The Williams Companies, Inc. (WMB) 10-Q31 Oct 222022 Q3 Quarterly reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
Document and Entity Information - shares	Sep. 30, 2022	Oct. 27, 2022
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2022
Document Transition Report	false
Entity File Number	1-4174
Entity Registrant Name	WILLIAMS COMPANIES, INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	73-0569878
Entity Address, Address Line One	One Williams Center
Entity Address, City or Town	Tulsa
Entity Address, State or Province	OK
Entity Address, Postal Zip Code	74172-0172
City Area Code	800
Local Phone Number	945-5426
Title of 12(b) Security	Common Stock, $1.00 par value
Trading Symbol	WMB
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		1,218,339,828
Entity Central Index Key	0000107263
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31

Consolidated Statement of Incom

Consolidated Statement of Income (Unaudited) - USD ($) shares in Thousands, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Revenues:
Revenues		$ 3,021	$ 2,475	$ 8,035	$ 7,370
Costs and expenses:
Operating and maintenance expenses		486	409	1,345	1,148
Depreciation and amortization expenses		500	487	1,504	1,388
Selling, general, and administrative expenses		163	152	477	389
Other (income) expense – net		33	1	14	12
Total costs and expenses		2,201	2,120	6,089	5,676
Operating income (loss)		820	355	1,946	1,694
Equity earnings (losses)		193	157	492	423
Other investing income (loss) – net		1	2	4	6
Interest incurred		(296)	(295)	(871)	(892)
Interest capitalized		5	3	13	8
Other income (expense) – net		(6)	4	5	4
Income (loss) before income taxes		717	226	1,589	1,243
Less: Provision (benefit) for income taxes		96	53	169	313
Net income (loss)		621	173	1,420	930
Less: Net income (loss) attributable to noncontrolling interests		21	8	40	35
Net income (loss) attributable to The Williams Companies, Inc.		600	165	1,380	895
Less: Preferred stock dividends		1	1	2	2
Net income (loss) available to common stockholders		$ 599	$ 164	$ 1,378	$ 893
Basic earnings (loss) per common share:
Net income (loss)		$ 0.49	$ 0.14	$ 1.13	$ 0.74
Weighted-average shares (thousands)		1,218,964	1,215,434	1,218,202	1,215,113
Diluted earnings (loss) per common share:
Net income (loss)		$ 0.49	$ 0.13	$ 1.13	$ 0.73
Weighted-average shares (thousands)		1,222,472	1,217,979	1,222,153	1,217,558
Service [Member]
Revenues:
Revenues		$ 1,685	$ 1,506	$ 4,828	$ 4,418
NonRegulated Service Commodity Consideration [Member]
Revenues:
Revenues		60	64	223	164
Product [Member]
Revenues:
Revenues		1,260	1,296	3,475	3,229
Energy Commodities and Service
Revenues:
Revenues	[1]	16	(391)	(491)	(441)
Oil and Gas, Purchased [Member]
Costs and expenses:
Product costs		990	1,043	2,650	2,672
Natural Gas Purchased For Shrink [Member]
Costs and expenses:
Product costs		$ 29	$ 28	$ 99	$ 67

[1]We record transactions that qualify as derivatives at fair value with changes in fair value recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses on derivatives held for energy trading purposes are presented on a net basis in revenue.

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income (Loss) (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Comprehensive income (loss):
Net income (loss)	$ 621	$ 173	$ 1,420	$ 930
Designated cash flow hedging activities:
Net unrealized gain (loss) from derivative instruments, net of taxes of $3 and $1 in 2022 and $5 and $14 in 2021	(8)	(17)	(3)	(43)
Reclassifications into earnings of net derivative instruments (gain) loss, net of taxes of $— and $— in 2022 and ($5) and ($7) in 2021	0	15	0	21
Pension and other postretirement benefits:
Net actuarial gain (loss) arising during the year, net of taxes of ($1) and ($1) in 2022 and $— and $— in 2021	2	0	2	0
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 2022 and ($1) and ($3) in 2021	2	3	7	9
Other comprehensive income (loss)	(4)	1	6	(13)
Comprehensive income (loss)	617	174	1,426	917
Less: Comprehensive income (loss) attributable to noncontrolling interests	21	8	40	35
Comprehensive income (loss) attributable to The Williams Companies, Inc.	$ 596	$ 166	$ 1,386	$ 882

Consolidated Statement of Com_2

Consolidated Statement of Comprehensive Income (Loss) (Parenthetical) (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), after Reclassification, Tax [Abstract]
Energy commodity contracts	$ 3	$ 5	$ 1	$ 14
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification, Tax	0	(5)	0	(7)
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	(1)	0	(1)	0
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Tax	$ (1)	$ (1)	$ (2)	$ (3)

Consolidated Balance Sheet (Una

Consolidated Balance Sheet (Unaudited) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Current assets:
Cash and cash equivalents	$ 859	$ 1,680
Trade accounts and other receivables	2,674	1,986
Allowance for doubtful accounts	(15)	(8)
Trade accounts and other receivables – net	2,659	1,978
Inventories	447	379
Derivative assets	201	301
Other current assets and deferred charges	272	211
Total current assets	4,438	4,549
Investments	5,066	5,127
Property, plant, and equipment	46,186	44,184
Accumulated depreciation and amortization	(15,848)	(14,926)
Property, plant, and equipment – net	30,338	29,258
Intangible assets – net of accumulated amortization	7,493	7,402
Regulatory assets, deferred charges, and other	1,337	1,276
Total assets	48,672	47,612
Current liabilities:
Accounts payable	2,613	1,746
Accrued liabilities	1,527	1,201
Long-term debt due within one year	877	2,025
Total current liabilities	5,017	4,972
Long-term debt	22,530	21,650
Deferred income tax liabilities	2,637	2,453
Regulatory liabilities, deferred income, and other	4,578	4,436
Contingent liabilities and commitments (Note 11)
Stockholders’ equity:
Preferred stock ($1 par value; 30 million shares authorized at September 30, 2022 and December 31, 2021; 35,000 shares issued at September 30, 2022 and December 31, 2021)	35	35
Common stock ($1 par value; 1,470 million shares authorized at September 30, 2022 and December 31, 2021; 1,253 million shares issued at September 30, 2022 and 1,250 million shares issued at December 31, 2021)	1,253	1,250
Capital in excess of par value	24,527	24,449
Retained deficit	(13,419)	(13,237)
Accumulated other comprehensive income (loss)	(27)	(33)
Treasury stock, at cost (35 million shares of common stock)	(1,050)	(1,041)
Total stockholders’ equity	11,319	11,423
Noncontrolling interests in consolidated subsidiaries	2,591	2,678
Total equity	13,910	14,101
Total liabilities and equity	$ 48,672	$ 47,612

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) (Unaudited) - $ / shares	Sep. 30, 2022	Dec. 31, 2021
Stockholders’ equity:
Common stock, par value of shares authorized	$ 1	$ 1
Common stock, shares authorized	1,470,000,000	1,470,000,000
Common stock, shares issued	1,253,000,000	1,250,000,000
Treasury stock, shares of common stock	35,000,000	35,000,000
Preferred Stock, Par or Stated Value Per Share	$ 1	$ 1
Preferred Stock, Shares Authorized	30,000,000	30,000,000
Preferred Stock, Shares Issued	35,000	35,000

Consolidated Statement of Chang

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, 2020	$ 14,583	$ 11,769	$ 35	$ 1,248	$ 24,371	$ (12,748)	$ (96)	$ (1,041)	$ 2,814
Net income (loss)	930	895	0	0	0	895	0	0	35
Other comprehensive income (loss)	(13)	(13)	0	0	0	0	(13)	0	0
Cash dividends – common stock ($1.275 per share)	(1,494)	(1,494)	0	0	0	(1,494)	0	0	0
Dividends and distributions to noncontrolling interests	(135)	0	0	0	0	0	0	0	(135)
Stock-based compensation and related common stock issuances, net of tax	54	54	0	1	53	0	0	0	0
Purchase of partial interest in consolidated subsidiary	(3)	0	0	0	0	0	0	0	(3)
Contributions from noncontrolling interests	9	0	0	0	0	0	0	0	9
Other	(12)	(13)	0	0	1	(14)	0	0	1
Net increase (decrease) in equity	(664)	(571)	0	1	54	(613)	(13)	0	(93)
Period End at Sep. 30, 2021	13,919	11,198	35	1,249	24,425	(13,361)	(109)	(1,041)	2,721
Period Start at Jun. 30, 2021	14,265	11,512	35	1,249	24,401	(13,022)	(110)	(1,041)	2,753
Net income (loss)	173	165	0	0	0	165	0	0	8
Other comprehensive income (loss)	1	1	0	0	0	0	1	0	0
Cash dividends – common stock ($1.275 per share)	(498)	(498)	0	0	0	(498)	0	0	0
Dividends and distributions to noncontrolling interests	(40)	0	0	0	0	0	0	0	(40)
Stock-based compensation and related common stock issuances, net of tax	23	23	0	0	23	0	0	0	0
Purchase of partial interest in consolidated subsidiary	(3)	0	0	0	0	0	0	0	(3)
Contributions from noncontrolling interests	3	0	0	0	0	0	0	0	3
Other	(5)	(5)	0	0	1	(6)	0	0	0
Net increase (decrease) in equity	(346)	(314)	0	0	24	(339)	1	0	(32)
Period End at Sep. 30, 2021	13,919	11,198	35	1,249	24,425	(13,361)	(109)	(1,041)	2,721
Period Start at Dec. 31, 2021	14,101	11,423	35	1,250	24,449	(13,237)	(33)	(1,041)	2,678
Net income (loss)	1,420	1,380	0	0	0	1,380	0	0	40
Other comprehensive income (loss)	6	6	0	0	0	0	6	0	0
Cash dividends – common stock ($1.275 per share)	(1,553)	(1,553)	0	0	0	(1,553)	0	0	0
Dividends and distributions to noncontrolling interests	(141)	0	0	0	0	0	0	0	(141)
Stock-based compensation and related common stock issuances, net of tax	82	82	0	3	79	0	0	0	0
Contributions from noncontrolling interests	15	0	0	0	0	0	0	0	15
Purchase of treasury stock	(9)	(9)	0	0	0	0	0	(9)	0
Other	(11)	(10)	0	0	(1)	(9)	0	0	(1)
Net increase (decrease) in equity	(191)	(104)	0	3	78	(182)	6	(9)	(87)
Period End at Sep. 30, 2022	13,910	11,319	35	1,253	24,527	(13,419)	(27)	(1,050)	2,591
Period Start at Jun. 30, 2022	13,836	11,226	35	1,253	24,500	(13,498)	(23)	(1,041)	2,610
Net income (loss)	621	600	0	0	0	600	0	0	21
Other comprehensive income (loss)	(4)	(4)	0	0	0	0	(4)	0	0
Cash dividends – common stock ($1.275 per share)	(518)	(518)	0	0	0	(518)	0	0	0
Dividends and distributions to noncontrolling interests	(46)	0	0	0	0	0	0	0	(46)
Stock-based compensation and related common stock issuances, net of tax	28	28	0	0	28	0	0	0	0
Contributions from noncontrolling interests	7	0	0	0	0	0	0	0	7
Purchase of treasury stock	(9)	(9)	0	0	0	0	0	(9)	0
Other	(5)	(4)	0	0	(1)	(3)	0	0	(1)
Net increase (decrease) in equity	74	93	0	0	27	79	(4)	(9)	(19)
Period End at Sep. 30, 2022	$ 13,910	$ 11,319	$ 35	$ 1,253	$ 24,527	$ (13,419)	$ (27)	$ (1,050)	$ 2,591

Consolidated Statement of Cha_2

Consolidated Statement of Changes in Equity (Parenthetical) (Unaudited) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Common Stock, Dividends, Per Share, Declared	$ 0.425	$ 0.41	$ 1.275	$ 1.23

Consolidated Statement of Cash

Consolidated Statement of Cash Flows (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021
OPERATING ACTIVITIES:
Net income (loss)	$ 1,420	$ 930
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation and amortization	1,504	1,388
Provision (benefit) for deferred income taxes	182	313
Equity (earnings) losses	(492)	(423)
Distributions from unconsolidated affiliates	688	574
Net unrealized (gain) loss from derivative instruments	329	317
Amortization of stock-based awards	58	60
Cash provided (used) by changes in current assets and liabilities:
Accounts receivable	(672)	(538)
Inventories	(76)	(112)
Other current assets and deferred charges	(62)	(67)
Accounts payable	743	570
Accrued liabilities	167	67
Changes in current and noncurrent derivative assets and liabilities	86	(267)
Other, including changes in noncurrent assets and liabilities	(205)	(6)
Net cash provided (used) by operating activities	3,670	2,806
FINANCING ACTIVITIES:
Proceeds from long-term debt	1,752	898
Payments of long-term debt	(2,019)	(887)
Proceeds from issuance of common stock	53	6
Common dividends paid	(1,553)	(1,494)
Dividends and distributions paid to noncontrolling interests	(141)	(135)
Contributions from noncontrolling interests	15	6
Payments for debt issuance costs	(14)	(7)
Other – net	(49)	(13)
Net cash provided (used) by financing activities	(1,956)	(1,626)
INVESTING ACTIVITIES:
Capital expenditures (1)	(1,447)	(957)
Dispositions – net	(19)	5
Contributions in aid of construction	8	46
Purchases of businesses, net of cash acquired (Note 3)	(933)	(126)
Purchases of and contributions to equity-method investments	(140)	(79)
Other – net	(4)	3
Net cash provided (used) by investing activities	(2,535)	(1,108)
Increase (decrease) in cash and cash equivalents	(821)	72
Cash and cash equivalents at beginning of year	1,680	142
Cash and cash equivalents at end of period	859	214
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
(1) Increases to property, plant, and equipment	(1,549)	(1,001)
Changes in related accounts payable and accrued liabilities	102	44
Capital expenditures	$ (1,447)	$ (957)

General, Description of Busines

General, Description of Business, and Basis of Presentation	9 Months Ended
General, Description of Business, and Basis of Presentation	Sep. 30, 2022
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 our consolidated financial statements and notes thereto for the year ended December 31, 2021, in Exhibit 99.1 of our Form 8-K dated May 2, 2022. 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 our 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. Effective January 1, 2022, following an organizational realignment, our natural gas liquids (NGLs) and natural gas marketing services, previously reported within the West segment, along with the former Sequent segment, are now all managed within the Gas & NGL Marketing Services segment. As a result, beginning with the reporting of first-quarter 2022, our operations are presented within the following reportable segments: Transmission & Gulf of Mexico, Northeast G&P, West, and Gas & NGL Marketing Services, consistent with the manner in which our chief operating decision maker evaluates performance and allocates resources. All remaining business activities, including our upstream operations, as well as corporate activities are included in Other. Prior period segment disclosures have been recast for the new segment presentation. Additionally, beginning in 2022 and concurrent with the integration of our legacy gas marketing operations and the marketing operations acquired in the Sequent Acquisition (see Note 3 – Acquisitions), all natural gas marketing revenues from Gas & NGL Marketing Services are presented net of the related costs of those activities in our Consolidated Statement of Income, as subsequent to the integration the entire natural gas marketing portfolio is considered held for trading purposes which requires net presentation . Transmission & Gulf of Mexico is comprised of our interstate natural gas pipelines and complimentary natural gas storage facilities within 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), a 50 percent equity-method investment in Gulfstream Natural Gas System, L.L.C. (Gulfstream), and a 60 percent equity-method investment in Discovery Producer Services LLC (Discovery). Transmission & Gulf of Mexico also includes natural gas storage facilities and pipelines providing services in north Texas. 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), 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 east Texas and northwest Louisiana, and the Mid-Continent region which includes the Anadarko and Permian basins. This segment also includes our NGL 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 (OPPL), 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 equity-method investment in Brazos Permian II, LLC (Brazos Permian II). Gas & NGL Marketing Services is comprised of our NGL and natural gas marketing and trading operations, which includes risk management and the storage and transportation of natural gas on strategically positioned assets, including our Transco system. Basis of Presentation Significant risks and uncertainties We believe that the carrying value of certain of our property, plant, and equipment and 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 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

Variable Interest Entities	9 Months Ended
Variable Interest Entities	Sep. 30, 2022
Variable Interest Entity Disclosures [Abstract]
Variable Interest Entities [Text Block]	Note 2 – Variable Interest Entities Consolidated VIEs As of September 30, 2022, 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. The following table presents amounts included in our Consolidated Balance Sheet that are only for the use or obligation of our consolidated VIEs: September 30, December 31, (Millions) Assets (liabilities): Cash and cash equivalents $ 53 $ 78 Trade accounts and other receivables – net 142 132 Inventories 3 3 Other current assets and deferred charges 6 7 Property, plant, and equipment – net 5,155 5,295 Intangible assets – net of accumulated amortization 2,186 2,267 Regulatory assets, deferred charges, and other 29 20 Accounts payable (74) (61) Accrued liabilities (28) (29) Regulatory liabilities, deferred income, and other (282) (287) Nonconsolidated VIEs Targa Train 7 We own a 20 percent interest in Targa Train 7, which provides fractionation services at Mont Belvieu, Texas, and is a VIE due primarily to our limited participating rights as the minority equity holder. At September 30, 2022, the carrying value of our investment in Targa Train 7 was $46 million. Our maximum exposure to loss is limited to the carrying value of our investment.

Acquisitions

Acquisitions	9 Months Ended
Acquisitions	Sep. 30, 2022
Business Combinations [Abstract]
Acquisitions [Text Block]	Note 3 – Acquisitions Trace Acquisition On April 29, 2022, we closed on the acquisition of 100 percent of Gemini Arklatex, LLC through which we acquired the Haynesville Shale region gas gathering and related assets of Trace Midstream (Trace Acquisition) for $972 million of cash funded with cash on hand and proceeds from issuance of commercial paper, subject to post-closing adjustments. The purpose of the Trace Acquisition was to expand our footprint into the east Texas area of the Haynesville Shale region, increasing in-basin scale in one of the largest growth basins in the country. During the period from the acquisition date of April 29, 2022 to September 30, 2022, the operations acquired in the Trace Acquisition contributed Revenues of $99 million and Modified EBITDA (as defined in Note 12 – Segment Disclosures) of $48 million. Costs related to the Trace Acquisition of $8 million are reported within our West segment and included in Selling, general, and administrative expenses in our Consolidated Statement of Income. We accounted for the Trace Acquisition as a business combination, which requires, among other things, that identifiable assets acquired and liabilities assumed be recognized at their acquisition date fair values. The valuation techniques used consisted of the income approach (excess earnings method) for valuation of intangible assets and depreciated replacement costs for property, plant, and equipment. The following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired, which are included in the West segment, and liabilities assumed at April 29, 2022. The fair value of accounts receivable acquired equals contractual amounts receivable. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily intangible assets and property, plant, and equipment; however, adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date, as new information related to facts and circumstances as of the acquisition date may be identified. After the June 30, 2022, financial statements were issued, we received an updated valuation report from a third-party valuation firm resulting in an increase of $11 million in property, plant, and equipment and a decrease of $11 million in intangible assets. (Millions) Cash and cash equivalents $ 39 Trade accounts and other receivables – net 18 Property, plant, and equipment – net 448 Intangible assets – net of accumulated amortization 472 Other noncurrent assets 20 Total assets acquired $ 997 Accounts payable $ 12 Accrued liabilities 5 Other noncurrent liabilities 8 Total liabilities assumed $ 25 Net assets acquired $ 972 Intangible assets Intangible assets recognized in the Trace Acquisition are related to contractual customer relationships from gas gathering agreements with our customers. The basis for determining the value of these intangible assets is estimated future net cash flows to be derived from acquired contractual customer relationships discounted using a risk-adjusted discount rate. These intangible assets are being amortized on a straight-line basis over an initial period of 20 years which represents the term over which the contractual customer relationships are expected to contribute to our cash flows. Approximately 2 percent of the expected future revenues from these contractual customer relationships are impacted by our ability and intent to renew or renegotiate existing customer contracts. We expense costs incurred to renew or extend the terms of our gas gathering contracts with customers. Based on the estimated future revenues during the current contract periods (as estimated at the time of the acquisition), the weighted-average period prior to the next renewal or extension of the existing contractual customer relationships is approximately 19 years. Sequent Acquisition On July 1, 2021, we closed on the acquisition of 100 percent of Sequent Energy Management, L.P. and Sequent Energy Canada, Corp (Sequent Acquisition). Total consideration for this acquisition was $159 million, which included $109 million related to working capital. The purpose of the Sequent Acquisition was to expand our natural gas marketing activities as well as optimize our pipeline and storage capabilities with expansions into new markets to reach incremental gas-fired power generation, liquified natural gas exports, and future renewable natural gas and other emerging opportunities. During the period from the acquisition date of July 1, 2021 to December 31, 2021, results for the operations acquired in the Sequent Acquisition included net product sales of $(43) million (including $80 million of purchases from affiliates), net loss on commodity derivatives of $43 million, and unfavorable Modified EBITDA of $112 million. Both the Revenues and Modified EBITDA amounts reflect a net unrealized loss on commodity derivatives of $109 million for the period. Costs related to the Sequent Acquisition for the period from the acquisition date of July 1, 2021 to December 31, 2021 of $5 million were included in Selling, general, and administrative expenses in our Consolidated Statement of Income for the year ended December 31, 2021. We accounted for the Sequent Acquisition as a business combination. The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired, which are included in the Gas & NGL Marketing Services segment, and liabilities assumed at July 1, 2021. The fair value of accounts receivable acquired equals contractual amounts receivable. The fair value of the intangible assets were measured using an income approach. The inventory acquired relates to natural gas in underground storage. The fair value of this inventory was based on the market price of the underlying commodity at the acquisition date. See Note 9 – Fair Value Measurements and Guarantees for the valuation techniques used to measure fair value of derivative assets and liabilities. (Millions) Cash and cash equivalents $ 8 Trade accounts and other receivables – net 498 Inventories 121 Other current assets and deferred charges 4 Commodity derivatives included in Other current assets and deferred charges 57 Property, plant, and equipment – net 5 Intangible assets – net of accumulated amortization 306 Other noncurrent assets 3 Commodity derivatives included in other noncurrent assets 49 Total assets acquired $ 1,051 Accounts payable $ 514 Accrued liabilities 46 Commodity derivatives included in Accrued liabilities 116 Other noncurrent liabilities 1 Commodity derivatives included in other noncurrent liabilities 215 Total liabilities assumed $ 892 Net assets acquired $ 159 Intangible assets Intangible assets are primarily related to transportation and storage capacity contracts. The basis for determining the value of these intangible assets was estimated future net cash flows to be derived from acquired transportation and storage capacity contracts that provide future economic benefits due to their market location, discounted using an industry weighted-average cost of capital. This intangible asset is being amortized based on the expected benefit period over which the underlying contracts are expected to contribute to our cash flows ranging from 1 year to 8 years. As a result, we expect a significant portion of the amortization to be recognized within the first few years of this range. Supplemental Pro Forma The following pro forma Revenues and Net income (loss) attributable to The Williams Companies, Inc. for the three months ended September 30, 2021 and nine months ended September 30, 2022 and 2021, are presented as if the Trace Acquisition had been completed on January 1, 2021, and the Sequent Acquisition had been completed on January 1, 2020. These pro forma amounts are not necessarily indicative of what the actual results would have been if the Trace Acquisition and Sequent Acquisition had in fact occurred on the dates or for the periods indicated, nor do they purport to project Revenues or Net income (loss) attributable to The Williams Companies, Inc. for any future periods or as of any date. These amounts do not give effect to any potential cost savings, operating synergies, or revenue enhancements to result from the transaction or the potential costs to achieve these cost savings, operating synergies, and revenue enhancements. Three Months Ended September 30, 2021 As Reported Pro Forma Trace Pro Forma Combined (Millions) Revenues $ 2,475 $ 31 $ 2,506 Net income (loss) attributable to The Williams Companies, Inc. 165 11 176 Nine Months Ended September 30, 2022 As Reported Pro Forma Trace (1) Pro Forma Combined (Millions) Revenues $ 8,035 $ 45 $ 8,080 Net income (loss) attributable to The Williams Companies, Inc. 1,380 18 1,398 Nine Months Ended September 30, 2021 As Reported Pro Forma Trace Pro Forma Sequent (2) Pro Forma Combined (Millions) Revenues $ 7,370 $ 86 $ 188 $ 7,644 Net income (loss) attributable to The Williams Companies, Inc. 895 31 4 930 (1) Excludes results from operations acquired in the Trace Acquisition for the period beginning on the acquisition date of April 29, 2022, as these results are included in the amounts as reported. (2) Excludes results from operations acquired in the Sequent Acquisition for the period beginning on the acquisition date of July 1, 2021, as these results are included in the amounts as reported. Seasonality can impact natural gas usage and operating results; thus, the results for the operations acquired in the Sequent Acquisition for interim periods are not necessarily indicative of annual results and can vary significantly from quarter to quarter. Purchase of North Texas Assets On August 31, 2022, we purchased a group of assets in north Texas, primarily natural gas storage facilities and pipelines, from NorTex Midstream Holdings, LLC (NorTex Asset Purchase) for approximately $424 million. These assets are included in the Transmission & Gulf of Mexico segment.

Revenue Recognition

Revenue Recognition	9 Months Ended
Revenue Recognition	Sep. 30, 2022
Revenue Recognition [Abstract]
Revenue Recognition [Text Block]	Note 4 – Revenue Recognition Revenue by Category The following table presents our revenue disaggregated by major service line: Transco Northwest Pipeline Gulf of Mexico Midstream and Storage Northeast Midstream West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Three Months Ended September 30, 2022 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 685 $ 109 $ — $ — $ — $ — $ — $ (18) $ 776 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — — 99 354 407 — — (50) 810 Commodity consideration — — 11 2 47 — — — 60 Other 3 — 9 57 15 1 — (5) 80 Total service revenues 688 109 119 413 469 1 — (73) 1,726 Product sales 81 — 51 40 245 3,109 238 (523) 3,241 Total revenues from contracts with customers 769 109 170 453 714 3,110 238 (596) 4,967 Other revenues (1) 3 — 3 6 (6) 2,607 (23) (1) 2,589 Other adjustments (2) — — — — — (4,779) — 244 (4,535) Total revenues $ 772 $ 109 $ 173 $ 459 $ 708 $ 938 $ 215 $ (353) $ 3,021 Three Months Ended September 30, 2021 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 642 $ 107 $ — $ — $ — $ — $ — $ (12) $ 737 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — — 74 340 306 — — (37) 683 Commodity consideration — — 13 (1) 52 — — — 64 Other 3 — 5 52 12 — — (6) 66 Total service revenues 645 107 92 391 370 — — (55) 1,550 Product sales 20 — 72 19 184 2,140 116 (353) 2,198 Total revenues from contracts with customers 665 107 164 410 554 2,140 116 (408) 3,748 Other revenues (1) 1 1 3 7 (23) 873 (18) (3) 841 Other adjustments (2) — — — — — (2,131) — 17 (2,114) Total revenues $ 666 $ 108 $ 167 $ 417 $ 531 $ 882 $ 98 $ (394) $ 2,475 Transco Northwest Pipeline Gulf of Mexico Midstream and Storage Northeast Midstream West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Nine Months Ended September 30, 2022 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 2,014 $ 329 $ — $ — $ — $ — $ — $ (54) $ 2,289 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — — 265 1,027 1,089 — — (114) 2,267 Commodity consideration — — 54 12 157 — — — 223 Other 8 — 21 162 41 2 — (16) 218 Total service revenues 2,022 329 340 1,201 1,287 2 — (184) 4,997 Product sales 140 — 215 110 684 8,422 522 (1,442) 8,651 Total revenues from contracts with customers 2,162 329 555 1,311 1,971 8,424 522 (1,626) 13,648 Other revenues (1) 6 2 7 19 (14) 5,838 (72) (10) 5,776 Other adjustments (2) — — — — — (11,911) — 522 (11,389) Total revenues $ 2,168 $ 331 $ 562 $ 1,330 $ 1,957 $ 2,351 $ 450 $ (1,114) $ 8,035 Nine Months Ended September 30, 2021 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 1,880 $ 328 $ — $ — $ — $ — $ — $ (17) $ 2,191 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — — 250 966 860 — — (98) 1,978 Commodity consideration — — 34 4 126 — — — 164 Other 8 — 15 145 40 2 — (15) 195 Total service revenues 1,888 328 299 1,115 1,026 2 — (130) 4,528 Product sales 50 — 178 75 441 3,955 216 (796) 4,119 Total revenues from contracts with customers 1,938 328 477 1,190 1,467 3,957 216 (926) 8,647 Other revenues (1) 3 1 8 19 (17) 835 (3) (9) 837 Other adjustments (2) — — — — — (2,131) — 17 (2,114) Total revenues $ 1,941 $ 329 $ 485 $ 1,209 $ 1,450 $ 2,661 $ 213 $ (918) $ 7,370 ______________________________ (1) Revenues not derived from contracts with customers primarily 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 our Consolidated Statement of Income, and realized and unrealized gains and losses associated with our derivative contracts, which are reported in Net gain (loss) on commodity derivatives in our Consolidated Statement of Income. (2) Other adjustments reflect certain costs of Gas & NGL Marketing Services’ risk management activities. As we are acting as agent for natural gas marketing customers, the resulting revenues are presented net of the related costs of those activities in our Consolidated Statement of Income. In addition, the related derivatives qualify as held for trading purposes, which requires net presentation. (See Note 1 – General, Description of Business, and Basis of Presentation.) Contract Assets The following table presents a reconciliation of our contract assets: Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Balance at beginning of period $ 48 $ 38 $ 22 $ 12 Revenue recognized in excess of amounts invoiced 54 51 158 134 Minimum volume commitments invoiced (41) (39) (119) (96) Balance at end of period $ 61 $ 50 $ 61 $ 50 Contract Liabilities The following table presents a reconciliation of our contract liabilities: Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Balance at beginning of period $ 1,115 $ 1,193 $ 1,126 $ 1,209 Payments received and deferred 34 14 144 99 Significant financing component 2 3 7 8 Contract liability acquired 2 1 2 1 Recognized in revenue (71) (48) (197) (154) Balance at end of period $ 1,082 $ 1,163 $ 1,082 $ 1,163 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 (MVC) 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 September 30, 2022, 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 September 30, 2022, 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 September 30, 2022. Contract Liabilities Remaining Performance Obligations (Millions) 2022 (three months) $ 52 $ 916 2023 (one year) 154 3,610 2024 (one year) 126 3,340 2025 (one year) 118 3,015 2026 (one year) 105 2,517 Thereafter 527 17,191 Total $ 1,082 $ 30,589 Accounts Receivable The following is a summary of our Trade accounts and other receivables – net : September 30, 2022 December 31, 2021 (Millions) Accounts receivable related to revenues from contracts with customers $ 1,824 $ 1,451 Receivables from derivatives 788 462 Other accounts receivable 47 65 Trade accounts and other receivables – net $ 2,659 $ 1,978

Provision (Benefit) for Income

Provision (Benefit) for Income Taxes	9 Months Ended
Provision (Benefit) for Income Taxes	Sep. 30, 2022
Income Tax Disclosure [Abstract]
Provision (Benefit) for Income Taxes [Text Block]	Note 5 – Provision (Benefit) for Income Taxes The Provision (benefit) for income taxes includes: Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Current: Federal $ — $ 1 $ (27) $ (1) State 4 1 14 1 4 2 (13) — Deferred: Federal 163 40 247 240 State (71) 11 (65) 73 92 51 182 313 Provision (benefit) for income taxes $ 96 $ 53 $ 169 $ 313 The effective income tax rate for the total provision (benefit) for the three months ended September 30, 2022, is less than the federal statutory rate primarily due to the effect of state income taxes, including a $92 million state income tax benefit related to a decrease in our estimate of the deferred state income tax rate (net of federal effect) driven primarily by the enacted decline in the Pennsylvania state income tax rate over the next several years, partially offset by a $23 million unfavorable revision to a state net operating loss carryforward (net of federal benefit). The effective income tax rate for the total provision (benefit) for the nine months ended September 30, 2022, is less than the federal statutory rate primarily due to the release of a valuation allowance on foreign tax credits, the effect of state income taxes, including a $92 million state income tax benefit related to a decrease in our estimate of the deferred state income tax rate (net of federal effect), and federal settlements. The effective income tax rates for the total provision (benefit) for the three and nine months ended September 30, 2021, are greater than the federal statutory rate, primarily due to the effect of state income taxes. We have a valuation allowance on certain deferred income tax assets that serves to reduce those assets to amounts that will, more likely than not, be realized. We must evaluate whether we will ultimately realize these tax benefits considering all available positive and negative evidence, which incorporates management’s assessment of available tax planning strategies, future reversals of existing taxable temporary differences, and the availability and character of future taxable income. During the second quarter of 2022, we released $88 million of valuation allowance upon determining we expect to utilize an additional $70 million of foreign tax credits and $18 million related to various state net operating loss carryforwards and state credits. During the second quarter of 2022, we finalized settlements for 2011 through 2014 on certain contested matters with the Internal Revenue Service (IRS). These settlements resulted in decreasing our unrecognized tax positions of approximately $46 million, which favorably impacted the Provision (benefit) for income taxes . We anticipate receiving $3 million of cash refunds (net of payments) from the IRS related to these items in 2022.

Earnings (Loss) Per Common Shar

Earnings (Loss) Per Common Share	9 Months Ended
Earnings (Loss) Per Common Share	Sep. 30, 2022
Earnings Per Share [Abstract]
Earnings (Loss) Per Common Share [Text Block]	Note 6 – Earnings (Loss) Per Common Share Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Dollars in millions, except per-share Net income (loss) available to common stockholders $ 599 $ 164 $ 1,378 $ 893 Basic weighted-average shares 1,218,964 1,215,434 1,218,202 1,215,113 Effect of dilutive securities: Nonvested restricted stock units 3,269 2,539 3,682 2,437 Stock options 239 6 269 8 Diluted weighted-average shares 1,222,472 1,217,979 1,222,153 1,217,558 Earnings (loss) per common share: Basic $ .49 $ .14 $ 1.13 $ .74 Diluted $ .49 $ .13 $ 1.13 $ .73

Employee Benefit Plans

Employee Benefit Plans	9 Months Ended
Employee Benefit Plans	Sep. 30, 2022
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 Nine Months Ended 2022 2021 2022 2021 (Millions) Components of net periodic benefit cost (credit): Service cost $ 7 $ 8 $ 21 $ 23 Interest cost 8 7 23 21 Expected return on plan assets (11) (11) (33) (33) Amortization of net actuarial loss 3 4 9 11 Net actuarial loss from settlements — — — 1 Net periodic benefit cost (credit) $ 7 $ 8 $ 20 $ 23 Other Postretirement Benefits Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Components of net periodic benefit cost (credit): Service cost $ 1 $ 1 $ 1 $ 1 Interest cost 1 1 4 4 Expected return on plan assets (3) (2) (8) (7) Reclassification to regulatory liability — — 1 1 Net periodic benefit cost (credit) $ (1) $ — $ (2) $ (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 our Consolidated Statement of Income.

Debt and Banking Arrangements

Debt and Banking Arrangements	9 Months Ended
Debt and Banking Arrangements	Sep. 30, 2022
Debt Disclosure [Abstract]
Debt and Banking Arrangements [Text Block]	Note 8 – Debt and Banking Arrangements Long-Term Debt Issuances and retirements On January 18, 2022, we early retired $1.25 billion of 3.6 percent senior unsecured notes due March 15, 2022. On May 16, 2022, we early retired $750 million of 3.35 percent senior unsecured notes due August 15, 2022. On August 8, 2022, we issued $1.0 billion of 4.65 percent senior unsecured notes due August 15, 2032, and $750 million of 5.30 percent senior unsecured notes due August 15, 2052. On October 17, 2022, we early retired $850 million of 3.7 percent senior unsecured notes due January 15, 2023. Commercial Paper Program At September 30, 2022, no commercial paper was outstanding under our $3.5 billion commercial paper program. Credit Facility September 30, 2022 Stated Capacity Outstanding (Millions) Long-term credit facility (1) $ 3,750 $ — Letters of credit under certain bilateral bank agreements 40 (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.

Fair Value Measurements and Gua

Fair Value Measurements and Guarantees	9 Months Ended
Fair Value Measurements and Guarantees	Sep. 30, 2022
Fair Value Disclosures [Abstract]
Fair Value Measurements and Guarantees [Text Block]	Note 9 – 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, 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 Fair Quoted Significant Significant (Millions) Assets (liabilities) at September 30, 2022: Measured on a recurring basis: ARO Trust investments $ 216 $ 216 $ 216 $ — $ — Commodity derivative assets (1) 95 95 3 54 38 Commodity derivative liabilities (1) (815) (815) (54) (717) (44) Other financial assets (liabilities) – net (11) (11) — (11) — Additional disclosures: Long-term debt, including current portion (23,407) (21,911) — (21,911) — Guarantees (38) (25) — (9) (16) Assets (liabilities) at December 31, 2021: Measured on a recurring basis: ARO Trust investments $ 260 $ 260 $ 260 $ — $ — Commodity derivative assets (2) 84 84 2 81 1 Commodity derivative liabilities (2) (488) (488) (69) (403) (16) Other financial assets (liabilities) – net (7) (7) — (7) — Additional disclosures: Long-term debt, including current portion (23,675) (27,768) — (27,768) — Guarantees (39) (26) — (10) (16) (1) Net commodity derivative assets and liabilities exclude $210 million of net cash collateral in Level 1. (2) Net commodity derivative assets and liabilities exclude $296 million of net cash collateral in Level 1. 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 our Consolidated Balance Sheet. Both realized and unrealized gains and losses are ultimately recorded as regulatory assets or liabilities. Commodity derivatives : Commodity derivatives include exchange-traded contracts and over-the-counter (OTC) contracts, which consist of physical forwards, futures, and swaps that are measured at fair value on a recurring basis. We also have other derivatives related to asset management agreements and other contracts that require physical delivery. Derivatives classified as Level 1 are valued using New York Mercantile Exchange (NYMEX) futures prices. Derivatives classified as Level 2 are valued using basis transactions that represent the cost to transport natural gas from a NYMEX delivery point to the contract delivery point. These transactions are based on quotes obtained either through electronic trading platforms or directly from brokers. Derivatives classified as Level 3 are valued using a combination of observable and unobservable inputs. The fair value amounts are presented on a net basis and reflect the netting of asset and liability positions permitted under the terms of our master netting arrangements and cash held on deposit in margin accounts that we have received or remitted to collateralize certain derivative positions. Commodity derivative assets are reported in Derivative assets and Regulatory assets, deferred charges, and other in our Consolidated Balance Sheet. Commodity derivative liabilities are reported in Accrued liabilities and Regulatory liabilities, deferred income, and other in our Consolidated Balance Sheet. Changes in the fair value of our derivative assets and liabilities are recorded in Net gain (loss) on commodity derivatives and Net processing commodity expenses in our Consolidated Statement of Income. See Note 10 – Derivatives for additional information on our derivatives. 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, Leidy South, 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 our Consolidated Balance Sheet. The maximum potential undiscounted exposure is approximately $24 million at September 30, 2022. 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 our 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.

Derivatives

Derivatives	9 Months Ended
Derivatives	Sep. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives [Text Block]	Note 10 – Derivatives Commodity-Related Derivatives We are exposed to commodity price risk. To manage this volatility, we use various contracts in our marketing and trading activities that generally meet the definition of derivatives. Derivative positions are monitored using techniques including, but not limited to value at risk. Derivative instruments are recognized at fair value in our Consolidated Balance Sheet as either assets or liabilities and are presented on a net basis by counterparty, net of margin deposits. See Note 9 – Fair Value Measurements and Guarantees for additional fair value information. In our Consolidated Statement of Cash Flows, any cash impacts of settled commodity-related derivatives are recorded as operating activities. We enter into commodity-related derivatives to economically hedge exposures to natural gas, NGLs, and crude oil and retain exposure to price changes that can, in a volatile energy market, be material and can adversely affect our results of operations. At September 30, 2022, the notional volume of the net long (short) positions for our commodity-related derivative contracts were as follows: Commodity Unit of Measure Net Long (Short) Position Index Risk Natural Gas MMBtu 485,699,255 Central Hub Risk - Henry Hub Natural Gas MMBtu (58,780,281) Basis Risk Natural Gas MMBtu (60,614,348) Central Hub Risk - Mont Belvieu Natural Gas Liquids Barrels (52,710,000) Basis Risk Natural Gas Liquids Barrels (2,520,000) Central Hub Risk - WTI Crude Oil Barrels (216,000) Derivative Financial Statement Presentation The fair value of commodity-related derivatives, which are not designated as hedging instruments for accounting purposes, was reflected as follows: September 30, December 31, Derivative Category Assets (Liabilities) Assets (Liabilities) (Millions) Current $ 1,144 $ (1,475) $ 619 $ (760) Noncurrent 328 (717) 166 (429) Total derivatives $ 1,472 $ (2,192) $ 785 $ (1,189) Gross amounts recognized $ 1,472 $ (2,192) $ 785 $ (1,189) Counterparty and collateral netting offset (1,246) 1,456 (476) 772 Amounts recognized in our Consolidated Balance Sheet $ 226 $ (736) $ 309 $ (417) For the three and nine months ended September 30, 2022 and 2021 the pre-tax effects of commodity-related derivatives in Net gain (loss) on commodity derivatives reflected within Total revenues and Net processing commodity expenses in our Consolidated Statement of Income were as follows: Gain (Loss) Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Realized commodity-related derivatives designated as hedging instruments $ — $ (20) $ — $ (28) Realized commodity-related derivatives not designated as hedging instruments (13) (62) (145) (96) Unrealized commodity-related derivatives not designated as hedging instruments 29 (309) (346) (317) Net gain (loss) on commodity derivatives $ 16 $ (391) $ (491) $ (441) Realized commodity-related derivatives not designated as hedging instruments in Net processing commodity expenses $ 6 $ 1 $ 12 $ 1 Unrealized commodity-related derivatives not designated as hedging instruments in Net processing commodity expenses $ 6 $ — $ 17 $ — Contingent Features Generally, collateral may be provided by a parent guaranty, letter of credit, or cash. If collateral is required, fair value amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral are offset against fair value amounts recognized for derivatives executed with the same counterparty. We have specific trade and credit contracts that contain minimum credit rating requirements. These credit rating requirements typically give counterparties the right to suspend or terminate credit if our credit ratings are downgraded to non-investment grade status. Under such circumstances, we would need to post collateral to continue transacting business with these counterparties. As of September 30, 2022, the contractually required collateral in the event of a credit rating downgrade to non-investment grade status was $18 million. We maintain accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, we may be required to deposit cash into these accounts. At September 30, 2022, net cash collateral held on deposit in broker margin accounts was $210 million.

Contingent Liabilities

Contingent Liabilities	9 Months Ended
Contingent Liabilities	Sep. 30, 2022
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 putative class actions against us, our former affiliate WPX Energy, Inc. (WPX) and its subsidiaries, and others alleging the manipulation of published gas price indices in 2000 and 2002 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. We reached an agreement to settle two of the class actions, and on August 5, 2019, the final judgment of dismissal with prejudice was entered. We also reached an agreement to settle the individual action and on January 18, 2022, it was dismissed. On March 30, 2017, the Nevada federal district 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 plaintiff’s 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, where the plaintiffs re-urged their motion for class certification. Two putative class actions remain unresolved and they have been remanded to their originally filed court, the Wisconsin federal district court, where the plaintiffs again re-urged their motion for class certification. Trial was scheduled to begin June 14, 2021, but the court struck the setting due to the pending motion for class certification. On June 28, 2022, the court granted plaintiffs’ motion for class certification. On July 12, 2022, defendants filed a petition for permission to appeal the order with the United States Court of Appeals for the Seventh Circuit and a motion to stay with the trial court. We reached an agreement to resolve the two remaining actions, which the court must approve. We have fully accrued for the preliminary settlement agreement. 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. Oral argument was held on December 15, 2021. 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. On August 23, 2021, the court approved the settlement, but two objectors filed an appeal with the United States Court of Appeals for the Fifth Circuit. 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. Trial was held May 10 through May 17, 2021. On December 29, 2021, the court entered judgment in our favor in the amount of $410 million, plus interest at the contractual rate, and our reasonable attorneys’ fees and expenses. On September 21, 2022, the court entered a final order and judgment awarding us the termination fee, attorney’s fees, expenses, and interest in the amount of $602 million plus additional interest starting September 17, 2022. Energy Transfer has appealed to the Delaware Supreme Court. 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 September 30, 2022, we have accrued liabilities totaling $32 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 September 30, 2022, 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 propose and promulgate 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, reviews and updates to the National Ambient Air Quality Standards, and rules for new and existing source performance standards for volatile organic compound and methane. We continuously monitor these regulatory changes and how they may impact our operations. Implementation of new or modified regulations may result in impacts to our operations and increase the cost of additions to Property, plant, and equipment – net in our Consolidated Balance Sheet for both new and existing facilities in affected areas; however, due to regulatory uncertainty on final rule content and applicability timeframes, we are unable to reasonably estimate the cost of these regulatory impacts at this time. 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 September 30, 2022, 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 September 30, 2022, we have accrued liabilities totaling $10 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 September 30, 2022, we have accrued environmental liabilities of $18 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 September 30, 2022, 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

Segment Disclosures

Segment Disclosures	9 Months Ended
Segment Disclosures	Sep. 30, 2022
Segment Reporting [Abstract]
Segment Disclosures [Text Block]	Note 12 – Segment Disclosures Our reportable segments are Transmission & Gulf of Mexico, Northeast G&P, West, and Gas & NGL Marketing Services. 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); ◦ Other investing income (loss) – net; ◦ 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 Modified EBITDA to Net income (loss) as reported in our Consolidated Statement of Income. Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Modified EBITDA by segment: Transmission & Gulf of Mexico $ 638 $ 630 $ 1,987 $ 1,936 Northeast G&P 464 442 1,332 1,253 West 337 257 885 702 Gas & NGL Marketing Services (1) 20 (262) (249) (161) Other 140 38 284 91 1,599 1,105 4,239 3,821 Accretion expense associated with asset retirement obligations for nonregulated operations (12) (12) (36) (33) Depreciation and amortization expenses (500) (487) (1,504) (1,388) Equity earnings (losses) 193 157 492 423 Other investing income (loss) – net 1 2 4 6 Proportional Modified EBITDA of equity-method investments (273) (247) (748) (702) Interest expense (291) (292) (858) (884) (Provision) benefit for income taxes (96) (53) (169) (313) Net income (loss) $ 621 $ 173 $ 1,420 $ 930 _____________ (1) Modified EBITDA for the three and nine months ended September 30, 2022, includes charges of $64 million and $76 million associated with lower of cost or net realizable value adjustments to our inventory. These charges are reflected in Product Sales and Product costs in our Consolidated Statement of Income. The following table reflects the reconciliation of Segment revenues to Total revenues as reported in our Consolidated Statement of Income. Transmission Northeast G&P West Gas & NGL Marketing Services (1) Other Eliminations Total (Millions) Three Months Ended September 30, 2022 Segment revenues: Service revenues External $ 880 $ 408 $ 393 $ 1 $ 3 $ — $ 1,685 Internal 30 9 32 — 3 (74) — Total service revenues 910 417 425 1 6 (74) 1,685 Total service revenues – commodity consideration 11 2 47 — — — 60 Product sales External 78 11 61 1,079 31 — 1,260 Internal 43 29 184 (195) 207 (268) — Total product sales 121 40 245 884 238 (268) 1,260 Net gain (loss) on commodity derivatives Realized — — (9) 54 (58) — (13) Unrealized 1 — — (1) 29 — 29 Total net gain (loss) on commodity derivatives (2) 1 — (9) 53 (29) — 16 Total revenues $ 1,043 $ 459 $ 708 $ 938 $ 215 $ (342) $ 3,021 Three Months Ended September 30, 2021 Segment revenues: Service revenues External $ 812 $ 390 $ 300 $ — $ 4 $ — $ 1,506 Internal 24 9 20 — 4 (57) — Total service revenues 836 399 320 — 8 (57) 1,506 Total service revenues – commodity consideration 13 (1) 52 — — — 64 Product sales External 54 (1) 13 1,183 47 — 1,296 Internal 34 20 164 51 64 (333) — Total product sales 88 19 177 1,234 111 (333) 1,296 Net gain (loss) on commodity derivatives Realized — — (18) (58) (6) — (82) Unrealized — — — (294) (15) — (309) Total net gain (loss) on commodity derivatives (2) — — (18) (352) (21) — (391) Total revenues $ 937 $ 417 $ 531 $ 882 $ 98 $ (390) $ 2,475 Transmission Northeast G&P West Gas & NGL Marketing Services (1) Other Eliminations Total (Millions) Nine Months Ended September 30, 2022 Segment revenues: Service revenues External $ 2,563 $ 1,178 $ 1,073 $ 2 $ 12 $ — $ 4,828 Internal 88 30 66 — 10 (194) — Total service revenues 2,651 1,208 1,139 2 22 (194) 4,828 Total service revenues – commodity consideration 54 12 157 — — — 223 Product sales External 187 24 111 3,073 80 — 3,475 Internal 147 86 573 (349) 442 (899) — Total product sales 334 110 684 2,724 522 (899) 3,475 Net gain (loss) on commodity derivatives Realized — — (23) (18) (104) — (145) Unrealized 1 — — (357) 10 — (346) Total net gain (loss) on commodity derivatives (2) 1 — (23) (375) (94) — (491) Total revenues $ 3,040 $ 1,330 $ 1,957 $ 2,351 $ 450 $ (1,093) $ 8,035 Nine Months Ended September 30, 2021 Segment revenues: Service revenues External $ 2,445 $ 1,101 $ 857 $ 2 $ 13 $ — $ 4,418 Internal 48 29 51 — 10 (138) — Total service revenues 2,493 1,130 908 2 23 (138) 4,418 Total service revenues – commodity consideration 34 4 126 — — — 164 Product sales External 141 11 43 2,912 122 — 3,229 Internal 81 64 398 137 94 (774) — Total product sales 222 75 441 3,049 216 (774) 3,229 Net gain (loss) on commodity derivatives Realized — — (25) (93) (6) — (124) Unrealized — — — (297) (20) — (317) Total net gain (loss) on commodity derivatives (2) — — (25) (390) (26) — (441) Total revenues $ 2,749 $ 1,209 $ 1,450 $ 2,661 $ 213 $ (912) $ 7,370 _____________ (1) See Note 1 – General, Description of Business, and Basis of Presentation.

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	9 Months Ended
Variable Interest Entities (Tables)	Sep. 30, 2022
Variable Interest Entity Disclosures [Abstract]
Schedule of Variable Interest Entities [Table Text Block]	The following table presents amounts included in our Consolidated Balance Sheet that are only for the use or obligation of our consolidated VIEs: September 30, December 31, (Millions) Assets (liabilities): Cash and cash equivalents $ 53 $ 78 Trade accounts and other receivables – net 142 132 Inventories 3 3 Other current assets and deferred charges 6 7 Property, plant, and equipment – net 5,155 5,295 Intangible assets – net of accumulated amortization 2,186 2,267 Regulatory assets, deferred charges, and other 29 20 Accounts payable (74) (61) Accrued liabilities (28) (29) Regulatory liabilities, deferred income, and other (282) (287)

Acquisitions (Tables)

Acquisitions (Tables)	9 Months Ended
Acquisitions (Tables)	Sep. 30, 2022
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Information	The following pro forma Revenues and Net income (loss) attributable to The Williams Companies, Inc. for the three months ended September 30, 2021 and nine months ended September 30, 2022 and 2021, are presented as if the Trace Acquisition had been completed on January 1, 2021, and the Sequent Acquisition had been completed on January 1, 2020. These pro forma amounts are not necessarily indicative of what the actual results would have been if the Trace Acquisition and Sequent Acquisition had in fact occurred on the dates or for the periods indicated, nor do they purport to project Revenues or Net income (loss) attributable to The Williams Companies, Inc. for any future periods or as of any date. These amounts do not give effect to any potential cost savings, operating synergies, or revenue enhancements to result from the transaction or the potential costs to achieve these cost savings, operating synergies, and revenue enhancements. Three Months Ended September 30, 2021 As Reported Pro Forma Trace Pro Forma Combined (Millions) Revenues $ 2,475 $ 31 $ 2,506 Net income (loss) attributable to The Williams Companies, Inc. 165 11 176 Nine Months Ended September 30, 2022 As Reported Pro Forma Trace (1) Pro Forma Combined (Millions) Revenues $ 8,035 $ 45 $ 8,080 Net income (loss) attributable to The Williams Companies, Inc. 1,380 18 1,398 Nine Months Ended September 30, 2021 As Reported Pro Forma Trace Pro Forma Sequent (2) Pro Forma Combined (Millions) Revenues $ 7,370 $ 86 $ 188 $ 7,644 Net income (loss) attributable to The Williams Companies, Inc. 895 31 4 930 (1) Excludes results from operations acquired in the Trace Acquisition for the period beginning on the acquisition date of April 29, 2022, as these results are included in the amounts as reported. (2) Excludes results from operations acquired in the Sequent Acquisition for the period beginning on the acquisition date of July 1, 2021, as these results are included in the amounts as reported.
Trace Midstream Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table presents the preliminary allocation of the acquisition date fair value of the major classes of the assets acquired, which are included in the West segment, and liabilities assumed at April 29, 2022. The fair value of accounts receivable acquired equals contractual amounts receivable. The allocation is considered preliminary because the valuation work has not been completed due to the ongoing review of the valuation results and validation of significant inputs and assumptions. Preliminary fair value measurements were made for certain acquired assets and liabilities, primarily intangible assets and property, plant, and equipment; however, adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date, as new information related to facts and circumstances as of the acquisition date may be identified. After the June 30, 2022, financial statements were issued, we received an updated valuation report from a third-party valuation firm resulting in an increase of $11 million in property, plant, and equipment and a decrease of $11 million in intangible assets. (Millions) Cash and cash equivalents $ 39 Trade accounts and other receivables – net 18 Property, plant, and equipment – net 448 Intangible assets – net of accumulated amortization 472 Other noncurrent assets 20 Total assets acquired $ 997 Accounts payable $ 12 Accrued liabilities 5 Other noncurrent liabilities 8 Total liabilities assumed $ 25 Net assets acquired $ 972
Sequent Acquisition
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	We accounted for the Sequent Acquisition as a business combination. The following table presents the allocation of the acquisition date fair value of the major classes of the assets acquired, which are included in the Gas & NGL Marketing Services segment, and liabilities assumed at July 1, 2021. The fair value of accounts receivable acquired equals contractual amounts receivable. The fair value of the intangible assets were measured using an income approach. The inventory acquired relates to natural gas in underground storage. The fair value of this inventory was based on the market price of the underlying commodity at the acquisition date. See Note 9 – Fair Value Measurements and Guarantees for the valuation techniques used to measure fair value of derivative assets and liabilities. (Millions) Cash and cash equivalents $ 8 Trade accounts and other receivables – net 498 Inventories 121 Other current assets and deferred charges 4 Commodity derivatives included in Other current assets and deferred charges 57 Property, plant, and equipment – net 5 Intangible assets – net of accumulated amortization 306 Other noncurrent assets 3 Commodity derivatives included in other noncurrent assets 49 Total assets acquired $ 1,051 Accounts payable $ 514 Accrued liabilities 46 Commodity derivatives included in Accrued liabilities 116 Other noncurrent liabilities 1 Commodity derivatives included in other noncurrent liabilities 215 Total liabilities assumed $ 892 Net assets acquired $ 159

Revenue Recognition (Tables)

Revenue Recognition (Tables)	9 Months Ended
Revenue Recognition (Tables)	Sep. 30, 2022
Revenue Recognition [Abstract]
Disaggregation of Revenue [Table Text Block]	The following table presents our revenue disaggregated by major service line: Transco Northwest Pipeline Gulf of Mexico Midstream and Storage Northeast Midstream West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Three Months Ended September 30, 2022 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 685 $ 109 $ — $ — $ — $ — $ — $ (18) $ 776 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — — 99 354 407 — — (50) 810 Commodity consideration — — 11 2 47 — — — 60 Other 3 — 9 57 15 1 — (5) 80 Total service revenues 688 109 119 413 469 1 — (73) 1,726 Product sales 81 — 51 40 245 3,109 238 (523) 3,241 Total revenues from contracts with customers 769 109 170 453 714 3,110 238 (596) 4,967 Other revenues (1) 3 — 3 6 (6) 2,607 (23) (1) 2,589 Other adjustments (2) — — — — — (4,779) — 244 (4,535) Total revenues $ 772 $ 109 $ 173 $ 459 $ 708 $ 938 $ 215 $ (353) $ 3,021 Three Months Ended September 30, 2021 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 642 $ 107 $ — $ — $ — $ — $ — $ (12) $ 737 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — — 74 340 306 — — (37) 683 Commodity consideration — — 13 (1) 52 — — — 64 Other 3 — 5 52 12 — — (6) 66 Total service revenues 645 107 92 391 370 — — (55) 1,550 Product sales 20 — 72 19 184 2,140 116 (353) 2,198 Total revenues from contracts with customers 665 107 164 410 554 2,140 116 (408) 3,748 Other revenues (1) 1 1 3 7 (23) 873 (18) (3) 841 Other adjustments (2) — — — — — (2,131) — 17 (2,114) Total revenues $ 666 $ 108 $ 167 $ 417 $ 531 $ 882 $ 98 $ (394) $ 2,475 Transco Northwest Pipeline Gulf of Mexico Midstream and Storage Northeast Midstream West Midstream Gas & NGL Marketing Services Other Eliminations Total (Millions) Nine Months Ended September 30, 2022 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 2,014 $ 329 $ — $ — $ — $ — $ — $ (54) $ 2,289 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — — 265 1,027 1,089 — — (114) 2,267 Commodity consideration — — 54 12 157 — — — 223 Other 8 — 21 162 41 2 — (16) 218 Total service revenues 2,022 329 340 1,201 1,287 2 — (184) 4,997 Product sales 140 — 215 110 684 8,422 522 (1,442) 8,651 Total revenues from contracts with customers 2,162 329 555 1,311 1,971 8,424 522 (1,626) 13,648 Other revenues (1) 6 2 7 19 (14) 5,838 (72) (10) 5,776 Other adjustments (2) — — — — — (11,911) — 522 (11,389) Total revenues $ 2,168 $ 331 $ 562 $ 1,330 $ 1,957 $ 2,351 $ 450 $ (1,114) $ 8,035 Nine Months Ended September 30, 2021 Revenues from contracts with customers: Service revenues: Regulated interstate natural gas transportation and storage $ 1,880 $ 328 $ — $ — $ — $ — $ — $ (17) $ 2,191 Gathering, processing, transportation, fractionation, and storage: Monetary consideration — — 250 966 860 — — (98) 1,978 Commodity consideration — — 34 4 126 — — — 164 Other 8 — 15 145 40 2 — (15) 195 Total service revenues 1,888 328 299 1,115 1,026 2 — (130) 4,528 Product sales 50 — 178 75 441 3,955 216 (796) 4,119 Total revenues from contracts with customers 1,938 328 477 1,190 1,467 3,957 216 (926) 8,647 Other revenues (1) 3 1 8 19 (17) 835 (3) (9) 837 Other adjustments (2) — — — — — (2,131) — 17 (2,114) Total revenues $ 1,941 $ 329 $ 485 $ 1,209 $ 1,450 $ 2,661 $ 213 $ (918) $ 7,370 ______________________________ (1) Revenues not derived from contracts with customers primarily 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 our Consolidated Statement of Income, and realized and unrealized gains and losses associated with our derivative contracts, which are reported in Net gain (loss) on commodity derivatives in our Consolidated Statement of Income. (2) Other adjustments reflect certain costs of Gas & NGL Marketing Services’ risk management activities. As we are acting as agent for natural gas marketing customers, the resulting revenues are presented net of the related costs of those activities in our Consolidated Statement of Income. In addition, the related derivatives qualify as held for trading purposes, which requires net presentation. (See Note 1 – General, Description of Business, and Basis of Presentation.)
Contract with Customer, Asset and Liability [Table Text Block]	The following table presents a reconciliation of our contract assets: Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Balance at beginning of period $ 48 $ 38 $ 22 $ 12 Revenue recognized in excess of amounts invoiced 54 51 158 134 Minimum volume commitments invoiced (41) (39) (119) (96) Balance at end of period $ 61 $ 50 $ 61 $ 50 Contract Liabilities The following table presents a reconciliation of our contract liabilities: Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Balance at beginning of period $ 1,115 $ 1,193 $ 1,126 $ 1,209 Payments received and deferred 34 14 144 99 Significant financing component 2 3 7 8 Contract liability acquired 2 1 2 1 Recognized in revenue (71) (48) (197) (154) Balance at end of period $ 1,082 $ 1,163 $ 1,082 $ 1,163
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]	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 September 30, 2022. Contract Liabilities Remaining Performance Obligations (Millions) 2022 (three months) $ 52 $ 916 2023 (one year) 154 3,610 2024 (one year) 126 3,340 2025 (one year) 118 3,015 2026 (one year) 105 2,517 Thereafter 527 17,191 Total $ 1,082 $ 30,589
Contract With Customer Accounts Receivable [Table Text Block]	The following is a summary of our Trade accounts and other receivables – net : September 30, 2022 December 31, 2021 (Millions) Accounts receivable related to revenues from contracts with customers $ 1,824 $ 1,451 Receivables from derivatives 788 462 Other accounts receivable 47 65 Trade accounts and other receivables – net $ 2,659 $ 1,978

Provision (Benefit) for Incom_2

Provision (Benefit) for Income Taxes (Tables)	9 Months Ended
Provision (Benefit) for Income Taxes (Tables)	Sep. 30, 2022
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 Nine Months Ended 2022 2021 2022 2021 (Millions) Current: Federal $ — $ 1 $ (27) $ (1) State 4 1 14 1 4 2 (13) — Deferred: Federal 163 40 247 240 State (71) 11 (65) 73 92 51 182 313 Provision (benefit) for income taxes $ 96 $ 53 $ 169 $ 313

Earnings (Loss) Per Common Sh_2

Earnings (Loss) Per Common Share (Tables)	9 Months Ended
Earnings (Loss) Per Common Share (Tables)	Sep. 30, 2022
Earnings Per Share [Abstract]
Earnings (Loss) Per Common Share [Table Text Block]	Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Dollars in millions, except per-share Net income (loss) available to common stockholders $ 599 $ 164 $ 1,378 $ 893 Basic weighted-average shares 1,218,964 1,215,434 1,218,202 1,215,113 Effect of dilutive securities: Nonvested restricted stock units 3,269 2,539 3,682 2,437 Stock options 239 6 269 8 Diluted weighted-average shares 1,222,472 1,217,979 1,222,153 1,217,558 Earnings (loss) per common share: Basic $ .49 $ .14 $ 1.13 $ .74 Diluted $ .49 $ .13 $ 1.13 $ .73

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	9 Months Ended
Employee Benefit Plans (Tables)	Sep. 30, 2022
Retirement Benefits [Abstract]
Schedule of Net Benefit Costs [Table Text Block]	Net periodic benefit cost (credit) is as follows: Pension Benefits Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Components of net periodic benefit cost (credit): Service cost $ 7 $ 8 $ 21 $ 23 Interest cost 8 7 23 21 Expected return on plan assets (11) (11) (33) (33) Amortization of net actuarial loss 3 4 9 11 Net actuarial loss from settlements — — — 1 Net periodic benefit cost (credit) $ 7 $ 8 $ 20 $ 23 Other Postretirement Benefits Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Components of net periodic benefit cost (credit): Service cost $ 1 $ 1 $ 1 $ 1 Interest cost 1 1 4 4 Expected return on plan assets (3) (2) (8) (7) Reclassification to regulatory liability — — 1 1 Net periodic benefit cost (credit) $ (1) $ — $ (2) $ (1)

Debt and Banking Arrangements (

Debt and Banking Arrangements (Tables)	9 Months Ended
Debt and Banking Arrangements (Tables)	Sep. 30, 2022
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities [Table Text Block]	Credit Facility September 30, 2022 Stated Capacity Outstanding (Millions) Long-term credit facility (1) $ 3,750 $ — Letters of credit under certain bilateral bank agreements 40 (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.

Fair Value Measurements and G_2

Fair Value Measurements and Guarantees (Tables)	9 Months Ended
Fair Value Measurements and Guarantees (Tables)	Sep. 30, 2022
Fair Value Disclosures [Abstract]
Fair Value Assets and Liabilities Measured On Recurring Basis [Table Text Block]	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, 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 Fair Quoted Significant Significant (Millions) Assets (liabilities) at September 30, 2022: Measured on a recurring basis: ARO Trust investments $ 216 $ 216 $ 216 $ — $ — Commodity derivative assets (1) 95 95 3 54 38 Commodity derivative liabilities (1) (815) (815) (54) (717) (44) Other financial assets (liabilities) – net (11) (11) — (11) — Additional disclosures: Long-term debt, including current portion (23,407) (21,911) — (21,911) — Guarantees (38) (25) — (9) (16) Assets (liabilities) at December 31, 2021: Measured on a recurring basis: ARO Trust investments $ 260 $ 260 $ 260 $ — $ — Commodity derivative assets (2) 84 84 2 81 1 Commodity derivative liabilities (2) (488) (488) (69) (403) (16) Other financial assets (liabilities) – net (7) (7) — (7) — Additional disclosures: Long-term debt, including current portion (23,675) (27,768) — (27,768) — Guarantees (39) (26) — (10) (16) (1) Net commodity derivative assets and liabilities exclude $210 million of net cash collateral in Level 1. (2) Net commodity derivative assets and liabilities exclude $296 million of net cash collateral in Level 1.

Derivatives (Tables)

Derivatives (Tables)	9 Months Ended
Derivatives (Tables)	Sep. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	At September 30, 2022, the notional volume of the net long (short) positions for our commodity-related derivative contracts were as follows: Commodity Unit of Measure Net Long (Short) Position Index Risk Natural Gas MMBtu 485,699,255 Central Hub Risk - Henry Hub Natural Gas MMBtu (58,780,281) Basis Risk Natural Gas MMBtu (60,614,348) Central Hub Risk - Mont Belvieu Natural Gas Liquids Barrels (52,710,000) Basis Risk Natural Gas Liquids Barrels (2,520,000) Central Hub Risk - WTI Crude Oil Barrels (216,000)
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location	The fair value of commodity-related derivatives, which are not designated as hedging instruments for accounting purposes, was reflected as follows: September 30, December 31, Derivative Category Assets (Liabilities) Assets (Liabilities) (Millions) Current $ 1,144 $ (1,475) $ 619 $ (760) Noncurrent 328 (717) 166 (429) Total derivatives $ 1,472 $ (2,192) $ 785 $ (1,189) Gross amounts recognized $ 1,472 $ (2,192) $ 785 $ (1,189) Counterparty and collateral netting offset (1,246) 1,456 (476) 772 Amounts recognized in our Consolidated Balance Sheet $ 226 $ (736) $ 309 $ (417)
Pretax Effect Of Interest Rate And Energy Related Derivatives	For the three and nine months ended September 30, 2022 and 2021 the pre-tax effects of commodity-related derivatives in Net gain (loss) on commodity derivatives reflected within Total revenues and Net processing commodity expenses in our Consolidated Statement of Income were as follows: Gain (Loss) Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Realized commodity-related derivatives designated as hedging instruments $ — $ (20) $ — $ (28) Realized commodity-related derivatives not designated as hedging instruments (13) (62) (145) (96) Unrealized commodity-related derivatives not designated as hedging instruments 29 (309) (346) (317) Net gain (loss) on commodity derivatives $ 16 $ (391) $ (491) $ (441) Realized commodity-related derivatives not designated as hedging instruments in Net processing commodity expenses $ 6 $ 1 $ 12 $ 1 Unrealized commodity-related derivatives not designated as hedging instruments in Net processing commodity expenses $ 6 $ — $ 17 $ —

Segment Disclosures (Tables)

Segment Disclosures (Tables)	9 Months Ended
Segment Disclosures (Tables)	Sep. 30, 2022
Segment Reporting [Abstract]
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 our Consolidated Statement of Income. Three Months Ended Nine Months Ended 2022 2021 2022 2021 (Millions) Modified EBITDA by segment: Transmission & Gulf of Mexico $ 638 $ 630 $ 1,987 $ 1,936 Northeast G&P 464 442 1,332 1,253 West 337 257 885 702 Gas & NGL Marketing Services (1) 20 (262) (249) (161) Other 140 38 284 91 1,599 1,105 4,239 3,821 Accretion expense associated with asset retirement obligations for nonregulated operations (12) (12) (36) (33) Depreciation and amortization expenses (500) (487) (1,504) (1,388) Equity earnings (losses) 193 157 492 423 Other investing income (loss) – net 1 2 4 6 Proportional Modified EBITDA of equity-method investments (273) (247) (748) (702) Interest expense (291) (292) (858) (884) (Provision) benefit for income taxes (96) (53) (169) (313) Net income (loss) $ 621 $ 173 $ 1,420 $ 930 _____________ (1) Modified EBITDA for the three and nine months ended September 30, 2022, includes charges of $64 million and $76 million associated with lower of cost or net realizable value adjustments to our inventory. These charges are reflected in Product Sales and Product costs
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 our Consolidated Statement of Income. Transmission Northeast G&P West Gas & NGL Marketing Services (1) Other Eliminations Total (Millions) Three Months Ended September 30, 2022 Segment revenues: Service revenues External $ 880 $ 408 $ 393 $ 1 $ 3 $ — $ 1,685 Internal 30 9 32 — 3 (74) — Total service revenues 910 417 425 1 6 (74) 1,685 Total service revenues – commodity consideration 11 2 47 — — — 60 Product sales External 78 11 61 1,079 31 — 1,260 Internal 43 29 184 (195) 207 (268) — Total product sales 121 40 245 884 238 (268) 1,260 Net gain (loss) on commodity derivatives Realized — — (9) 54 (58) — (13) Unrealized 1 — — (1) 29 — 29 Total net gain (loss) on commodity derivatives (2) 1 — (9) 53 (29) — 16 Total revenues $ 1,043 $ 459 $ 708 $ 938 $ 215 $ (342) $ 3,021 Three Months Ended September 30, 2021 Segment revenues: Service revenues External $ 812 $ 390 $ 300 $ — $ 4 $ — $ 1,506 Internal 24 9 20 — 4 (57) — Total service revenues 836 399 320 — 8 (57) 1,506 Total service revenues – commodity consideration 13 (1) 52 — — — 64 Product sales External 54 (1) 13 1,183 47 — 1,296 Internal 34 20 164 51 64 (333) — Total product sales 88 19 177 1,234 111 (333) 1,296 Net gain (loss) on commodity derivatives Realized — — (18) (58) (6) — (82) Unrealized — — — (294) (15) — (309) Total net gain (loss) on commodity derivatives (2) — — (18) (352) (21) — (391) Total revenues $ 937 $ 417 $ 531 $ 882 $ 98 $ (390) $ 2,475 Transmission Northeast G&P West Gas & NGL Marketing Services (1) Other Eliminations Total (Millions) Nine Months Ended September 30, 2022 Segment revenues: Service revenues External $ 2,563 $ 1,178 $ 1,073 $ 2 $ 12 $ — $ 4,828 Internal 88 30 66 — 10 (194) — Total service revenues 2,651 1,208 1,139 2 22 (194) 4,828 Total service revenues – commodity consideration 54 12 157 — — — 223 Product sales External 187 24 111 3,073 80 — 3,475 Internal 147 86 573 (349) 442 (899) — Total product sales 334 110 684 2,724 522 (899) 3,475 Net gain (loss) on commodity derivatives Realized — — (23) (18) (104) — (145) Unrealized 1 — — (357) 10 — (346) Total net gain (loss) on commodity derivatives (2) 1 — (23) (375) (94) — (491) Total revenues $ 3,040 $ 1,330 $ 1,957 $ 2,351 $ 450 $ (1,093) $ 8,035 Nine Months Ended September 30, 2021 Segment revenues: Service revenues External $ 2,445 $ 1,101 $ 857 $ 2 $ 13 $ — $ 4,418 Internal 48 29 51 — 10 (138) — Total service revenues 2,493 1,130 908 2 23 (138) 4,418 Total service revenues – commodity consideration 34 4 126 — — — 164 Product sales External 141 11 43 2,912 122 — 3,229 Internal 81 64 398 137 94 (774) — Total product sales 222 75 441 3,049 216 (774) 3,229 Net gain (loss) on commodity derivatives Realized — — (25) (93) (6) — (124) Unrealized — — — (297) (20) — (317) Total net gain (loss) on commodity derivatives (2) — — (25) (390) (26) — (441) Total revenues $ 2,749 $ 1,209 $ 1,450 $ 2,661 $ 213 $ (912) $ 7,370 _____________ (1) See Note 1 – General, Description of Business, and Basis of Presentation.

General, Description of Busin_2

General, Description of Business, and Basis of Presentation (Details)	9 Months Ended
	Sep. 30, 2022
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%
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%
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%
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%
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%
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%
Discovery Producer Services LLC [Member] \| Transmission And Gulf Of Mexico [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	60%
Laurel Mountain Midstream, LLC [Member] \| Northeast G And P [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	69%
Overland Pass Pipeline Company LLC [Member] \| West [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50%
Rocky Mountain Midstream Holdings LLC [Member] \| West [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50%
Targa Train 7 LLC \| West [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	20%
Blue Racer Midstream LLC \| Northeast G And P [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50%
Brazos Permian II LLC [Member] \| West [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	15%

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Variable Interest Entity [Line Items]
Assets	$ 48,672	$ 47,612
Variable Interest Entity, Primary Beneficiary [Member] \| Cash and cash equivalents [Member]
Variable Interest Entity [Line Items]
Assets	53	78
Variable Interest Entity, Primary Beneficiary [Member] \| Trade accounts and other receivables - net [Member]
Variable Interest Entity [Line Items]
Assets	142	132
Variable Interest Entity, Primary Beneficiary [Member] \| Inventories [Member]
Variable Interest Entity [Line Items]
Assets	3	3
Variable Interest Entity, Primary Beneficiary [Member] \| Other current assets and deferred charges [Member]
Variable Interest Entity [Line Items]
Assets	6	7
Variable Interest Entity, Primary Beneficiary [Member] \| Property, plant, and equipment - net [Member]
Variable Interest Entity [Line Items]
Assets	5,155	5,295
Variable Interest Entity, Primary Beneficiary [Member] \| Intangible assets - net of accumulated amortization [Member]
Variable Interest Entity [Line Items]
Assets	2,186	2,267
Variable Interest Entity, Primary Beneficiary [Member] \| Regulatory assets, deferred charges, and other [Member]
Variable Interest Entity [Line Items]
Assets	29	20
Variable Interest Entity, Primary Beneficiary [Member] \| Accounts payable [Member]
Variable Interest Entity [Line Items]
Liabilities	(74)	(61)
Variable Interest Entity, Primary Beneficiary [Member] \| Accrued liabilities [Member]
Variable Interest Entity [Line Items]
Liabilities	(28)	(29)
Variable Interest Entity, Primary Beneficiary [Member] \| Regulatory liabilities, deferred income, and other [Member]
Variable Interest Entity [Line Items]
Liabilities	$ (282)	$ (287)
Variable Interest Entity, Primary Beneficiary [Member] \| Williams Companies Inc [Member] \| Northeast JV [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	65%
Variable Interest Entity, Primary Beneficiary [Member] \| Williams Companies Inc [Member] \| Gulfstar One [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity Ownership Percentage	51%
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%
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%
Equity Method Investments	$ 46

Acquisitions (Details)

Acquisitions (Details) - USD ($) $ in Millions					3 Months Ended			5 Months Ended	6 Months Ended	9 Months Ended
Acquisitions (Details) - USD ($) $ in Millions		Aug. 31, 2022	Apr. 29, 2022	Jul. 01, 2021	Sep. 30, 2022		Sep. 30, 2021	Sep. 30, 2022	Dec. 31, 2021	Sep. 30, 2022		Sep. 30, 2021
Business Acquisition [Line Items]
Revenues					$ 3,021		$ 2,475			$ 8,035		$ 7,370
Modified EBITDA Earnings Loss					1,599		1,105			4,239		3,821
Net Income (Loss) Attributable to Parent					600		165			1,380		895
Pro Forma
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue							2,506			8,080		7,644
Business Acquisition, Pro Forma Net Income (Loss)							176			1,398		930
Product [Member]
Business Acquisition [Line Items]
Revenues					1,260		1,296			3,475		3,229
Energy Commodities and Service
Business Acquisition [Line Items]
Revenues	[1]				16		(391)			(491)		(441)
Gain (Loss) on Derivative Instruments \| Energy Related Derivative \| Not Designated as Hedging Instrument [Member]
Business Acquisition [Line Items]
Unrealized Gain (Loss) on Derivatives					29		(309)			(346)		(317)
West [Member] \| Product [Member]
Business Acquisition [Line Items]
Revenues					61		13			111		43
West [Member] \| Energy Commodities and Service
Business Acquisition [Line Items]
Revenues	[1]				(9)		(18)			(23)		(25)
West [Member] \| Operating Segments [Member]
Business Acquisition [Line Items]
Revenues					708		531			1,957		1,450
Modified EBITDA Earnings Loss					337		257			885		702
West [Member] \| Operating Segments [Member] \| Product [Member]
Business Acquisition [Line Items]
Revenues					245		177			684		441
Gas & NGL Marketing Services \| Product [Member]
Business Acquisition [Line Items]
Revenues	[2]				1,079		1,183			3,073		2,912
Gas & NGL Marketing Services \| Energy Commodities and Service
Business Acquisition [Line Items]
Revenues	[1],[2]				53		(352)			(375)		(390)
Gas & NGL Marketing Services \| Operating Segments [Member]
Business Acquisition [Line Items]
Revenues	[2]				938		882			2,351		2,661
Modified EBITDA Earnings Loss					20	[3]	(262)			(249)	[3]	(161)
Gas & NGL Marketing Services \| Operating Segments [Member] \| Product [Member]
Business Acquisition [Line Items]
Revenues	[2]				884		1,234			2,724		3,049
Transmission And Gulf Of Mexico [Member] \| NorTex Acquisition [Member]
Business Acquisition [Line Items]
Payments to Acquire Productive Assets		$ 424
Transmission And Gulf Of Mexico [Member] \| Product [Member]
Business Acquisition [Line Items]
Revenues					78		54			187		141
Transmission And Gulf Of Mexico [Member] \| Energy Commodities and Service
Business Acquisition [Line Items]
Revenues	[1]				1		0			1		0
Transmission And Gulf Of Mexico [Member] \| Operating Segments [Member]
Business Acquisition [Line Items]
Revenues					1,043		937			3,040		2,749
Modified EBITDA Earnings Loss					638		630			1,987		1,936
Transmission And Gulf Of Mexico [Member] \| Operating Segments [Member] \| Product [Member]
Business Acquisition [Line Items]
Revenues					121		88			334		222
Trace Midstream Acquisition
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired			100%
Business Combination, Consideration Transferred			$ 972
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Property, Plant, and Equipment					11
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Intangibles					$ (11)
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents			39
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables			18
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment			448
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles			472
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets			20
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets			997
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable			12
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other			5
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other			8
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities			25
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net			$ 972
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life			20 years
Percentage Of Finite Lived Intangible Assets Impacted By Our Intent Or Ability To Renew Or Extend Arrangement			2%
Acquired Finite-lived Intangible Asset, Weighted-Average Period before Renewal or Extension			19 years
Trace Midstream Acquisition \| Pro Forma
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue							31			45	[4]	86
Business Acquisition, Pro Forma Net Income (Loss)							$ 11			18	[4]	31
Trace Midstream Acquisition \| West [Member] \| Selling, general, and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition Related Costs										$ 8
Trace Midstream Acquisition \| West [Member] \| Operating Segments [Member]
Business Acquisition [Line Items]
Revenues								$ 99
Modified EBITDA Earnings Loss								$ 48
Sequent Acquisition
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired				100%
Business Combination, Consideration Transferred				$ 159
Business Combination, Working Capital Acquired				109
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents				8
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables				498
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Inventory				121
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other				4
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment				5
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles				306
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets				3
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets				1,051
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable				514
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other				46
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other				1
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities				892
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net				$ 159
Sequent Acquisition \| Pro Forma
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue	[5]											188
Business Acquisition, Pro Forma Net Income (Loss)	[5]											$ 4
Sequent Acquisition \| Minimum [Member]
Business Acquisition [Line Items]
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life				1 year
Sequent Acquisition \| Maximum [Member]
Business Acquisition [Line Items]
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life				8 years
Sequent Acquisition \| Derivative
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other				$ 57
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets				49
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other				116
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other				$ 215
Sequent Acquisition \| Gas & NGL Marketing Services \| Energy Commodities and Service
Business Acquisition [Line Items]
Revenues									$ (43)
Sequent Acquisition \| Gas & NGL Marketing Services \| Selling, general, and administrative expenses [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition Related Costs									5
Sequent Acquisition \| Gas & NGL Marketing Services \| Gain (Loss) on Derivative Instruments \| Energy Related Derivative \| Not Designated as Hedging Instrument [Member]
Business Acquisition [Line Items]
Unrealized Gain (Loss) on Derivatives									(109)
Sequent Acquisition \| Gas & NGL Marketing Services \| Operating Segments [Member]
Business Acquisition [Line Items]
Modified EBITDA Earnings Loss									(112)
Sequent Acquisition \| Gas & NGL Marketing Services \| Operating Segments [Member] \| Product [Member]
Business Acquisition [Line Items]
Revenues									(43)
Affiliate Costs									$ 80

[1]We record transactions that qualify as derivatives at fair value with changes in fair value recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses on derivatives held for energy trading purposes are presented on a net basis in revenue.[2]See Note 1 – General, Description of Business, and Basis of Presentation.[3] Modified EBITDA for the three and nine months ended September 30, 2022, includes charges of $64 million and $76 million associated with lower of cost or net realizable value adjustments to our inventory. These charges are reflected in Product Sales and Product costs

Revenue Recognition Revenue by

Revenue Recognition Revenue by Category (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ 4,967	$ 3,748	$ 13,648	$ 8,647
Revenue Not from Contract with Customer	[1]	2,589	841	5,776	837
Revenue Not from Contract with Customer, Other	[2]	(4,535)	(2,114)	(11,389)	(2,114)
Total revenues		3,021	2,475	8,035	7,370
Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		776	737	2,289	2,191
NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		810	683	2,267	1,978
NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		60	64	223	164
Total revenues		60	64	223	164
Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		80	66	218	195
Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1,726	1,550	4,997	4,528
Total revenues		1,685	1,506	4,828	4,418
Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		3,241	2,198	8,651	4,119
Total revenues		1,260	1,296	3,475	3,229
Transco [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		769	665	2,162	1,938
Revenue Not from Contract with Customer	[1]	3	1	6	3
Revenue Not from Contract with Customer, Other	[2]	0	0	0	0
Total revenues		772	666	2,168	1,941
Transco [Member] \| Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		685	642	2,014	1,880
Transco [Member] \| NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Transco [Member] \| NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Transco [Member] \| Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		3	3	8	8
Transco [Member] \| Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		688	645	2,022	1,888
Transco [Member] \| Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		81	20	140	50
Northwest Pipeline [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		109	107	329	328
Revenue Not from Contract with Customer	[1]	0	1	2	1
Revenue Not from Contract with Customer, Other	[2]	0	0	0	0
Total revenues		109	108	331	329
Northwest Pipeline [Member] \| Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		109	107	329	328
Northwest Pipeline [Member] \| NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Northwest Pipeline [Member] \| NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Northwest Pipeline [Member] \| Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Northwest Pipeline [Member] \| Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		109	107	329	328
Northwest Pipeline [Member] \| Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Transmission And Gulf Of Mexico Midstream [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		170	164	555	477
Revenue Not from Contract with Customer	[1]	3	3	7	8
Revenue Not from Contract with Customer, Other	[2]	0	0	0	0
Total revenues		173	167	562	485
Transmission And Gulf Of Mexico Midstream [Member] \| Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Transmission And Gulf Of Mexico Midstream [Member] \| NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		99	74	265	250
Transmission And Gulf Of Mexico Midstream [Member] \| NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		11	13	54	34
Transmission And Gulf Of Mexico Midstream [Member] \| Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		9	5	21	15
Transmission And Gulf Of Mexico Midstream [Member] \| Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		119	92	340	299
Transmission And Gulf Of Mexico Midstream [Member] \| Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		51	72	215	178
Northeast Midstream [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		453	410	1,311	1,190
Revenue Not from Contract with Customer	[1]	6	7	19	19
Revenue Not from Contract with Customer, Other	[2]	0	0	0	0
Total revenues		459	417	1,330	1,209
Northeast Midstream [Member] \| Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Northeast Midstream [Member] \| NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		354	340	1,027	966
Northeast Midstream [Member] \| NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		2	(1)	12	4
Northeast Midstream [Member] \| Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		57	52	162	145
Northeast Midstream [Member] \| Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		413	391	1,201	1,115
Northeast Midstream [Member] \| Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		40	19	110	75
West Midstream [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		714	554	1,971	1,467
Revenue Not from Contract with Customer	[1]	(6)	(23)	(14)	(17)
Revenue Not from Contract with Customer, Other	[2]	0	0	0	0
Total revenues		708	531	1,957	1,450
West Midstream [Member] \| Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
West Midstream [Member] \| NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		407	306	1,089	860
West Midstream [Member] \| NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		47	52	157	126
West Midstream [Member] \| Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		15	12	41	40
West Midstream [Member] \| Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		469	370	1,287	1,026
West Midstream [Member] \| Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		245	184	684	441
Gas & NGL Marketing Services
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		3,110	2,140	8,424	3,957
Revenue Not from Contract with Customer	[1]	2,607	873	5,838	835
Revenue Not from Contract with Customer, Other	[2]	(4,779)	(2,131)	(11,911)	(2,131)
Total revenues		938	882	2,351	2,661
Gas & NGL Marketing Services \| Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Gas & NGL Marketing Services \| NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Gas & NGL Marketing Services \| NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Gas & NGL Marketing Services \| Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1	0	2	2
Gas & NGL Marketing Services \| Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		1	0	2	2
Gas & NGL Marketing Services \| Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		3,109	2,140	8,422	3,955
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		238	116	522	216
Revenue Not from Contract with Customer	[1]	(23)	(18)	(72)	(3)
Revenue Not from Contract with Customer, Other	[2]	0	0	0	0
Total revenues		215	98	450	213
Other [Member] \| Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Other [Member] \| NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Other [Member] \| NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Other [Member] \| Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Other [Member] \| Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Other [Member] \| Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		238	116	522	216
Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(596)	(408)	(1,626)	(926)
Revenue Not from Contract with Customer	[1]	(1)	(3)	(10)	(9)
Revenue Not from Contract with Customer, Other	[2]	244	17	522	17
Total revenues		(353)	(394)	(1,114)	(918)
Intersegment Eliminations [Member] \| Regulated Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(18)	(12)	(54)	(17)
Intersegment Eliminations [Member] \| NonRegulated Service Monetary Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(50)	(37)	(114)	(98)
Intersegment Eliminations [Member] \| NonRegulated Service Commodity Consideration [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0	0	0	0
Intersegment Eliminations [Member] \| Other Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(5)	(6)	(16)	(15)
Intersegment Eliminations [Member] \| Service [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		(73)	(55)	(184)	(130)
Intersegment Eliminations [Member] \| Product [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		$ (523)	$ (353)	$ (1,442)	$ (796)

[1] Revenues not derived from contracts with customers primarily 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 our Consolidated Statement of Income, and realized and unrealized gains and losses associated with our derivative contracts, which are reported in Net gain (loss) on commodity derivatives in our Consolidated Statement of Income.

Revenue Recognition Contract As

Revenue Recognition Contract Assets (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Revenue Recognition [Abstract]
Contract with Customer, Asset, Net - Beginning of Period	$ 48	$ 38	$ 22	$ 12
Contract with Customer, Asset, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	54	51	158	134
Contract with Customer, Asset, Reclassified to Receivable	(41)	(39)	(119)	(96)
Contract with Customer, Asset, Net - End of Period	$ 61	$ 50	$ 61	$ 50

Revenue Recognition Contract Li

Revenue Recognition Contract Liabilities (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Contract With Customer, Liability [Line Items]
Contract with Customer, Liability - Beginning of Period	$ 1,115	$ 1,193	$ 1,126	$ 1,209
Contract with Customer, Liability, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress	34	14	144	99
Other Significant Noncash Transaction, Value of Consideration Received	2	3	7	8
Contract with Customer, Liability, Increase (Decrease) for Contract Acquired in Business Combination	2	1	2	1
Contract with Customer, Liability, Revenue Recognized	(71)	(48)	(197)	(154)
Contract with Customer, Liability - End of Period	$ 1,082	$ 1,163	$ 1,082	$ 1,163

Revenue Recognition Contract _2

Revenue Recognition Contract Liabilities Performance Obligations (Details) - USD ($) $ in Millions	Sep. 30, 2022	Jun. 30, 2022	Dec. 31, 2021	Sep. 30, 2021	Jun. 30, 2021	Dec. 31, 2020
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	$ 1,082	$ 1,115	$ 1,126	$ 1,163	$ 1,193	$ 1,209
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	52
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	154
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	126
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	118
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	105
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Contract with Customer, Liability	$ 527
Performance Obligations Related To Contract Liabilities [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	3 months
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	1 year
Performance Obligations Related To Contract Liabilities [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period

Revenue Recognition Remaining P

Revenue Recognition Remaining Performance Obligations (Details) $ in Millions	Sep. 30, 2022 USD ($)
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 30,589
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	916
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	3,610
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	3,340
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	3,015
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	2,517
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue Recognition [Abstract]
Revenue, Remaining Performance Obligation, Amount	$ 17,191
Remaining Performance Obligations [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	3 months
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	1 year
Remaining Performance Obligations [Member] \| Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period

Revenue Recognition Accounts Re

Revenue Recognition Accounts Receivable (Details) - USD ($) $ in Millions	Sep. 30, 2022	Dec. 31, 2021
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	$ 2,659	$ 1,978
Derivative Receivables
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	788	462
Accounts Receivable Related To Contracts With Customers [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	1,824	1,451
Other Accounts Receivable [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, Net, Current	$ 47	$ 65

Provision (Benefit) for Incom_3

Provision (Benefit) for Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2022	Jun. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Current:
Federal	$ 0		$ 1	$ (27)	$ (1)
State	4		1	14	1
Total	4		2	(13)	0
Deferred:
Federal	163		40	247	240
State	(71)		11	(65)	73
Total	92		51	182	313
Provision (benefit) for income taxes	96		$ 53	169	$ 313
Valuation Allowance [Line Items]
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount		$ 88
Operating Loss Carryforwards [Line Items]
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount	92			92
Deferred Tax Assets, Tax Credit Carryforwards, Foreign		70
Deferred Tax Assets, Operating Loss Carryforwards, State and Local	$ 23	18		23
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions		$ 46
Scenario, Plan
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Proceeds from Income Tax Refunds				$ 3

Earnings (Loss) Per Common Sh_3

Earnings (Loss) Per Common Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Earnings Per Share Table [Line Items]
Net income (loss) available to common stockholders	$ 599	$ 164	$ 1,378	$ 893
Basic weighted-average shares	1,218,964	1,215,434	1,218,202	1,215,113
Effect of dilutive securities:
Diluted weighted-average shares	1,222,472	1,217,979	1,222,153	1,217,558
Earnings (loss) per common share:
Basic	$ 0.49	$ 0.14	$ 1.13	$ 0.74
Diluted	$ 0.49	$ 0.13	$ 1.13	$ 0.73
Nonvested restricted stock units [Member]
Effect of dilutive securities:
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	3,269	2,539	3,682	2,437
Stock Options [Member]
Effect of dilutive securities:
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	239	6	269	8

Employee Benefit Plans (Quarter

Employee Benefit Plans (Quarterly Info) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Pension Benefits [Member]
Components of net periodic benefit cost (credit):
Service cost	$ 7	$ 8	$ 21	$ 23
Interest cost	8	7	23	21
Expected return on plan assets	(11)	(11)	(33)	(33)
Amortization of net actuarial loss	3	4	9	11
Net actuarial loss from settlements	0	0	0	1
Net periodic benefit cost (credit)	7	8	20	23
Other Postretirement Benefits [Member]
Components of net periodic benefit cost (credit):
Service cost	1	1	1	1
Interest cost	1	1	4	4
Expected return on plan assets	(3)	(2)	(8)	(7)
Reclassification to regulatory liability	0	0	1	1
Net periodic benefit cost (credit)	$ (1)	$ 0	$ (2)	$ (1)

Debt and Banking Arrangements L

Debt and Banking Arrangements Long-Term Debt Issuances and Retirements (Details 1) - Williams Companies Inc [Member] - USD ($) $ in Millions	Oct. 17, 2022	May 16, 2022	Jan. 18, 2022	Aug. 08, 2022
3.6 Percent Senior Unsecured Notes Due 2022
Debt Instrument [Line Items]
Extinguishment of Debt, Amount			$ 1,250
Long-term debt interest rate			3.60%
3.35 Percent Senior Unsecured Notes Due 2022
Debt Instrument [Line Items]
Extinguishment of Debt, Amount		$ 750
Long-term debt interest rate		3.35%
4.65 Percent Senior Unsecured Notes Due 2032
Debt Instrument [Line Items]
Debt Instrument, Face Amount				$ 1,000
Long-term debt interest rate				4.65%
5.30 Percent Senior Unsecured Notes Due 2052
Debt Instrument [Line Items]
Debt Instrument, Face Amount				$ 750
Long-term debt interest rate				5.30%
3.7 Percent Senior Unsecured Notes Due 2023 \| Subsequent Event [Member]
Debt Instrument [Line Items]
Extinguishment of Debt, Amount	$ 850
Long-term debt interest rate	3.70%

Debt and Banking Arrangements C

Debt and Banking Arrangements Credit Facilities and Commercial Paper (Details 2) - Williams Companies Inc [Member] $ in Millions	Sep. 30, 2022 USD ($)
Credit Facility and Commercial Paper [Line Items]
Commercial paper, outstanding	$ 0
Credit facility, capacity	3,750	[1]
Credit facility, loans outstanding	0	[1]
Commercial Paper [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, capacity	3,500
Letters Of Credit Under Certain Bilateral Bank Agreements [Member]
Credit Facility and Commercial Paper [Line Items]
Credit facility, letters of credit outstanding	$ 40

[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.

Fair Value Measurements and G_3

Fair Value Measurements and Guarantees Recurring Measurements and Additional (Details) - USD ($) $ in Millions	Sep. 30, 2022		Dec. 31, 2021
Measured on a recurring basis:
Derivative Asset, Fair Value, Gross Asset	$ 1,472		$ 785
Derivative Liability, Fair Value, Gross Liability	(2,192)		(1,189)
Additional disclosures:
Collateral Already Posted, Aggregate Fair Value	210
Carrying Amount [Member]
Additional disclosures:
Long-term debt, including current portion	(23,407)		(23,675)
Guarantees	(38)		(39)
Fair Value [Member]
Additional disclosures:
Long-term debt, including current portion	(21,911)		(27,768)
Guarantees	(25)		(26)
Level 1 [Member]
Additional disclosures:
Long-term debt, including current portion	0		0
Guarantees	0		0
Collateral Already Posted, Aggregate Fair Value	210		296
Level 2 [Member]
Additional disclosures:
Long-term debt, including current portion	(21,911)		(27,768)
Guarantees	(9)		(10)
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	216		260
Derivative Asset, Fair Value, Gross Asset	95	[1]	84	[2]
Derivative Liability, Fair Value, Gross Liability	(815)	[1]	(488)	[2]
Other financial assets (liabilities) – net	(11)		(7)
Fair Value, Recurring [Member] \| Fair Value [Member]
Measured on a recurring basis:
ARO Trust investments	216		260
Derivative Asset, Fair Value, Gross Asset	95	[1]	84	[2]
Derivative Liability, Fair Value, Gross Liability	(815)	[1]	(488)	[2]
Other financial assets (liabilities) – net	(11)		(7)
Fair Value, Recurring [Member] \| Level 1 [Member]
Measured on a recurring basis:
ARO Trust investments	216		260
Derivative Asset, Fair Value, Gross Asset	3	[1]	2	[2]
Derivative Liability, Fair Value, Gross Liability	(54)	[1]	(69)	[2]
Other financial assets (liabilities) – net	0		0
Fair Value, Recurring [Member] \| Level 2 [Member]
Measured on a recurring basis:
ARO Trust investments	0		0
Derivative Asset, Fair Value, Gross Asset	54	[1]	81	[2]
Derivative Liability, Fair Value, Gross Liability	(717)	[1]	(403)	[2]
Other financial assets (liabilities) – net	(11)		(7)
Fair Value, Recurring [Member] \| Level 3 [Member]
Measured on a recurring basis:
ARO Trust investments	0		0
Derivative Asset, Fair Value, Gross Asset	38	[1]	1	[2]
Derivative Liability, Fair Value, Gross Liability	(44)	[1]	(16)	[2]
Other financial assets (liabilities) – net	0		$ 0
WilTel Guarantee [Member]
Additional disclosures:
Guarantor Obligations, Maximum Exposure, Undiscounted	24
Indemnification Agreement [Member] \| Carrying Amount [Member]
Additional disclosures:
Guarantees	$ 0

[1]Net commodity derivative assets and liabilities exclude $210 million of net cash collateral in Level 1.[2]Net commodity derivative assets and liabilities exclude $296 million of net cash collateral in Level 1.

Derivatives - Commodity Related

Derivatives - Commodity Related Derivatives (Details) - Not Designated as Hedging Instrument [Member]	Sep. 30, 2022 MMBTU Boe
Public Utilities, Inventory, Natural Gas \| Index Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume \| MMBTU	485,699,255
Public Utilities, Inventory, Natural Gas \| Central Hub Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume \| MMBTU	(58,780,281)
Public Utilities, Inventory, Natural Gas \| Basis Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume \| MMBTU	(60,614,348)
Natural Gas Liquids \| Central Hub Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume \| Boe	(52,710,000)
Natural Gas Liquids \| Basis Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume \| Boe	(2,520,000)
Crude Oil \| Central Hub Risk
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Nonmonetary Notional Amount Net Long Short Position Volume \| Boe	(216,000)

Derivatives - Financial Stateme

Derivatives - Financial Statement Presentation (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 1,472		$ 1,472		$ 785
Derivative Liability, Fair Value, Gross Liability	(2,192)		(2,192)		(1,189)
Derivative Asset, Fair Value, Gross Liability	(1,246)		(1,246)		(476)
Derivative Liability, Fair Value, Gross Asset	1,456		1,456		772
Derivative Asset	226		226		309
Derivative Liability	(736)		(736)		(417)
Energy Related Derivative \| Gain (Loss) on Derivative Instruments
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gain (Loss) on Derivative Instruments, Net, Pretax	16	$ (391)	(491)	$ (441)
Designated as Hedging Instrument [Member] \| Energy Related Derivative \| Gain (Loss) on Derivative Instruments
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Gain (Loss) on Derivative, Net	0	(20)	0	(28)
Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	1,472		1,472		785
Derivative Liability, Fair Value, Gross Liability	(2,192)		(2,192)		(1,189)
Not Designated as Hedging Instrument [Member] \| Energy Related Derivative \| Gain (Loss) on Derivative Instruments
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(13)	(62)	(145)	(96)
Unrealized Gain (Loss) on Derivatives	29	(309)	(346)	(317)
Not Designated as Hedging Instrument [Member] \| Energy Related Derivative \| Cost of Sales
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative, Gain (Loss) on Derivative, Net	6	1	12	1
Unrealized Gain (Loss) on Derivatives	6	$ 0	17	$ 0
Other Current Liabilities \| Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	1,144		1,144		619
Derivative Liability, Fair Value, Gross Liability	(1,475)		(1,475)		(760)
Regulatory liabilities, deferred income, and other [Member] \| Not Designated as Hedging Instrument [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	328		328		166
Derivative Liability, Fair Value, Gross Liability	$ (717)		$ (717)		$ (429)

Derivatives - Contingent Featur

Derivatives - Contingent Features (Details) $ in Millions	Sep. 30, 2022 USD ($)
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Additional Collateral, Aggregate Fair Value	$ 18
Collateral Already Posted, Aggregate Fair Value	$ 210

Contingent Liabilities (Details

Contingent Liabilities (Details) - USD ($) $ in Millions				1 Months Ended
Contingent Liabilities (Details) - USD ($) $ in Millions	Sep. 21, 2022	Dec. 29, 2021	May 20, 2016	Jan. 31, 2020	Sep. 30, 2022
Loss Contingencies [Line Items]
Accrued environmental loss liabilities					$ 32
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
Litigation Settlement, Amount Awarded from Other Party	$ 602	$ 410
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					10
Former Operations [Member]
Loss Contingencies [Line Items]
Accrued environmental loss liabilities					$ 18

Segment Disclosures Reconciliat

Segment Disclosures Reconciliation of Segment Modified EBITDA to Consolidated Net Income (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2022		Sep. 30, 2021	Sep. 30, 2022		Sep. 30, 2021
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	$ 1,599		$ 1,105	$ 4,239		$ 3,821
Accretion expense associated with asset retirement obligations for nonregulated operations	(12)		(12)	(36)		(33)
Depreciation and amortization expenses	(500)		(487)	(1,504)		(1,388)
Equity earnings (losses)	193		157	492		423
Other investing income (loss) - net	1		2	4		6
Proportional Modified EBITDA of equity-method investments	(273)		(247)	(748)		(702)
Interest expense	(291)		(292)	(858)		(884)
(Provision) benefit for income taxes	(96)		(53)	(169)		(313)
Net income (loss)	621		173	1,420		930
Inventory Write-down	64			76
Operating Segments [Member] \| Transmission And Gulf Of Mexico [Member]
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	638		630	1,987		1,936
Operating Segments [Member] \| Northeast G And P [Member]
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	464		442	1,332		1,253
Operating Segments [Member] \| West [Member]
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	337		257	885		702
Operating Segments [Member] \| Gas & NGL Marketing Services
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	20	[1]	(262)	(249)	[1]	(161)
Operating Segments [Member] \| Other [Member]
Reconciliation of Modified EBITDA to Net Income (Loss):
Modified EBITDA Earnings (Loss)	$ 140		$ 38	$ 284		$ 91

[1] Modified EBITDA for the three and nine months ended September 30, 2022, includes charges of $64 million and $76 million associated with lower of cost or net realizable value adjustments to our inventory. These charges are reflected in Product Sales and Product costs

Segment Disclosures Reconcili_2

Segment Disclosures Reconciliation of Segment Revenues to Consolidated (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Segment revenues
Revenues		$ 3,021	$ 2,475	$ 8,035	$ 7,370
Intersegment Elimination [Member]
Segment revenues
Revenues		(342)	(390)	(1,093)	(912)
Operating Segments [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		1,043	937	3,040	2,749
Operating Segments [Member] \| Northeast G And P [Member]
Segment revenues
Revenues		459	417	1,330	1,209
Operating Segments [Member] \| West [Member]
Segment revenues
Revenues		708	531	1,957	1,450
Operating Segments [Member] \| Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	938	882	2,351	2,661
Operating Segments [Member] \| Other [Member]
Segment revenues
Revenues		215	98	450	213
Service [Member]
Segment revenues
Revenues		1,685	1,506	4,828	4,418
Service [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		880	812	2,563	2,445
Service [Member] \| Northeast G And P [Member]
Segment revenues
Revenues		408	390	1,178	1,101
Service [Member] \| West [Member]
Segment revenues
Revenues		393	300	1,073	857
Service [Member] \| Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	1	0	2	2
Service [Member] \| Other [Member]
Segment revenues
Revenues		3	4	12	13
Service [Member] \| Intersegment Elimination [Member]
Segment revenues
Revenues		(74)	(57)	(194)	(138)
Service [Member] \| Intersegment Elimination [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		(30)	(24)	(88)	(48)
Service [Member] \| Intersegment Elimination [Member] \| Northeast G And P [Member]
Segment revenues
Revenues		(9)	(9)	(30)	(29)
Service [Member] \| Intersegment Elimination [Member] \| West [Member]
Segment revenues
Revenues		(32)	(20)	(66)	(51)
Service [Member] \| Intersegment Elimination [Member] \| Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	0	0	0	0
Service [Member] \| Intersegment Elimination [Member] \| Other [Member]
Segment revenues
Revenues		(3)	(4)	(10)	(10)
Service [Member] \| Operating Segments [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		910	836	2,651	2,493
Service [Member] \| Operating Segments [Member] \| Northeast G And P [Member]
Segment revenues
Revenues		417	399	1,208	1,130
Service [Member] \| Operating Segments [Member] \| West [Member]
Segment revenues
Revenues		425	320	1,139	908
Service [Member] \| Operating Segments [Member] \| Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	1	0	2	2
Service [Member] \| Operating Segments [Member] \| Other [Member]
Segment revenues
Revenues		6	8	22	23
NonRegulated Service Commodity Consideration [Member]
Segment revenues
Revenues		60	64	223	164
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		11	13	54	34
NonRegulated Service Commodity Consideration [Member] \| Operating Segments [Member] \| Northeast G And P [Member]
Segment revenues
Revenues		2	(1)	12	4
NonRegulated Service Commodity Consideration [Member] \| Operating Segments [Member] \| West [Member]
Segment revenues
Revenues		47	52	157	126
NonRegulated Service Commodity Consideration [Member] \| Operating Segments [Member] \| Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	0	0	0	0
NonRegulated Service Commodity Consideration [Member] \| Operating Segments [Member] \| Other [Member]
Segment revenues
Revenues		0	0	0	0
Product [Member]
Segment revenues
Revenues		1,260	1,296	3,475	3,229
Product [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		78	54	187	141
Product [Member] \| Northeast G And P [Member]
Segment revenues
Revenues		11	(1)	24	11
Product [Member] \| West [Member]
Segment revenues
Revenues		61	13	111	43
Product [Member] \| Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	1,079	1,183	3,073	2,912
Product [Member] \| Other [Member]
Segment revenues
Revenues		31	47	80	122
Product [Member] \| Intersegment Elimination [Member]
Segment revenues
Revenues		(268)	(333)	(899)	(774)
Product [Member] \| Intersegment Elimination [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		(43)	(34)	(147)	(81)
Product [Member] \| Intersegment Elimination [Member] \| Northeast G And P [Member]
Segment revenues
Revenues		(29)	(20)	(86)	(64)
Product [Member] \| Intersegment Elimination [Member] \| West [Member]
Segment revenues
Revenues		(184)	(164)	(573)	(398)
Product [Member] \| Intersegment Elimination [Member] \| Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	195	(51)	349	(137)
Product [Member] \| Intersegment Elimination [Member] \| Other [Member]
Segment revenues
Revenues		(207)	(64)	(442)	(94)
Product [Member] \| Operating Segments [Member] \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues		121	88	334	222
Product [Member] \| Operating Segments [Member] \| Northeast G And P [Member]
Segment revenues
Revenues		40	19	110	75
Product [Member] \| Operating Segments [Member] \| West [Member]
Segment revenues
Revenues		245	177	684	441
Product [Member] \| Operating Segments [Member] \| Gas & NGL Marketing Services
Segment revenues
Revenues	[1]	884	1,234	2,724	3,049
Product [Member] \| Operating Segments [Member] \| Other [Member]
Segment revenues
Revenues		238	111	522	216
Energy Commodities and Service
Segment revenues
Revenues	[2]	16	(391)	(491)	(441)
Energy Commodities and Service \| Realized Gain (Loss)
Segment revenues
Revenues		(13)	(82)	(145)	(124)
Energy Commodities and Service \| Unrealized Gain (Loss)
Segment revenues
Revenues		29	(309)	(346)	(317)
Energy Commodities and Service \| Transmission And Gulf Of Mexico [Member]
Segment revenues
Revenues	[2]	1	0	1	0
Energy Commodities and Service \| Transmission And Gulf Of Mexico [Member] \| Realized Gain (Loss)
Segment revenues
Revenues		0	0	0	0
Energy Commodities and Service \| Transmission And Gulf Of Mexico [Member] \| Unrealized Gain (Loss)
Segment revenues
Revenues		1	0	1	0
Energy Commodities and Service \| Northeast G And P [Member]
Segment revenues
Revenues	[2]	0	0	0	0
Energy Commodities and Service \| Northeast G And P [Member] \| Realized Gain (Loss)
Segment revenues
Revenues		0	0	0	0
Energy Commodities and Service \| Northeast G And P [Member] \| Unrealized Gain (Loss)
Segment revenues
Revenues		0	0	0	0
Energy Commodities and Service \| West [Member]
Segment revenues
Revenues	[2]	(9)	(18)	(23)	(25)
Energy Commodities and Service \| West [Member] \| Realized Gain (Loss)
Segment revenues
Revenues		(9)	(18)	(23)	(25)
Energy Commodities and Service \| West [Member] \| Unrealized Gain (Loss)
Segment revenues
Revenues		0	0	0	0
Energy Commodities and Service \| Gas & NGL Marketing Services
Segment revenues
Revenues	[1],[2]	53	(352)	(375)	(390)
Energy Commodities and Service \| Gas & NGL Marketing Services \| Realized Gain (Loss)
Segment revenues
Revenues	[1]	54	(58)	(18)	(93)
Energy Commodities and Service \| Gas & NGL Marketing Services \| Unrealized Gain (Loss)
Segment revenues
Revenues	[1]	(1)	(294)	(357)	(297)
Energy Commodities and Service \| Other [Member]
Segment revenues
Revenues	[2]	(29)	(21)	(94)	(26)
Energy Commodities and Service \| Other [Member] \| Realized Gain (Loss)
Segment revenues
Revenues		(58)	(6)	(104)	(6)
Energy Commodities and Service \| Other [Member] \| Unrealized Gain (Loss)
Segment revenues
Revenues		29	(15)	10	(20)
Energy Commodities and Service \| Intersegment Elimination [Member]
Segment revenues
Revenues	[2]	0	0	0	0
Energy Commodities and Service \| Intersegment Elimination [Member] \| Realized Gain (Loss)
Segment revenues
Revenues		0	0	0	0
Energy Commodities and Service \| Intersegment Elimination [Member] \| Unrealized Gain (Loss)
Segment revenues
Revenues		$ 0	$ 0	$ 0	$ 0

[1]See Note 1 – General, Description of Business, and Basis of Presentation.[2]We record transactions that qualify as derivatives at fair value with changes in fair value recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses on derivatives held for energy trading purposes are presented on a net basis in revenue.