Exhibit 99.1

News Release Williams (NYSE: WMB) One Williams Center Tulsa, OK 74172 800-Williams www.williams.com

DATE: Wednesday, Nov. 6, 2024

MEDIA CONTACT:	INVESTOR CONTACTS:
media@williams.com (800) 945-8723	Danilo Juvane (918) 573-5075	Caroline Sardella (918) 230-9992

Williams Delivers Record Third-Quarter Results Driven by Continued Strength of Base Business

TULSA, Okla. – Williams (NYSE: WMB) today announced its unaudited financial results for the three and nine months ended Sept. 30, 2024.

Demonstrated track record of year-over-year financial gains

•GAAP net income of $705 million, or $0.58 per diluted share (EPS) – up 8% vs. 3Q 2023

•Adjusted net income of $528 million, or $0.43 per diluted share (Adj. EPS)

•Record 3Q Adjusted EBITDA of $1.703 billion – up $51 million or 3% vs. 3Q 2023

•Cash flow from operations (CFFO) of $1.243 billion

•Available funds from operations (AFFO) of $1.286 billion – up $56 million or 5% vs. 3Q 2023

•Dividend coverage ratio of 2.22x (AFFO basis)

•Increased midpoint for full-year 2024 guidance by $125 million to $7.075 billion Adjusted EBITDA

Proven project execution continues to deliver long-term, stable growth

•Placed Transco's Regional Energy Access into full service ahead of schedule on Aug. 1

•Placed MountainWest's Uinta Basin expansion in-service

•Placed portion of Transco's Southside Reliability Enhancement in-service

•Placed Anchor in-service and completed construction on Whale in Deepwater Gulf of Mexico

•Began construction on Transco's Commonwealth Energy Connector

•Obtained favorable rulings and began construction on Louisiana Energy Gateway project

•Began construction on two solar projects in the Northeast and signed commercial agreements with Florida utility fully subscribing large-scale Lakeland Solar project

Captured new, high-return growth projects across footprint

•Received FERC certificate for MountainWest Overthrust Westbound expansion

•Filed FERC application for Transco's ~1.6 Bcf/d Southeast Supply Enhancement project

•Executed agreement on Transco's Dalton Lateral Expansion II

•Executed agreements on three new expansions on Northwest Pipeline, totaling ~260 MMcf/d of firm capacity

1

CEO Perspective

Alan Armstrong, president and chief executive officer, made the following comments:

“Williams delivered another quarter of impressive financial results, with Adjusted EBITDA hitting a third quarter record of $1.7 billion, up 3 percent over third quarter 2023, driven primarily by our natural gas transmission expansions and Gulf Coast storage acquisition. We've exceeded financial expectations each quarter this year, and our crisp execution along with our core business strength gives us the confidence to raise our 2024 Adjusted EBITDA guidance midpoint by $125 million to $7.075 billion.

“Our teams continue to excel in executing large-scale expansion projects to serve growing natural gas demand for residential, commercial and industrial use. In addition to placing Transco's Regional Energy Access in service ahead of schedule, we also brought online an expansion to MountainWest as well as a portion of Transco's Southside Reliability Enhancement. Construction is underway on the Louisiana Energy Gateway project as well as Transco’s Commonwealth Energy Connector. In the Deepwater Gulf of Mexico, we commissioned our large-scale facilities to receive production from both Chevron's Anchor field in August and Shell's Whale field as they ramp up production in the fourth quarter.

"Not only do we have a clear line of sight to a full roster of projects in execution, but we continue to commercialize vital, high-return projects across our footprint. We executed a precedent agreement on another expansion to the Transco Dalton Lateral driven by load growth from data center demand and industrial re-shoring in the Atlanta area. In the Rockies and Northwest, we entered into new binding agreements for three separate natural gas transmission expansions to serve power and load growth, including a large coal-to-gas power plant conversion. In addition, we filed the FERC application for Transco's Southeast Supply Enhancement project, a 1.6 Bcf/d expansion to meet growing residential, commercial and industrial demand in cities across the Mid-Atlantic and Southeast.

Armstrong added, "All this activity underscores the accelerating demand for natural gas transmission capacity in the United States, particularly in the growing regions where we operate. As the most natural gas-centric energy infrastructure provider with access to the most prolific U.S. basins, Williams is the best positioned to serve steadily increasing domestic needs for clean and affordable energy, while also helping unlock vast U.S. reserves for the global market."

2

Williams Summary Financial Information	3Q				Year to Date
Amounts in millions, except ratios and per-share amounts. Per share amounts are reported on a diluted basis. Net income amounts are from continuing operations attributable to The Williams Companies, Inc. available to common stockholders.	2024		2023		2024		2023
GAAP Measures
Net Income	$705		$654		$1,737		$2,127
Net Income Per Share	$0.58		$0.54		$1.42		$1.74
Cash Flow From Operations	$1,243		$1,234		$3,756		$4,125
Non-GAAP Measures (1)
Adjusted EBITDA	$1,703		$1,652		$5,304		$5,058
Adjusted Net Income	$528		$547		$1,768		$1,746
Adjusted Earnings Per Share	$0.43		$0.45		$1.45		$1.43
Available Funds from Operations	$1,286		$1,230		$4,043		$3,890
Dividend Coverage Ratio	2.22	x	2.26	x	2.33	x	2.38	x
Other
Debt-to-Adjusted EBITDA at Quarter End (2)	3.75	x	3.45	x
Capital Investments (Excluding Acquisitions) (3) (4)	$720		$805		$1,946		$2,045
(1) Schedules reconciling Adjusted Net Income, Adjusted EBITDA, Available Funds from Operations and Dividend Coverage Ratio (non-GAAP measures) to the most comparable GAAP measure are available at www.williams.com and as an attachment to this news release.
(2) Does not represent leverage ratios measured for WMB credit agreement compliance or leverage ratios as calculated by the major credit ratings agencies. Debt is net of cash on hand, and Adjusted EBITDA reflects the sum of the last four quarters.
(3) Capital Investments include increases to property, plant, and equipment (growth & maintenance capital), purchases of and contributions to equity-method investments and purchases of other long-term investments.
(4) Third-quarter and year-to-date 2024 capital excludes $151 million for the consolidation of our Discovery JV, which closed in August 2024. Year-to-date 2024 capital also excludes $1.844 billion for the acquisition of the Gulf Coast storage assets, which closed January 2024. Third-quarter and year-to-date 2023 capital excludes ($29) million and $1.024 billion, respectively, for the acquisition of MountainWest Pipeline Holding Company, which closed February 2023.

GAAP Measures

Third-quarter 2024 net income increased by $51 million compared to the prior year reflecting $141 million of higher service revenues driven by acquisitions and expansion projects, partially offset by higher net interest expense from recent debt issuances and retirements, higher operating costs, depreciation and interest expense resulting from recent acquisitions, and lower net realized product sales from upstream operations. Third-quarter 2024 gains of $149 million from the sale of our interests in Aux Sable and $127 million associated with the Discovery Acquisition were partially offset by the absence of a $130 million gain on the sale of the Bayou Ethane system in 2023. The tax provision changed unfavorably primarily due to higher pretax income and the absence of a $25 million benefit in 2023 associated with a decrease in our estimated deferred state income tax rate.

Year-to-date 2024 net income decreased by $390 million compared to the prior year reflecting an unfavorable change of $643 million in net unrealized gains/losses on commodity derivatives, higher net interest expense from recent debt issuances and retirements, lower realized hedge gains in the West, and higher operating costs, depreciation and interest expense resulting from recent acquisitions. These unfavorable changes were partially offset by a $441 million increase in service revenues driven by acquisitions and expansion projects, and the net favorable change of $146 million from the previously discussed Aux Sable, Discovery, and Bayou Ethane transactions. The tax provision decreased primarily due to lower pretax income.

Third-quarter 2024 cash flow from operations was generally consistent with the prior year, while year-to-date 2024 decreased compared to the prior year primarily due to unfavorable net changes in both working capital and derivative collateral requirements, partially offset by higher operating results exclusive of non-cash items.

3

Non-GAAP Measures

Third-quarter 2024 Adjusted EBITDA increased by $51 million over the prior year, driven by the previously described favorable net contributions from acquisitions and expansion projects. Year-to-date 2024 Adjusted EBITDA increased by $246 million over the prior year, similarly reflecting favorable net contributions from acquisitions and expansion projects, partially offset by lower realized hedge gains in the West.

Third-quarter 2024 Adjusted Net Income declined by $19 million over the prior year, while year-to-date 2024 Adjusted Net Income increased $22 million over the prior year, both driven by the previously described impacts to net income, adjusted primarily to remove the effects of the gains associated with Bayou Ethane, Discovery, and Aux Sable, net unrealized gains/losses on commodity derivatives, acquisition-related costs, and the related income tax effects.

Third-quarter and year-to-date Available Funds From Operations (AFFO) increased by $56 million and $153 million, respectively, compared to the prior year primarily due to higher results from continuing operations exclusive of non-cash items.

Business Segment Results & Form 10-Q

Williams' operations are comprised of the following reportable segments: Transmission & Gulf of Mexico, Northeast G&P, West and Gas & NGL Marketing Services, as well as Other. For more information, see the company's third-quarter 2024 Form 10-Q.

	Third Quarter						Year to Date
Amounts in millions	Modified EBITDA			Adjusted EBITDA			Modified EBITDA			Adjusted EBITDA
	3Q 2024	3Q 2023	Change	3Q 2024	3Q 2023	Change	2024	2023	Change	2024	2023	Change
Transmission & Gulf of Mexico	$811	$881	($70)	$830	$754	$76	$2,448	$2,327	$121	$2,481	$2,230	$251
Northeast G&P	476	454	22	484	485	(1)	1,461	1,439	22	1,467	1,470	(3)
West	323	315	8	330	315	15	968	931	37	977	913	64
Gas & NGL Marketing Services	11	43	(32)	4	16	(12)	(14)	678	(692)	179	231	(52)
Other	58	81	(23)	55	82	(27)	181	196	(15)	200	214	(14)
Total	$1,679	$1,774	($95)	$1,703	$1,652	$51	$5,044	$5,571	($527)	$5,304	$5,058	$246
Note: Williams uses Modified EBITDA for its segment reporting. Definitions of Modified EBITDA and Adjusted EBITDA and schedules reconciling to net income are included in this news release.

Transmission & Gulf of Mexico

Third-quarter 2024 Modified EBITDA declined compared to the prior year driven by the absence of the previously mentioned gain on the sale of the Bayou Ethane system, as well as hurricane impacts, partially offset by favorable net contributions from the Gulf Coast Storage acquisition and the Regional Energy Access expansion project. Year-to-date 2024 Modified EBITDA improved as the favorable net contributions from acquisitions, including MountainWest, and transmission expansions, along with lower one-time acquisition and transition costs, more than offset the absence of the Bayou Ethane gain and the absence of earnings from the Bayou Ethane system. Third-quarter and year-to-date Adjusted EBITDA, which excludes the Bayou Ethane gain and acquisition and transition costs, improved compared to the prior year.

Northeast G&P

Third-quarter and year-to-date 2024 Modified EBITDA increased compared to the prior year driven by higher rates at Susquehanna Supply Hub and Bradford, partially offset by lower gathering volumes. The improved Modified EBITDA for both periods also reflects the absence of our share of a loss contingency accrual at Aux Sable in 2023, which is excluded from Adjusted EBITDA.

4

West

Third-quarter 2024 Modified and Adjusted EBITDA increased compared to the prior year benefiting from the DJ Basin Acquisitions, partially offset by lower gathering volumes and lower realized gains on natural gas hedges. Both metrics also improved for the year-to-date period reflecting similar drivers, as well as improved commodity margins reflecting favorable changes in shrink prices related to the absence of a short-term gas price spike at Opal in 2023. The year-to-date Modified EBITDA was also impacted by the absence of a first-quarter 2023 favorable contract settlement, which is excluded from Adjusted EBITDA.

Gas & NGL Marketing Services

Third-quarter 2024 Modified EBITDA decreased from the prior year reflecting lower NGL marketing margins and a $14 million net unfavorable change in unrealized gains/losses on commodity derivatives, which is excluded from Adjusted EBITDA. Year-to-date 2024 Modified EBITDA also decreased from the prior year reflecting a decline in both gas marketing margins and NGL marketing margins, as well as a $642 million net unfavorable change in unrealized gains/losses on commodity derivatives, which is excluded from Adjusted EBITDA.

Other

Third-quarter and year-to-date 2024 Modified and Adjusted EBITDA decreased compared to the prior year driven by lower net realized product sales from upstream operations.

2024 Financial Guidance

The company now expects 2024 Adjusted EBITDA between $7 billion and $7.150 billion, which is an increase to the midpoint of guidance by $125 million. In addition, the company continues to expect 2024 growth capex between $1.45 billion and $1.75 billion and maintenance capex between $1.1 billion and $1.3 billion, which includes capital of $350 million for emissions reduction and modernization initiatives. For 2025, the company continues to expect Adjusted EBITDA between $7.2 billion and $7.6 billion with growth capex between $1.65 billion and $1.95 billion and maintenance capex between $750 million and $850 million, which includes capital of $100 million for emissions reduction and modernization initiatives. Williams anticipates a leverage ratio midpoint for 2024 of 3.80x and an increase in the dividend by 6.1% on an annualized basis to $1.90 in 2024 from $1.79 in 2023.

Williams' Third-Quarter 2024 Materials to be Posted Shortly; Q&A Webcast Scheduled for Tomorrow

Williams' third-quarter 2024 earnings presentation will be posted at www.williams.com. The company's third-quarter 2024 earnings conference call and webcast with analysts and investors is scheduled for Thursday, Nov. 7, at 9:30 a.m. Eastern Time (8:30 a.m. Central Time). Participants who wish to join the call by phone must register using the following link: https://register.vevent.com/register/BIf053fa45b660426a89b026a932aec0ae.

A webcast link to the conference call will be provided on Williams' Investor Relations website. A replay of the webcast will also be available on the website for at least 90 days following the event.

About Williams

Williams (NYSE: WMB) is a trusted energy industry leader committed to safely, reliably, and responsibly meeting growing energy demand. We use our 33,000-mile pipeline infrastructure to move a third of the nation’s natural gas to where it's needed most, supplying the energy used to heat our homes, cook our food and generate low-carbon electricity. For over a century, we’ve been driven by a passion for doing things the right way. Today, our team of problem solvers is leading the charge into the clean energy future – by powering the global economy while delivering immediate emissions reductions within our natural gas network and investing in new energy technologies. Learn more at www.williams.com.

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The Williams Companies, Inc.

Consolidated Statement of Income

(Unaudited)

		Three Months Ended   September 30,				Nine Months Ended   September 30,
		2024		2023		2024		2023
	(Millions, except per-share amounts)
Revenues:
Service revenues		$	1,911	$	1,770	$	5,653	$	5,212
Service revenues – commodity consideration		34		45		82		108
Product sales		703		720		2,158		2,158
Net gain (loss) from commodity derivatives		5		24		(133)		645
Total revenues		2,653		2,559		7,760		8,123
Costs and expenses:
Product costs		517		484		1,467		1,458
Net processing commodity expenses		7		31		29		129
Operating and maintenance expenses		580		522		1,613		1,466
Depreciation and amortization expenses		566		521		1,654		1,542
Selling, general, and administrative expenses		170		146		520		483
Gain on sale of business		—		(130)		—		(130)
Other (income) expense – net		(25)		(9)		(69)		(49)
Total costs and expenses		1,815		1,565		5,214		4,899
Operating income (loss)		838		994		2,546		3,224
Equity earnings (losses)		147		127		431		434
Other investing income (loss) – net		290		24		332		45
Interest expense		(338)		(314)		(1,026)		(914)
Other income (expense) – net		31		30		95		69
Income (loss) before income taxes		968		861		2,378		2,858
Less: Provision (benefit) for income taxes		227		176		549		635
Income (loss) from continuing operations		741		685		1,829		2,223
Income (loss) from discontinued operations		—		(1)		—		(88)
Net income (loss)		741		684		1,829		2,135
Less: Net income (loss) attributable to noncontrolling interests		35		30		90		94
Net income (loss) attributable to The Williams Companies, Inc.		706		654		1,739		2,041
Less: Preferred stock dividends		1		1		2		2
Net income (loss) available to common stockholders		$	705	$	653	$	1,737	$	2,039
Amounts attributable to The Williams Companies, Inc. available to common stockholders:
Income (loss) from continuing operations		$	705	$	654	$	1,737	$	2,127
Income (loss) from discontinued operations		—		(1)		—		(88)
Net income (loss) available to common stockholders		$	705	$	653	$	1,737	$	2,039
Basic earnings (loss) per common share:
Income (loss) from continuing operations		$	.58	$	.54	$	1.43	$	1.74
Income (loss) from discontinued operations		—		—		—		(.07)
Net income (loss) available to common stockholders		$	.58	$	.54	$	1.43	$	1.67
Weighted-average shares (thousands)		1,219,537		1,216,951		1,219,021		1,218,021
Diluted earnings (loss) per common share:
Income (loss) from continuing operations		$	.58	$	.54	$	1.42	$	1.74
Income (loss) from discontinued operations		—		—		—		(.07)
Net income (loss) available to common stockholders		$	.58	$	.54	$	1.42	$	1.67
Weighted-average shares (thousands)		1,222,869		1,220,073		1,222,444		1,222,650

6

The Williams Companies, Inc.

Consolidated Balance Sheet

(Unaudited)

	September 30,		December 31,
	2024		2023
	(Millions, except per-share amounts)
ASSETS
Current assets:
Cash and cash equivalents	$	762	$	2,150
Trade accounts and other receivables (net of allowance of ($4) at September 30, 2024 and($3) at December 31, 2023)	1,310		1,655
Inventories	275		274
Derivative assets	143		239
Other current assets and deferred charges	208		195
Total current assets	2,698		4,513
Investments	4,201		4,637
Property, plant, and equipment	56,479		51,842
Accumulated depreciation and amortization	(18,505)		(17,531)
Property, plant, and equipment – net	37,974		34,311
Intangible assets – net of accumulated amortization	7,305		7,593
Regulatory assets, deferred charges, and other	1,659		1,573
Total assets	$	53,837	$	52,627
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	1,137	$	1,379
Derivative liabilities	95		105
Accrued and other current liabilities	1,203		1,284
Commercial paper	—		725
Long-term debt due within one year	2,284		2,337
Total current liabilities	4,719		5,830
Long-term debt	24,825		23,376
Deferred income tax liabilities	4,312		3,846
Regulatory liabilities, deferred income, and other	5,116		4,684
Contingent liabilities and commitments
Equity:
Stockholders’ equity:
Preferred stock ($1 par value; 30 million shares authorized at September 30, 2024 and December 31, 2023; 35 thousand shares issued at September 30, 2024 and December 31, 2023)	35		35
Common stock ($1 par value; 1,470 million shares authorized at September 30, 2024 and December 31, 2023; 1,258 million shares issued at September 30, 2024 and 1,256 million shares issued at December 31, 2023)	1,258		1,256
Capital in excess of par value	24,611		24,578
Retained deficit	(12,296)		(12,287)
Accumulated other comprehensive income (loss)	—		—
Treasury stock, at cost (39 million shares at September 30, 2024 and December 31, 2023 of common stock)	(1,180)		(1,180)
Total stockholders’ equity	12,428		12,402
Noncontrolling interests in consolidated subsidiaries	2,437		2,489
Total equity	14,865		14,891
Total liabilities and equity	$	53,837	$	52,627

7

The Williams Companies, Inc.

Consolidated Statement of Cash Flows

(Unaudited)

	Nine Months Ended   September 30,
	2024		2023
	(Millions)
OPERATING ACTIVITIES:
Net income (loss)	$	1,829	$	2,135
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation and amortization	1,654		1,542
Provision (benefit) for deferred income taxes	467		586
Equity (earnings) losses	(431)		(434)
Distributions from equity-method investees	580		607
Net unrealized (gain) loss from commodity derivative instruments	210		(433)
Gain on sale of business	—		(130)
Gain on disposition of equity-method investments	(149)		—
Gain on consolidation of equity-method investments	(127)		—
Inventory write-downs	8		28
Amortization of stock-based awards	69		59
Cash provided (used) by changes in current assets and liabilities:
Accounts receivable	367		1,295
Inventories	(6)		29
Other current assets and deferred charges	(16)		(5)
Accounts payable	(317)		(1,072)
Accrued and other current liabilities	(108)		(114)
Changes in current and noncurrent commodity derivative assets and liabilities	(74)		172
Other, including changes in noncurrent assets and liabilities	(200)		(140)
Net cash provided (used) by operating activities	3,756		4,125
FINANCING ACTIVITIES:
Proceeds from (payments of) commercial paper – net	(723)		(352)
Proceeds from long-term debt	3,594		2,754
Payments of long-term debt	(2,286)		(21)
Payments for debt issuance costs	(31)		(21)
Proceeds from issuance of common stock	8		8
Purchases of treasury stock	—		(130)
Common dividends paid	(1,737)		(1,635)
Dividends and distributions paid to noncontrolling interests	(178)		(174)
Contributions from noncontrolling interests	36		18
Other – net	(34)		(19)
Net cash provided (used) by financing activities	(1,351)		428
INVESTING ACTIVITIES:
Property, plant, and equipment:
Capital expenditures (1)	(1,805)		(1,845)
Dispositions - net	(73)		(33)
Proceeds from sale of business	—		348
Purchases of businesses, net of cash acquired	(1,995)		(1,024)
Proceeds from dispositions of equity-method investments	161		—
Purchases of and contributions to equity-method investments	(101)		(80)
Other – net	20		3
Net cash provided (used) by investing activities	(3,793)		(2,631)
Increase (decrease) in cash and cash equivalents	(1,388)		1,922
Cash and cash equivalents at beginning of year	2,150		152
Cash and cash equivalents at end of period	$	762	$	2,074
_________
(1)  Increases to property, plant, and equipment	$	(1,840)	$	(1,960)
Changes in related accounts payable and accrued liabilities	35		115
Capital expenditures	$	(1,805)	$	(1,845)

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Transmission & Gulf of Mexico
(UNAUDITED)
	2023										2024
(Dollars in millions)	1st Qtr		2nd Qtr		3rd Qtr		4th Qtr		Year		1st Qtr		2nd Qtr		3rd Qtr		Year-to-date
Regulated interstate natural gas transportation, storage, and other revenues (1)	$	774	$	786	$	794	$	822	$	3,176	$	836	$	805	$	833	$	2,474
Gathering, processing, storage and transportation revenues (1)	100		104		114		100		418		137		147		167		451
Other fee revenues	6		8		5		4		23		12		9		7		28
Commodity margins	10		8		7		8		33		9		5		11		25
Operating and administrative costs (1)	(254)		(254)		(257)		(270)		(1,035)		(254)		(261)		(294)		(809)
Other segment income (expenses) - net (1)	26		31		36		26		119		43		54		46		143
Gain on sale of business	—		—		130		(1)		129		—		—		—		—
Proportional Modified EBITDA of equity-method investments	53		48		52		52		205		46		49		41		136
Modified EBITDA	715		731		881		741		3,068		829		808		811		2,448
Adjustments	13		17		(127)		11		(86)		10		4		19		33
Adjusted EBITDA	$	728	$	748	$	754	$	752	$	2,982	$	839	$	812	$	830	$	2,481
Statistics for Operated Assets
Natural Gas Transmission (2)
Transcontinental Gas Pipe Line
Avg. daily transportation volumes (MMdth)	14.3		13.2		14.0		14.0		13.9		14.6		12.9		14.3		13.9
Avg. daily firm reserved capacity (MMdth)	19.5		19.4		19.4		19.3		19.4		20.3		19.7		20.1		20.0
Northwest Pipeline LLC
Avg. daily transportation volumes (MMdth)	3.1		2.3		2.3		2.8		2.6		3.1		2.2		2.1		2.5
Avg. daily firm reserved capacity (MMdth)	3.8		3.8		3.8		3.8		3.8		3.8		3.7		3.7		3.7
MountainWest (3)
Avg. daily transportation volumes (MMdth)	4.2		3.2		3.8		4.2		3.9		4.3		3.2		3.6		3.7
Avg. daily firm reserved capacity (MMdth)	7.8		7.5		7.5		7.9		7.7		8.4		8.0		8.1		8.1
Gulfstream - Non-consolidated
Avg. daily transportation volumes (MMdth)	1.0		1.2		1.4		1.1		1.2		1.0		1.2		1.4		1.2
Avg. daily firm reserved capacity (MMdth)	1.4		1.4		1.4		1.4		1.4		1.4		1.4		1.4		1.4
Gathering, Processing, and Crude Oil Transportation
Consolidated (4)
Gathering volumes (Bcf/d)	0.28		0.23		0.27		0.27		0.26		0.25		0.23		0.55		0.55
Plant inlet natural gas volumes (Bcf/d)	0.43		0.40		0.46		0.46		0.44		0.45		0.27		0.73		0.69
NGL production (Mbbls/d)	28		24		28		26		27		28		17		49		45
NGL equity sales (Mbbls/d)	7		5		6		5		6		5		3		9		9
Crude oil transportation volumes (Mbbls/d)	119		111		134		130		123		118		114		109		113
Non-consolidated (5)
Gathering volumes (Bcf/d)	0.36		0.30		0.36		0.33		0.34		0.27		0.35		—		—
Plant inlet natural gas volumes (Bcf/d)	0.36		0.30		0.36		0.33		0.34		0.27		0.35		—		—
NGL production (Mbbls/d)	28		21		30		28		27		15		26		—		—
NGL equity sales (Mbbls/d)	8		3		8		7		7		3		7		—		—
(1) Excludes certain amounts associated with revenues and operating costs for tracked or reimbursable charges.
(2) Tbtu converted to MMdth at one trillion British thermal units = one million dekatherms.
(3) Includes 100% of the volumes associated with the MountainWest Acquisition transmission assets after the purchase on February 14, 2023, including 100% of the volumes associated with the operated equity-method investment White River Hub, LLC. Average volumes were calculated over the period owned.
(4) Volumes associated with the Discovery assets for the 3rd Qtr 2024 and Year 2024 are presented entirely in the Consolidated section. We acquired the remaining 40 percent of Discovery on August 1, 2024.
(5) Includes 100% of the volumes associated with operated equity-method investment Discovery Producer Services through 2nd Qtr 2024.

9

Northeast G&P
(UNAUDITED)
	2023										2024
(Dollars in millions)	1st Qtr		2nd Qtr		3rd Qtr		4th Qtr		Year		1st Qtr		2nd Qtr		3rd Qtr		Year-to-date
Gathering, processing, transportation, and fractionation revenues (1)	$	391	$	431	$	417	$	411	$	1,650	$	411	$	398	$	407	$	1,216
Other fee revenues	32		27		27		28		114		34		35		33		102
Commodity margins	5		(1)		7		1		12		11		—		8		19
Operating and administrative costs (1)	(101)		(101)		(115)		(107)		(424)		(108)		(108)		(120)		(336)
Other segment income (expenses) - net	—		—		(1)		(9)		(10)		(1)		3		(1)		1
Proportional Modified EBITDA of equity-method investments	143		159		119		153		574		157		153		149		459
Modified EBITDA	470		515		454		477		1,916		504		481		476		1,461
Adjustments	—		—		31		8		39		—		(2)		8		6
Adjusted EBITDA	$	470	$	515	$	485	$	485	$	1,955	$	504	$	479	$	484	$	1,467
Statistics for Operated Assets
Gathering and Processing
Consolidated (2)
Gathering volumes (Bcf/d)	4.42		4.61		4.41		4.37		4.45		4.33		4.11		4.04		4.16
Plant inlet natural gas volumes (Bcf/d)	1.92		1.79		1.93		1.93		1.89		1.76		1.77		1.99		1.84
NGL production (Mbbls/d)	144		135		144		133		139		133		136		140		137
NGL equity sales (Mbbls/d)	1		1		—		1		1		1		1		1		1
Non-consolidated (3)
Gathering volumes (Bcf/d)	6.97		7.03		6.83		6.85		6.92		6.79		6.42		6.40		6.54
Plant inlet natural gas volumes (Bcf/d)	0.77		0.93		0.99		1.01		0.93		0.98		0.94		0.98		0.97
NGL production (Mbbls/d)	54		64		71		69		65		72		70		72		71
NGL equity sales (Mbbls/d)	4		5		4		4		4		3		6		5		5
(1) Excludes certain amounts associated with revenues and operating costs for reimbursable charges.
(2) Includes volumes associated with Susquehanna Supply Hub, the Northeast JV, and Utica Supply Hub, all of which are consolidated.
(3) Includes 100% of the volumes associated with operated equity-method investments, including the Laurel Mountain Midstream partnership, Blue Racer Midstream, and the Bradford Supply Hub and the Marcellus South Supply Hub within the Appalachia Midstream Services partnership.

10

West
(UNAUDITED)
	2023										2024
(Dollars in millions)	1st Qtr		2nd Qtr		3rd Qtr		4th Qtr		Year		1st Qtr		2nd Qtr		3rd Qtr		Year-to-date
Net gathering, processing, transportation, storage, and fractionation revenues (1)	$	382	$	373	$	371	$	397	$	1,523	$	421	$	397	$	409	$	1,227
Other fee revenues	5		7		4		8		24		8		5		4		17
Commodity margins	(24)		18		21		19		34		12		30		27		69
Operating and administrative costs (1)	(115)		(122)		(122)		(144)		(503)		(139)		(148)		(157)		(444)
Other segment income (expenses) - net	23		(7)		(4)		(14)		(2)		—		(2)		5		3
Proportional Modified EBITDA of equity-method investments	33		43		45		41		162		25		36		35		96
Modified EBITDA	304		312		315		307		1,238		327		318		323		968
Adjustments	(18)		—		—		16		(2)		1		1		7		9
Adjusted EBITDA	$	286	$	312	$	315	$	323	$	1,236	$	328	$	319	$	330	$	977
Statistics for Operated Assets
Gathering and Processing
Consolidated (2)
Gathering volumes (Bcf/d) (3)	5.47		5.51		5.60		6.03		6.02		5.75		5.25		5.38		5.46
Plant inlet natural gas volumes (Bcf/d)	0.92		1.06		1.12		1.63		1.54		1.52		1.48		1.57		1.52
NGL production (Mbbls/d)	25		40		61		99		91		87		91		91		89
NGL equity sales (Mbbls/d)	6		16		22		14		14		6		8		6		7
Non-consolidated
Gathering volumes (Bcf/d)	0.32		0.33		0.33		—		—		—		—		—		—
Plant inlet natural gas volumes (Bcf/d)	0.32		0.32		0.32		—		—		—		—		—		—
NGL production (Mbbls/d)	37		38		38		—		—		—		—		—		—
NGL and Crude Oil Transportation volumes (Mbbls/d) (4)	161		217		244		250		218		220		292		304		272
(1) Excludes certain amounts associated with revenues and operating costs for reimbursable charges.
(2) Excludes volumes associated with equity-method investments that are not consolidated in our results.
(3) Includes 100% of the volumes associated with the Cureton Acquisition gathering assets after the purchase on November 30, 2023. Average volumes were calculated over the period owned.
(4) Includes 100% of the volumes associated with Overland Pass Pipeline Company (an operated equity-method investment), RMM (during the first three quarters of 2023), as well as volumes for our consolidated Bluestem pipeline.

11

Gas & NGL Marketing Services
(UNAUDITED)
	2023										2024
(Dollars in millions)	1st Qtr		2nd Qtr		3rd Qtr		4th Qtr		Year		1st Qtr		2nd Qtr		3rd Qtr		Year-to-date
Commodity margins	$	265	$	(2)	$	38	$	88	$	389	$	236	$	3	$	23	$	262
Other fee revenues	1		—		—		—		1		—		—		—		—
Net unrealized gain (loss) from derivative instruments	333		94		24		208		659		(95)		(106)		10		(191)
Operating and administrative costs	(32)		(24)		(19)		(24)		(99)		(40)		(23)		(22)		(85)
Modified EBITDA	567		68		43		272		950		101		(126)		11		(14)
Adjustments	(336)		(84)		(27)		(203)		(650)		88		112		(7)		193
Adjusted EBITDA	$	231	$	(16)	$	16	$	69	$	300	$	189	$	(14)	$	4	$	179
Statistics
Product Sales Volumes
Natural Gas (Bcf/d)	7.24		6.56		7.31		7.11		7.05		7.53		6.98		7.14		7.22
NGLs (Mbbls/d)	234		239		245		173		223		170		162		182		171

12

Other
(UNAUDITED)
	2023										2024
(Dollars in millions)	1st Qtr		2nd Qtr		3rd Qtr		4th Qtr		Year		1st Qtr		2nd Qtr		3rd Qtr		Year-to-date
Service revenues	$	3	$	5	$	4	$	4	$	16	$	4	$	4	$	4	$	12
Net realized product sales	120		97		127		145		489		113		109		96		318
Net unrealized gain (loss) from derivative instruments	(6)		(11)		(1)		19		1		3		(25)		3		(19)
Operating and administrative costs	(48)		(54)		(58)		(65)		(225)		(51)		(50)		(51)		(152)
Other segment income (expenses) - net	5		5		10		8		28		7		9		4		20
Net gain from Energy Transfer litigation judgment	—		—		—		534		534		—		—		—		—
Proportional Modified EBITDA of equity-method investments	—		(1)		(1)		—		(2)		—		—		2		2
Modified EBITDA	74		41		81		645		841		76		47		58		181
Adjustments	6		11		1		(553)		(535)		(2)		24		(3)		19
Adjusted EBITDA	$	80	$	52	$	82	$	92	$	306	$	74	$	71	$	55	$	200
Statistics
Net Product Sales Volumes
Natural Gas (Bcf/d)	0.26		0.29		0.31		0.30		0.29		0.28		0.24		0.29		0.27
NGLs (Mbbls/d)	3		6		9		10		7		8		8		9		8
Crude Oil (Mbbls/d)	1		3		5		7		4		5		5		4		5

13

Capital Expenditures and Investments
(UNAUDITED)
	2023										2024
(Dollars in millions)	1st Qtr		2nd Qtr		3rd Qtr		4th Qtr		Year		1st Qtr		2nd Qtr		3rd Qtr		Year-to-date
Capital expenditures:
Transmission & Gulf of Mexico	$	205	$	263	$	382	$	404	$	1,254	$	310	$	397	$	459	$	1,166
Northeast G&P	99		74		115		71		359		71		46		54		171
West	169		197		141		121		628		120		90		98		308
Other	72		76		52		75		275		43		46		71		160
Total (1)	$	545	$	610	$	690	$	671	$	2,516	$	544	$	579	$	682	$	1,805
Purchases of and contributions to equity-method investments:
Transmission & Gulf of Mexico	$	8	$	18	$	6	$	9	$	41	$	27	$	10	$	—	$	37
Northeast G&P	31		12		4		52		99		25		19		19		63
West	—		—		1		—		1		—		1		—		1
Other	—		—		—		—		—		—		—		—		—
Total	$	39	$	30	$	11	$	61	$	141	$	52	$	30	$	19	$	101
Summary:
Transmission & Gulf of Mexico	$	213	$	281	$	388	$	413	$	1,295	$	337	$	407	$	459	$	1,203
Northeast G&P	130		86		119		123		458		96		65		73		234
West	169		197		142		121		629		120		91		98		309
Other	72		76		52		75		275		43		46		71		160
Total	$	584	$	640	$	701	$	732	$	2,657	$	596	$	609	$	701	$	1,906
Capital investments:
Increases to property, plant, and equipment	$	484	$	684	$	792	$	604	$	2,564	$	509	$	632	$	699	$	1,840
Purchases of businesses, net of cash acquired	1,056		(3)		(29)		544		1,568		1,851		(7)		151		1,995
Purchases of and contributions to equity-method investments	39		30		11		61		141		52		30		19		101
Purchases of other long-term investments	2		1		2		1		6		2		1		2		5
Total	$	1,581	$	712	$	776	$	1,210	$	4,279	$	2,414	$	656	$	871	$	3,941
(1) Increases to property, plant, and equipment	$	484	$	684	$	792	$	604	$	2,564	$	509	$	632	$	699	$	1,840
Changes in related accounts payable and accrued liabilities	61		(74)		(102)		67		(48)		35		(53)		(17)		(35)
Capital expenditures	$	545	$	610	$	690	$	671	$	2,516	$	544	$	579	$	682	$	1,805
Contributions from noncontrolling interests	$	3	$	15	$	—	$	—	$	18	$	26	$	10	$	—	$	36
Contributions in aid of construction	$	11	$	7	$	2	$	8	$	28	$	10	$	13	$	—	$	23
Proceeds from sale of business	$	—	$	—	$	348	$	(2)	$	346	$	—	$	—	$	—	$	—
Proceeds from dispositions of equity-method investments	$	—	$	—	$	—	$	—	$	—	$	—	$	—	$	161	$	161

14

Non-GAAP Measures

This news release and accompanying materials may include certain financial measures – adjusted EBITDA, adjusted income (“earnings”), adjusted earnings per share, available funds from operations and dividend coverage ratio – that are non-GAAP financial measures as defined under the rules of the SEC.

Our segment performance measure, modified EBITDA, is defined as net income (loss) before income (loss) from discontinued operations, income tax expense, interest expense, equity earnings from equity-method investments, other net investing income, impairments of equity investments and goodwill, depreciation and amortization expense, and accretion expense associated with asset retirement obligations for nonregulated operations. We also add our proportional ownership share (based on ownership interest) of modified EBITDA of equity-method investments.

Adjusted EBITDA further excludes items of income or loss that we characterize as unrepresentative of our ongoing operations. Such items are excluded from net income to determine adjusted income and adjusted earnings per share. Management believes this measure provides investors meaningful insight into results from ongoing operations.

Available funds from operations (AFFO) is defined as net income (loss) excluding the effect of certain noncash items, reduced by distributions from equity-method investees, net distributions to noncontrolling interests, and preferred dividends. AFFO may also be adjusted to exclude certain items that we characterize as unrepresentative of our ongoing operations.

This news release is accompanied by a reconciliation of these non-GAAP financial measures to their nearest GAAP financial measures. Management uses these financial measures because they are accepted financial indicators used by investors to compare company performance. In addition, management believes that these measures provide investors an enhanced perspective of the operating performance of assets and the cash that the business is generating.

Neither adjusted EBITDA, adjusted income, nor available funds from operations are intended to represent cash flows for the period, nor are they presented as an alternative to net income or cash flow from operations. They should not be considered in isolation or as substitutes for a measure of performance prepared in accordance with United States generally accepted accounting principles.

15

Reconciliation of Income (Loss) from Continuing Operations Attributable to The Williams Companies, Inc. to Non-GAAP Adjusted Income
(UNAUDITED)
	2023										2024
(Dollars in millions, except per-share amounts)	1st Qtr		2nd Qtr		3rd Qtr		4th Qtr		Year		1st Qtr		2nd Qtr		3rd Qtr		Year-to-date
Income (loss) from continuing operations attributable to The Williams Companies, Inc. available to common stockholders	$	926	$	547	$	654	$	1,146	$	3,273	$	631	$	401	$	705	$	1,737
Income (loss) from continuing operations - diluted earnings (loss) per common share (1)	$	.76	$	.45	$	.54	$	.94	$	2.68	$	.52	$	.33	$	.58	$	1.42
Adjustments:
Transmission & Gulf of Mexico
MountainWest acquisition and transition-related costs*	$	13	$	17	$	3	$	9	$	42	$	—	$	1	$	3	$	4
Gulf Coast Storage acquisition and transition-related costs*	—		—		—		1		1		10		3		—		13
Gain on sale of business	—		—		(130)		1		(129)		—		—		—		—
Impact of change in payroll policy*	—		—		—		—		—		—		—		16		16
Total Transmission & Gulf of Mexico adjustments	13		17		(127)		11		(86)		10		4		19		33
Northeast G&P
Accrual for loss contingency*	—		—		—		10		10		—		(3)		—		(3)
Our share of operator transition costs at Blue Racer Midstream*	—		—		—		—		—		—		1		1		2
Our share of accrual for loss contingency at Aux Sable Liquid    Products LP	—		—		31		(2)		29		—		—		—		—
Impact of change in payroll policy*	—		—		—		—		—		—		—		7		7
Total Northeast G&P adjustments	—		—		31		8		39		—		(2)		8		6
West
Cureton acquisition and transition-related costs*	—		—		—		6		6		1		1		—		2
Gain from contract settlement	(18)		—		—		—		(18)		—		—		—		—
Impairment of assets held for sale	—		—		—		10		10		—		—		—		—
Impact of change in payroll policy*	—		—		—		—		—		—		—		7		7
Total West adjustments	(18)		—		—		16		(2)		1		1		7		9
Gas & NGL Marketing Services
Impact of volatility on NGL linefill transactions*	(3)		10		(3)		5		9		(6)		5		2		1
Net unrealized (gain) loss from derivative instruments	(333)		(94)		(24)		(208)		(659)		94		107		(10)		191
Impact of change in payroll policy*	—		—		—		—		—		—		—		1		1
Total Gas & NGL Marketing Services adjustments	(336)		(84)		(27)		(203)		(650)		88		112		(7)		193
Other
Net unrealized (gain) loss from derivative instruments	6		11		1		(19)		(1)		(2)		24		(3)		19
Net gain from Energy Transfer litigation judgment	—		—		—		(534)		(534)		—		—		—		—
Total Other adjustments	6		11		1		(553)		(535)		(2)		24		(3)		19
Adjustments included in Modified EBITDA	(335)		(56)		(122)		(721)		(1,234)		97		139		24		260
Adjustments below Modified EBITDA
Gain on remeasurement of RMM investment	—		—		—		(30)		(30)		—		—		—		—
Gain on remeasurement of Discovery investment	—		—		—		—		—		—		—		(127)		(127)
Gain on sale of Aux Sable investment	—		—		—		—		—		—		—		(149)		(149)
Imputed interest expense on deferred consideration obligations*	—		—		—		—		—		12		12		11		35
Amortization of intangible assets from Sequent acquisition	15		14		15		15		59		7		7		8		22
	15		14		15		(15)		29		19		19		(257)		(219)
Total adjustments	(320)		(42)		(107)		(736)		(1,205)		116		158		(233)		41
Less tax effect for above items	78		10		25		178		291		(28)		(38)		56		(10)
Adjustments for tax-related items (2)	—		—		(25)		—		(25)		—		—		—		—
Adjusted income from continuing operations available to common stockholders	$	684	$	515	$	547	$	588	$	2,334	$	719	$	521	$	528	$	1,768
Adjusted income from continuing operations - diluted earnings per common share (1)	$	.56	$	.42	$	.45	$	.48	$	1.91	$	.59	$	.43	$	.43	$	1.45
Weighted-average shares - diluted (thousands)	1,225,781		1,219,915		1,220,073		1,221,894		1,221,616		1,222,222		1,222,236		1,222,869		1,222,444
(1) The sum of earnings per share for the quarters may not equal the total earnings per share for the year due to changes in the weighted-average number of common shares outstanding.
(2) The third quarter of 2023 includes an adjustment associated with a decrease in our estimated deferred state income tax rate.
*Amounts for the 2024 periods are included in Additional adjustments on the Reconciliation of Cash Flow from Operating Activities to Non-GAAP Available Funds from Operations (AFFO).

16

Reconciliation of "Net Income (Loss)" to “Modified EBITDA” and Non-GAAP “Adjusted EBITDA”
(UNAUDITED)
	2023										2024
(Dollars in millions)	1st Qtr		2nd Qtr		3rd Qtr		4th Qtr		Year		1st Qtr		2nd Qtr		3rd Qtr		Year-to-date
Net income (loss)	$	957	$	494	$	684	$	1,168	$	3,303	$	662	$	426	$	741	$	1,829
Provision (benefit) for income taxes	284		175		176		370		1,005		193		129		227		549
Interest expense	294		306		314		322		1,236		349		339		338		1,026
Equity (earnings) losses	(147)		(160)		(127)		(155)		(589)		(137)		(147)		(147)		(431)
Other investing (income) loss - net	(8)		(13)		(24)		(63)		(108)		(24)		(18)		(290)		(332)
Proportional Modified EBITDA of equity-method investments	229		249		215		246		939		228		238		227		693
Depreciation and amortization expenses	506		515		521		529		2,071		548		540		566		1,654
Accretion expense associated with asset retirement obligations for nonregulated operations	15		14		14		16		59		18		21		17		56
(Income) loss from discontinued operations, net of tax	—		87		1		9		97		—		—		—		—
Modified EBITDA	$	2,130	$	1,667	$	1,774	$	2,442	$	8,013	$	1,837	$	1,528	$	1,679	$	5,044
Transmission & Gulf of Mexico	$	715	$	731	$	881	$	741	$	3,068	$	829	$	808	$	811	$	2,448
Northeast G&P	470		515		454		477		1,916		504		481		476		1,461
West	304		312		315		307		1,238		327		318		323		968
Gas & NGL Marketing Services	567		68		43		272		950		101		(126)		11		(14)
Other	74		41		81		645		841		76		47		58		181
Total Modified EBITDA	$	2,130	$	1,667	$	1,774	$	2,442	$	8,013	$	1,837	$	1,528	$	1,679	$	5,044
Adjustments (1):
Transmission & Gulf of Mexico	$	13	$	17	$	(127)	$	11	$	(86)	$	10	$	4	$	19	$	33
Northeast G&P	—		—		31		8		39		—		(2)		8		6
West	(18)		—		—		16		(2)		1		1		7		9
Gas & NGL Marketing Services	(336)		(84)		(27)		(203)		(650)		88		112		(7)		193
Other	6		11		1		(553)		(535)		(2)		24		(3)		19
Total Adjustments	$	(335)	$	(56)	$	(122)	$	(721)	$	(1,234)	$	97	$	139	$	24	$	260
Adjusted EBITDA:
Transmission & Gulf of Mexico	$	728	$	748	$	754	$	752	$	2,982	$	839	$	812	$	830	$	2,481
Northeast G&P	470		515		485		485		1,955		504		479		484		1,467
West	286		312		315		323		1,236		328		319		330		977
Gas & NGL Marketing Services	231		(16)		16		69		300		189		(14)		4		179
Other	80		52		82		92		306		74		71		55		200
Total Adjusted EBITDA	$	1,795	$	1,611	$	1,652	$	1,721	$	6,779	$	1,934	$	1,667	$	1,703	$	5,304
(1) Adjustments by segment are detailed in the "Reconciliation of Income (Loss) from Continuing Operations Attributable to The Williams Companies, Inc. to Non-GAAP Adjusted Income," which is also included in these materials.

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Reconciliation of Cash Flow from Operating Activities to Non-GAAP Available Funds from Operations (AFFO)
(UNAUDITED)
	2023										2024
(Dollars in millions, except coverage ratios)	1st Qtr		2nd Qtr		3rd Qtr		4th Qtr		Year		1st Qtr		2nd Qtr		3rd Qtr		Year-to-date
Net cash provided (used) by operating activities	$	1,514	$	1,377	$	1,234	$	1,813	$	5,938	$	1,234	$	1,279	$	1,243	$	3,756
Exclude: Cash (provided) used by changes in:
Accounts receivable	(1,269)		(154)		128		206		(1,089)		(314)		44		(97)		(367)
Inventories, including write-downs	(45)		(19)		7		14		(43)		(38)		35		1		(2)
Other current assets and deferred charges	4		(28)		29		(65)		(60)		(9)		(3)		28		16
Accounts payable	1,017		203		(148)		(63)		1,009		309		(90)		98		317
Accrued and other current liabilities	318		(246)		42		(95)		19		218		(142)		32		108
Changes in current and noncurrent commodity derivative assets and liabilities	(82)		(37)		(53)		(28)		(200)		68		73		(67)		74
Other, including changes in noncurrent assets and liabilities	40		47		53		106		246		61		90		49		200
Preferred dividends paid	(1)		—		(1)		(1)		(3)		(1)		—		(1)		(2)
Dividends and distributions paid to noncontrolling interests	(54)		(58)		(62)		(39)		(213)		(64)		(66)		(48)		(178)
Contributions from noncontrolling interests	3		15		—		—		18		26		10		—		36
Adjustment to exclude litigation-related charges in discontinued operations	—		115		1		9		125		—		—		—		—
Adjustment to exclude net gain from Energy Transfer litigation judgment	—		—		—		(534)		(534)		—		—		—		—
Additional Adjustments *	—		—		—		—		—		17		20		48		85
Available funds from operations	$	1,445	$	1,215	$	1,230	$	1,323	$	5,213	$	1,507	$	1,250	$	1,286	$	4,043
Common dividends paid	$	546	$	545	$	544	$	544	$	2,179	$	579	$	579	$	579	$	1,737
Coverage ratio:
Available funds from operations divided by Common dividends paid	2.65		2.23		2.26		2.43		2.39		2.60		2.16		2.22		2.33
* See detail on Reconciliation of Income (Loss) from Continuing Operations Attributable to The Williams Companies, Inc. to Non-GAAP Adjusted Income.

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Reconciliation of Net Income (Loss) from Continuing Operations to Modified EBITDA, Non-GAAP Adjusted EBITDA and Cash Flow from Operating Activities to Non-GAAP Available Funds from Operations (AFFO)
	2024 Guidance						2025 Guidance
(Dollars in millions, except per-share amounts and coverage ratio)	Low		Mid		High		Low		Mid		High
Net income (loss) from continuing operations	$	2,330	$	2,390	$	2,450	$	2,373	$	2,523	$	2,673
Provision (benefit) for income taxes	720		735		750		735		785		835
Interest expense			1,365						1,390
Equity (earnings) losses			(555)						(610)
Proportional Modified EBITDA of equity-method investments			905						990
Depreciation and amortization expenses and accretion for asset retirement obligations associated with nonregulated operations			2,300						2,325
Other			(326)						(8)
Modified EBITDA	$	6,739	$	6,814	$	6,889	$	7,195	$	7,395	$	7,595
EBITDA Adjustments			261						5
Adjusted EBITDA	$	7,000	$	7,075	$	7,150	$	7,200	$	7,400	$	7,600
Net income (loss) from continuing operations	$	2,330	$	2,390	$	2,450	$	2,373	$	2,523	$	2,673
Less: Net income (loss) attributable to noncontrolling interests and preferred dividends			131						115
Net income (loss) from continuing operations attributable to The Williams Companies, Inc. available to common stockholders	$	2,199	$	2,259	$	2,319	$	2,258	$	2,408	$	2,558
Adjustments:
Adjustments included in Modified EBITDA (1)			261						5
Adjustments below Modified EBITDA (2)			(206)						18
Allocation of adjustments to noncontrolling interests			—						—
Total adjustments			55						23
Less tax effect for above items			(14)						(6)
Adjusted income from continuing operations available to common stockholders	$	2,240	$	2,300	$	2,360	$	2,275	$	2,425	$	2,575
Adjusted income from continuing operations - diluted earnings per common share	$	1.83	$	1.88	$	1.93	$	1.85	$	1.97	$	2.10
Weighted-average shares - diluted (millions)			1,224						1,228
Available Funds from Operations (AFFO):
Net cash provided by operating activities (net of changes in working capital, changes in current and noncurrent derivative assets and liabilities, and changes in other, including changes in noncurrent assets and liabilities)	$	5,350	$	5,425	$	5,500	$	5,295	$	5,445	$	5,595
Preferred dividends paid			(3)						(3)
Dividends and distributions paid to noncontrolling interests			(230)						(235)
Contributions from noncontrolling interests			36						18
Additional adjustments (3)			92						—
Available funds from operations (AFFO)	$	5,245	$	5,320	$	5,395	$	5,075	$	5,225	$	5,375
AFFO per common share	$	4.29	$	4.35	$	4.41	$	4.13	$	4.25	$	4.38
Common dividends paid			$	2,320			5%-7% Dividend growth
Coverage Ratio (AFFO/Common dividends paid)	2.26x		2.29x		2.33x				~2.12x
(1) 2024 primarily includes September year-to-date adjustments of $260 million as shown in the "Reconciliation of Income (Loss) from Continuing Operations Attributable to The Williams Companies, Inc. to Non-GAAP Adjusted Income"
(2) 2024 primarily includes September year-to-date adjustments of ($219) million including the Gain on remeasurement of Discovery investment and Gain on sale of Aux Sable investment
(3) 2024 primarily includes September year-to-date adjustments of $85 million as shown in the "Reconciliation of Cash Flow from Operating Activities to Non-GAAP Available Funds from Operations (AFFO)"

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Forward-Looking Statements

The reports, filings, and other public announcements of The Williams Companies, Inc. (Williams) may contain or incorporate by reference statements that do not directly or exclusively relate to historical facts. Such statements are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (Securities Act), and Section 21E of the Securities Exchange Act of 1934, as amended (Exchange Act). These forward-looking statements relate to anticipated financial performance, management’s plans and objectives for future operations, business prospects, outcomes of regulatory proceedings, market conditions, and other matters. We make these forward-looking statements in reliance on the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995.

All statements, other than statements of historical facts, included in this report that address activities, events, or developments that we expect, believe, or anticipate will exist or may occur in the future, are forward-looking statements. Forward-looking statements can be identified by various forms of words such as “anticipates,” “believes,” “seeks,” “could,” “may,” “should,” “continues,” “estimates,” “expects,” “forecasts,” “intends,” “might,” “goals,” “objectives,” “targets,” “planned,” “potential,” “projects,” “scheduled,” “will,” “assumes,” “guidance,” “outlook,” “in-service date,” or other similar expressions. These forward-looking statements are based on management’s beliefs and assumptions and on information currently available to management and include, among others, statements regarding:

•Levels of dividends to Williams stockholders;

•Future credit ratings of Williams and its affiliates;

•Amounts and nature of future capital expenditures;

•Expansion and growth of our business and operations;

•Expected in-service dates for capital projects;

•Financial condition and liquidity;

•Business strategy;

•Cash flow from operations or results of operations;

•Seasonality of certain business components;

•Natural gas, natural gas liquids, and crude oil prices, supply, and demand;

•Demand for our services.

Forward-looking statements are based on numerous assumptions, uncertainties, and risks that could cause future events or results to be materially different from those stated or implied in this report. Many of the factors that will determine these results are beyond our ability to control or predict. Specific factors that could cause actual results to differ from results contemplated by the forward-looking statements include, among others, the following:

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•Availability of supplies, market demand, and volatility of prices;

•Development and rate of adoption of alternative energy sources;

•The impact of existing and future laws and regulations, the regulatory environment, environmental matters, and litigation, as well as our ability and the ability of other energy companies with whom we conduct or seek to conduct business, to obtain necessary permits and approvals, and our ability to achieve favorable rate proceeding outcomes;

•Our exposure to the credit risk of our customers and counterparties;

•Our ability to acquire new businesses and assets and successfully integrate those operations and assets into existing businesses as well as successfully expand our facilities, and consummate asset sales on acceptable terms;

•Whether we are able to successfully identify, evaluate, and timely execute our capital projects and investment opportunities;

•The strength and financial resources of our competitors and the effects of competition;

•The amount of cash distributions from and capital requirements of our investments and joint ventures in which we participate;

•Whether we will be able to effectively execute our financing plan;

•Increasing scrutiny and changing expectations from stakeholders with respect to our environmental, social, and governance practices;

•The physical and financial risks associated with climate change;

•The impacts of operational and developmental hazards and unforeseen interruptions;

•The risks resulting from outbreaks or other public health crises;

•Risks associated with weather and natural phenomena, including climate conditions and physical damage to our facilities;

•Acts of terrorism, cybersecurity incidents, and related disruptions;

•Our costs and funding obligations for defined benefit pension plans and other postretirement benefit plans;

•Changes in maintenance and construction costs, as well as our ability to obtain sufficient construction-related inputs, including skilled labor;

•Inflation, interest rates, and general economic conditions (including future disruptions and volatility in the global credit markets and the impact of these events on customers and suppliers);

•Risks related to financing, including restrictions stemming from debt agreements, future changes in credit ratings as determined by nationally recognized credit rating agencies, and the availability and cost of capital;

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•The ability of the members of the Organization of Petroleum Exporting Countries and other oil exporting nations to agree to and maintain oil price and production controls and the impact on domestic production;

•Changes in the current geopolitical situation, including the Russian invasion of Ukraine and conflicts in the Middle East, including between Israel and Hamas and conflicts involving Iran and its proxy forces;

•Changes in U.S. governmental administration and policies;

•Whether we are able to pay current and expected levels of dividends;

•Additional risks described in our filings with the Securities and Exchange Commission (SEC).

Given the uncertainties and risk factors that could cause our actual results to differ materially from those contained in any forward-looking statement, we caution investors not to unduly rely on our forward-looking statements. We disclaim any obligations to, and do not intend to, update the above list or announce publicly the result of any revisions to any of the forward-looking statements to reflect future events or developments.

In addition to causing our actual results to differ, the factors listed above and referred to below may cause our intentions to change from those statements of intention set forth in this report. Such changes in our intentions may also cause our results to differ. We may change our intentions, at any time and without notice, based upon changes in such factors, our assumptions, or otherwise.

Because forward-looking statements involve risks and uncertainties, we caution that there are important factors, in addition to those listed above, that may cause actual results to differ materially from those contained in the forward-looking statements. For a detailed discussion of those factors, see Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2023, as filed with the SEC on February 21, 2024, and as may be supplemented by disclosures in Part II, Item 1A. Risk Factors in subsequent Quarterly Reports on Form 10-Q.

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