strategic decisions, including transactions such as monetizing non-core assets or contributing assets to new ventures with third parties, as well as unfavorable changes in expected producer activities, could impact our assumptions and ultimately result in impairments of these assets. Such transactions or developments may also indicate that certain of our equity-method investments have experienced other-than-temporary declines in value, which could result in impairment.

Variable Interest Entities

6 Months Ended

Jun. 30, 2021

Variable Interest Entities [Text Block]

Note 2 – Variable Interest Entities

Consolidated VIEs

As of June 30, 2021, we consolidate the following VIEs:

Northeast JV

We own a 65 percent interest in the Northeast JV, a subsidiary that is a VIE due to certain of our voting rights being disproportionate to our obligation to absorb losses and substantially all of the Northeast JV’s activities being performed on our behalf. We are the primary beneficiary because we have the power to direct the activities that most significantly impact the Northeast JV’s economic performance. The Northeast JV provides midstream services for producers in the Marcellus Shale and Utica Shale regions. Future expansion activity is expected to be funded with capital contributions from us and the other equity partner on a proportional basis.

Gulfstar One

We own a 51 percent interest in Gulfstar One, a subsidiary that, due to certain risk-sharing provisions in its customer contracts, is a VIE. Gulfstar One includes a proprietary floating production system, Gulfstar FPS, and associated pipelines that provide production handling and gathering services in the eastern deepwater Gulf of Mexico. We are the primary beneficiary because we have the power to direct the activities that most significantly impact Gulfstar One’s economic performance.

Cardinal

We own a 66 percent interest in Cardinal, a subsidiary that provides gathering services for the Utica Shale region and is a VIE due to certain risks shared with customers. We are the primary beneficiary because we have the power to direct the activities that most significantly impact Cardinal’s economic performance. Future expansion activity is expected to be funded with capital contributions from us and the other equity partner on a proportional basis.

The following table presents amounts included in the Consolidated Balance Sheet that are only for the use or obligation of our consolidated VIEs:


	June 30, 2021		December 31, 2020
	(Millions)
Assets (liabilities):
Cash and cash equivalents	$	81	$	107
Trade accounts and other receivables – net	151		148


Other current assets and deferred charges	9		7

Property, plant, and equipment – net	5,406		5,514
Intangible assets – net of accumulated amortization	2,322		2,376
Regulatory assets, deferred charges, and other	15		15
Accounts payable	(55)		(42)

Accrued liabilities	(39)		(34)




Regulatory liabilities, deferred income, and other	(286)		(289)

Nonconsolidated VIEs

Targa Train 7

We own a 20 percent interest in Targa Train 7, which provides fractionation services at Mt. Belvieu and is a VIE due primarily to our limited participating rights as the minority equity holder. At June 30, 2021, the carrying value of our investment in Targa Train 7 was $49 million. Our maximum exposure to loss is limited to the carrying value of our investment.

Brazos Permian II

We own a 15 percent interest in Brazos Permian II, which provides gathering and processing services in the Delaware basin and is a VIE due primarily to our limited participating rights as the minority equity holder. During the first quarter of 2020 we recorded an impairment of our equity-method investment in Brazos Permian II. Our maximum exposure to loss is limited to the carrying value of our investment.

Revenue Recognition

6 Months Ended

Jun. 30, 2021

Revenue Recognition [Abstract]

Revenue Recognition [Text Block]

Note 3 – Revenue Recognition

Revenue by Category

The following table presents our revenue disaggregated by major service line:


	Transco		Northwest Pipeline		Gulf of Mexico Midstream		Northeast Midstream		West Midstream		Other		Eliminations		Total
	(Millions)
Three Months Ended June 30, 2021
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	613	$	108	$	—	$	—	$	—	$	—	$	(2)	$	719
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	—		—		90		315		278		—		(26)		657
Commodity consideration	—		—		10		2		39		—		—		51
Other	2		—		7		52		10		—		(4)		67
Total service revenues	615		108		107		369		327		—		(32)		1,494
Product sales	16		—		53		24		726		44		(87)		776
Total revenues from contracts with customers	631		108		160		393		1,053		44		(119)		2,270
Other revenues (1)	—		—		3		6		(1)		8		(3)		13
Total revenues	$	631	$	108	$	163	$	399	$	1,052	$	52	$	(122)	$	2,283

Three Months Ended June 30, 2020
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	592	$	110	$	—	$	—	$	—	$	—	$	(1)	$	701
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	—		—		78		308		297		—		(19)		664
Commodity consideration	—		—		3		1		21		—		—		25
Other	2		—		10		41		17		—		(4)		66
Total service revenues	594		110		91		350		335		—		(24)		1,456
Product sales	20		—		17		1		303		—		(31)		310
Total revenues from contracts with customers	614		110		108		351		638		—		(55)		1,766
Other revenues (1)	2		—		1		5		2		9		(4)		15
Total revenues	$	616	$	110	$	109	$	356	$	640	$	9	$	(59)	$	1,781


	Transco		Northwest Pipeline		Gulf of Mexico Midstream		Northeast Midstream		West Midstream		Other		Eliminations		Total
	(Millions)
Six Months Ended June 30, 2021
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	1,238	$	221	$	—	$	—	$	—	$	—	$	(5)	$	1,454
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	—		—		176		626		540		—		(47)		1,295
Commodity consideration	—		—		21		5		74		—		—		100
Other	5		—		10		93		29		—		(8)		129
Total service revenues	1,243		221		207		724		643		—		(60)		2,978
Product sales	30		—		106		56		1,806		100		(177)		1,921
Total revenues from contracts with customers	1,273		221		313		780		2,449		100		(237)		4,899
Other revenues (1)	2		—		5		12		(32)		15		(6)		(4)
Total revenues	$	1,275	$	221	$	318	$	792	$	2,417	$	115	$	(243)	$	4,895

Six Months Ended June 30, 2020
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	1,196	$	225	$	—	$	—	$	—	$	—	$	(3)	$	1,418
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	—		—		177		620		596		—		(41)		1,352
Commodity consideration	—		—		8		3		42		—		—		53
Other	5		—		16		82		26		—		(9)		120
Total service revenues	1,201		225		201		705		664		—		(53)		2,943
Product sales	40		—		49		30		662		—		(60)		721
Total revenues from contracts with customers	1,241		225		250		735		1,326		—		(113)		3,664
Other revenues (1)	2		—		3		10		5		17		(7)		30
Total revenues	$	1,243	$	225	$	253	$	745	$	1,331	$	17	$	(120)	$	3,694

______________________________

(1)Revenues not derived from contracts with customers consist of leasing revenues associated with our headquarters building and management fees that we receive for certain services we provide to operated equity-method investments, which are reported in Service revenues in the Consolidated Statement of Operations, and amounts associated with our derivative contracts, which are reported in Product sales in the Consolidated Statement of Operations.

Contract Assets

The following table presents a reconciliation of our contract assets:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Balance at beginning of period	$	25	$	18	$	12	$	8
Revenue recognized in excess of amounts invoiced	38		46		83		69
Minimum volume commitments invoiced	(25)		(34)		(57)		(47)
Balance at end of period	$	38	$	30	$	38	$	30

Contract Liabilities

The following table presents a reconciliation of our contract liabilities:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Balance at beginning of period	$	1,171	$	1,189	$	1,209	$	1,215
Payments received and deferred	72		74		85		102
Significant financing component	2		2		5		5
Recognized in revenue	(52)		(62)		(106)		(119)
Balance at end of period	$	1,193	$	1,203	$	1,193	$	1,203

Remaining Performance Obligations

Remaining performance obligations primarily include reservation charges on contracted capacity for our gas pipeline firm transportation contracts with customers, storage capacity contracts, long-term contracts containing minimum volume commitments associated with our midstream businesses, and fixed payments associated with offshore production handling. For our interstate natural gas pipeline businesses, remaining performance obligations reflect the rates for such services in our current Federal Energy Regulatory Commission (FERC) tariffs for the life of the related contracts; however, these rates may change based on future tariffs approved by the FERC and the amount and timing of these changes are not currently known.

Our remaining performance obligations exclude variable consideration, including contracts with variable consideration for which we have elected the practical expedient for consideration recognized in revenue as billed. Certain of our contracts contain evergreen and other renewal provisions for periods beyond the initial term of the contract. The remaining performance obligation amounts as of June 30, 2021, do not consider potential future performance obligations for which the renewal has not been exercised and exclude contracts with customers for which the underlying facilities have not received FERC authorization to be placed into service. Consideration received prior to June 30, 2021, that will be recognized in future periods is also excluded from our remaining performance obligations and is instead reflected in contract liabilities.

The following table presents the amount of the contract liabilities balance expected to be recognized as revenue when performance obligations are satisfied and the transaction price allocated to the remaining performance obligations under certain contracts as of June 30, 2021.


	Contract Liabilities		Remaining Performance Obligations
	(Millions)
2021 (six months)	$	83	$	1,724
2022 (one year)	130		3,409
2023 (one year)	111		3,137
2024 (one year)	106		2,723
2025 (one year)	101		2,330

Thereafter	662		18,055
Total	$	1,193	$	31,378

Accounts Receivable

The following is a summary of our Trade accounts and other receivables – net:


	June 30, 2021		December 31, 2020
	(Millions)
Accounts receivable related to revenues from contracts with customers	$	928	$	892
Other accounts receivable	71		107
Trade accounts and other receivables – net	$	999	$	999

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.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
-Topic 606
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Provision (Benefit) for Income Taxes [Text Block]

Investing Activities	6 Months Ended
Investing Activities	Jun. 30, 2021
Investments [Abstract]
Investing Activities [Text Block]	Note 4 – Investing Activities Equity Earnings (Losses) Equity earnings (losses) for the six months ended June 30, 2020, includes a $78 million loss associated with the first-quarter 2020 full impairment of goodwill recognized by our investee RMM, which was allocated entirely to our member interest per the terms of the membership agreement. Impairment of Equity-Method Investments Impairment of equity-method investments for the six months ended June 30, 2020, includes $938 million associated with the first-quarter 2020 impairment of certain equity-method investments (see Note 10 – Fair Value Measurements and Guarantees).

Provision (Benefit) for Income Taxes

6 Months Ended

Jun. 30, 2021

Income Tax Disclosure [Abstract]

Note 5 – Provision (Benefit) for Income Taxes

The Provision (benefit) for income taxes includes:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Current:
Federal	$	—	$	—	$	(2)	$	(28)
State	1		(1)		—		—
	1		(1)		(2)		(28)
Deferred:
Federal	85		93		200		(41)
State	33		25		62		(18)

	118		118		262		(59)
Provision (benefit) for income taxes	$	119	$	117	$	260	$	(87)

The effective income tax rates for the total provision (benefit) for both the three and six months ended June 30, 2021 and 2020 are greater than the federal statutory rate, primarily due to the effect of state income taxes.

During the next 12 months, we do not expect ultimate resolution of any unrecognized tax benefit associated with domestic or international matters to have a material impact on our unrecognized tax benefit position.

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.

Earnings (Loss) Per Common Share [Text Block]

Earnings (Loss) Per Common Share

6 Months Ended

Jun. 30, 2021

Earnings Per Share [Abstract]

Note 6 – Earnings (Loss) Per Common Share


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Dollars in millions, except per-share amounts; shares in thousands)
Net income (loss) available to common stockholders	$	304	$	303	$	729	$	(215)
Basic weighted-average shares	1,215,250		1,213,601		1,214,950		1,213,310
Effect of dilutive securities:
Nonvested restricted stock units	2,208		980		2,385		—
Stock options	18		—		9		—
Diluted weighted-average shares (1)	1,217,476		1,214,581		1,217,344		1,213,310
Earnings (loss) per common share:
Basic	$	.25	$	.25	$	.60	$	(.18)
Diluted	$	.25	$	.25	$	.60	$	(.18)

______________________________

(1)For the six months ended June 30, 2020, 1.1 million weighted-average nonvested restricted stock units have been excluded from the computation of diluted earnings (loss) per common share as their inclusion would be antidilutive due to our loss available to common stockholders.

Employee Benefit Plans

6 Months Ended

Jun. 30, 2021

Retirement Benefits [Abstract]

Employee Benefit Plans [Text Block]

Note 7 – Employee Benefit Plans

Net periodic benefit cost (credit) is as follows:


	Pension Benefits
	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Components of net periodic benefit cost (credit):
Service cost	$	7	$	7	$	15	$	15
Interest cost	7		9		14		19
Expected return on plan assets	(11)		(14)		(22)		(27)

Amortization of net actuarial loss	3		7		7		11
Net actuarial loss from settlements	1		2		1		8
Net periodic benefit cost (credit)	$	7	$	11	$	15	$	26


	Other Postretirement Benefits
	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Components of net periodic benefit cost (credit):

Interest cost	$	2	$	1	$	3	$	3
Expected return on plan assets	(3)		(2)		(5)		(5)


Reclassification to regulatory liability	—		—		1		1
Net periodic benefit cost (credit)	$	(1)	$	(1)	$	(1)	$	(1)

The components of Net periodic benefit cost (credit) other than the Service cost component are included in Other income (expense) – net below Operating income (loss) in the Consolidated Statement of Operations.

During the six months ended June 30, 2021, we contributed $3 million to our pension plans and $3 million to our other postretirement benefit plans. We presently anticipate making additional contributions of approximately $1 million to our pension plans and approximately $2 million to our other postretirement benefit plans in the remainder of 2021.

The entire disclosure for retirement benefits.

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Debt and Banking Arrangements [Text Block]

Debt and Banking Arrangements

6 Months Ended

Jun. 30, 2021

Debt Disclosure [Abstract]

Note 8 – Debt and Banking Arrangements

Long-Term Debt

Issuances and retirements

On March 2, 2021, we completed a public offering of $900 million of 2.6 percent senior unsecured notes due 2031.

Commercial Paper Program

At June 30, 2021, no Commercial paper was outstanding under our $4 billion commercial paper program.

Credit Facilities


	June 30, 2021
	Stated Capacity		Outstanding
	(Millions)

Long-term credit facility (1)	$	4,500	$	—
Letters of credit under certain bilateral bank agreements			17

(1)In managing our available liquidity, we do not expect a maximum outstanding amount in excess of the capacity of our credit facility inclusive of any outstanding amounts under our commercial paper program.

Stockholders' Equity

6 Months Ended

Jun. 30, 2021

Stockholders' Equity Note [Abstract]

Stockholders' Equity [Text Block]

Note 9 – Stockholders’ Equity

Stockholder Rights Agreement

As disclosed in our Annual Report on Form 10-K filed February 24, 2021, a purported shareholder filed a putative class action lawsuit in the Delaware Court of Chancery challenging our stockholder rights agreement (Rights Agreement). On February 26, 2021, the Delaware Court of Chancery issued a decision which declared the Rights Agreement unenforceable and permanently enjoined the continued operation of the Rights Agreement, which otherwise would have expired on March 20, 2021.

AOCI

The following table presents the changes in AOCI by component, net of income taxes:


	Cash Flow Hedges		Foreign Currency Translation		Pension and Other Postretirement Benefits		Total
	(Millions)
Balance at December 31, 2020	$	(3)	$	(1)	$	(92)	$	(96)

Other comprehensive income (loss) before reclassifications	(26)		—		—		(26)
Amounts reclassified from accumulated other comprehensive income (loss)	6		—		6		12
Other comprehensive income (loss)	(20)		—		6		(14)

Balance at June 30, 2021	$	(23)	$	(1)	$	(86)	$	(110)

Reclassifications out of AOCI are presented in the following table by component for the six months ended June 30, 2021:

Component

Reclassifications

Classification

(Millions)

Cash flow hedges:

Energy commodity contracts

Product sales

Pension and other postretirement benefits:

Amortization of actuarial (gain) loss and net actuarial loss from settlements included in net periodic benefit cost (credit)

Other income (expense) – net below Operating income (loss)

Income tax benefit

(4)

Provision (benefit) for income taxes

Reclassifications during the period

Fair Value Measurements and Guarantees

6 Months Ended

Jun. 30, 2021

Fair Value Disclosures [Abstract]

Fair Value Measurements and Guarantees [Text Block]

Note 10 – Fair Value Measurements and Guarantees

The following table presents, by level within the fair value hierarchy, certain of our significant financial assets and liabilities. The carrying values of cash and cash equivalents, accounts receivable, margin deposits, and accounts payable approximate fair value because of the short-term nature of these instruments. Therefore, these assets and liabilities are not presented in the following table.


					Fair Value Measurements Using
	Carrying Amount		Fair Value		Quoted Prices In Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	(Millions)
Assets (liabilities) at June 30, 2021:
Measured on a recurring basis:
ARO Trust investments	$	257	$	257	$	257	$	—	$	—




Additional disclosures:

Long-term debt, including current portion	(23,234)		(27,643)		—		(27,643)		—
Guarantees	(40)		(26)		—		(10)		(16)

Assets (liabilities) at December 31, 2020:
Measured on a recurring basis:
ARO Trust investments	$	235	$	235	$	235	$	—	$	—



Additional disclosures:
Long-term debt, including current portion	(22,344)		(27,043)		—		(27,043)		—
Guarantees	(40)		(27)		—		(11)		(16)

Fair Value Methods

We use the following methods and assumptions in estimating the fair value of our financial instruments:

Assets measured at fair value on a recurring basis

ARO Trust investments: Transco deposits a portion of its collected rates, pursuant to its rate case settlement, into an external trust (ARO Trust) that is specifically designated to fund future asset retirement obligations (ARO). The ARO Trust invests in a portfolio of actively traded mutual funds that are measured at fair value on a recurring basis based on quoted prices in an active market and is reported in Regulatory assets, deferred charges, and other in the Consolidated Balance Sheet. Both realized and unrealized gains and losses are ultimately recorded as regulatory assets or liabilities.

Additional fair value disclosures

Long-term debt, including current portion: The disclosed fair value of our long-term debt is determined primarily by a market approach using broker quoted indicative period-end bond prices. The quoted prices are based on observable transactions in less active markets for our debt or similar instruments. The fair values of the financing obligations associated with our Dalton lateral and Atlantic Sunrise projects, which are included within long-term debt, were determined using an income approach.

Guarantees: Guarantees primarily consist of a guarantee we have provided in the event of nonpayment by our previously owned communications subsidiary, Williams Communications Group (WilTel), on a lease performance obligation that extends through 2042. Guarantees also include an indemnification related to a disposed operation.

To estimate the fair value of the WilTel guarantee, an estimated default rate is applied to the sum of the future contractual lease payments using an income approach. The estimated default rate is determined by obtaining the average cumulative issuer-weighted corporate default rate based on the credit rating of WilTel’s current owner and the term of the underlying obligation. The default rate is published by Moody’s Investors Service. The carrying value of the WilTel guarantee is reported in Accrued liabilities in the Consolidated Balance Sheet. The maximum potential undiscounted exposure is approximately $26 million at June 30, 2021. Our exposure declines systematically through the remaining term of WilTel’s obligation.

The fair value of the guarantee associated with the indemnification related to a disposed operation was estimated using an income approach that considered probability-weighted scenarios of potential levels of future performance. The terms of the indemnification do not limit the maximum potential future payments associated with the guarantee. The carrying value of this guarantee is reported in Regulatory liabilities, deferred income, and other in the Consolidated Balance Sheet.

We are required by our revolving credit agreement to indemnify lenders for certain taxes required to be withheld from payments due to the lenders and for certain tax payments made by the lenders. The maximum potential amount of future payments under these indemnifications is based on the related borrowings and such future payments cannot currently be determined. These indemnifications generally continue indefinitely unless limited by the underlying tax regulations and have no carrying value. We have never been called upon to perform under these indemnifications and have no current expectation of a future claim.

Nonrecurring fair value measurements

During the first quarter of 2020, we observed a significant decline in the publicly traded price of our common stock (NYSE: WMB), which declined 40 percent during the quarter, including a 26 percent decline in the month of March. These changes were generally attributed to macroeconomic and geopolitical conditions, including significant declines in crude oil prices driven by both surplus supply and a decrease in demand caused by the coronavirus (COVID-19) pandemic. As a result of these conditions, we performed an interim assessment of the goodwill associated with our Northeast G&P reporting unit as of March 31, 2020.

The assessment considered the total fair value of the businesses within the Northeast G&P reporting unit, which was determined using income and market approaches. We utilized internally developed industry weighted-average discount rates and estimates of valuation multiples of comparable publicly traded gathering and processing companies. In assessing the fair value as of the March 31, 2020 measurement date, we were required to consider recent publicly available indications of value, which included lower observed publicly traded EBITDA (earnings before interest, taxes, depreciation, and amortization) market multiples as compared with recent history and significantly higher industry weighted-average discount rates. The fair value of the reporting unit was further reconciled to our estimated total enterprise value as of March 31, 2020, which considered observable valuation multiples of comparable publicly traded companies applied to each distinct business including the Northeast G&P reporting unit. This assessment indicated that the estimated fair value of the Northeast G&P reporting unit was below its carrying value, including goodwill. As a result of this Level 3 measurement, we recognized a full impairment charge of $187 million as of March 31, 2020, in Impairment of goodwill in the Consolidated Statement of Operations. Our partner’s $65 million share of this impairment is reflected within Net income (loss) attributable to noncontrolling interests in the Consolidated Statement of Operations.

The following table presents impairments of equity-method investments associated with certain nonrecurring fair value measurements within Level 3 of the fair value hierarchy.


					Impairments
					Six Months Ended June 30,
	Segment	Date of Measurement	Fair Value		2021		2020
			(Millions)





Impairment of equity-method investments:
RMM (1)	West	March 31, 2020	$	557			$	243
Brazos Permian II (1)	West	March 31, 2020	—				193
Caiman II (2)	Northeast G&P	March 31, 2020	191				229
Appalachia Midstream Investments (2)	Northeast G&P	March 31, 2020	2,700				127
Aux Sable (2)	Northeast G&P	March 31, 2020	7				39
Laurel Mountain (2)	Northeast G&P	March 31, 2020	236				10
Discovery (2)	Transmission & Gulf of Mexico	March 31, 2020	367				97





Impairment of equity-method investments					$	—	$	938

_______________

(1)Following the previously described declining market conditions during the first quarter of 2020, we evaluated these investments for other-than-temporary impairment. The fair value was measured using an income approach. Both investees operate in primarily oil-driven basins where significant expected reductions in producer activities led to reduced estimates of expected future cash flows. Our fair value estimates also reflected discount rates of approximately 17 percent for these investments. We also considered any debt held at the investee level, and its impact to fair value. The industry weighted-average discount rates utilized were significantly influenced by the market declines previously discussed.

(2)Following the previously described declining market conditions during the first quarter of 2020, we evaluated these investments for other-than-temporary impairment. The impairments within our Northeast G&P segment are primarily associated with operations in wet-gas areas where producer drilling activities are influenced by NGL prices which historically trend with crude oil prices. The fair values of our investments in Caiman II and Aux Sable Liquid Products LP (Aux Sable) were estimated using a market approach, reflecting valuation multiples ranging from 5.0x to 6.2x EBITDA (weighted-average 6.0x). The fair values of the other investments, including gathering systems that are part of Appalachia Midstream Investments, were estimated using an income approach, with discount rates ranging from 9.7 percent to 13.5 percent (weighted-average 12.6 percent). We also considered any debt held at the investee level, and its impact to fair value. The assumed valuation multiples and industry weighted-average discount rates utilized were both significantly influenced by the market declines previously discussed.

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.

Segment Disclosures [Text Block]

Contingent Liabilities	6 Months Ended
Contingent Liabilities	Jun. 30, 2021
Commitments and Contingencies Disclosure [Abstract]
Contingent Liabilities [Text Block]	Note 11 – Contingent Liabilities Reporting of Natural Gas-Related Information to Trade Publications Direct and indirect purchasers of natural gas in various states filed individual and class actions against us, our former affiliate WPX Energy, Inc. (WPX) and its subsidiaries, and others alleging the manipulation of published gas price indices and seeking unspecified amounts of damages. Such actions were transferred to the Nevada federal district court for consolidation of discovery and pre-trial issues. We have agreed to indemnify WPX and its subsidiaries related to this matter. In the individual action, filed by Farmland Industries Inc. (Farmland), the court issued an order on May 24, 2016, granting one of our co-defendant’s motion for summary judgment as to Farmland’s claims. On January 5, 2017, the court extended such ruling to us, entering final judgment in our favor. Farmland appealed. On March 27, 2018, the appellate court reversed the district court’s grant of summary judgment, and on April 10, 2018, the defendants filed a petition for rehearing with the appellate court, which was denied on May 9, 2018. The case was remanded to the Nevada federal district court and subsequently remanded to its originally filed court, the Kansas federal district court where we re-urged our motion for summary judgment. The district court denied the motion but granted our request to seek permission for an immediate appeal to the appellate court. Oral argument occurred before the appellate court on January 19, 2021. On June 22, 2021, the appellate court ruled that we are not entitled to summary judgment and remanded the case to the Kansas federal district court. The court has scheduled trial to begin May 9, 2022. In the putative class actions, on March 30, 2017, the court issued an order denying the plaintiffs’ motions for class certification. On June 13, 2017, the United States Court of Appeals for the Ninth Circuit granted the plaintiffs’ petition for permission to appeal the order. On August 6, 2018, the Ninth Circuit reversed the order denying class certification and remanded the case to the Nevada federal district court. We reached an agreement to settle two of the actions, and on April 22, 2019, the Nevada federal district court preliminarily approved the settlements, which are on behalf of Kansas and Missouri class members. The final fairness hearing on the settlement occurred August 5, 2019, and a final judgment of dismissal with prejudice was entered the same day. Two putative class actions remain unresolved, and they have been remanded to their originally filed court, the Wisconsin federal district court. Trial was scheduled to begin June 14, 2021, but the court struck the setting and has not reset it. Because of the uncertainty around the remaining unresolved issues, we cannot reasonably estimate a range of potential exposure at this time. However, it is reasonably possible that the ultimate resolution of these actions and our related indemnification obligation could result in a potential loss that may be material to our results of operations. In connection with this indemnification, we have an accrued liability balance associated with this matter and have exposure to future developments. Alaska Refinery Contamination Litigation We are involved in litigation arising from our ownership and operation of the North Pole Refinery in North Pole, Alaska, from 1980 until 2004, through our wholly owned subsidiaries Williams Alaska Petroleum Inc. (WAPI) and MAPCO Inc. We sold the refinery to Flint Hills Resources Alaska, LLC (FHRA), a subsidiary of Koch Industries, Inc., in 2004. The litigation involves three cases, with filing dates ranging from 2010 to 2014. The actions primarily arise from sulfolane contamination allegedly emanating from the refinery. A putative class action lawsuit was filed by James West in 2010 naming us, WAPI, and FHRA as defendants. We and FHRA filed claims against each other seeking, among other things, contractual indemnification alleging that the other party caused the sulfolane contamination. In 2011, we and FHRA settled the claim with James West. Certain claims by FHRA against us were resolved by the Alaska Supreme Court in our favor. FHRA’s claims against us for contractual indemnification and statutory claims for damages related to off-site sulfolane were remanded to the Alaska Superior Court. The State of Alaska filed its action in March 2014, seeking damages. The City of North Pole (North Pole) filed its lawsuit in November 2014, seeking past and future damages, as well as punitive damages. Both we and WAPI asserted counterclaims against the State of Alaska and North Pole, and cross-claims against FHRA. FHRA has also filed cross-claims against us. The underlying factual basis and claims in the cases are similar and may duplicate exposure. As such, in February 2017, the three cases were consolidated into one action in state court containing the remaining claims from the James West case and those of the State of Alaska and North Pole. The State of Alaska later announced the discovery of additional contaminants per- and polyfluoralkyl (PFOS and PFOA) offsite of the refinery, and the court permitted the State of Alaska to amend its complaint to add a claim for offsite PFOS/PFOA contamination. The court subsequently remanded the offsite PFOS/PFOA claims to the Alaska Department of Environmental Conservation for investigation and stayed the claims pending their potential resolution at the administrative agency. Several trial dates encompassing all three cases have been scheduled and stricken. In the summer of 2019, the court deconsolidated the cases for purposes of trial. A bench trial on all claims except North Pole’s claims began in October 2019. In January 2020, the Alaska Superior Court issued its Memorandum of Decision finding in favor of the State of Alaska and FHRA, with the total incurred and potential future damages estimated to be $86 million. The court found that FHRA is not entitled to contractual indemnification from us because FHRA contributed to the sulfolane contamination. On March 23, 2020, the court entered final judgment in the case. Filing deadlines were stayed until May 1, 2020. However, on April 21, 2020, we filed a Notice of Appeal. We also filed post-judgment motions including a Motion for New Trial and a Motion to Alter or Amend the Judgment. These post-trial motions were resolved with the court’s denial of the last motion on June 11, 2020. Our Statement of Points on Appeal was filed on July 13, 2020. On June 22, 2020, the court stayed the North Pole’s case pending resolution of the appeal in the State of Alaska and FHRA case. On December 23, 2020, we filed our opening brief on appeal. We have recorded an accrued liability in the amount of our estimate of the probable loss. It is reasonably possible that we may not be successful on appeal and could ultimately pay up to the amount of judgment. Royalty Matters Certain of our customers, including Chesapeake Energy Corporation (Chesapeake), have been named in various lawsuits alleging underpayment of royalties and claiming, among other things, violations of anti-trust laws and the Racketeer Influenced and Corrupt Organizations Act. We have also been named as a defendant in certain of these cases filed in Pennsylvania based on allegations that we improperly participated with Chesapeake in causing the alleged royalty underpayments. We believe that the claims asserted are subject to indemnity obligations owed to us by Chesapeake. Chesapeake has reached a settlement to resolve substantially all Pennsylvania royalty cases pending, which settlement applies to both Chesapeake and us. The settlement does not require any contribution from us and is awaiting court approval. Litigation Against Energy Transfer and Related Parties On April 6, 2016, we filed suit in Delaware Chancery Court against Energy Transfer Equity, L.P. (Energy Transfer) and LE GP, LLC (the general partner for Energy Transfer) alleging willful and material breaches of the Agreement and Plan of Merger (ETE Merger Agreement) with Energy Transfer resulting from the private offering by Energy Transfer on March 8, 2016, of Series A Convertible Preferred Units (Special Offering) to certain Energy Transfer insiders and other accredited investors. The suit seeks, among other things, an injunction ordering the defendants to unwind the Special Offering and to specifically perform their obligations under the ETE Merger Agreement. On April 19, 2016, we filed an amended complaint seeking the same relief. On May 3, 2016, Energy Transfer and LE GP, LLC filed an answer and counterclaims. On May 13, 2016, we filed a separate complaint in Delaware Chancery Court against Energy Transfer, LE GP, LLC and the other Energy Transfer affiliates that are parties to the ETE Merger Agreement, alleging material breaches of the ETE Merger Agreement for failing to cooperate and use necessary efforts to obtain a tax opinion required under the ETE Merger Agreement (Tax Opinion) and for otherwise failing to use necessary efforts to consummate the merger under the ETE Merger Agreement wherein we would be merged with and into the newly formed Energy Transfer Corp LP (ETC) (ETC Merger). The suit sought, among other things, a declaratory judgment and injunction preventing Energy Transfer from terminating or otherwise avoiding its obligations under the ETE Merger Agreement due to any failure to obtain the Tax Opinion. The Court of Chancery coordinated the Special Offering and Tax Opinion suits. On May 20, 2016, the Energy Transfer defendants filed amended affirmative defenses and verified counterclaims in the Special Offering and Tax Opinion suits, alleging certain breaches of the ETE Merger Agreement by us and seeking, among other things, a declaration that we were not entitled to specific performance, that Energy Transfer could terminate the ETC Merger, and that Energy Transfer is entitled to a $1.48 billion termination fee. On June 24, 2016, following a two-day trial, the court issued a Memorandum Opinion and Order denying our requested relief in the Tax Opinion suit. The court did not rule on the substance of our claims related to the Special Offering or on the substance of Energy Transfer’s counterclaims. On June 27, 2016, we filed an appeal of the court’s decision with the Supreme Court of Delaware, seeking reversal and remand to pursue damages. On March 23, 2017, the Supreme Court of Delaware affirmed the Court of Chancery’s ruling. On March 30, 2017, we filed a motion for reargument with the Supreme Court of Delaware, which was denied on April 5, 2017. On September 16, 2016, we filed an amended complaint with the Court of Chancery seeking damages for breaches of the ETE Merger Agreement by defendants. On September 23, 2016, Energy Transfer filed a second amended and supplemental affirmative defenses and verified counterclaim with the Court of Chancery seeking, among other things, payment of the $1.48 billion termination fee due to our alleged breaches of the ETE Merger Agreement. On December 1, 2017, the court granted our motion to dismiss certain of Energy Transfer’s counterclaims, including its claim seeking payment of the $1.48 billion termination fee. On December 8, 2017, Energy Transfer filed a motion for reargument, which the Court of Chancery denied on April 16, 2018. The Court of Chancery originally scheduled trial for May 20 through May 24, 2019; the court struck that setting and reset trial to occur in 2020. All 2020 trial settings were struck due to COVID-19. Trial was held May 10 through May 17, 2021. Post-trial argument is scheduled for September 16, 2021. Environmental Matters We are a participant in certain environmental activities in various stages including assessment studies, cleanup operations, and/or remedial processes at certain sites, some of which we currently do not own. We are monitoring these sites in a coordinated effort with other potentially responsible parties, the U.S. Environmental Protection Agency (EPA), or other governmental authorities. We are jointly and severally liable along with unrelated third parties in some of these activities and solely responsible in others. Certain of our subsidiaries have been identified as potentially responsible parties at various Superfund and state waste disposal sites. In addition, these subsidiaries have incurred, or are alleged to have incurred, various other hazardous materials removal or remediation obligations under environmental laws. As of June 30, 2021, we have accrued liabilities totaling $31 million for these matters, as discussed below. Estimates of the most likely costs of cleanup are generally based on completed assessment studies, preliminary results of studies, or our experience with other similar cleanup operations. At June 30, 2021, certain assessment studies were still in process for which the ultimate outcome may yield different estimates of most likely costs. Therefore, the actual costs incurred will depend on the final amount, type, and extent of contamination discovered at these sites, the final cleanup standards mandated by the EPA or other governmental authorities, and other factors. The EPA and various state regulatory agencies routinely promulgate and propose new rules and issue updated guidance to existing rules. These rulemakings include, but are not limited to, rules for reciprocating internal combustion engine and combustion turbine maximum achievable control technology, air quality standards for one-hour nitrogen dioxide emissions, and volatile organic compound and methane new source performance standards impacting design and operation of storage vessels, pressure valves, and compressors. The EPA previously issued its rule regarding National Ambient Air Quality Standards for ground-level ozone. We are monitoring the rule’s implementation as it will trigger additional federal and state regulatory actions that may impact our operations. Implementation of the regulations is expected to result in impacts to our operations and increase the cost of additions to Property, plant, and equipment – net in the Consolidated Balance Sheet for both new and existing facilities in affected areas. We are unable to reasonably estimate the cost of additions that may be required to meet the regulations at this time due to uncertainty created by various legal challenges to these regulations and the need for further specific regulatory guidance. Continuing operations Our interstate gas pipelines are involved in remediation activities related to certain facilities and locations for polychlorinated biphenyls, mercury, and other hazardous substances. These activities have involved the EPA and various state environmental authorities, resulting in our identification as a potentially responsible party at various Superfund waste sites. At June 30, 2021, we have accrued liabilities of $4 million for these costs. We expect that these costs will be recoverable through rates. We also accrue environmental remediation costs for natural gas underground storage facilities, primarily related to soil and groundwater contamination. At June 30, 2021, we have accrued liabilities totaling $8 million for these costs. Former operations We have potential obligations in connection with assets and businesses we no longer operate. These potential obligations include remediation activities at the direction of federal and state environmental authorities and the indemnification of the purchasers of certain of these assets and businesses for environmental and other liabilities existing at the time the sale was consummated. Our responsibilities relate to the operations of the assets and businesses described below. •Former agricultural fertilizer and chemical operations and former retail petroleum and refining operations; •Former petroleum products and natural gas pipelines; •Former petroleum refining facilities; •Former exploration and production and mining operations; •Former electricity and natural gas marketing and trading operations. At June 30, 2021, we have accrued environmental liabilities of $19 million related to these matters. Other Divestiture Indemnifications Pursuant to various purchase and sale agreements relating to divested businesses and assets, we have indemnified certain purchasers against liabilities that they may incur with respect to the businesses and assets acquired from us. The indemnities provided to the purchasers are customary in sale transactions and are contingent upon the purchasers incurring liabilities that are not otherwise recoverable from third parties. The indemnities generally relate to breach of warranties, tax, historic litigation, personal injury, property damage, environmental matters, right of way, and other representations that we have provided. At June 30, 2021, other than as previously disclosed, we are not aware of any material claims against us involving the above-described indemnities; thus, we do not expect any of the indemnities provided pursuant to the sales agreements to have a material impact on our future financial position. Any claim for indemnity brought against us in the future may have a material adverse effect on our results of operations in the period in which the claim is made. In addition to the foregoing, various other proceedings are pending against us that are incidental to our operations, none of which are expected to be material to our expected future annual results of operations, liquidity, and financial position. Summary We have disclosed our estimated range of reasonably possible losses for certain matters above, as well as all significant matters for which we are unable to reasonably estimate a range of possible loss. We estimate that for all other matters for which we are able to reasonably estimate a range of loss, our aggregate reasonably possible losses beyond amounts accrued are immaterial to our expected future annual results of operations, liquidity, and financial position. These calculations have been made without consideration of any potential recovery from third parties.

Segment Disclosures

6 Months Ended

Jun. 30, 2021

Segment Reporting [Abstract]

Note 12 – Segment Disclosures

Our reportable segments are Transmission & Gulf of Mexico, Northeast G&P, and West. All remaining business activities are included in Other. (See Note 1 – General, Description of Business, and Basis of Presentation.)

Performance Measurement

We evaluate segment operating performance based upon Modified EBITDA. This measure represents the basis of our internal financial reporting and is the primary performance measure used by our chief operating decision maker in measuring performance and allocating resources among our reportable segments. Intersegment Service revenues primarily represent transportation services provided to our marketing business and gathering services provided to our oil and gas properties. Intersegment Product sales primarily represent the sale of NGLs from our natural gas processing plants and our oil and gas properties to our marketing business.

We define Modified EBITDA as follows:

•Net income (loss) before:

◦Provision (benefit) for income taxes;

◦Interest incurred, net of interest capitalized;

◦Equity earnings (losses);

◦Impairment of equity-method investments;

◦Other investing income (loss) – net;

◦Impairment of goodwill;

◦Depreciation and amortization expenses;

◦Accretion expense associated with asset retirement obligations for nonregulated operations.

•This measure is further adjusted to include our proportionate share (based on ownership interest) of Modified EBITDA from our equity-method investments calculated consistently with the definition described above.

The following table reflects the reconciliation of Segment revenues to Total revenues as reported in the Consolidated Statement of Operations and Total assets by reportable segment.


	Transmission & Gulf of Mexico		Northeast G&P		West		Other		Eliminations		Total
	(Millions)
Three Months Ended June 30, 2021
Segment revenues:
Service revenues
External	$	811	$	364	$	280	$	5	$	—	$	1,460
Internal	12		9		11		3		(35)		—
Total service revenues	823		373		291		8		(35)		1,460
Total service revenues – commodity consideration	10		2		39		—		—		51
Product sales
External	47		8		696		21		—		772
Internal	20		16		26		23		(85)		—
Total product sales	67		24		722		44		(85)		772
Total revenues	$	900	$	399	$	1,052	$	52	$	(120)	$	2,283

Three Months Ended June 30, 2020
Segment revenues:
Service revenues
External	$	783	$	342	$	316	$	5	$	—	$	1,446
Internal	12		12		—		4		(28)		—
Total service revenues	795		354		316		9		(28)		1,446
Total service revenues – commodity consideration	3		1		21		—		—		25
Product sales
External	29		(8)		289		—		—		310
Internal	7		9		14		—		(30)		—
Total product sales	36		1		303		—		(30)		310
Total revenues	$	834	$	356	$	640	$	9	$	(58)	$	1,781

Six Months Ended June 30, 2021
Segment revenues:
Service revenues
External	$	1,633	$	711	$	559	$	9	$	—	$	2,912
Internal	24		20		16		6		(66)		—
Total service revenues	1,657		731		575		15		(66)		2,912
Total service revenues – commodity consideration	21		5		74		—		—		100
Product sales
External	87		12		1,714		70		—		1,883
Internal	47		44		54		30		(175)		—
Total product sales	134		56		1,768		100		(175)		1,883
Total revenues	$	1,812	$	792	$	2,417	$	115	$	(241)	$	4,895


	Transmission & Gulf of Mexico		Northeast G&P		West		Other		Eliminations		Total
	(Millions)

Six Months Ended June 30, 2020
Segment revenues:
Service revenues
External	$	1,597	$	686	$	627	$	10	$	—	$	2,920
Internal	27		26		—		7		(60)		—
Total service revenues	1,624		712		627		17		(60)		2,920
Total service revenues – commodity consideration	8		3		42		—		—		53
Product sales
External	70		15		636		—		—		721
Internal	18		15		26		—		(59)		—
Total product sales	88		30		662		—		(59)		721
Total revenues	$	1,720	$	745	$	1,331	$	17	$	(119)	$	3,694

June 30, 2021
Total assets (1)	$	19,575	$	14,470	$	10,448	$	2,570	$	(1,556)	$	45,507
December 31, 2020
Total assets	$	19,110	$	14,569	$	10,558	$	927	$	(999)	$	44,165

______________

(1) The increase at our Other segment is primarily due to increased cash balance and the acquisitions of oil and gas properties in 2021. In February 2021, we acquired properties in the Wamsutter field in Wyoming from a supermajor oil and gas company for approximately $79 million, a portion of which was paid in the prior year. We recorded $290 million of property, plant, and equipment and $207 million of ARO related to this transaction. In June 2021, we acquired additional properties also in the Wamsutter field in Wyoming from an oil and gas company for approximately $86 million in cash, which is net of approximately $48 million reflecting the full settlement of outstanding receivables. We recorded $257 million of property, plant, and equipment and $125 million of ARO related to this transaction. Our oil and gas exploration and production activities are accounted for under the successful efforts method.

The following table reflects the reconciliation of Modified EBITDA to Net income (loss) as reported in the Consolidated Statement of Operations.


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Modified EBITDA by segment:
Transmission & Gulf of Mexico	$	646	$	615	$	1,306	$	1,277
Northeast G&P	409		370		811		739
West	231		253		546		468
Other	20		8		53		15
	1,306		1,246		2,716		2,499
Accretion expense associated with asset retirement obligations for nonregulated operations	(11)		(7)		(21)		(17)
Depreciation and amortization expenses	(463)		(430)		(901)		(859)
Impairment of goodwill	—		—		—		(187)
Equity earnings (losses)	135		108		266		130
Impairment of equity-method investments	—		—		—		(938)
Other investing income (loss) – net	2		1		4		4
Proportional Modified EBITDA of equity-method investments	(230)		(192)		(455)		(384)
Interest expense	(298)		(294)		(592)		(590)
(Provision) benefit for income taxes	(119)		(117)		(260)		87

Net income (loss)	$	322	$	315	$	757	$	(255)

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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Variable Interest Entity Disclosures [Abstract]

Subsequent Event	6 Months Ended
Subsequent Event	Jun. 30, 2021
Subsequent Events [Abstract]
Subsequent Event [Text Block]	Note 13 – Subsequent Event In July 2021, we completed the acquisition of 100 percent of Sequent Energy Management, L.P. and Sequent Energy Canada, Corp. (collectively, Sequent). Total consideration paid was $134 million, which includes $84 million of working capital acquired, and is subject to post-closing adjustment. Sequent focuses on asset management and the wholesale marketing, trading, storage, and transportation of natural gas for a diverse set of natural gas utilities and producers, and moves gas to markets through transportation and storage agreements on strategically positioned assets, including along our Transco system. Due to the recent closing of this acquisition, we have not provided all required disclosures as the information necessary is still under development. We plan to provide these disclosures in future filings.

Variable Interest Entities (Tables)

6 Months Ended

Jun. 30, 2021

Schedule of Variable Interest Entities [Table Text Block]

The following table presents amounts included in the Consolidated Balance Sheet that are only for the use or obligation of our consolidated VIEs:


	June 30, 2021		December 31, 2020
	(Millions)
Assets (liabilities):
Cash and cash equivalents	$	81	$	107
Trade accounts and other receivables – net	151		148


Other current assets and deferred charges	9		7

Property, plant, and equipment – net	5,406		5,514
Intangible assets – net of accumulated amortization	2,322		2,376
Regulatory assets, deferred charges, and other	15		15
Accounts payable	(55)		(42)

Accrued liabilities	(39)		(34)




Regulatory liabilities, deferred income, and other	(286)		(289)

Tabular disclosure of the significant judgments and assumptions made in determining whether a variable interest (as defined) held by the entity requires the variable interest entity (VIE) (as defined) to be consolidated and (or) disclose information about its involvement with the VIE, individually or in aggregate (as applicable); the nature of restrictions, if any, on the consolidated VIE's assets and on the settlement of its liabilities reported by an entity in its statement of financial position, including the carrying amounts of such assets and liabilities; the nature of, and changes in, the risks associated with involvement in the VIE; how involvement with the VIE affects the entity's financial position, financial performance, and cash flows; the lack of recourse if creditors (or beneficial interest holders) of the consolidated VIE have no recourse to the general credit of the primary beneficiary (if applicable); the terms of arrangements, giving consideration to both explicit arrangements and implicit variable interests, if any, that could require the entity to provide financial support to the VIE, including events or circumstances that could expose the entity to a loss; the methodology used by the entity for determining whether or not it is the primary beneficiary of the variable interest entity; the significant factors considered and judgments made in determining that the power to direct the activities of a VIE that most significantly impact the VIE's economic performance are shared (as defined); the carrying amounts and classification of assets and liabilities of the VIE included in the statement of financial position; the entity's maximum exposure to loss, if any, as a result of its involvement with the VIE, including how the maximum exposure is determined and significant sources of the entity's exposure to the VIE; a comparison of the carrying amounts of the assets and liabilities and the entity's maximum exposure to loss; information about any liquidity arrangements, guarantees, and (or) other commitments by third parties that may affect the fair value or risk of the entity's variable interest in the VIE; whether or not the entity has provided financial support or other support (explicitly or implicitly) to the VIE that it was not previously contractually required to provide or whether the entity intends to provide that support, including the type and amount of the support and the primary reasons for providing the support; and supplemental information the entity determines necessary to provide.

Disaggregation of Revenue [Table Text Block]

Revenue Recognition (Tables)

6 Months Ended

Jun. 30, 2021

Revenue Recognition [Abstract]

The following table presents our revenue disaggregated by major service line:


	Transco		Northwest Pipeline		Gulf of Mexico Midstream		Northeast Midstream		West Midstream		Other		Eliminations		Total
	(Millions)
Three Months Ended June 30, 2021
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	613	$	108	$	—	$	—	$	—	$	—	$	(2)	$	719
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	—		—		90		315		278		—		(26)		657
Commodity consideration	—		—		10		2		39		—		—		51
Other	2		—		7		52		10		—		(4)		67
Total service revenues	615		108		107		369		327		—		(32)		1,494
Product sales	16		—		53		24		726		44		(87)		776
Total revenues from contracts with customers	631		108		160		393		1,053		44		(119)		2,270
Other revenues (1)	—		—		3		6		(1)		8		(3)		13
Total revenues	$	631	$	108	$	163	$	399	$	1,052	$	52	$	(122)	$	2,283

Three Months Ended June 30, 2020
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	592	$	110	$	—	$	—	$	—	$	—	$	(1)	$	701
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	—		—		78		308		297		—		(19)		664
Commodity consideration	—		—		3		1		21		—		—		25
Other	2		—		10		41		17		—		(4)		66
Total service revenues	594		110		91		350		335		—		(24)		1,456
Product sales	20		—		17		1		303		—		(31)		310
Total revenues from contracts with customers	614		110		108		351		638		—		(55)		1,766
Other revenues (1)	2		—		1		5		2		9		(4)		15
Total revenues	$	616	$	110	$	109	$	356	$	640	$	9	$	(59)	$	1,781


	Transco		Northwest Pipeline		Gulf of Mexico Midstream		Northeast Midstream		West Midstream		Other		Eliminations		Total
	(Millions)
Six Months Ended June 30, 2021
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	1,238	$	221	$	—	$	—	$	—	$	—	$	(5)	$	1,454
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	—		—		176		626		540		—		(47)		1,295
Commodity consideration	—		—		21		5		74		—		—		100
Other	5		—		10		93		29		—		(8)		129
Total service revenues	1,243		221		207		724		643		—		(60)		2,978
Product sales	30		—		106		56		1,806		100		(177)		1,921
Total revenues from contracts with customers	1,273		221		313		780		2,449		100		(237)		4,899
Other revenues (1)	2		—		5		12		(32)		15		(6)		(4)
Total revenues	$	1,275	$	221	$	318	$	792	$	2,417	$	115	$	(243)	$	4,895

Six Months Ended June 30, 2020
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	1,196	$	225	$	—	$	—	$	—	$	—	$	(3)	$	1,418
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	—		—		177		620		596		—		(41)		1,352
Commodity consideration	—		—		8		3		42		—		—		53
Other	5		—		16		82		26		—		(9)		120
Total service revenues	1,201		225		201		705		664		—		(53)		2,943
Product sales	40		—		49		30		662		—		(60)		721
Total revenues from contracts with customers	1,241		225		250		735		1,326		—		(113)		3,664
Other revenues (1)	2		—		3		10		5		17		(7)		30
Total revenues	$	1,243	$	225	$	253	$	745	$	1,331	$	17	$	(120)	$	3,694

______________________________

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

The following table presents a reconciliation of our contract assets:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Balance at beginning of period	$	25	$	18	$	12	$	8
Revenue recognized in excess of amounts invoiced	38		46		83		69
Minimum volume commitments invoiced	(25)		(34)		(57)		(47)
Balance at end of period	$	38	$	30	$	38	$	30

Contract Liabilities

The following table presents a reconciliation of our contract liabilities:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Balance at beginning of period	$	1,171	$	1,189	$	1,209	$	1,215
Payments received and deferred	72		74		85		102
Significant financing component	2		2		5		5
Recognized in revenue	(52)		(62)		(106)		(119)
Balance at end of period	$	1,193	$	1,203	$	1,193	$	1,203

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


	Contract Liabilities		Remaining Performance Obligations
	(Millions)
2021 (six months)	$	83	$	1,724
2022 (one year)	130		3,409
2023 (one year)	111		3,137
2024 (one year)	106		2,723
2025 (one year)	101		2,330

Thereafter	662		18,055
Total	$	1,193	$	31,378

Contract With Customer Accounts Receivable [Table Text Block]

The following is a summary of our Trade accounts and other receivables – net:


	June 30, 2021		December 31, 2020
	(Millions)
Accounts receivable related to revenues from contracts with customers	$	928	$	892
Other accounts receivable	71		107
Trade accounts and other receivables – net	$	999	$	999

Provision (Benefit) for Income Taxes (Tables)

6 Months Ended

Jun. 30, 2021

Income Tax Disclosure [Abstract]

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

The Provision (benefit) for income taxes includes:


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Current:
Federal	$	—	$	—	$	(2)	$	(28)
State	1		(1)		—		—
	1		(1)		(2)		(28)
Deferred:
Federal	85		93		200		(41)
State	33		25		62		(18)

	118		118		262		(59)
Provision (benefit) for income taxes	$	119	$	117	$	260	$	(87)

Earnings (Loss) Per Common Share (Tables)

6 Months Ended

Jun. 30, 2021

Earnings Per Share [Abstract]

Earnings (Loss) Per Common Share [Table Text Block]


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Dollars in millions, except per-share amounts; shares in thousands)
Net income (loss) available to common stockholders	$	304	$	303	$	729	$	(215)
Basic weighted-average shares	1,215,250		1,213,601		1,214,950		1,213,310
Effect of dilutive securities:
Nonvested restricted stock units	2,208		980		2,385		—
Stock options	18		—		9		—
Diluted weighted-average shares (1)	1,217,476		1,214,581		1,217,344		1,213,310
Earnings (loss) per common share:
Basic	$	.25	$	.25	$	.60	$	(.18)
Diluted	$	.25	$	.25	$	.60	$	(.18)

______________________________

Employee Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2021

Retirement Benefits [Abstract]

Schedule of Net Benefit Costs [Table Text Block]

Net periodic benefit cost (credit) is as follows:


	Pension Benefits
	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Components of net periodic benefit cost (credit):
Service cost	$	7	$	7	$	15	$	15
Interest cost	7		9		14		19
Expected return on plan assets	(11)		(14)		(22)		(27)

Amortization of net actuarial loss	3		7		7		11
Net actuarial loss from settlements	1		2		1		8
Net periodic benefit cost (credit)	$	7	$	11	$	15	$	26


	Other Postretirement Benefits
	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Components of net periodic benefit cost (credit):

Interest cost	$	2	$	1	$	3	$	3
Expected return on plan assets	(3)		(2)		(5)		(5)


Reclassification to regulatory liability	—		—		1		1
Net periodic benefit cost (credit)	$	(1)	$	(1)	$	(1)	$	(1)

Debt and Banking Arrangements (Tables)

6 Months Ended

Jun. 30, 2021

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities [Table Text Block]

Credit Facilities


	June 30, 2021
	Stated Capacity		Outstanding
	(Millions)

Long-term credit facility (1)	$	4,500	$	—
Letters of credit under certain bilateral bank agreements			17

Stockholders' Equity (Tables)

6 Months Ended

Jun. 30, 2021

Stockholders' Equity Note [Abstract]

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

AOCI

The following table presents the changes in AOCI by component, net of income taxes:


	Cash Flow Hedges		Foreign Currency Translation		Pension and Other Postretirement Benefits		Total
	(Millions)
Balance at December 31, 2020	$	(3)	$	(1)	$	(92)	$	(96)

Other comprehensive income (loss) before reclassifications	(26)		—		—		(26)
Amounts reclassified from accumulated other comprehensive income (loss)	6		—		6		12
Other comprehensive income (loss)	(20)		—		6		(14)

Balance at June 30, 2021	$	(23)	$	(1)	$	(86)	$	(110)

Reclassifications Out Of Accumulated Other Comprehensive Income [Table Text Block]

Reclassifications out of AOCI are presented in the following table by component for the six months ended June 30, 2021:

Component

Reclassifications

Classification

(Millions)

Cash flow hedges:

Energy commodity contracts

Product sales

Pension and other postretirement benefits:

Amortization of actuarial (gain) loss and net actuarial loss from settlements included in net periodic benefit cost (credit)

Other income (expense) – net below Operating income (loss)

Income tax benefit

(4)

Provision (benefit) for income taxes

Reclassifications during the period

Fair Value Measurements and Guarantees (Tables)

6 Months Ended

Jun. 30, 2021

Fair Value Disclosures [Abstract]

Fair Value Assets and Liabilities Measured On Recurring Basis [Table Text Block]


					Fair Value Measurements Using
	Carrying Amount		Fair Value		Quoted Prices In Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	(Millions)
Assets (liabilities) at June 30, 2021:
Measured on a recurring basis:
ARO Trust investments	$	257	$	257	$	257	$	—	$	—




Additional disclosures:

Long-term debt, including current portion	(23,234)		(27,643)		—		(27,643)		—
Guarantees	(40)		(26)		—		(10)		(16)

Assets (liabilities) at December 31, 2020:
Measured on a recurring basis:
ARO Trust investments	$	235	$	235	$	235	$	—	$	—



Additional disclosures:
Long-term debt, including current portion	(22,344)		(27,043)		—		(27,043)		—
Guarantees	(40)		(27)		—		(11)		(16)

Fair Value Measurements, Nonrecurring [Table Text Block]

The following table presents impairments of equity-method investments associated with certain nonrecurring fair value measurements within Level 3 of the fair value hierarchy.


					Impairments
					Six Months Ended June 30,
	Segment	Date of Measurement	Fair Value		2021		2020
			(Millions)





Impairment of equity-method investments:
RMM (1)	West	March 31, 2020	$	557			$	243
Brazos Permian II (1)	West	March 31, 2020	—				193
Caiman II (2)	Northeast G&P	March 31, 2020	191				229
Appalachia Midstream Investments (2)	Northeast G&P	March 31, 2020	2,700				127
Aux Sable (2)	Northeast G&P	March 31, 2020	7				39
Laurel Mountain (2)	Northeast G&P	March 31, 2020	236				10
Discovery (2)	Transmission & Gulf of Mexico	March 31, 2020	367				97





Impairment of equity-method investments					$	—	$	938

_______________

Segment Disclosures (Tables)

6 Months Ended

Jun. 30, 2021

Segment Reporting [Abstract]

Reconciliation of Revenue from Segments to Consolidated [Table Text Block]

The following table reflects the reconciliation of Segment revenues to Total revenues as reported in the Consolidated Statement of Operations and Total assets by reportable segment.


	Transmission & Gulf of Mexico		Northeast G&P		West		Other		Eliminations		Total
	(Millions)
Three Months Ended June 30, 2021
Segment revenues:
Service revenues
External	$	811	$	364	$	280	$	5	$	—	$	1,460
Internal	12		9		11		3		(35)		—
Total service revenues	823		373		291		8		(35)		1,460
Total service revenues – commodity consideration	10		2		39		—		—		51
Product sales
External	47		8		696		21		—		772
Internal	20		16		26		23		(85)		—
Total product sales	67		24		722		44		(85)		772
Total revenues	$	900	$	399	$	1,052	$	52	$	(120)	$	2,283

Three Months Ended June 30, 2020
Segment revenues:
Service revenues
External	$	783	$	342	$	316	$	5	$	—	$	1,446
Internal	12		12		—		4		(28)		—
Total service revenues	795		354		316		9		(28)		1,446
Total service revenues – commodity consideration	3		1		21		—		—		25
Product sales
External	29		(8)		289		—		—		310
Internal	7		9		14		—		(30)		—
Total product sales	36		1		303		—		(30)		310
Total revenues	$	834	$	356	$	640	$	9	$	(58)	$	1,781

Six Months Ended June 30, 2021
Segment revenues:
Service revenues
External	$	1,633	$	711	$	559	$	9	$	—	$	2,912
Internal	24		20		16		6		(66)		—
Total service revenues	1,657		731		575		15		(66)		2,912
Total service revenues – commodity consideration	21		5		74		—		—		100
Product sales
External	87		12		1,714		70		—		1,883
Internal	47		44		54		30		(175)		—
Total product sales	134		56		1,768		100		(175)		1,883
Total revenues	$	1,812	$	792	$	2,417	$	115	$	(241)	$	4,895


	Transmission & Gulf of Mexico		Northeast G&P		West		Other		Eliminations		Total
	(Millions)

Six Months Ended June 30, 2020
Segment revenues:
Service revenues
External	$	1,597	$	686	$	627	$	10	$	—	$	2,920
Internal	27		26		—		7		(60)		—
Total service revenues	1,624		712		627		17		(60)		2,920
Total service revenues – commodity consideration	8		3		42		—		—		53
Product sales
External	70		15		636		—		—		721
Internal	18		15		26		—		(59)		—
Total product sales	88		30		662		—		(59)		721
Total revenues	$	1,720	$	745	$	1,331	$	17	$	(119)	$	3,694

June 30, 2021
Total assets (1)	$	19,575	$	14,470	$	10,448	$	2,570	$	(1,556)	$	45,507
December 31, 2020
Total assets	$	19,110	$	14,569	$	10,558	$	927	$	(999)	$	44,165

______________

Reconciliation of Modified EBITDA to Net Income (Loss) [Table Text Block]

The following table reflects the reconciliation of Modified EBITDA to Net income (loss) as reported in the Consolidated Statement of Operations.


	Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020
	(Millions)
Modified EBITDA by segment:
Transmission & Gulf of Mexico	$	646	$	615	$	1,306	$	1,277
Northeast G&P	409		370		811		739
West	231		253		546		468
Other	20		8		53		15
	1,306		1,246		2,716		2,499
Accretion expense associated with asset retirement obligations for nonregulated operations	(11)		(7)		(21)		(17)
Depreciation and amortization expenses	(463)		(430)		(901)		(859)
Impairment of goodwill	—		—		—		(187)
Equity earnings (losses)	135		108		266		130
Impairment of equity-method investments	—		—		—		(938)
Other investing income (loss) – net	2		1		4		4
Proportional Modified EBITDA of equity-method investments	(230)		(192)		(455)		(384)
Interest expense	(298)		(294)		(592)		(590)
(Provision) benefit for income taxes	(119)		(117)		(260)		87

Net income (loss)	$	322	$	315	$	757	$	(255)

General, Description of Business, and Basis of Presentation (Details)		6 Months Ended
	Oct. 31, 2020	Jun. 30, 2021
Williams Companies Inc [Member] \| Blue Racer Midstream LLC \| Beneficial Owner
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest	29.00%
Williams Companies Inc [Member] \| Transmission And Gulf Of Mexico [Member] \| Gulfstar One [Member]
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Variable Interest Entity Ownership Percentage		51.00%
Williams Companies Inc [Member] \| Northeast G And P [Member] \| Northeast JV [Member]
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Variable Interest Entity Ownership Percentage		65.00%
Williams Companies Inc [Member] \| Northeast G And P [Member] \| Cardinal Gas Services LLC [Member]
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Variable Interest Entity Ownership Percentage		66.00%
Williams Companies Inc [Member] \| Northeast G And P [Member] \| Appalachia Midstream Services, LLC [Member]
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest		66.00%
Williams Companies Inc [Member] \| West [Member] \| Conway Fractionator [Member]
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest		50.00%
Williams Companies Inc [Member] \| West [Member] \| Brazos Permian II LLC [Member]
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest		15.00%
Gulfstream Natural Gas System, LLC [Member] \| Transmission And Gulf Of Mexico [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50.00%
Discovery Producer Services LLC [Member] \| Transmission And Gulf Of Mexico [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		60.00%
Laurel Mountain Midstream, LLC [Member] \| Northeast G And P [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		69.00%
Caiman Energy II [Member] \| Northeast G And P [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	58.00%
Overland Pass Pipeline Company LLC [Member] \| West [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50.00%
Rocky Mountain Midstream Holdings LLC [Member] \| West [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50.00%
Targa Train 7 LLC \| West [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		20.00%
Blue Racer Midstream LLC \| Northeast G And P [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50.00%

Variable Interest Entities (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2021	Dec. 31, 2020
Variable Interest Entity [Line Items]
Assets	$ 45,507	$ 44,165
Equity Method Investments	5,124	5,159
Variable Interest Entity, Primary Beneficiary [Member] \| Cash and cash equivalents [Member]
Variable Interest Entity [Line Items]
Assets	81	107
Variable Interest Entity, Primary Beneficiary [Member] \| Trade accounts and other receivables - net [Member]
Variable Interest Entity [Line Items]
Assets	151	148
Variable Interest Entity, Primary Beneficiary [Member] \| Other current assets and deferred charges [Member]
Variable Interest Entity [Line Items]
Assets	9	7
Variable Interest Entity, Primary Beneficiary [Member] \| Property, plant, and equipment - net [Member]
Variable Interest Entity [Line Items]
Assets	5,406	5,514
Variable Interest Entity, Primary Beneficiary [Member] \| Intangible assets - net of accumulated amortization [Member]
Variable Interest Entity [Line Items]
Assets	2,322	2,376
Variable Interest Entity, Primary Beneficiary [Member] \| Regulatory assets, deferred charges, and other [Member]
Variable Interest Entity [Line Items]
Assets	15	15
Variable Interest Entity, Primary Beneficiary [Member] \| Accounts payable [Member]
Variable Interest Entity [Line Items]
Liabilities	(55)	(42)
Variable Interest Entity, Primary Beneficiary [Member] \| Accrued liabilities [Member]
Variable Interest Entity [Line Items]
Liabilities	(39)	(34)
Variable Interest Entity, Primary Beneficiary [Member] \| Regulatory liabilities, deferred income, and other [Member]
Variable Interest Entity [Line Items]
Liabilities	$ (286)	$ (289)
Variable Interest Entity, Primary Beneficiary [Member] \| Williams Companies Inc [Member] \| Northeast JV [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	65.00%
Variable Interest Entity, Primary Beneficiary [Member] \| Williams Companies Inc [Member] \| Gulfstar One [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	51.00%
Variable Interest Entity, Primary Beneficiary [Member] \| Williams Companies Inc [Member] \| Cardinal Gas Services LLC [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	66.00%
Variable Interest Entity, Not Primary Beneficiary [Member] \| Williams Companies Inc [Member] \| Targa Train 7 LLC
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	20.00%
Equity Method Investments	$ 49
Variable Interest Entity, Not Primary Beneficiary [Member] \| Williams Companies Inc [Member] \| Brazos Permian II LLC [Member] \| Investments [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	15.00%

Revenue Recognition Revenue by Category (Details) - USD ($)
$ in Millions

3 Months Ended

6 Months Ended

Jun. 30, 2021

Jun. 30, 2020

Jun. 30, 2021

Jun. 30, 2020

Revenue from Contract with Customer, Excluding Assessed Tax

$ 2,270

$ 1,766

$ 4,899

$ 3,664

^[1]

(4)

Regulated Service [Member]

2,283

1,781

4,895

3,694

Revenue from Contract with Customer, Excluding Assessed Tax

719

701

1,454

1,418

NonRegulated Service Monetary Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

657

664

1,295

1,352

NonRegulated Service Commodity Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

100

100

Other Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

129

120

Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

1,494

1,456

2,978

2,943

1,460

1,446

2,912

2,920

Product [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

776

310

1,921

721

772

310

1,883

721

Transco [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

631

614

1,273

1,241

^[1]

Transco [Member] | Regulated Service [Member]

631

616

1,275

1,243

Revenue from Contract with Customer, Excluding Assessed Tax

613

592

1,238

1,196

Transco [Member] | NonRegulated Service Monetary Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Transco [Member] | NonRegulated Service Commodity Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Transco [Member] | Other Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Transco [Member] | Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

615

594

1,243

1,201

Transco [Member] | Product [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Northwest Pipeline [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

108

110

221

225

^[1]

Northwest Pipeline [Member] | Regulated Service [Member]

108

110

221

225

Revenue from Contract with Customer, Excluding Assessed Tax

108

110

221

225

Northwest Pipeline [Member] | NonRegulated Service Monetary Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Northwest Pipeline [Member] | NonRegulated Service Commodity Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Northwest Pipeline [Member] | Other Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Northwest Pipeline [Member] | Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

108

110

221

225

Northwest Pipeline [Member] | Product [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Transmission And Gulf Of Mexico Midstream [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

160

108

313

250

^[1]

Transmission And Gulf Of Mexico Midstream [Member] | Regulated Service [Member]

163

109

318

253

Revenue from Contract with Customer, Excluding Assessed Tax

Transmission And Gulf Of Mexico Midstream [Member] | NonRegulated Service Monetary Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

176

177

Transmission And Gulf Of Mexico Midstream [Member] | NonRegulated Service Commodity Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Transmission And Gulf Of Mexico Midstream [Member] | Other Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Transmission And Gulf Of Mexico Midstream [Member] | Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

107

207

201

Transmission And Gulf Of Mexico Midstream [Member] | Product [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

106

Northeast Midstream [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

393

351

780

735

^[1]

Northeast Midstream [Member] | Regulated Service [Member]

399

356

792

745

Revenue from Contract with Customer, Excluding Assessed Tax

Northeast Midstream [Member] | NonRegulated Service Monetary Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

315

308

626

620

Northeast Midstream [Member] | NonRegulated Service Commodity Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Northeast Midstream [Member] | Other Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Northeast Midstream [Member] | Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

369

350

724

705

Northeast Midstream [Member] | Product [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

West Midstream [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

1,053

638

2,449

1,326

^[1]

(1)

(32)

West Midstream [Member] | Regulated Service [Member]

1,052

640

2,417

1,331

Revenue from Contract with Customer, Excluding Assessed Tax

West Midstream [Member] | NonRegulated Service Monetary Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

278

297

540

596

West Midstream [Member] | NonRegulated Service Commodity Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

West Midstream [Member] | Other Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

West Midstream [Member] | Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

327

335

643

664

West Midstream [Member] | Product [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

726

303

1,806

662

Other [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

100

^[1]

Other [Member] | Regulated Service [Member]

115

Revenue from Contract with Customer, Excluding Assessed Tax

Other [Member] | NonRegulated Service Monetary Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Other [Member] | NonRegulated Service Commodity Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Other [Member] | Other Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Other [Member] | Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Other [Member] | Product [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

100

Intersegment Eliminations [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

(119)

(55)

(237)

(113)

^[1]

(3)

(4)

(6)

(7)

Intersegment Eliminations [Member] | Regulated Service [Member]

(122)

(59)

(243)

(120)

Revenue from Contract with Customer, Excluding Assessed Tax

(2)

(1)

(5)

(3)

Intersegment Eliminations [Member] | NonRegulated Service Monetary Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

(26)

(19)

(47)

(41)

Intersegment Eliminations [Member] | NonRegulated Service Commodity Consideration [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

Intersegment Eliminations [Member] | Other Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

(4)

(8)

(9)

Intersegment Eliminations [Member] | Service [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

(32)

(24)

(60)

(53)

Intersegment Eliminations [Member] | Product [Member]

Revenue from Contract with Customer, Excluding Assessed Tax

$ (87)

$ (31)

$ (177)

$ (60)

[1]

Revenues not derived from contracts with customers consist of leasing revenues associated with our headquarters building and management fees that we receive for certain services we provide to operated equity-method investments, which are reported in Service revenues in the Consolidated Statement of Operations, and amounts associated with our derivative contracts, which are reported in Product sales in the Consolidated Statement of Operations.

Revenue Recognition Contract Assets (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Revenue Recognition [Abstract]
Contract with Customer, Asset, Net - Beginning of Period	$ 25	$ 18	$ 12	$ 8
Contract with Customer, Asset, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	38	46	83	69
Contract with Customer, Asset, Reclassified to Receivable	(25)	(34)	(57)	(47)
Contract with Customer, Asset, Net - End of Period	$ 38	$ 30	$ 38	$ 30

Revenue Recognition Contract Liabilities (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Contract With Customer, Liability [Line Items]
Contract with Customer, Liability - Beginning of Period	$ 1,171	$ 1,189	$ 1,209	$ 1,215
Contract with Customer, Liability, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	72	74	85	102
Other Significant Noncash Transaction, Value of Consideration Received	2	2	5	5
Contract with Customer, Liability, Revenue Recognized	(52)	(62)	(106)	(119)
Contract with Customer, Liability - End of Period	$ 1,193	$ 1,203	$ 1,193	$ 1,203

Revenue Recognition Contract Liabilities Performance Obligations (Details) - USD ($) $ in Millions	Jun. 30, 2021	Mar. 31, 2021	Dec. 31, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	$ 1,193	$ 1,171	$ 1,209	$ 1,203	$ 1,189	$ 1,215
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	83
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	130
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	111
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	106
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	101
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	$ 662
Performance Obligations Related To Contract Liabilities [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	6 months
Performance Obligations Related To Contract Liabilities [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Performance Obligations Related To Contract Liabilities [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period

Revenue Recognition Remaining Performance Obligations (Details) $ in Millions	Jun. 30, 2021 USD ($)
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 31,378
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-07-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	1,724
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	3,409
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	3,137
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	2,723
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	2,330
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 18,055
Remaining Performance Obligations [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	6 months
Remaining Performance Obligations [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Remaining Performance Obligations [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period

Revenue Recognition Accounts Receivable (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	$ 999	$ 999
Accounts Receivable Related To Contracts With Customers [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	928	892
Other Accounts Receivable [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	$ 71	$ 107

Investing Activities (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
Investing Activities (Details) - USD ($) $ in Millions	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Schedule of Equity Method Investments [Line Items]
Other investing income (loss) - net	$ 2	$ 1	$ 4	$ 4
Equity Method Investment, Other than Temporary Impairment	0	0	0	938
Proceeds from dispositions of equity-method investments			1	0
Equity earnings (losses)	$ 135	$ 108	266	130
Impairment Of Equity-Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Other than Temporary Impairment			$ 0	938
Rocky Mountain Midstream Holdings LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings (losses)				$ (78)

Provision (Benefit) for Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Current:
Federal	$ 0	$ 0	$ (2)	$ (28)
State	1	(1)	0	0
Total	1	(1)	(2)	(28)
Deferred:
Federal	85	93	200	(41)
State	33	25	62	(18)
Total	118	118	262	(59)
Provision (benefit) for income taxes	$ 119	$ 117	$ 260	$ (87)

Amount of current income tax expense (benefit) and deferred income tax expense (benefit) pertaining to continuing operations.

Earnings Per Share Table [Line Items]

Earnings (Loss) Per Common Share (Details) - USD ($)
$ / shares in Units, shares in Thousands, $ in Millions

3 Months Ended

6 Months Ended

Jun. 30, 2021

Jun. 30, 2020

Jun. 30, 2021

Jun. 30, 2020

Net income (loss) available to common stockholders

$ 304

$ 303

$ 729

$ (215)

Basic weighted-average shares

1,215,250

1,213,601

1,214,950

1,213,310

Effect of dilutive securities:

Diluted weighted-average shares (1)

1,217,476

1,214,581

1,217,344

1,213,310

^[1]

Earnings (loss) per common share:

Basic

$ 0.25

$ 0.60

$ (0.18)

Diluted

$ 0.25

$ 0.60

$ (0.18)

Nonvested restricted stock units [Member]

Effect of dilutive securities:

Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements

2,208

980

2,385

Stock Options [Member]

Effect of dilutive securities:

Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements

Nonvested restricted stock units [Member]

Earnings (loss) per common share:

Number of weighted-average shares excluded from computation of diluted earnings per common share

1,100

[1]	For the six months ended June 30, 2020, 1.1 million weighted-average nonvested restricted stock units have been excluded from the computation of diluted earnings (loss) per common share as their inclusion would be antidilutive due to our loss available to common stockholders.

Employee Benefit Plans (Quarterly Info) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Pension Benefits [Member]
Components of net periodic benefit cost (credit):
Service cost	$ 7	$ 7	$ 15	$ 15
Interest cost	7	9	14	19
Expected return on plan assets	(11)	(14)	(22)	(27)
Amortization of net actuarial loss	3	7	7	11
Net actuarial loss from settlements	1	2	1	8
Net periodic benefit cost (credit)	7	11	15	26
Employer contributions			3
Estimated future employer contributions in current fiscal year	1		1
Other Postretirement Benefits [Member]
Components of net periodic benefit cost (credit):
Interest cost	2	1	3	3
Expected return on plan assets	(3)	(2)	(5)	(5)
Reclassification to regulatory liability	0	0	1	1
Net periodic benefit cost (credit)	(1)	$ (1)	(1)	$ (1)
Employer contributions			3
Estimated future employer contributions in current fiscal year	$ 2		$ 2

Debt and Banking Arrangements Long-Term Debt Issuances and Retirements (Details 1) - 2.6 Percent Senior Unsecured Notes Due 2031 - Williams Companies Inc [Member] $ in Millions	Mar. 02, 2021 USD ($)
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 900
Long-term debt interest rate	2.60%

Debt and Banking Arrangements Credit Facilities and Commercial Paper (Details 2) - Williams Companies Inc [Member]
$ in Millions

Jun. 30, 2021

USD ($)

Credit Facility and Commercial Paper [Line Items]

Credit facility, capacity

$ 4,500

^[1]

Credit facility, loans outstanding

^[1]

Commercial Paper [Member]

Credit Facility and Commercial Paper [Line Items]

Commercial paper, outstanding

Credit facility, capacity

4,000

Letters Of Credit Under Certain Bilateral Bank Agreements [Member]

Credit Facility and Commercial Paper [Line Items]

Credit facility, letters of credit outstanding

$ 17

[1]	In managing our available liquidity, we do not expect a maximum outstanding amount in excess of the capacity of our credit facility inclusive of any outstanding amounts under our commercial paper program.

The carrying value as of the balance sheet date of the current and noncurrent portions of long-term obligations drawn from a line of credit, which is a bank's commitment to make loans up to a specific amount. Examples of items that might be included in the application of this element may consist of letters of credit, standby letters of credit, and revolving credit arrangements, under which borrowings can be made up to a maximum amount as of any point in time conditional on satisfaction of specified terms before, as of and after the date of drawdowns on the line. Includes short-term obligations that would normally be classified as current liabilities but for which (a) postbalance sheet date issuance of a long term obligation to refinance the short term obligation on a long term basis, or (b) the enterprise has entered into a financing agreement that clearly permits the enterprise to refinance the short-term obligation on a long term basis and the following conditions are met (1) the agreement does not expire within 1 year and is not cancelable by the lender except for violation of an objectively determinable provision, (2) no violation exists at the BS date, and (3) the lender has entered into the financing agreement is expected to be financially capable of honoring the agreement.

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Stockholders' Equity Table Of Changes In AOCI (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total, Beginning Balance			$ (96)
Other comprehensive income (loss)	$ (10)	$ 29	(14)	$ 23
Total, Ending Balance	(110)		(110)
Accumulated Other Comprehensive Income (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total, Beginning Balance			(96)
Other comprehensive income (loss) before reclassifications			(26)
Amounts reclassified from accumulated other comprehensive income (loss)			12
Other comprehensive income (loss)	(10)	$ 29	(14)	$ 23
Total, Ending Balance	(110)		(110)
Cash Flow Hedges
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total, Beginning Balance			(3)
Other comprehensive income (loss) before reclassifications			(26)
Amounts reclassified from accumulated other comprehensive income (loss)			6
Other comprehensive income (loss)			(20)
Total, Ending Balance	(23)		(23)
Foreign Currency Translation
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total, Beginning Balance			(1)
Other comprehensive income (loss) before reclassifications			0
Amounts reclassified from accumulated other comprehensive income (loss)			0
Other comprehensive income (loss)			0
Total, Ending Balance	(1)		(1)
Pension and Other Postretirement Benefits
Accumulated Other Comprehensive Income (Loss) [Line Items]
Total, Beginning Balance			(92)
Other comprehensive income (loss) before reclassifications			0
Amounts reclassified from accumulated other comprehensive income (loss)			6
Other comprehensive income (loss)			6
Total, Ending Balance	$ (86)		$ (86)

Stockholders' Equity Table Of Reclassifications from AOCI (Details) - Reclassification out of Accumulated Other Comprehensive Income [Member] $ in Millions	6 Months Ended
	Jun. 30, 2021 USD ($)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income tax benefit	$ (4)
Reclassifications during the period	12
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Energy commodity contracts	8
Pension and Other Postretirement Benefits
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of actuarial (gain) loss and net actuarial loss from settlements included in net periodic benefit cost (credit)	$ 8

Fair Value Measurements and Guarantees Recurring Measurements and Additional (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Carrying Amount [Member]
Additional disclosures:
Long-term debt, including current portion	$ (23,234)	$ (22,344)
Guarantees	(40)	(40)
Fair Value [Member]
Additional disclosures:
Long-term debt, including current portion	(27,643)	(27,043)
Guarantees	(26)	(27)
Level 1 [Member]
Additional disclosures:
Long-term debt, including current portion	0	0
Guarantees	0	0
Level 2 [Member]
Additional disclosures:
Long-term debt, including current portion	(27,643)	(27,043)
Guarantees	(10)	(11)
Level 3 [Member]
Additional disclosures:
Long-term debt, including current portion	0	0
Guarantees	(16)	(16)
Fair Value, Recurring [Member] \| Carrying Amount [Member]
Measured on a recurring basis:
ARO Trust investments	257	235
Fair Value, Recurring [Member] \| Fair Value [Member]
Measured on a recurring basis:
ARO Trust investments	257	235
Fair Value, Recurring [Member] \| Level 1 [Member]
Measured on a recurring basis:
ARO Trust investments	257	235
Fair Value, Recurring [Member] \| Level 2 [Member]
Measured on a recurring basis:
ARO Trust investments	0	0
Fair Value, Recurring [Member] \| Level 3 [Member]
Measured on a recurring basis:
ARO Trust investments	0	$ 0
WilTel Guarantee [Member]
Additional disclosures:
Guarantor Obligations, Maximum Exposure, Undiscounted	26
Indemnification Agreement [Member] \| Carrying Amount [Member]
Additional disclosures:
Guarantees	$ 0

Fair Value Measurements and Guarantees Nonrecurring Measurements (Details) - USD ($)
$ in Millions

1 Months Ended

3 Months Ended

6 Months Ended

Mar. 31, 2020

Jun. 30, 2021

Jun. 30, 2020

Mar. 31, 2020

Jun. 30, 2021

Jun. 30, 2020

Share Price Change

26.00%

40.00%

Goodwill, Impairment Loss

$ 0

$ 187

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Equity Method Investment, Other than Temporary Impairment

$ 0

938

Impairment Of Equity-Method Investments [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Equity Method Investment, Other than Temporary Impairment

$ 0

$ 938

Fair Value, Nonrecurring [Member] | Level 3 [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Goodwill, Impairment Loss

$ 187

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Equity Method Investment, Other than Temporary Impairment

^[1]

$ 127

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Rocky Mountain Midstream Holdings LLC [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | West [Member] | Impairment Of Equity-Method Investments [Member]

^[1]

2,700

$ 2,700

2,700

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Equity Method Investment, Other than Temporary Impairment

^[2]

243

Rocky Mountain Midstream Holdings LLC [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | West [Member] | Investments [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Rocky Mountain Midstream Holdings LLC [Member] | Measurement Input, Discount Rate [Member]

^[2]

$ 557

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Brazos Permian II LLC [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | West [Member] | Impairment Of Equity-Method Investments [Member]

17.00%

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Equity Method Investment, Other than Temporary Impairment

^[2]

$ 193

Brazos Permian II LLC [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | West [Member] | Investments [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Brazos Permian II LLC [Member] | Measurement Input, Discount Rate [Member]

^[2]

$ 0

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Caiman Energy II [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | Northeast G And P [Member] | Impairment Of Equity-Method Investments [Member]

17.00%

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Equity Method Investment, Other than Temporary Impairment

^[1]

$ 229

Caiman Energy II [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | Northeast G And P [Member] | Investments [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Aux Sable Liquid Products LP [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | Northeast G And P [Member] | Impairment Of Equity-Method Investments [Member]

^[1]

191

$ 191

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Equity Method Investment, Other than Temporary Impairment

^[1]

Aux Sable Liquid Products LP [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | Northeast G And P [Member] | Investments [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Laurel Mountain Midstream, LLC [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | Northeast G And P [Member] | Impairment Of Equity-Method Investments [Member]

^[1]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Equity Method Investment, Other than Temporary Impairment

^[1]

Laurel Mountain Midstream, LLC [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | Northeast G And P [Member] | Investments [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Discovery Producer Services LLC [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | Transmission And Gulf Of Mexico [Member] | Impairment Of Equity-Method Investments [Member]

^[1]

236

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Equity Method Investment, Other than Temporary Impairment

^[1]

Discovery Producer Services LLC [Member] | Fair Value, Nonrecurring [Member] | Level 3 [Member] | Transmission And Gulf Of Mexico [Member] | Investments [Member]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Minimum [Member] | Caiman Energy II And Aux Sable Liquid Products LP [Member] | Measurement Input, EBITDA Multiple [Member]

^[1]

$ 367

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Minimum [Member] | Appalachia Midstream Services LLC And Laurel Mountain Midstream LLC And Discovery Producer Services LLC [Member] | Measurement Input, Discount Rate [Member]

500.00%

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Maximum [Member] | Caiman Energy II And Aux Sable Liquid Products LP [Member] | Measurement Input, EBITDA Multiple [Member]

9.70%

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Maximum [Member] | Appalachia Midstream Services LLC And Laurel Mountain Midstream LLC And Discovery Producer Services LLC [Member] | Measurement Input, Discount Rate [Member]

620.00%

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Weighted Average [Member] | Caiman Energy II And Aux Sable Liquid Products LP [Member] | Measurement Input, EBITDA Multiple [Member]

13.50%

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Weighted Average [Member] | Appalachia Midstream Services LLC And Laurel Mountain Midstream LLC And Discovery Producer Services LLC [Member] | Measurement Input, Discount Rate [Member]

600.00%

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

12.60%

Noncontrolling Interests

Goodwill, Impairment Loss

$ 65

[1]

Following the previously described declining market conditions during the first quarter of 2020, we evaluated these investments for other-than-temporary impairment. The impairments within our Northeast G&P segment are primarily associated with operations in wet-gas areas where producer drilling activities are influenced by NGL prices which historically trend with crude oil prices. The fair values of our investments in Caiman II and Aux Sable Liquid Products LP (Aux Sable) were estimated using a market approach, reflecting valuation multiples ranging from 5.0x to 6.2x EBITDA (weighted-average 6.0x). The fair values of the other investments, including gathering systems that are part of Appalachia Midstream Investments, were estimated using an income approach, with discount rates ranging from 9.7 percent to 13.5 percent (weighted-average 12.6 percent). We also considered any debt held at the investee level, and its impact to fair value. The assumed valuation multiples and industry weighted-average discount rates utilized were both significantly influenced by the market declines previously discussed.

[2]

Following the previously described declining market conditions during the first quarter of 2020, we evaluated these investments for other-than-temporary impairment. The fair value was measured using an income approach. Both investees operate in primarily oil-driven basins where significant expected reductions in producer activities led to reduced estimates of expected future cash flows. Our fair value estimates also reflected discount rates of approximately 17 percent for these investments. We also considered any debt held at the investee level, and its impact to fair value. The industry weighted-average discount rates utilized were significantly influenced by the market declines previously discussed.

Contingent Liabilities (Details) - USD ($) $ in Millions		1 Months Ended
Contingent Liabilities (Details) - USD ($) $ in Millions	May 20, 2016	Jan. 31, 2020	Jun. 30, 2021
Loss Contingencies [Line Items]
Accrued environmental loss liabilities			$ 31
Former Alaska Refinery [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Awarded, Value		$ 86
Energy Transfer Merger [Member]
Loss Contingencies [Line Items]
Loss contingency, damages sought, value	$ 1,480
Gas Pipeline [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities			4
Natural Gas Under Ground Storage Facilities [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities			8
Former Operations [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities			$ 19

Segment Disclosures Reconciliation of Segment Revenues to Consolidated (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Segment revenues
Revenues	$ 2,283	$ 1,781	$ 4,895	$ 3,694
Intersegment Elimination [Member]
Segment revenues
Revenues	(120)	(58)	(241)	(119)
Operating Segments [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues	900	834	1,812	1,720
Operating Segments [Member] \| Northeast G And P [Member]
Segment revenues
Revenues	399	356	792	745
Operating Segments [Member] \| West [Member]
Segment revenues
Revenues	1,052	640	2,417	1,331
Operating Segments [Member] \| Other [Member]
Segment revenues
Revenues	52	9	115	17
Service [Member]
Segment revenues
Revenues	1,460	1,446	2,912	2,920
Service [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues	811	783	1,633	1,597
Service [Member] \| Northeast G And P [Member]
Segment revenues
Revenues	364	342	711	686
Service [Member] \| West [Member]
Segment revenues
Revenues	280	316	559	627
Service [Member] \| Other [Member]
Segment revenues
Revenues	5	5	9	10
Service [Member] \| Intersegment Elimination [Member]
Segment revenues
Revenues	(35)	(28)	(66)	(60)
Service [Member] \| Intersegment Elimination [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues	(12)	(12)	(24)	(27)
Service [Member] \| Intersegment Elimination [Member] \| Northeast G And P [Member]
Segment revenues
Revenues	(9)	(12)	(20)	(26)
Service [Member] \| Intersegment Elimination [Member] \| West [Member]
Segment revenues
Revenues	(11)	0	(16)	0
Service [Member] \| Intersegment Elimination [Member] \| Other [Member]
Segment revenues
Revenues	(3)	(4)	(6)	(7)
Service [Member] \| Operating Segments [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues	823	795	1,657	1,624
Service [Member] \| Operating Segments [Member] \| Northeast G And P [Member]
Segment revenues
Revenues	373	354	731	712
Service [Member] \| Operating Segments [Member] \| West [Member]
Segment revenues
Revenues	291	316	575	627
Service [Member] \| Operating Segments [Member] \| Other [Member]
Segment revenues
Revenues	8	9	15	17
NonRegulated Service Commodity Consideration [Member]
Segment revenues
Revenues	51	25	100	53
NonRegulated Service Commodity Consideration [Member] \| Intersegment Elimination [Member]
Segment revenues
Revenues	0	0	0	0
NonRegulated Service Commodity Consideration [Member] \| Operating Segments [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues	10	3	21	8
NonRegulated Service Commodity Consideration [Member] \| Operating Segments [Member] \| Northeast G And P [Member]
Segment revenues
Revenues	2	1	5	3
NonRegulated Service Commodity Consideration [Member] \| Operating Segments [Member] \| West [Member]
Segment revenues
Revenues	39	21	74	42
NonRegulated Service Commodity Consideration [Member] \| Operating Segments [Member] \| Other [Member]
Segment revenues
Revenues	0	0	0	0
Product [Member]
Segment revenues
Revenues	772	310	1,883	721
Product [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues	47	29	87	70
Product [Member] \| Northeast G And P [Member]
Segment revenues
Revenues	8	(8)	12	15
Product [Member] \| West [Member]
Segment revenues
Revenues	696	289	1,714	636
Product [Member] \| Other [Member]
Segment revenues
Revenues	21	0	70	0
Product [Member] \| Intersegment Elimination [Member]
Segment revenues
Revenues	(85)	(30)	(175)	(59)
Product [Member] \| Intersegment Elimination [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues	(20)	(7)	(47)	(18)
Product [Member] \| Intersegment Elimination [Member] \| Northeast G And P [Member]
Segment revenues
Revenues	(16)	(9)	(44)	(15)
Product [Member] \| Intersegment Elimination [Member] \| West [Member]
Segment revenues
Revenues	(26)	(14)	(54)	(26)
Product [Member] \| Intersegment Elimination [Member] \| Other [Member]
Segment revenues
Revenues	(23)	0	(30)	0
Product [Member] \| Operating Segments [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues	67	36	134	88
Product [Member] \| Operating Segments [Member] \| Northeast G And P [Member]
Segment revenues
Revenues	24	1	56	30
Product [Member] \| Operating Segments [Member] \| West [Member]
Segment revenues
Revenues	722	303	1,768	662
Product [Member] \| Operating Segments [Member] \| Other [Member]
Segment revenues
Revenues	$ 44	$ 0	$ 100	$ 0

Segment Disclosures Reconciliation of Segment Assets to Consolidated (Details) - USD ($)
$ in Millions

1 Months Ended

6 Months Ended

Jun. 30, 2021

Feb. 28, 2021

Jun. 30, 2021

Jun. 30, 2020

Dec. 31, 2020

Property, Plant and Equipment, Additions

$ 45,507

$ 44,165

693

$ 581

Transmission And Gulf Of Mexico [Member]

Northeast G And P [Member]

19,575

19,110

14,470

14,569

West [Member]

10,448

10,558

Other [Member]

Other [Member] | 2021 Wamsutter Field Acquisition

2,570

^[1]

2,570

^[1]

927

Payments to Acquire Productive Assets

$ 79

Property, Plant and Equipment, Additions

257

290

Asset Retirement Obligation, Liabilities Incurred

125

$ 207

Increase (Decrease) in Accounts and Other Receivables

Intersegment Elimination [Member]