Item 1. Financial Statements

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Item 1. Financial Statements


			Page
Williams:

Consolidated Statements of Comprehensive Income – Three and Six Months Ended June 30, 2026 and 2025			9

Consolidated Balance Sheets – June 30, 2026 and December 31, 2025			10
Consolidated Statements of Changes in Equity – Three and Six Months Ended June 30, 2026 and 2025			11
Consolidated Statements of Cash Flows – Six Months Ended June 30, 2026 and 2025			13
Transco:

Statements of Net Income – Three and Six Months Ended June 30, 2026 and 2025			14
Balance Sheets – June 30, 2026 and December 31, 2025			15
Statements of Changes in Member’s Equity – Three and Six Months Ended June 30, 2026 and 2025			16
Statements of Cash Flows – Six Months Ended June 30, 2026 and 2025			17
NWP:

Statements of Net Income – Three and Six Months Ended June 30, 2026 and 2025			18
Balance Sheets – June 30, 2026 and December 31, 2025			19
Statements of Changes in Member’s Equity – Three and Six Months Ended June 30, 2026 and 2025			20
Statements of Cash Flows – Six Months Ended June 30, 2026 and 2025			21

Combined Notes to Financial Statements			22

The Williams Companies, Inc.

Consolidated Statement of Comprehensive Income

(Unaudited)



	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
	(Millions, except per-share amounts)
Revenues:
Service revenues	$	2,152	$	2,041	$	4,358	$	4,044
Service revenues – commodity consideration	45		47		91		96
Product sales	762		657		1,899		1,715
Net gain (loss) from commodity derivatives	94		36		(265)		(26)
Total revenues	3,053		2,781		6,083		5,829
Costs and expenses:
Product costs	509		474		1,052		1,089
Net processing commodity expenses	6		4		21		32
Operating and maintenance expenses	597		572		1,162		1,114
Depreciation, depletion, and amortization expenses	592		605		1,176		1,190
General and administrative expenses	180		168		373		362
Gain on sale of certain assets (Note 3)	(12)		—		(194)		—



Other operating (income) expense – net	(1)		13		(10)		3
Total costs and expenses	1,871		1,836		3,580		3,790
Operating income (loss)	1,182		945		2,503		2,039
Equity earnings (losses)	159		142		320		297


Other investing income (loss) – net (Note 3)	134		4		158		12
Interest expense	(371)		(350)		(747)		(699)



Other income (expense) – net	32		16		58		30
Income (loss) before income taxes	1,136		757		2,292		1,679
Less: Provision (benefit) for income taxes	260		174		504		367


Net income (loss)	876		583		1,788		1,312
Less: Net income (loss) attributable to noncontrolling interests	49		37		96		75
Net income (loss) attributable to The Williams Companies, Inc.	827		546		1,692		1,237
Less: Preferred stock dividends	—		—		1		1
Net income (loss) available to common stockholders	$	827	$	546	$	1,691	$	1,236




Basic earnings (loss) per common share:


Net income (loss) available to common stockholders	$	.68	$	.45	$	1.38	$	1.01
Weighted-average shares (millions)	1,224		1,222		1,223		1,221
Diluted earnings (loss) per common share:


Net income (loss) available to common stockholders	$	.68	$	.45	$	1.38	$	1.01
Weighted-average shares (millions)	1,225		1,224		1,226		1,224

Comprehensive income (loss):
Net income (loss)	$	876	$	583	$	1,788	$	1,312
Other comprehensive income (loss), net of taxes of $— and $1 in 2026 and $(1) and $(1) in 2025	(1)		1		(3)		1
Comprehensive income (loss)	875		584		1,785		1,313
Less: Comprehensive income (loss) attributable to noncontrolling interests	49		37		96		75
Comprehensive income (loss) attributable to The Williams Companies, Inc.	$	826	$	547	$	1,689	$	1,238

See the Combined Notes to Financial Statements.

The Williams Companies, Inc.

Consolidated Balance Sheet

(Unaudited)



	June 30,		December 31,
	2026		2025
	(Millions, except per-share amounts)
ASSETS
Current assets:
Cash and cash equivalents	$	203	$	63
Trade accounts and other receivables (net of allowance of ($1) at June 30, 2026 and December 31, 2025)	1,968		2,084
Inventories	335		314
Assets held for sale (Note 3)	60		318
Derivative assets	159		209
Other current assets and deferred charges	398		256
Total current assets	3,123		3,244

Investments	4,515		4,559
Property, plant, and equipment	65,278		62,010
Accumulated depreciation, depletion, and amortization	(20,868)		(20,014)
Property, plant, and equipment – net	44,410		41,996
Intangible assets – net	6,577		6,763
Regulatory assets, deferred charges, and other	1,985		2,011
Total assets	$	60,610	$	58,573

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	2,220	$	2,224
Liabilities held for sale (Note 3)	9		63
Derivative liabilities	127		135
Other current liabilities	1,518		1,639
Commercial paper	475		700
Long-term debt due within one year	2,197		1,345
Total current liabilities	6,546		6,106

Long-term debt	28,121		27,316
Deferred income tax liabilities	5,596		5,170
Regulatory liabilities, deferred income, and other	4,979		4,986
Contingent liabilities and commitments (Note 9)

Equity:
Stockholders’ equity:
Preferred stock ($1 par value; 30 million shares authorized at June 30, 2026 and December 31, 2025; 35 thousand shares issued at June 30, 2026 and December 31, 2025)	35		35
Common stock ($1 par value; 1,470 million shares authorized at June 30, 2026 and December 31, 2025; 1,262 million shares issued at June 30, 2026 and 1,261 million shares issued at December 31, 2025)	1,262		1,261
Capital in excess of par value	24,783		24,801
Retained deficit	(11,834)		(12,237)
Accumulated other comprehensive income (loss)	124		127
Treasury stock, at cost (39 million shares at June 30, 2026 and December 31, 2025 of common stock)	(1,180)		(1,180)
Total stockholders’ equity	13,190		12,807
Noncontrolling interests in consolidated subsidiaries	2,178		2,188
Total equity	15,368		14,995
Total liabilities and equity	$	60,610	$	58,573

See the Combined Notes to Financial Statements.

The Williams Companies, Inc.

Consolidated Statement of Changes in Equity

(Unaudited)


	The Williams Companies, Inc. Stockholders
	Preferred Stock		Common Stock		Capital in Excess of Par Value		Retained Deficit		AOCI*		Treasury Stock		Total Stockholders’ Equity		Noncontrolling Interests		Total Equity
	(Millions)
Balance at March 31, 2026	$	35	$	1,262	$	24,767	$	(12,017)	$	125	$	(1,180)	$	12,992	$	2,170	$	15,162

Net income (loss)	—		—		—		827		—		—		827		49		876
Other comprehensive income (loss)	—		—		—		—		(1)		—		(1)		—		(1)



Cash dividends – common stock ($0.525 per share)	—		—		—		(642)		—		—		(642)		—		(642)

Stock-based compensation and related common stock issuances, net of tax	—		—		16		—		—		—		16		—		16


Dividends and distributions to noncontrolling interests	—		—		—		—		—		—		—		(73)		(73)
Contributions from noncontrolling interests	—		—		—		—		—		—		—		32		32

Other	—		—		—		(2)		—		—		(2)		—		(2)
Net increase (decrease) in equity	—		—		16		183		(1)		—		198		8		206
Balance at June 30, 2026	$	35	$	1,262	$	24,783	$	(11,834)	$	124	$	(1,180)	$	13,190	$	2,178	$	15,368

Balance at March 31, 2025	$	35	$	1,260	$	24,616	$	(12,320)	$	76	$	(1,180)	$	12,487	$	2,378	$	14,865
Net income (loss)	—		—		—		546		—		—		546		37		583
Other comprehensive income (loss)	—		—		—		—		1		—		1		—		1
Cash dividends – common stock ($0.500 per share)	—		—		—		(611)		—		—		(611)		—		(611)

Stock-based compensation and related common stock issuances, net of tax	—		—		17		—		—		—		17		—		17

Dividends and distributions to noncontrolling interests	—		—		—		—		—		—		—		(62)		(62)
Contributions from noncontrolling interests	—		—		—		—		—		—		—		14		14

Other	—		—		—		(2)		—		—		(2)		—		(2)
Net increase (decrease) in equity	—		—		17		(67)		1		—		(49)		(11)		(60)
Balance at June 30, 2025	$	35	$	1,260	$	24,633	$	(12,387)	$	77	$	(1,180)	$	12,438	$	2,367	$	14,805

*Accumulated Other Comprehensive Income (Loss)

See the Combined Notes to Financial Statements.

The Williams Companies, Inc.

Consolidated Statement of Changes in Equity (Continued)

(Unaudited)


	The Williams Companies, Inc. Stockholders
	Preferred Stock		Common Stock		Capital in Excess of Par Value		Retained Deficit		AOCI*		Treasury Stock		Total Stockholders’ Equity		Noncontrolling Interests		Total Equity
	(Millions)

















Balance at December 31, 2025	$	35	$	1,261	$	24,801	$	(12,237)	$	127	$	(1,180)	$	12,807	$	2,188	$	14,995
Net income (loss)	—		—		—		1,692		—		—		1,692		96		1,788
Other comprehensive income (loss)	—		—		—		—		(3)		—		(3)		—		(3)
Cash dividends – common stock ($1.050 per share)	—		—		—		(1,284)		—		—		(1,284)		—		(1,284)
Stock-based compensation and related common stock issuances, net of tax	—		1		(18)		—		—		—		(17)		—		(17)
Dividends and distributions to noncontrolling interests	—		—		—		—		—		—		—		(140)		(140)


Contributions from noncontrolling interests	—		—		—		—		—		—		—		32		32


Other	—		—		—		(5)		—		—		(5)		2		(3)
Net increase (decrease) in equity	—		1		(18)		403		(3)		—		383		(10)		373
Balance at June 30, 2026	$	35	$	1,262	$	24,783	$	(11,834)	$	124	$	(1,180)	$	13,190	$	2,178	$	15,368

Balance at December 31, 2024	$	35	$	1,258	$	24,643	$	(12,396)	$	76	$	(1,180)	$	12,436	$	2,404	$	14,840
Net income (loss)	—		—		—		1,237		—		—		1,237		75		1,312
Other comprehensive income (loss)	—		—		—		—		1		—		1		—		1
Cash dividends – common stock ($1.000 per share)	—		—		—		(1,221)		—		—		(1,221)		—		(1,221)
Stock-based compensation and related common stock issuances, net of tax	—		2		(10)		—		—		—		(8)		—		(8)
Dividends and distributions to noncontrolling interests	—		—		—		—		—		—		—		(131)		(131)


Contributions from noncontrolling interests	—		—		—		—		—		—		—		19		19

Other	—		—		—		(7)		—		—		(7)		—		(7)
Net increase (decrease) in equity	—		2		(10)		9		1		—		2		(37)		(35)
Balance at June 30, 2025	$	35	$	1,260	$	24,633	$	(12,387)	$	77	$	(1,180)	$	12,438	$	2,367	$	14,805

*Accumulated Other Comprehensive Income (Loss)

See the Combined Notes to Financial Statements.

The Williams Companies, Inc.

Consolidated Statement of Cash Flows

(Unaudited)


	Six Months Ended June 30,
	2026		2025
	(Millions)
OPERATING ACTIVITIES:
Net income (loss)	$	1,788	$	1,312
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation, depletion, and amortization	1,176		1,190
Provision (benefit) for deferred income taxes	492		186
Equity (earnings) losses	(320)		(297)
Distributions from equity-method investees	448		412


Gain on sale of certain assets (Note 3)	(194)		—

Net unrealized (gain) loss from commodity derivative instruments	83		(4)

Gain on disposition of equity-method investments (Note 3)	(127)		—

Inventory write-downs	12		4
Amortization of stock-based awards	39		49
Cash provided (used) by changes in current assets and liabilities:
Accounts receivable	106		301
Inventories	(32)		(61)
Other current assets and deferred charges	(23)		(36)
Accounts payable	(240)		(265)
Other current liabilities	(58)		150
Changes in current and noncurrent commodity derivative assets and liabilities	(56)		19
Other, including changes in noncurrent assets and liabilities	(115)		(77)
Net cash provided (used) by operating activities	2,979		2,883
FINANCING ACTIVITIES:
Proceeds from (payments of) commercial paper – net	(224)		(454)
Proceeds from long-term debt	2,790		2,994
Payments of long-term debt	(1,119)		(975)
Payments for debt issuance costs	(33)		(26)
Proceeds from issuance of common stock	8		5

Common dividends paid	(1,284)		(1,221)
Dividends and distributions paid to noncontrolling interests	(140)		(131)
Contributions from noncontrolling interests	32		19
Other – net	(79)		(57)
Net cash provided (used) by financing activities	(49)		154
INVESTING ACTIVITIES:
Property, plant, and equipment:
Capital expenditures (1)	(3,193)		(1,984)
Dispositions – net (Note 3)	345		(40)

Proceeds from sale of business (Note 7)	48		—

Proceeds from disposition of equity-method investments (Note 3)	6		—
Purchases of and contributions to equity-method investments	(91)		(179)
Other – net	95		9
Net cash provided (used) by investing activities	(2,790)		(2,194)
Increase (decrease) in cash and cash equivalents	140		843
Cash and cash equivalents at beginning of year	63		60
Cash and cash equivalents at end of period	$	203	$	903
_________
(1) Increases to property, plant, and equipment	$	(3,347)	$	(2,041)
Changes in related accounts payable and accrued liabilities	154		57
Capital expenditures	$	(3,193)	$	(1,984)

See the Combined Notes to Financial Statements.

Transcontinental Gas Pipe Line Company, LLC

Statement of Net Income

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
	(Millions)
Revenues:
Natural gas transportation service revenues:
Affiliate	$	18	$	18	$	35	$	36
Third-party	685		676		1,419		1,348
Natural gas storage service revenues	59		63		117		118
Natural gas product sales:
Affiliate	6		3		12		4
Third-party	21		23		42		40
Other service revenues:
Affiliate	—		1		2		2
Third-party	15		7		24		13
Total revenues	804		791		1,651		1,561

Costs and expenses:
Natural gas product costs:
Affiliate	—		3		3		5
Third-party	27		23		51		39
Operating and maintenance expenses:
Affiliate	42		39		90		84
Third-party	76		78		162		157
Depreciation and amortization expenses	146		166		290		315
General and administrative expenses:
Affiliate	47		43		95		90
Third-party	9		10		20		20
Taxes, other than income taxes	31		31		64		61

Other operating (income) expense – net	5		15		9		21
Total costs and expenses	383		408		784		792

Operating income (loss)	421		383		867		769

Interest expense	(83)		(81)		(169)		(162)
Interest income:
Affiliate	10		6		20		12
Third-party	1		1		3		3
Allowance for equity and borrowed funds used during construction (AFUDC)	17		6		29		15
Other income (expense) – net	1		(1)		1		(2)
Net income (loss)	$	367	$	314	$	751	$	635

See the Combined Notes to Financial Statements.

Transcontinental Gas Pipe Line Company, LLC

Balance Sheet

(Unaudited)



	June 30,		December 31,
	2026		2025
	(Millions)
ASSETS
Current assets:
Cash and cash equivalents	$	—	$	—
Trade accounts and other receivables:
Advances to affiliate	900		954
Trade	260		306
Affiliates	10		7
Other	42		23
Inventories	97		82
Regulatory assets	146		126
Other current assets and deferred charges	32		24
Total current assets	1,487		1,522

Property, plant, and equipment	21,562		21,012
Accumulated depreciation and amortization	(6,580)		(6,404)
Property, plant, and equipment – net	14,982		14,608
Regulatory assets	245		268
Deferred charges and other	472		466
Total assets	$	17,186	$	16,864

LIABILITIES AND MEMBER’S EQUITY
Current liabilities:
Payables:
Trade	$	351	$	225
Affiliates	48		62
Regulatory liabilities	106		93
Accrued interest	69		53

Reserve for rate refunds (Note 9)	—		179
Accrual for litigation settlement (Note 9)	—		75
Other current liabilities	204		143
Asset retirement obligations	57		41
Long-term debt due within one year	247		246
Total current liabilities	1,082		1,117
Long-term debt	5,643		5,642
Regulatory liabilities	905		914
Asset retirement obligations	548		573
Deferred income and other	287		227
Contingent liabilities and commitments (Note 9)

Member’s equity:
Member’s capital	5,363		5,088
Retained earnings	3,358		3,303
Total member’s equity	8,721		8,391
Total liabilities and member’s equity	$	17,186	$	16,864

See the Combined Notes to Financial Statements.

Transcontinental Gas Pipe Line Company, LLC

Statement of Changes in Member’s Equity

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
	(Millions)
Member’s Capital:
Balance at beginning of period	$	5,363	$	5,088	$	5,088	$	5,088
Cash contributions from parent	—		—		275		—


Balance at end of period	5,363		5,088		5,363		5,088
Retained Earnings:
Balance at beginning of period	3,349		3,292		3,303		3,217
Net income	367		314		751		635
Cash distributions to parent	(358)		(360)		(696)		(606)


Balance at end of period	3,358		3,246		3,358		3,246

Total Member’s Equity	$	8,721	$	8,334	$	8,721	$	8,334

See the Combined Notes to Financial Statements.

Transcontinental Gas Pipe Line Company, LLC

Statement of Cash Flows

(Unaudited)


	Six Months Ended June 30,
	2026		2025
	(Millions)
OPERATING ACTIVITIES:
Net income (loss)	$	751	$	635
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation and amortization	290		315

Allowance for equity funds used during construction (equity AFUDC)	(23)		(12)

Cash provided (used) by changes in current assets and liabilities:
Affiliate receivables	(3)		17
Trade and other accounts receivable	27		(29)

Inventories	(15)		(3)
Regulatory assets	(20)		(50)
Other current assets and deferred charges	(8)		(3)
Trade accounts payable	(22)		(17)
Affiliate payables	(14)		(13)

Reserve for rate refunds (Note 9)	(179)		86
Other current liabilities	88		75
Other, including changes in noncurrent assets and liabilities	(19)		(14)
Net cash provided (used) by operating activities	853		987

FINANCING ACTIVITIES:

Proceeds from other financing obligations	22		2

Payments on other financing obligations	(19)		(17)
Payments for debt issuance costs	(1)		—
Cash distributions to parent	(696)		(606)
Cash contributions from parent	275		—

Net cash provided (used) by financing activities	(419)		(621)
INVESTING ACTIVITIES:
Property, plant, and equipment:
Capital expenditures (1)	(524)		(405)
Contributions and advances for construction costs	31		16
Dispositions – net	(50)		(47)
Advances to affiliate – net	54		83

Purchase of asset retirement obligations trust investments	(19)		(27)
Proceeds from sale of asset retirement obligations trust investments	74		14

Net cash provided (used) by investing activities	(434)		(366)


Increase (decrease) in cash and cash equivalents	—		—
Cash and cash equivalents at beginning of year	—		—
Cash and cash equivalents at end of period	$	—	$	—
____________________________
(1) Increases to property, plant, and equipment, exclusive of equity AFUDC	$	(591)	$	(390)
Changes in related accounts payable and accrued liabilities	67		(15)
Capital expenditures	$	(524)	$	(405)

See the Combined Notes to Financial Statements.

Northwest Pipeline LLC

Statement of Net Income

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
	(Millions)
Revenues:
Natural gas transportation service revenues	$	112	$	107	$	226	$	212
Natural gas storage service revenues	3		4		7		8
Other service revenues	3		2		5		4
Total revenues	118		113		238		224

Costs and expenses:
Operating and maintenance expenses:
Affiliate	14		11		28		25
Third-party	15		13		24		20
Depreciation and amortization expenses	31		30		61		59
General and administrative expenses:
Affiliate	10		10		20		20
Third-party	2		1		5		4
Taxes, other than income taxes	4		4		8		8

Other operating (income) expense – net	(5)		(4)		(10)		(10)
Total costs and expenses	71		65		136		126

Operating income (loss)	47		48		102		98

Interest expense	(9)		(7)		(17)		(14)
Interest income:
Affiliate	2		1		4		1
Third-party	2		—		3		1
Allowance for equity and borrowed funds used during construction (AFUDC)	4		2		6		4
Other income (expense) – net	1		1		1		1
Net income (loss)	$	47	$	45	$	99	$	91

See the Combined Notes to Financial Statements.

Northwest Pipeline LLC

Balance Sheet

(Unaudited)



	June 30,		December 31,
	2026		2025
	(Millions)
ASSETS
Current Assets:
Cash and cash equivalents	$	—	$	—
Trade accounts and other receivables:
Advances to affiliate	212		218
Trade	39		41

Other	8		1

Inventories	10		9



Regulatory assets	4		3


Other current assets and deferred charges	4		8
Total current assets	277		280

Property, plant, and equipment	4,542		4,434
Accumulated depreciation and amortization	(2,243)		(2,164)
Property, plant, and equipment – net	2,299		2,270


Regulatory assets	92		80
Deferred charges and other	34		30



Total assets	$	2,702	$	2,660

LIABILITIES AND MEMBER’S EQUITY
Current Liabilities:
Payables:

Trade	$	48	$	39
Affiliates	13		12
Regulatory liabilities	20		20



Other current liabilities	39		32

Long-term debt due within one year	499		—
Total current liabilities	619		103
Long-term debt	250		748
Regulatory liabilities	198		225
Asset retirement obligations	156		152
Deferred income and other	9		5
Contingent liabilities and commitments (Note 9)

Member’s Equity:
Member’s capital	1,328		1,305
Retained earnings	142		122
Total member’s equity	1,470		1,427
Total liabilities and member’s equity	$	2,702	$	2,660

See the Combined Notes to Financial Statements.

Northwest Pipeline LLC

Statement of Changes in Member’s Equity

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
	(Millions)
Member’s Capital:
Balance at beginning of period	$	1,328	$	1,159	$	1,305	$	1,074
Cash contributions from parent	—		46		25		131
Noncash return of capital	—		—		(2)		—
Balance at end of period	1,328		1,205		1,328		1,205
Retained Earnings:
Balance at beginning of period	145		111		122		89
Net income	47		45		99		91
Cash distributions to parent	(50)		(40)		(79)		(64)
Balance at end of period	142		116		142		116






Total Member’s Equity	$	1,470	$	1,321	$	1,470	$	1,321

See the Combined Notes to Financial Statements.

Northwest Pipeline LLC

Statement of Cash Flows

(Unaudited)


	Six Months Ended June 30,
	2026		2025
	(Millions)
OPERATING ACTIVITIES:
Net income (loss)	$	99	$	91
Adjustments to reconcile to net cash provided (used) by operating activities:
Depreciation and amortization	61		59



Allowance for equity funds used during construction (equity AFUDC)	(5)		(3)
Cash provided (used) by changes in current assets and liabilities:

Trade and other accounts receivable	(5)		3



Other current assets and deferred charges	2		1
Trade accounts payable	1		(2)
Affiliate payables	(1)		(4)


Other current liabilities	(2)		(3)
Other, including changes in noncurrent assets and liabilities	(21)		(26)



Net cash provided (used) by operating activities	129		116

FINANCING ACTIVITIES:



Cash distributions to parent	(79)		(64)
Cash contributions from parent	25		131
Advances from affiliate – net	—		(26)
Net cash provided (used) by financing activities	(54)		41

INVESTING ACTIVITIES:
Property, plant, and equipment:
Capital expenditures (1)	(79)		(92)
Contributions and advances for construction costs	4		5
Dispositions – net	(6)		(6)
Advances to affiliate – net	6		(64)

Net cash provided (used) by investing activities	(75)		(157)

Increase (decrease) in cash and cash equivalents	—		—
Cash and cash equivalents at beginning of year	—		—
Cash and cash equivalents at end of period	$	—	$	—
____________________________________
(1) Increases to property, plant, and equipment, exclusive of equity AFUDC	$	(93)	$	(89)
Changes in related accounts payable and accrued liabilities	14		(3)
Capital expenditures	$	(79)	$	(92)

See the Combined Notes to Financial Statements.

Index of Combined Notes to Financial Statements

The Combined Notes to Financial Statements include information for multiple registrants, specifically The Williams Companies, Inc. (Williams), as well as Transcontinental Gas Pipe Line Company, LLC (Transco) and Northwest Pipeline LLC (NWP), both of which are wholly owned subsidiaries of Williams. References to subsidiaries by name, including equity-method investees, Transco, and NWP, refer exclusively to those businesses and operations.

The following list indicates the Registrants to which each of the combined notes apply. Specific disclosures within each combined note may apply to all Registrants unless indicated otherwise.


Note	Registrant	Page
Note 1 – Description of Business and Basis of Presentation	Williams, Transco, NWP	22
Note 2 – Variable Interest Entities	Williams	24
Note 3 – Divestitures	Williams	25

Note 4 – Revenue Recognition	Williams, Transco, NWP	27
Note 5 – Provision (Benefit) for Income Taxes	Williams	32






Note 6 – Debt and Banking Arrangements	Williams, Transco, NWP	32


Note 7 – Fair Value Measurements and Guarantees	Williams, Transco, NWP	35
Note 8 – Commodity Derivatives	Williams	37
Note 9 – Contingencies	Williams, Transco, NWP	39
Note 10 – Segment Disclosures	Williams, Transco, NWP	43
Note 11 – Subsequent Events	Williams	48

Note 1 – Description of Business and Basis of Presentation

Description of Business

Williams

Williams is a Delaware corporation whose common stock is listed and traded on the New York Stock Exchange. Its operations are located in the United States and are presented within the following reportable segments: Transmission, Power & Gulf; Northeast G&P; West; and Gas & NGL Marketing Services, consistent with the manner in which Williams’ Chief Executive Officer, the chief operating decision maker (CODM), evaluates performance and allocates resources. All remaining business activities, including upstream operations and corporate activities, are included in Other.

Transmission, Power & Gulf is comprised of interstate natural gas pipelines and their related natural gas storage facilities, including Transco, NWP, MountainWest Pipelines Holding LLC (MountainWest), and a 50 percent equity-method investment in Gulfstream Natural Gas System, L.L.C. (Gulfstream); natural gas gathering and processing (G&P) and crude oil production handling and transportation assets in the Gulf Coast region; and natural gas storage facilities and pipelines providing services in north Texas, Louisiana, and Mississippi. Transmission, Power & Gulf also includes power innovation projects under development that will deliver speed-to-market solutions in power grid-constrained markets.

Northeast G&P is comprised of Williams’ 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 variable interest entity, or VIE) which operates in West Virginia, Ohio, and Pennsylvania, a 66 percent interest in Cardinal Gas Services,

Notes (Continued)

L.L.C. (Cardinal) (a consolidated VIE) which operates in Ohio, a 50 percent equity-method investment in Blue Racer Midstream LLC (Blue Racer), and Appalachia Midstream Investments.

West is comprised of Williams’ gas gathering, processing, and treating operations in the Denver-Julesberg Basin (DJ Basin) and Piceance regions of Colorado, the southwest and Wamsutter regions of Wyoming, the Barnett Shale region of north-central Texas, the Eagle Ford Shale region of south Texas, and the Haynesville Shale region of east Texas and northwest Louisiana. In the first quarter of 2026, the Anadarko basin gathering assets in the Mid-Continent region were sold (see Note 3 – Divestitures). This segment also includes Williams’ NGL storage facilities, an undivided 50 percent interest in a NGL fractionator near Conway, Kansas, and a 50 percent equity-method investment in Overland Pass Pipeline Company LLC (OPPL).

Gas & NGL Marketing Services is comprised of Williams’ NGL and natural gas marketing and trading operations, which include risk management and transactions related to the storage and transportation of natural gas and NGLs on strategically positioned assets, as well as an equity-method investment in Cogentrix Co-Investment Fund, LP (Cogentrix) (a nonconsolidated VIE), representing an approximate 10 percent indirect interest in 11 natural gas power plants.

Transco

Transco is an interstate natural gas transmission company that owns and operates an interstate natural gas pipeline system extending from Texas, Louisiana, Mississippi and the Gulf of America through Alabama, Georgia, South Carolina, North Carolina, Virginia, Maryland, Delaware, Pennsylvania, and New Jersey to the New York City metropolitan area. The system serves customers in Texas and the 12 southeast and Atlantic seaboard states mentioned above, including major metropolitan areas in Georgia, Washington D.C., Maryland, North Carolina, New York, New Jersey, and Pennsylvania. Transco is a single-member limited liability company, and as such, single-member losses are limited to the amount of its investment.

NWP

NWP owns and operates an interstate pipeline system for the mainline transmission of natural gas. This system extends from the San Juan Basin in northwestern New Mexico and southwestern Colorado through Colorado, Utah, Wyoming, Idaho, Oregon, and Washington to a point on the Canadian border near Sumas, Washington. NWP is a single-member limited liability company, and as such, single-member losses are limited to the amount of its investment.

Basis of Presentation

The accompanying interim financial statements do not include all the notes in the annual financial statements and, therefore, should be read in conjunction with the financial statements and combined notes thereto for the year ended December 31, 2025, in the Annual Report on Form 10-K. The accompanying unaudited financial statements include all normal recurring adjustments and others that, in the opinion of management, are necessary to present fairly the interim financial statements.

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying combined notes. Actual results could differ from those estimates.

Significant Risks and Uncertainties

Management believes that the carrying value of certain of Williams’ property, plant, and equipment and intangible assets, notably certain assets acquired by Williams 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 management’s 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

Notes (Continued)

expected producer activities, could impact management’s assumptions and ultimately result in impairments of these assets. Such transactions or developments may also indicate that certain Williams’ equity-method investments have experienced other-than-temporary declines in value, which could result in impairment.

Accounting Standards Issued But Not Yet Adopted

In November 2024, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2024-03, Income Statement - Reporting Comprehensive Income - Expense Disaggregation Disclosures, which requires public entities to disclose additional information in the notes to financial statements for certain types of expenses (including purchases of inventory, employee compensation, depreciation, amortization, and depletion) in commonly presented expense captions (such as cost of sales or general and administrative expenses). The amendments are effective for fiscal years beginning after December 15, 2026, and interim periods within those fiscal years beginning after December 15, 2027, with early adoption permitted. The impact of this standard is currently being evaluated.

In May 2026, the FASB issued ASU 2026-02, Environmental Credits and Environmental Credit Obligations, which establishes guidance for the recognition, measurement, presentation, and disclosure of environmental credits and related obligations. The amendments are effective for fiscal years beginning after December 15, 2027, and interim periods within those fiscal years, with early adoption permitted. The impact of this standard is currently being evaluated and is expected to primarily relate to NWP's compliance with the Washington State Climate Commitment Act.

Note 2 – Variable Interest Entities

Consolidated VIEs

As of June 30, 2026, Williams consolidated the following VIEs:

Northeast JV

Williams owns a 65 percent interest in the Northeast JV, a subsidiary that is a VIE due to certain voting rights being disproportionate to the obligation to absorb losses and substantially all of the Northeast JV’s activities being performed on Williams’ behalf. Williams is the primary beneficiary because it has 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 Williams and the other equity partner on a proportional basis.

Cardinal

Williams owns 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. Williams is the primary beneficiary because it has 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 Williams and the other equity partner on a proportional basis.

Driftwood Pipeline

Williams owns an 80 percent interest in Driftwood Pipeline LLC (Driftwood Pipeline), a subsidiary that is a VIE because completion of the Driftwood Pipeline will require additional subordinated financial support from its equity holders in the form of capital contributions. Williams is the primary beneficiary because it has the power to direct the activities that most significantly impact Driftwood Pipeline’s economic performance. Williams, as the operator of Driftwood Pipeline, is responsible for the construction of Line 200 which will supply gas to Louisiana LNG LLC’s (Louisiana LNG) export facility near Lake Charles, Louisiana. The total remaining cost of the project is expected to be funded with capital contributions from Williams and the other equity partner on a proportional basis.

Notes (Continued)

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



	June 30,		December 31,
	2026		2025
	(Millions)
Assets (liabilities):
Cash and cash equivalents	$	183	$	53
Trade accounts and other receivables	170		155
Inventories	7		6
Other current assets and deferred charges	3		5
Property, plant, and equipment – net	4,406		4,412
Intangible assets – net	1,777		1,831
Regulatory assets, deferred charges, and other	21		23
Accounts payable	(61)		(56)
Other current liabilities	(32)		(19)

Regulatory liabilities, deferred income, and other	(76)		(78)

Nonconsolidated VIEs

Williams owns certain equity-method investments that are VIEs due primarily to its limited participating rights as a minority equity holder. Williams’ maximum exposure to loss is limited to the carrying value of these investments (included within Investments in the Consolidated Balance Sheet), which totaled $617 million at June 30, 2026. Included in this total is Williams’ investment in Louisiana LNG and Cogentrix (discussed below).

Louisiana LNG

Williams owns a 10 percent interest in Louisiana LNG, which is a VIE because completion of the LNG facilities will require additional subordinated financial support from its equity holders in the form of capital contributions. At June 30, 2026, the carrying value of our investment in Louisiana LNG was $289 million. Our maximum exposure to loss is limited to the carrying value of our investment. The total remaining cost of the project is expected to be funded with capital contributions from Williams and the other equity partners on a proportional basis.

Cogentrix

The Cogentrix investment represents an approximate 10 percent indirect interest in 11 natural gas power plants. Williams’ investment is accounted for under the equity-method within the Gas & NGL Marketing Services segment, while the investee is considered an investment company, which requires accounting for its investments at fair value. Williams’ equity earnings from Cogentrix reflect its share of the operating expenses and fair value changes recorded by the investee. The current carrying value reflects the favorable impact to fair value of an announced agreement to sell a significant portion of the underlying power plant assets. The Cogentrix investment is a VIE due primarily to our limited participation rights to direct Cogentrix’s activities. At June 30, 2026, the carrying value of our investment in Cogentrix was $289 million. Our maximum exposure to loss is limited to the carrying value of our investment.

Notes (Continued)

Note 3 – Divestitures

Sale of Permian Interests

Consolidated Permian Gathering Assets

In June 2026, Williams signed an agreement to sell certain gas gathering assets in the Permian basin within its West segment. This disposal group was classified as held for sale, with the associated assets and liabilities included in Assets held for sale and Liabilities held for sale, respectively, at June 30, 2026. Williams expects to recognize a gain upon closing in the third quarter of 2026. The results of operations for this disposal group were not significant for the reporting periods.

Brazos Permian II Equity-Method Investment

In June 2026, Williams completed the sale of an equity-method investment in Brazos Permian II, LLC within its West segment for total consideration of $143 million, resulting in the recognition of a $127 million gain reflected in Other investing income (loss) – net. The consideration received consisted primarily of publicly traded limited partner units of the acquirer measured at fair value on the transaction date. The limited partner units are classified as Level 1 within the fair value hierarchy and are remeasured at fair value each reporting period, with changes in fair value recognized in earnings (see Note 7 – Fair Value Measurements and Guarantees). Williams is required to hold the limited partner units for a minimum of six months following closing.

Sale of Mid-Continent Gathering Assets

In February 2026, Williams closed on the sale of certain gas gathering assets in the Mid-Continent region within its West segment for total consideration of $48 million. This disposal group was classified as held for sale, with the associated assets and liabilities included in Assets held for sale and Liabilities held for sale, respectively, at December 31, 2025 and an impairment was recognized (see Note 7 – Fair Value Measurements and Guarantees). The results of operations for this disposal group were not significant for the reporting periods.

Sale of South Mansfield Upstream Interests

In October 2025, Williams entered into an agreement to sell its interests in certain upstream ventures in the South Mansfield area of the Haynesville Shale region, included in upstream operations within Other, for consideration of $398 million with additional contingent consideration to possibly be received through 2029. Williams classified this disposal group as held for sale, with the associated assets and liabilities included in Assets held for sale and Liabilities held for sale, respectively, at December 31, 2025. The transaction closed on January 30, 2026, and as a result of the sale Williams recognized a gain of $182 million in the first quarter of 2026 and an additional gain of $12 million in the second quarter of 2026 within Other. The gain is reflected in Gain on sale of certain assets, and the proceeds are reflected in Dispositions – net. The results of operations for this disposal group, excluding the gains noted, were not significant for the reporting periods.

Notes (Continued)

Note 4 – Revenue Recognition

Revenue by Category

The following tables present Williams’ revenue disaggregated by major service line:


	Transmission, Power & Gulf		Northeast G&P		West		Gas & NGL Marketing Services		Other		Eliminations		Total
	(Millions)
Three Months Ended June 30, 2026
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	944	$	—	$	—	$	—	$	—	$	(19)	$	925
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	261		490		469		—		—		(68)		1,152
Commodity consideration	23		1		21		—		—		—		45
Other	12		26		6		—		—		(6)		38
Total service revenues	1,240		517		496		—		—		(93)		2,160
Product sales	129		17		228		1,096		138		(389)		1,219
Total revenues from contracts with customers	1,369		534		724		1,096		138		(482)		3,379
Other revenues (1)	16		13		—		537		13		(1)		578
Other adjustments (2)	—		—		—		(995)		—		91		(904)
Total revenues	$	1,385	$	547	$	724	$	638	$	151	$	(392)	$	3,053

Three Months Ended June 30, 2025
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	927	$	—	$	—	$	—	$	—	$	(21)	$	906
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	226		460		441		—		—		(55)		1,072
Commodity consideration	28		—		19		—		—		—		47
Other	13		25		5		—		—		(5)		38
Total service revenues	1,194		485		465		—		—		(81)		2,063
Product sales	108		44		210		1,213		137		(397)		1,315
Total revenues from contracts with customers	1,302		529		675		1,213		137		(478)		3,378
Other revenues (1)	10		12		1		596		53		(1)		671
Other adjustments (2)	—		—		—		(1,420)		—		152		(1,268)
Total revenues	$	1,312	$	541	$	676	$	389	$	190	$	(327)	$	2,781

Notes (Continued)


	Transmission, Power & Gulf		Northeast G&P		West		Gas & NGL Marketing Services		Other		Eliminations		Total
	(Millions)
Six Months Ended June 30, 2026
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	1,940	$	—	$	—	$	—	$	—	$	(39)	$	1,901
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	505		958		968		—		—		(135)		2,296
Commodity consideration	49		1		41		—		—		—		91
Other	47		50		13		—		—		(13)		97
Total service revenues	2,541		1,009		1,022		—		—		(187)		4,385
Product sales	258		56		458		3,473		281		(814)		3,712
Total revenues from contracts with customers	2,799		1,065		1,480		3,473		281		(1,001)		8,097
Other revenues (1)	27		25		(1)		1,733		(21)		(2)		1,761
Other adjustments (2)	—		—		—		(4,034)		—		259		(3,775)
Total revenues	$	2,826	$	1,090	$	1,479	$	1,172	$	260	$	(744)	$	6,083

Six Months Ended June 30, 2025
Revenues from contracts with customers:
Service revenues:
Regulated interstate natural gas transportation and storage	$	1,847	$	—	$	—	$	—	$	—	$	(41)	$	1,806
Gathering, processing, transportation, fractionation, and storage:
Monetary consideration	418		922		871		—		—		(100)		2,111
Commodity consideration	51		1		44		—		—		—		96
Other	30		49		12		—		—		(10)		81
Total service revenues	2,346		972		927		—		—		(151)		4,094
Product sales	223		101		474		3,269		292		(888)		3,471
Total revenues from contracts with customers	2,569		1,073		1,401		3,269		292		(1,039)		7,565
Other revenues (1)	15		23		—		1,696		26		(2)		1,758
Other adjustments (2)	—		—		—		(3,865)		—		371		(3,494)
Total revenues	$	2,584	$	1,096	$	1,401	$	1,100	$	318	$	(670)	$	5,829

(1)Revenues not derived from contracts with customers primarily consist of physical product sales related to commodity derivative contracts, realized and unrealized gains and losses associated with Williams’ commodity derivative contracts, which are reported in Net gain (loss) from commodity derivatives in the Consolidated Statement of Comprehensive Income, management fees received for certain services provided to operated equity-method investments, and leasing revenues associated with the Williams headquarters building.

(2)Other adjustments reflect certain costs of Gas & NGL Marketing Services’ risk management activities. As Williams is acting as agent for natural gas marketing customers or engages in energy trading activities, the resulting revenues are presented net of the related costs of those activities in the Consolidated Statement of Comprehensive Income.

For Transco and NWP, revenue disaggregation by major service line includes Natural gas transportation service revenues, Natural gas storage service revenues, Natural gas product sales, and Other service revenues, which are separately presented in their Statements of Net Income.

Notes (Continued)

Contract Assets

The following tables present a reconciliation of contract assets:


	Three Months Ended June 30,
	Williams				Transco				NWP
	2026		2025		2026		2025		2026		2025
	(Millions)
Balance at beginning of period	$	112	$	104	$	13	$	14	$	24	$	22
Revenue recognized in excess of amounts invoiced	20		28		—		—		—		1
Minimum volume commitments invoiced	(6)		(30)		—		(1)		—		—

Amortization of contract assets	(13)		—		(1)		—		—		—
Balance at end of period	$	113	$	102	$	12	$	13	$	24	$	23

	Six Months Ended June 30,
	Williams				Transco				NWP
	2026		2025		2026		2025		2026		2025
	(Millions)
Balance at beginning of period	$	109	$	98	$	13	$	10	$	24	$	21
Revenue recognized in excess of amounts invoiced	37		58		—		4		—		3

Minimum volume commitments invoiced	(10)		(53)		—		(1)		—		—
Amortization of contract assets	(23)		(1)		(1)		—		—		(1)
Balance at end of period	$	113	$	102	$	12	$	13	$	24	$	23

Notes (Continued)

Contract Liabilities

The following tables present a reconciliation of contract liabilities:


	Three Months Ended June 30,
	Williams				Transco
	2026		2025		2026		2025
	(Millions)
Balance at beginning of period	$	917	$	1,016	$	160	$	171
Payments received and deferred	86		86		—		—
Liabilities acquired and other additions	—		23		—		—
Significant financing component	1		2		—		—

Recognized in revenue	(72)		(73)		(3)		(3)
Balance at end of period	$	932	$	1,054	$	157	$	168

	Six Months Ended June 30,
	Williams				Transco
	2026		2025		2026		2025
	(Millions)
Balance at beginning of period	$	948	$	1,046	$	163	$	173
Payments received and deferred	127		120		—		—
Liabilities acquired and other additions	—		23		—		—
Significant financing component	3		4		—		—

Recognized in revenue	(146)		(139)		(6)		(5)
Balance at end of period	$	932	$	1,054	$	157	$	168

The following table presents the amount of the contract liabilities balance expected to be recognized as revenue when performance obligations are satisfied as of June 30, 2026:


	Contract Liabilities
	Williams		Transco
	(Millions)
2026 (six months)	$	110	$	5
2027 (one year)	165		11
2028 (one year)	130		11
2029 (one year)	98		10
2030 (one year)	72		10
Thereafter	357		110
Total	$	932	$	157

Notes (Continued)

Remaining Performance Obligations

Remaining performance obligations primarily include reservation charges on contracted capacity for Williams’ gas pipeline firm transportation contracts with customers, storage capacity contracts, long-term contracts containing MVC associated with midstream businesses, and fixed payments associated with offshore gathering and transportation. For Williams’ interstate natural gas pipeline businesses, including Transco and NWP, remaining performance obligations generally reflect the expected rates for such services for the life of the related contracts; however, these rates may change based on future tariffs approved by the FERC.

Remaining performance obligations exclude variable consideration, including contracts with variable consideration for which it has elected the practical expedient for consideration recognized in revenue as billed. Certain of its contracts contain evergreen and other renewal provisions for periods beyond the initial term of the contract. The remaining performance obligation amounts as of June 30, 2026, do not consider potential future performance obligations for which the renewal has not been exercised and exclude contracts with customers for which the underlying facilities have not received FERC authorization to be placed into service. Consideration received prior to June 30, 2026, that will be recognized in future periods is also excluded from its remaining performance obligations and is instead reflected in contract liabilities.

The following table presents the transaction price allocated to the remaining performance obligations under certain contracts as of June 30, 2026:


	Remaining Performance Obligations
	Williams		Transco		NWP
	(Millions)
2026 (six months)	$	2,271	$	1,511	$	201
2027 (one year)	4,425		2,877		399
2028 (one year)	3,968		2,635		375
2029 (one year)	3,379		2,222		349
2030 (one year)	2,800		1,842		343
Thereafter	13,892		10,055		1,930
Total	$	30,735	$	21,142	$	3,597

Accounts Receivable

The following is a summary of Williams’ Trade accounts and other receivables:


	June 30, 2026		December 31, 2025
	(Millions)
Accounts receivable related to revenues from contracts with customers	$	1,557	$	1,532
Receivables from derivatives	148		444
Other accounts receivable	263		108
Trade accounts and other receivables	$	1,968	$	2,084

Transco and NWP receivables from contracts with customers are included within Receivables - Trade and Receivables - Affiliates. Receivables that are not related to contracts with customers are included within Receivables - Advances to affiliate and Receivables - Other.

Notes (Continued)

Note 5 – Provision (Benefit) for Income Taxes

Williams’ Provision (benefit) for income taxes includes:


	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
	(Millions)
Current:
Federal	$	(6)	$	84	$	(3)	$	163
State	9		11		15		18

	3		95		12		181
Deferred:
Federal	226		63		430		152
State	31		16		62		34

	257		79		492		186
Provision (benefit) for income taxes	$	260	$	174	$	504	$	367

The effective income tax rates for the total provision (benefit) for the three and six months ended June 30, 2026 and 2025, are greater than the federal statutory rate, primarily due to the effect of state income taxes.

Note 6 – Debt and Banking Arrangements

Senior Unsecured Debt Activity

Issuances

Issuances in 2026 are as follows:


Issue Date	Maturity Date	Amount		Rate
		(Millions)
Williams’ Public Issuances:
January 8, 2026 (1)	March 15, 2033	$	500	5.650%
January 8, 2026	March 15, 2036	1,250		5.150%
January 8, 2026	March 15, 2056	1,000		5.950%

(1) Additional issuance of the 5.65 percent senior notes due 2033 issued on March 2, 2023, and trade interchangeably with such notes.

Retirements

Retirements in 2026 are as follows:


Date of Retirement	Maturity Date	Amount		Rate
		(Millions)
Williams:
March 2, 2026	March 2, 2026	$	1,100	5.400%

Notes (Continued)

Transco Debt Registration Rights

On November 20, 2025, Transco issued $1 billion of 5.1 percent senior unsecured notes due 2036 and $700 million of 5.75 percent senior unsecured notes due 2056. As part of the private debt placement, Transco entered into a registration rights agreement with the initial purchasers of the unsecured notes. Transco filed the registration statement in February 2026 and completed the exchange offer in April 2026.

Credit Facilities

On May 19, 2026, Williams, along with Transco and NWP, entered into a second amended and restated credit agreement (Williams Credit Agreement) with the lenders named therein and the administrative agent that provides for aggregate commitments of up to $3.75 billion, with the ability to increase such commitments by up to an additional $500 million under certain circumstances, not to exceed $4.25 billion in total. The Williams Credit Agreement was effective on May 19, 2026 and matures on May 19, 2031, and permits an additional one‑year maturity extension up to two times, subject to specified conditions. The facility also permits swing line loans of up to $200 million and letters of credit commitments of up to $500 million. Transco and NWP are each able to borrow up to $500 million under the facility, subject to availability.

On May 19, 2026, Williams, along with Transco and NWP, also entered into a 364-day credit agreement (364-Day Credit Agreement, and together with the Williams Credit Agreement, the Credit Agreements) with the lenders named therein and the administrative agent that provides for aggregate commitments of up to $1 billion with the ability to increase such commitments by up to an additional $150 million under certain circumstances. However, at no time may the aggregate commitments under the 364-Day Credit Agreement exceed $1.15 billion. The facility matures 364 days after the effective date of the 364-Day Credit Agreement (364-Day Maturity Date). The Borrowers may request, prior to the 364-Day Maturity Date, that the revolving loans under the 364-Day Credit Agreement be converted on the 364-Day Maturity Date into term loans that mature one year after the 364-Day Maturity Date, subject to certain conditions. Transco and NWP are each subject to a $100 million borrowing sublimit.

The Credit Agreements contain the following terms and conditions:

Various covenants may limit, among other things, a borrower’s and its material subsidiaries’ ability to grant certain liens supporting indebtedness, merge or consolidate, sell all or substantially all of its assets in certain circumstances, make certain distributions during an event of default, and each borrower and each borrower’s respective material subsidiaries’ ability to enter into certain restrictive agreements.
If an event of default with respect to a borrower occurs under the Credit Agreements, the lenders will be able to terminate the commitments for the respective borrowers and accelerate the maturity of the loans of the defaulting borrower under the applicable credit facility and exercise other rights and remedies.
Other than swing line loans, each time funds are borrowed, the applicable borrower may choose from two methods of calculating interest based on either a fluctuating or periodic fixed base rate, plus an applicable margin. Williams is required to pay a commitment fee based on the unused portion of the applicable Credit Agreements. The applicable margin is determined by reference to a pricing schedule based on the applicable borrower’s senior unsecured long-term debt ratings and the commitment fee is determined by reference to a pricing schedule based on Williams’ senior unsecured long-term debt ratings.

Significant financial covenants under the Credit Agreements require Williams’ ratio of debt to EBITDA (earnings before interest, taxes, depreciation, and amortization), each as defined, to be no greater than 5.0 to 1.0, except that for any fiscal quarter in which the funding of the purchase price for an acquisition (whether effectuated as one or a series of related transactions) with an aggregate purchase price of $25 million or more has been effected, and the following two fiscal quarters (in each case subject to certain limitations), the ratio of debt to EBITDA is to be no greater than 5.5 to 1.

Notes (Continued)

The ratio of debt to capitalization (defined as net worth plus debt), each as defined, must be no greater than 65 percent for each of Transco and NWP.


	June 30, 2026
	Stated Capacity		Outstanding
	(Millions)
Williams Credit Agreement (1)(2)	$	3,750	$	—
364-Day Credit Agreement (2)	1,000		—
Letters of credit under certain bilateral bank agreements			15

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

(2) Williams expects to be in compliance with the associated covenants for the June 30, 2026, reporting period.

Commercial Paper Program

At June 30, 2026, $475 million commercial paper was outstanding at a weighted-average interest rate of 3.94 percent under Williams’ $3.5 billion commercial paper program.

Notes (Continued)

Note 7 – Fair Value Measurements and Guarantees

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


					Fair Value Measurements Using
	Carrying Amount		Fair Value		Quoted Prices In Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
	(Millions)
Assets (liabilities) at June 30, 2026:
Measured on a recurring basis:
ARO Trust - Transco	$	321	$	321	$	321	$	—	$	—
Commodity derivative assets (1)	266		631		392		98		141
Commodity derivative liabilities (1)	(309)		(919)		(536)		(213)		(170)
Equity securities	123		123		123		—		—


Additional disclosures:


Guarantees	(34)		(26)		—		(10)		(16)
Debt by issuer, including current portion:
Williams	(23,300)		(22,875)		—		(22,875)		—
Transco	(5,890)		(5,827)		—		(5,827)		—
NWP	(749)		(747)		—		(747)		—
MountainWest	(379)		(386)		—		(386)		—
Total debt	(30,318)		(29,835)		—		(29,835)		—

Assets (liabilities) at December 31, 2025:
Measured on a recurring basis:
ARO Trust - Transco	$	356	$	356	$	356	$	—	$	—
Commodity derivative assets (1)	336		722		431		158		133
Commodity derivative liabilities (1)	(340)		(915)		(497)		(270)		(148)

Additional disclosures:

Guarantees	(35)		(28)		—		(12)		(16)
Debt by issuer, including current portion:
Williams	(21,649)		(21,556)		—		(21,556)		—
Transco	(5,888)		(5,941)		—		(5,941)		—
NWP	(748)		(747)		—		(747)		—
MountainWest	(376)		(385)		—		(385)		—
Total debt	(28,661)		(28,629)		—		(28,629)		—

(1)The carrying amount is presented net of counterparty offsetting arrangements and collateral (see Note 8 – Commodity Derivatives).

Notes (Continued)

Fair Value Methods

The following methods and assumptions are used in estimating the fair value of financial instruments:

Assets and Liabilities Measured at Fair Value on a Recurring Basis

ARO Trust

Transco is entitled to collect rates in the amounts necessary to fund its future asset retirement obligations (AROs) and deposits a portion of the collected rates into an external trust (ARO Trust). The ARO Trust invests in a moderate risk 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 Williams’ Consolidated Balance Sheet and in Deferred charges and other in the Transco Balance Sheet. The Money market fund held in the ARO Trust is considered an investment. Both realized and unrealized gains and losses are ultimately recorded to the ARO regulatory asset. The current annual funding obligation is approximately $51 million.

Investments within the ARO Trust were as follows:


	June 30, 2026				December 31, 2025
	Amortized Cost Basis		Fair Value		Amortized Cost Basis		Fair Value
	(Millions)
Money market fund	$	3	$	3	$	34	$	34
U.S. equity funds	38		145		53		169
International equity fund	32		58		32		51
Municipal bond fund	117		115		104		102
Total	$	190	$	321	$	223	$	356

Commodity derivatives

Williams’ 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. Williams also has 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. See Note 8 – Commodity Derivatives for additional information.

Equity securities

Williams has certain investments in equity securities consisting of publicly traded limited partner units that are actively traded on the New York Stock Exchange (see Note 3 – Divestitures). These equity securities are classified as Level 1 within the fair value hierarchy and are measured at fair value on a recurring basis using quoted market prices. Changes in fair value are recognized in Other investing income (loss) – net and the fair value is reported in Other current assets and deferred charges.

Notes (Continued)

Additional Fair Value Disclosures

Guarantees

Guarantees primarily consist of a guarantee Williams has provided in the event of nonpayment by a previously owned communications subsidiary, Williams Communications Group, Inc., (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 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 Other current liabilities. The maximum potential undiscounted liquidity exposure is approximately $20 million at June 30, 2026. The 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.

Williams is required by its 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. Williams has never been called upon to perform under these indemnifications and there is no current expectation of a future claim.

Long-term debt, including current portion

The disclosed fair value of 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 the debt or similar instruments. Transco includes financing obligations associated with certain completed projects, which were measured at fair value using an income approach.

Nonrecurring Fair Value Measurements

In December 2025, Williams’ management approved a plan to sell certain gas gathering assets in the Mid-Continent region. These operations were designated as held for sale at December 31, 2025. Accordingly, the disposal group, inclusive of Intangible assets – net, was measured at fair value using the expected sales price under a third-party contract, resulting in a fourth quarter 2025 impairment charge of $176 million within the West segment. Using these inputs, the fair value of the disposal group was measured at $48 million and classified within Level 2 of the fair value hierarchy. The estimated fair value of the Property, plant, and equipment – net and Intangible assets – net were determined using a market approach incorporating indications of interest from third parties. This disposal group was sold in the first quarter of 2026 (see Note 3 – Divestitures).

Note 8 – Commodity Derivatives

Williams is exposed to commodity price risk and utilizes derivatives to manage a portion of that risk. Williams reports the fair value of commodity derivatives in Derivative assets; Regulatory assets, deferred charges, and other; Derivative liabilities; or Regulatory liabilities, deferred income, and other. The asset and liability derivative positions are netted by counterparty as permitted under the terms of the master netting arrangements and are also presented net of cash held on deposit in margin accounts that Williams has received or remitted to collateralize certain derivative positions. See Note 7 – Fair Value Measurements and Guarantees for additional fair value

Notes (Continued)

information. In Williams’ Consolidated Statement of Cash Flows, any cash impacts of settled commodity derivatives are recorded as operating activities.

Williams experiences significant earnings volatility from the fair value accounting required for the derivatives used to hedge a portion of the economic value of the underlying transportation and storage capacity portfolios as well as upstream-related production. However, the unrealized fair value measurement gains and losses on the derivatives are generally offset by valuation changes in the economic value of the underlying production or transportation and storage capacity contracts, which are not recognized until the underlying transaction occurs.

Volumes

At June 30, 2026, the notional volume of the net long (short) positions for Williams’ commodity derivative contracts were as follows:


	Commodity	Unit of Measure	Net Long (Short) Position







Index Risk	Natural Gas	MMBtu	940,413,340
Central Hub Risk - Henry Hub	Natural Gas	MMBtu	(32,484,566)
Basis Risk	Natural Gas	MMBtu	488,887,861
Central Hub Risk - Mont Belvieu	Natural Gas Liquids	Barrels	(2,910,000)
Basis Risk	Natural Gas Liquids	Barrels	(350,000)
Central Hub Risk - WTI	Crude Oil	Barrels	(860,000)

Financial Statement Presentation

The fair value of commodity derivatives, which are not designated as hedging instruments for accounting purposes, is reflected as follows:


	June 30, 2026				December 31, 2025
Commodity Derivatives Categories	Assets		(Liabilities)		Assets		(Liabilities)
	(Millions)





Current	$	412	$	(525)	$	494	$	(535)
Noncurrent	219		(394)		228		(380)
Total commodity derivatives	631		(919)		722		(915)
Counterparty and collateral netting offset	(365)		610		(386)		575
Amounts recognized in Williams’ Consolidated Balance Sheet	$	266	$	(309)	$	336	$	(340)

Notes (Continued)

The pre-tax impacts of Williams’ commodity derivatives, which are not designated as hedging instruments for accounting purposes, are reflected as follows:



	Three Months Ended June 30,				Six Months Ended June 30,
	2026		2025		2026		2025
	(Millions)
Net gain (loss) from commodity derivatives within Total revenues:

Realized	$	(47)	$	12	$	(181)	$	(28)
Unrealized	141		24		(84)		2
	$	94	$	36	$	(265)	$	(26)

Net gain (loss) from commodity derivatives within Net processing commodity expenses:
Realized	$	(2)	$	(1)	$	(3)	$	(2)
Unrealized	1		12		1		2
	$	(1)	$	11	$	(2)	$	—
Total net gain (loss) from commodity derivatives	$	93	$	47	$	(267)	$	(26)

Contingent Features

Generally, collateral may be provided in the form of 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.

Williams has 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 Williams’ credit ratings are downgraded to non-investment grade status. Under such circumstances, Williams would need to post collateral to continue transacting business with these counterparties. At June 30, 2026, the contractually required collateral in the event of a credit rating downgrade to non-investment grade status was $60 million.

Williams maintains 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, Williams may be required to deposit cash into these accounts. At June 30, 2026 and December 31, 2025, net cash collateral held on deposit in broker margin accounts was $245 million and $189 million, respectively.

Note 9 – Contingencies

Royalty Matters

Certain customers, including Expand Energy Corporation (formerly Chesapeake Energy Corporation or 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. Williams has also been named as a defendant in certain of these cases filed in Pennsylvania based on allegations that Williams improperly participated with Chesapeake in causing the alleged royalty underpayments. Williams believes that the claims asserted are subject to indemnity obligations owed to Williams by Chesapeake, which obligations survived Chesapeake’s bankruptcy proceedings. Prior to its bankruptcy, Chesapeake reached a settlement to resolve substantially all Pennsylvania royalty cases pending. During the pendency of the bankruptcy, that settlement was renegotiated. The settlement applied to both Chesapeake and Williams and did not require any contribution from Williams. On August 23, 2021, after referral to the United States District Court for the Southern District of Texas by the bankruptcy court, the court approved the settlement. Two objectors filed an appeal with the United States Court of Appeals for the Fifth Circuit. On June 8, 2023, the Court of Appeals vacated the settlement approval and

Notes (Continued)

remanded to the United States District Court for the Southern District of Texas with instructions to dismiss the settlement proceedings for lack of jurisdiction. On August 31, 2023, the bankruptcy court entered an order finding the settlement agreements to be null and void. Certain plaintiffs filed a notice of dismissal of their claims against Chesapeake that arose prior to February 8, 2021, in the United States District Court for the Middle District of Pennsylvania lawsuits. The notice stated that plaintiffs are not releasing their claims against the other defendants, including Williams, or claims against Chesapeake that arose after February 9, 2021. Chesapeake has been dismissed from the lawsuits. Williams continues to believe the claims against Williams are subject to indemnity obligations owed to Williams by Chesapeake.

Rate Matters

On August 30, 2024, Transco filed a general rate case with the FERC for an overall increase in rates and to comply with the terms of the settlement of its prior rate case. On September 30, 2024, the FERC issued an order accepting and suspending Transco’s general rate filing to be effective March 1, 2025, subject to refund and the outcome of hearing procedures established by the FERC. The order also accepted rate decreases for certain services to be effective as of October 1, 2024. During the third quarter of 2025, Transco reached an agreement in principle with its customers and the other participants to settle all aspects of the rate case and accrued a related liability for rate refunds. Transco filed with the FERC in October 2025 for approval of the settlement. On December 30, 2025, the FERC approved the settlement which became effective March 1, 2026. A total net amount of $221 million was refunded in April 2026.

Construction Litigation

In February 2025, Transco received an adverse judgment related to litigation in the United States Bankruptcy Court for the District of Delaware involving a contractor that performed construction services for Transco’s Atlantic Sunrise project, which was completed in 2018. The total judgment award included amounts for unpaid invoices, interest, and attorney fees. During the fourth quarter of 2025, Transco reached an agreement in principle with the contractor to settle all aspects of the case. Transco accrued a related liability, capitalizing the amount of the settlement in principle. On March 27, 2026, the court approved the settlement and on April 14, 2026, the settlement was paid. Transco recovered $22 million of the settlement amount paid from the co-owner of the project in May 2026.

Environmental Matters

The U.S. Environmental Protection Agency (EPA), other federal agencies, and various state regulatory agencies routinely propose and promulgate new rules, issue updated guidance to rules, or revise existing rules. These rulemakings include, but are not limited to, reviews and updates to the National Ambient Air Quality Standards, and promulgation of rules for new and existing source performance standards for certain equipment emitting volatile organic compounds and methane as well as limitations on emissions of greenhouse gas compounds. Regulatory changes are continuously monitored including how they may impact operations. Implementation of new or revised regulations may result in impacts to operations and increase the cost of additions to Property, plant, and equipment – net for both new and existing facilities in affected areas; however, due to regulatory uncertainty on final rule content or guidance and applicability timeframes, the cost of these regulatory impacts is not known at this time.

Williams

Williams is a participant in certain environmental activities in various stages including assessment studies, cleanup operations, and/or remedial processes at certain sites, some of which Williams currently does not own. Williams is monitoring these sites in a coordinated effort with other potentially responsible parties, the EPA, or other governmental authorities. Williams is jointly and severally liable along with unrelated third parties in some of these activities and solely responsible in others. Certain of Williams’ 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

Notes (Continued)

environmental laws. At June 30, 2026, Williams has accrued liabilities totaling $37 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 Williams’ experience with other similar cleanup operations. At June 30, 2026, 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.

Continuing operations

Williams’ interstate gas pipelines are involved in remediation and monitoring activities related to certain facilities and locations for polychlorinated biphenyls (PCBs), mercury, and other hazardous substances. These activities have involved the EPA and various state environmental authorities, resulting in Williams’ identification as a potentially responsible party (PRP) at various Superfund waste sites. At June 30, 2026, Williams has accrued liabilities of $11 million (see Transco and NWP below) for these costs and expects to recover approximately $3 million through rates.

Williams also accrues environmental remediation costs for natural gas underground storage facilities, primarily related to soil and groundwater contamination. At June 30, 2026, Williams has accrued liabilities totaling $7 million for these costs.

Former operations

Williams has potential obligations in connection with assets and businesses it no longer operates. 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. At June 30, 2026, Williams has accrued environmental liabilities of $19 million related to these matters.

Transco

Transco has had studies underway for many years to test some of its facilities for the presence of toxic and hazardous substances such as PCBs and mercury to determine to what extent, if any, remediation may be necessary. Transco has also similarly evaluated past on-site disposal of hydrocarbons at a number of its facilities. Transco has worked closely with and responded to data requests from the EPA and state agencies regarding such potential contamination of certain of its sites. Transco is conducting environmental assessments and implementing a variety of remedial measures that may result in increases or decreases in the total estimated costs. Transco also has a program for monitoring certain environmental activities at its Eminence storage facility. At June 30, 2026, Transco has accrued liabilities of approximately $10 million for the expected ongoing remediation and monitoring costs.

Transco has been identified as a PRP at various Superfund and state waste disposal sites. Based on present volumetric estimates and other factors, its estimated aggregate exposure for remediation of these sites is less than $1 million. The estimated remediation costs for all of these sites are included in the environmental liabilities discussed above. Liability under the Comprehensive Environmental Response, Compensation and Liability Act and applicable state law can be joint and several with other PRPs. Although volumetric allocation is a factor in assessing liability, it is not necessarily determinative; thus, the ultimate liability could be substantially greater than the amounts described above.

Transco considers prudently incurred environmental assessment and remediation costs and the costs associated with compliance with environmental standards to be recoverable through rates. Historically, with limited exceptions, it has been permitted recovery of environmental costs, and it is Transco’s intent to continue seeking recovery of such costs through future rate filings.

Notes (Continued)

NWP

Beginning in the mid-1980s, NWP evaluated many of its facilities for the presence of toxic and hazardous substances to determine to what extent, if any, remediation might be necessary. NWP identified PCB contamination in air compressor systems, soils, and related properties at certain compressor station sites. Similarly, it identified hydrocarbon impacts at these facilities due to the former use of earthen pits, lubricating oil leaks or spills, and excess pipe coating released to the environment. In addition, heavy metals have been identified at these sites due to the former use of mercury containing meters and paint and welding rods containing lead, cadmium, and arsenic. The PCBs were remediated pursuant to a Consent Decree with the EPA in the late 1980s, and NWP conducted a voluntary clean-up of the hydrocarbon and mercury impacts in the early 1990s. In 2005, the Washington Department of Ecology required NWP to re-evaluate previous clean-ups in Washington. During 2006 to 2015, 129 meter stations were evaluated, of which 82 required remediation. As of June 30, 2026, six meter stations are still being remediated. During 2006 to 2018, 14 compressor stations were evaluated, of which 11 required remediation. As of June 30, 2026, four compressor stations are still being remediated. NWP had accrued liabilities totaling approximately $1 million at June 30, 2026 for the ongoing remediation. NWP is conducting environmental assessments and implementing a variety of remedial measures that may result in increases or decreases in the total estimated costs.

Environmental expenditures are expensed or capitalized depending on their future economic benefit and potential for rate recovery. NWP believes that, with respect to any expenditures required to meet applicable standards and regulations, the FERC would grant the requisite rate relief so that substantially all of such expenditures would be permitted to be recovered through rates.

Washington State Climate Commitment Act

In 2021, the state of Washington passed its Climate Commitment Act establishing a market-based cap-and-invest program to reduce carbon emissions. This program took effect on January 1, 2023, and sets a limit, or cap, on overall carbon emissions in the state and requires businesses like NWP to obtain allowances equal to its annual covered carbon emissions. The state’s cap will be reduced over time to meet the state’s carbon emissions reduction targets, which means fewer carbon emissions allowances will be available to purchase each year. These allowances can be purchased through quarterly auctions hosted by the state or bought and sold on a secondary market. In 2023, NWP began purchasing allowances for the carbon emissions from nine of its thirteen compressor stations within the state whose annual carbon emissions have exceeded 25,000 metric tons of carbon dioxide equivalent at least once since 2015. Additionally, NWP has program obligations as a natural gas supplier and began purchasing allowances for NWP’s delivery of natural gas to certain of its customers and certain of its facilities in the state whose annual carbon emissions are insufficient to require its direct participation in the program. NWP’s latest rate case settlement allows it to recover the costs of purchasing allowances under the program in its next rate case.

At June 30, 2026 and December 31, 2025, totals of $86 million and $72 million, respectively, were included in Regulatory assets and were comprised of the cost of the purchased allowances held, the estimated difference between the allowances held and the allowances required, and the interest income component of the regulatory asset. At June 30, 2026 and December 31, 2025, $4 million and $6 million respectively, were recorded in Other current liabilities as the estimated difference. Interest income of $2 million for the six months ended June 30, 2026 and 2025, were reflected in Other income (expense) – net.

Other Divestiture Indemnifications

Pursuant to various purchase and sale agreements relating to divested businesses and assets, Williams has indemnified certain purchasers against liabilities that they may incur with respect to the businesses and assets acquired. 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.

Notes (Continued)

At June 30, 2026, other than as previously disclosed, Williams is not aware of any material claims against it involving the above-described indemnities. Any claim for indemnity brought against Williams in the future may have a material adverse effect on Williams’ results of operations in the period in which the claim is made.

In addition to the foregoing, various other proceedings are pending against Williams that are incidental to its operations, none of which are expected to be material to Williams’ expected future annual results of operations, liquidity, and financial position.

Summary

Williams, Transco, and NWP have disclosed estimated ranges of reasonably possible losses for certain matters above, as well as all significant matters for which they are unable to reasonably estimate a range of possible loss. Williams, Transco, and NWP estimate that for all other matters for which they are able to reasonably estimate a range of loss, the aggregate reasonably possible losses beyond amounts accrued are immaterial to expected future annual results of operations, liquidity, and financial position. These calculations have been made without consideration of any potential recovery from third parties.

Note 10 – Segment Disclosures

Williams

Williams’ four reportable segments are Transmission, Power & Gulf; Northeast G&P; West; and Gas & NGL Marketing Services. All remaining business activities are included in Other. (See Note 1 – Description of Business and Basis of Presentation.)

Performance Measurement

Williams’ CODM is the Chief Executive Officer. Williams’ CODM primarily utilizes Modified EBITDA, its measure of segment profit and loss, to evaluate performance and make decisions on capital allocation and human resources. Such evaluation includes periodic comparisons of actual performance versus historical and budget, as well as projections of Modified EBITDA.

Williams defines Modified EBITDA of reportable segments as follows:

Income (loss) before income taxes excluding:

◦Contributions from upstream operations, corporate, and other business activities, including the gain on the sale of certain upstream assets;

◦Depreciation, depletion, and amortization expenses;

◦Equity earnings (losses);

◦Other investing income (loss) – net;

◦Interest expense; and

◦Accretion expense associated with AROs for nonregulated operations.

This measure is further adjusted to include Williams’ proportionate share (based on ownership interest) of Modified EBITDA from its equity-method investments, including its indirect share from interests owned by equity-method investees, calculated consistently with the definition described above.

Significant noncash items which are components of Modified EBITDA may include net unrealized gain (loss) from commodity derivatives within Total revenues, net unrealized gain (loss) from commodity derivatives within

Notes (Continued)

Net processing commodity expenses for Williams’ Gas & NGL Marketing Services segment, charges associated with lower of cost or net realizable value adjustments to the Gas & NGL Marketing Services segment inventory within Product sales (for natural gas marketing inventory as these sales are presented net of the related costs) and Product costs (for NGL marketing inventory), and impairments or write-offs of certain assets within Other operating (income) expense – net.

Intersegment Service revenues primarily represent transportation services provided to Williams’ marketing business and gathering services provided to its upstream oil and gas properties. Intersegment Product sales primarily represent the sale of natural gas and NGLs from Williams’ natural gas processing plants and its oil and gas properties to its marketing business.

Segment assets include Investments, Property, plant, and equipment – net, and Intangible assets – net.

The following tables present revenues, Modified EBITDA, significant expenses, and certain segment assets measures:


	Transmission, Power & Gulf		Northeast G&P		West		Gas & NGL Marketing Services (1)		Total
	(Millions)
Three Months Ended June 30, 2026
Segment revenues:
Service revenues
External	$	1,214	$	526	$	408	$	—	$	2,148
Internal	23		3		68		—		94
Total service revenues	1,237		529		476		—		2,242
Total service revenues – commodity consideration	23		1		21		—		45
Product sales
External	25		7		30		623		685
Internal	104		10		198		(75)		237
Total product sales	129		17		228		548		922
Net gain (loss) from commodity derivatives
Realized	(4)		—		(1)		(29)		(34)
Unrealized	—		—		—		119		119
Total net gain (loss) from commodity derivatives (2)	(4)		—		(1)		90		85
Total revenues of reportable segments	$	1,385	$	547	$	724	$	638	$	3,294
Segment costs and expenses and Proportional Modified EBITDA of equity-method investments:
Product costs and net realized processing commodity expenses	(135)		(18)		(219)		(507)
Net unrealized gain (loss) from commodity derivatives within Net processing commodity expenses	—		—		—		1
Operating and administrative expenses (3)	(300)		(109)		(166)		(18)
Recoverable power, transportation, and storage costs (4)	(53)		(47)		(16)		—
Other segment income (expenses) - net (5)	26		(1)		1		(1)

Proportional Modified EBITDA of equity-method investments	36		168		35		10
Total Modified EBITDA of reportable segments	$	959	$	540	$	359	$	123	$	1,981
Reconciliation of Modified EBITDA:
Contributions from upstream operations, corporate, and other business activities									86
Gain on sale of certain upstream assets (Note 3)									12
Depreciation, depletion, and amortization expenses									(592)
Equity earnings (losses)									159
Other investing income (loss) - net (Note 3)									134
Interest expense									(371)
Accretion expense associated with AROs for nonregulated operations									(24)
Proportional Modified EBITDA of equity-method investments									(249)
Income (loss) before income taxes									$	1,136

Additions to long-lived segment assets	$	1,556	$	20	$	42	$	1	$	1,619

Notes (Continued)


	Transmission, Power & Gulf		Northeast G&P		West		Gas & NGL Marketing Services (1)		Total
	(Millions)
Three Months Ended June 30, 2025
Segment revenues:
Service revenues
External	$	1,150	$	494	$	393	$	—	$	2,037
Internal	26		3		53		—		82
Total service revenues	1,176		497		446		—		2,119
Total service revenues – commodity consideration	28		—		19		—		47
Product sales
External	31		17		31		529		608
Internal	77		27		179		(126)		157
Total product sales	108		44		210		403		765
Net gain (loss) from commodity derivatives
Realized	—		—		1		2		3
Unrealized	—		—		—		(16)		(16)
Total net gain (loss) from commodity derivatives (2)	—		—		1		(14)		(13)
Total revenues of reportable segments	$	1,312	$	541	$	676	$	389	$	2,918
Segment costs and expenses and Proportional Modified EBITDA of equity-method investments:
Product costs and net realized processing commodity expenses	(119)		(38)		(201)		(421)
Net unrealized gain (loss) from commodity derivatives within Net processing commodity expenses	—		—		—		12
Operating and administrative expenses (3)	(286)		(113)		(150)		(19)
Recoverable power, transportation, and storage costs (4)	(55)		(41)		(15)		—
Other segment income (expenses) - net (5)	2		(2)		(1)		1

Proportional Modified EBITDA of equity-method investments	37		154		32		8
Total Modified EBITDA of reportable segments	$	891	$	501	$	341	$	(30)	$	1,703
Reconciliation of Modified EBITDA:
Contributions from upstream operations, corporate, and other business activities									118
Depreciation, depletion, and amortization expenses									(605)
Equity earnings (losses)									142
Other investing income (loss) - net									4
Interest expense									(350)
Accretion expense associated with AROs for nonregulated operations									(24)
Proportional Modified EBITDA of equity-method investments									(231)
Income (loss) before income taxes									$	757

Additions to long-lived segment assets	$	725	$	54	$	238	$	1	$	1,018

Notes (Continued)


	Transmission, Power & Gulf		Northeast G&P		West		Gas & NGL Marketing Services (1)		Total
	(Millions)
Six Months Ended June 30, 2026
Segment revenues:
Service revenues
External	$	2,476	$	1,026	$	848	$	—	$	4,350
Internal	48		7		134		—		189
Total service revenues	2,524		1,033		982		—		4,539
Total service revenues – commodity consideration	49		1		41		—		91
Product sales
External	61		22		71		1,618		1,772
Internal	197		34		387		(217)		401
Total product sales	258		56		458		1,401		2,173
Net gain (loss) from commodity derivatives
Realized	(5)		—		(2)		(156)		(163)
Unrealized	—		—		—		(73)		(73)
Total net gain (loss) from commodity derivatives (2)	(5)		—		(2)		(229)		(236)
Total revenues of reportable segments	$	2,826	$	1,090	$	1,479	$	1,172	$	6,567





Segment costs and expenses and Proportional Modified EBITDA of equity-method investments:
Product costs and net realized processing commodity expenses	(271)		(57)		(438)		(985)
Net unrealized gain (loss) from commodity derivatives within Net processing commodity expenses	—		—		—		1
Operating and administrative expenses (3)	(582)		(212)		(315)		(52)
Recoverable power, transportation, and storage costs (4)	(125)		(97)		(36)		—
Other segment income (expenses) - net (5)	48		4		5		(1)


Proportional Modified EBITDA of equity-method investments	73		336		71		28
Total Modified EBITDA of reportable segments	$	1,969	$	1,064	$	766	$	163	$	3,962
Reconciliation of Modified EBITDA:
Contributions from upstream operations, corporate, and other business activities									136
Gain on sale of certain upstream assets (Note 3)									194
Depreciation, depletion, and amortization expenses									(1,176)
Equity earnings (losses)									320
Other investing income (loss) - net (Note 3)									158
Interest expense									(747)
Accretion expense associated with AROs for nonregulated operations									(47)
Proportional Modified EBITDA of equity-method investments									(508)
Income (loss) before income taxes									$	2,292











Additions to long-lived segment assets	$	2,986	$	43	$	108	$	1	$	3,138

Notes (Continued)


	Transmission, Power & Gulf		Northeast G&P		West		Gas & NGL Marketing Services (1)		Total
	(Millions)

Six Months Ended June 30, 2025
Segment revenues:
Service revenues
External	$	2,263	$	987	$	786	$	—	$	4,036
Internal	48		7		98		—		153
Total service revenues	2,311		994		884		—		4,189
Total service revenues – commodity consideration	51		1		44		—		96
Product sales
External	57		35		71		1,461		1,624
Internal	166		66		403		(319)		316
Total product sales	223		101		474		1,142		1,940
Net gain (loss) from commodity derivatives
Realized	(1)		—		(1)		(33)		(35)
Unrealized	—		—		—		(9)		(9)
Total net gain (loss) from commodity derivatives (2)	(1)		—		(1)		(42)		(44)
Total revenues of reportable segments	$	2,584	$	1,096	$	1,401	$	1,100	$	6,181





Segment costs and expenses and Proportional Modified EBITDA of equity-method investments:
Product costs and net realized processing commodity expenses	(242)		(90)		(455)		(934)
Net unrealized gain (loss) from commodity derivatives within Net processing commodity expenses	—		—		—		2
Operating and administrative expenses (3)	(556)		(219)		(302)		(58)
Recoverable power, transportation, and storage costs (4)	(125)		(83)		(29)		—
Other segment income (expenses) - net (5)	15		(2)		10		1

Proportional Modified EBITDA of equity-method investments	73		313		70		11
Total Modified EBITDA of reportable segments	$	1,749	$	1,015	$	695	$	122	$	3,581
Reconciliation of Modified EBITDA:
Contributions from upstream operations, corporate, and other business activities									193

Depreciation, depletion, and amortization expenses									(1,190)
Equity earnings (losses)									297
Other investing income (loss) - net									12
Interest expense									(699)
Accretion expense associated with AROs for nonregulated operations									(48)
Proportional Modified EBITDA of equity-method investments									(467)
Income (loss) before income taxes									$	1,679











Additions to long-lived segment assets	$	1,027	$	113	$	795	$	1	$	1,936

As of June 30, 2026
Equity-method investments by reportable segment	$	537	$	3,183	$	432	$	289	$	4,441
Segment assets	$	29,057	$	12,279	$	12,163	$	308	$	53,807

As of December 31, 2025
Equity-method investments by reportable segment	$	512	$	3,236	$	460	$	292	$	4,500
Segment assets	$	26,515	$	12,533	$	12,398	$	317	$	51,763

(1) As Williams is acting as agent for natural gas marketing customers or engages in energy trading activities, the resulting revenues are presented net of the related costs of those activities.

(2) Williams records transactions that qualify as commodity 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 from commodity derivatives held for energy trading purposes are presented on a net basis in revenue.

Notes (Continued)

(3) Segment operating and administrative expenses primarily include payroll, maintenance and operating costs and taxes, and general and administrative expenses, including acquisition and transition-related expenses. It also includes project execution, information technology, finance and accounting, real estate and aviation, central engineering services, safety and operational discipline, supply chain and digital transformation, corporate strategic development, human resources, legal and government affairs, and executive and audit support services costs which are centrally managed and allocated to segments.

(4) Recoverable power, transportation and storage costs are charges incurred which are reimbursable pursuant to FERC stipulations or customer contracts.

(5) Other segment income (expenses) - net primarily includes equity AFUDC and regulatory credits and charges related to Williams’ regulated operations.

Transco

Transco manages and evaluates its business as one single reportable segment. Transco’s CODM is the Senior Vice President, Transmission, Power & Gulf. Transco’s CODM determines resource allocation and evaluates segment operating performance based upon Net income (loss) as reported on the Statement of Net Income.

Significant expenses within net income include Operating and maintenance expenses and General and administrative expenses, which are each separately presented on Transco’s Statement of Net Income. Other segment items within net income include natural gas product costs; depreciation and amortization expenses; taxes, other than income taxes; other operating (income) expense – net; interest expense; interest income; other income (expense) – net; and AFUDC.

Transco’s segment assets include Property, plant, and equipment – net as presented on the Balance Sheet.

NWP

NWP manages and evaluates its business as one single reportable segment. NWP’s CODM is the Senior Vice President, Transmission, Power & Gulf. NWP’s CODM determines resource allocation and evaluates segment operating performance based upon Net income (loss) as reported on the Statement of Net Income.

Significant expenses within net income include Operating and maintenance expenses and General and administrative expenses, which are each separately presented on NWP’s Statement of Net Income. Other segment items within net income include depreciation and amortization expenses; taxes, other than income taxes; other operating (income) expense – net; interest expense; interest income; other income (expense) – net; and AFUDC.

NWP’s segment assets include Property, plant, and equipment – net as presented on the Balance Sheet.

Note 11 – Subsequent Events

Momentum Midstream Acquisition

In July 2026, Williams agreed to acquire M6 Midstream LLC (Momentum) for total consideration up to $5.5 billion, including approximately $2 billion of Williams common stock, subject to certain holding restrictions. Momentum’s assets in the Haynesville Shale region include 6 Bcf/d of gathering capacity and 4 Bcf/d of pipeline capacity. The transaction is expected to close later this year, subject to customary closing conditions and regulatory approvals.

Power Innovation Joint Venture

In July 2026, Williams sold a 49 percent noncontrolling interest in five power innovation projects, Socrates, Apollo, Aquila, Socrates the Younger, and Neo, to an investor in exchange for $5.34 billion of committed capital. The initial July 2026 contribution of approximately $3.75 billion is expected to increase both Capital in excess of

Notes (Continued)

par value and Noncontrolling interests in consolidated subsidiaries, reflecting the change in Williams’ ownership interest while retaining control as an equity transaction. The balance of the committed capital is expected to be received through early 2027. Cash distributions will generally align with ownership percentages and distributions to the investor in excess of a target return will serve to reduce its investment balance. In addition, Williams has a buyout right between years 7 and 14 based on the investor’s outstanding investment balance, preserving Williams’ long-term upside in the projects.

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