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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2026
or
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from _____________ to _____________
The Williams Companies, Inc.
Transcontinental Gas Pipe Line Company, LLC
Northwest Pipeline LLC
(Exact name of registrant as specified in its charter)

| Commission file number: | State or Other Jurisdiction of Incorporation or Organization: | IRS Employer Identification No.:
The Williams Companies, Inc. | 1-4174 | Delaware | 73-0569878
Transcontinental Gas Pipe Line Company, LLC | 1-7584 | Delaware | 74-1079400
Northwest Pipeline LLC | 1-7414 | Delaware | 26-1157701

| Address of Principal Executive Offices: | Zip Code: | Registrant’s Telephone Number, Including Area Code:
The Williams Companies, Inc. | One Williams Center, Tulsa, Oklahoma | 74172 | 800-945-5426 (800-WILLIAMS)
Transcontinental Gas Pipe Line Company, LLC | 2800 Post Oak Boulevard, Houston, Texas | 77056 | 713-215-2000
Northwest Pipeline LLC | One Williams Center, Tulsa, Oklahoma | 74172 | 800-945-5426

NO CHANGE

(Former name, former address and former fiscal year, if changed since last report)
Securities registered pursuant to Section 12(b) of the Act:

| Title of Each Class | Trading Symbol(s) | Name of Each Exchange on Which Registered
The Williams Companies, Inc. | Common Stock, $1.00 par value | WMB | New York Stock Exchange
Transcontinental Gas Pipe Line Company, LLC | None | None | None
Northwest Pipeline LLC | None | None | None

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

The Williams Companies, Inc. | Yes | ☑ | No | ☐
Transcontinental Gas Pipe Line Company, LLC | Yes | ☑ | No | ☐
Northwest Pipeline LLC | Yes | ☑ | No | ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

The Williams Companies, Inc. | Yes | ☑ | No | ☐
Transcontinental Gas Pipe Line Company, LLC | Yes | ☑ | No | ☐
Northwest Pipeline LLC | Yes | ☑ | No | ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

The Williams Companies, Inc. | Large accelerated filer | ☑ | Accelerated filer | ☐ | Non-accelerated filer | ☐ | Smaller reporting company | ☐ | Emerging growth company | ☐
Transcontinental Gas Pipe Line Company, LLC | Large accelerated filer | ☐ | Accelerated filer | ☐ | Non-accelerated filer | ☑ | Smaller reporting company | ☐ | Emerging growth company | ☐
Northwest Pipeline LLC | Large accelerated filer | ☐ | Accelerated filer | ☐ | Non-accelerated filer | ☑ | Smaller reporting company | ☐ | Emerging growth company | ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.

The Williams Companies, Inc. | ☐
Transcontinental Gas Pipe Line Company, LLC | ☐
Northwest Pipeline LLC | ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

The Williams Companies, Inc. | Yes | ☐ | No | ☑
Transcontinental Gas Pipe Line Company, LLC | Yes | ☐ | No | ☑
Northwest Pipeline LLC | Yes | ☐ | No | ☑

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.

| July 30, 2026
The Williams Companies, Inc. | 1,223,167,472
Transcontinental Gas Pipe Line Company, LLC | None
Northwest Pipeline LLC | None

Both Transcontinental Gas Pipe Line Company, LLC and Northwest Pipeline LLC meet the conditions set forth in General Instructions H(1)(a) and (b) of Form 10‑Q and are therefore filing this Form 10‑Q with the reduced disclosure format specified in General Instructions H(2)(a), (b), and (c) of Form 10‑Q.
This combined Form 10‑Q is separately filed by The Williams Companies, Inc., Transcontinental Gas Pipe Line Company, LLC, and Northwest Pipeline LLC. Information contained herein relating to any individual registrant is filed by such registrant on its own behalf. Each registrant makes no representation as to information relating to the other registrants.

2

FORM 10-Q
TABLE OF CONTENTS

|  | Page
Part I. Financial Information |  | 8
Item 1. Financial Statements |  | 8
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations |  | 50
Item 3. Quantitative and Qualitative Disclosures About Market Risk |  | 75
Item 4. Controls and Procedures |  | 76
Part II. Other Information |  | 78
Item 1. Legal Proceedings |  | 78
Item 1A. Risk Factors |  | 78
Item 2. Unregistered Sales of Equity Securities, Use of Proceeds, and Issuer Purchases of Equity Securities |  | 78
Item 5. Other Information |  | 79
Item 6. Exhibits |  | 80

The reports, filings, and other public announcements of Williams, Transco, and NWP may contain or incorporate by reference statements that do not directly or exclusively relate to historical facts. Such statements are “forward-looking statements” within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act. These forward-looking statements relate to anticipated financial performance, management’s plans and objectives for future operations, business prospects, outcomes of regulatory proceedings, market conditions, and other matters. Williams, Transco, and NWP make these forward-looking statements in reliance on the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995, as applicable.
All statements, other than statements of historical facts, included in this report that address activities, events, or developments that Williams, Transco, and NWP expect, believe, or anticipate will exist or may occur in the future, are forward-looking statements. Forward-looking statements can be identified by various forms of words such as “anticipates,” “believes,” “seeks,” “could,” “may,” “should,” “continues,” “estimates,” “expects,” “forecasts,” “intends,” “might,” “goals,” “objectives,” “targets,” “planned,” “potential,” “projects,” “scheduled,” “will,” “assumes,” “guidance,” “outlook,” “in-service date,” or other similar expressions. These forward-looking statements are based on management’s beliefs and assumptions and on information currently available to management and include, among others, statements regarding:
•Levels of dividends to Williams’ stockholders;
•Future credit ratings of Transco, NWP, and Williams and its affiliates;
•Amounts and nature of future capital expenditures;
•Expansion and growth of business and operations;
•Expected in-service dates for capital projects;
•Financial condition and liquidity;
•Business strategy;
•Cash flow from operations or results of operations;
•Rate case filings;
3

Table of Contents
•Seasonality of certain business components;
•Natural gas, natural gas liquids, and crude oil prices, supply, and demand;
•Demand for services.
Forward-looking statements are based on numerous assumptions, uncertainties, and risks that could cause future events or results to be materially different from those stated or implied in this report. Many of the factors that will determine these results are beyond Williams’, Transco’s, and NWP’s ability to control or predict. Specific factors that could cause actual results to differ from results contemplated by the forward-looking statements include, among others, the following:
•Availability of supplies, market demand, and volatility of prices;
•Development and rate of adoption of alternative energy sources;
•The impact of existing and future laws and regulations, the regulatory environment, environmental matters, and litigation, as well as the ability and the ability of other energy companies with whom Williams, Transco, and NWP conduct or seek to conduct business, to obtain necessary permits and approvals, and the ability to achieve favorable rate proceeding outcomes;
•Exposure to the credit risk of customers and counterparties;
•Williams’ ability to acquire new businesses and assets and successfully integrate those operations and assets into existing businesses as well as successfully expand facilities and consummate asset sales on acceptable terms;
•The ability to successfully identify, evaluate, and timely execute on capital projects and investment opportunities;
•The strength and financial resources of competitors and the effects of competition;
•The amount of cash distributions from and capital requirements of Williams’ investments and joint ventures in which Williams participates;
•The ability of Williams to effectively execute on its financing plan;
•Increasing scrutiny and changing expectations from stakeholders with respect to environmental, social, and governance practices;
•The physical and financial risks associated with climate change;
•The impacts of operational and developmental hazards and unforeseen interruptions;
•The risks resulting from outbreaks or other public health crises;
•Risks associated with weather and natural phenomena, including climate conditions and physical damage to facilities;
•Acts of terrorism, cybersecurity incidents, and related disruptions;
•Williams’ costs and funding obligations for defined benefit pension plans and other postretirement benefit plans, and Transco’s and NWP’s allocations regarding the same;
•Changes in maintenance and construction costs, as well as the ability to obtain sufficient construction- related inputs, including skilled labor;
4

Table of Contents
•Inflation, interest rates, tariffs on foreign-made materials and goods (including steel and steel pipes) necessary to conduct business, and general economic conditions (including future disruptions and volatility in the global credit markets and the impact of these events on customers and suppliers);
•Risks related to financing, including restrictions stemming from debt agreements, future changes in credit ratings as determined by nationally recognized credit rating agencies, and the availability and cost of capital;
•The ability of the members of the Organization of Petroleum Exporting Countries (OPEC) and other oil exporting nations to agree to and maintain oil price and production controls and the impact on domestic production;
•Changes in the current geopolitical situation;
•Changes in U.S. governmental administration and policies;
•Whether Williams is able to pay current and expected levels of dividends;
•Additional risks described in Williams’, Transco’s, and NWP’s SEC filings.
Given the uncertainties and risk factors that could cause Williams’, Transco’s, and NWP’s actual results to differ materially from those contained in any forward-looking statement, Williams, Transco, and NWP caution investors not to unduly rely on these forward-looking statements. Williams, Transco, and NWP disclaim any obligations to, and do not intend to, update the above list or announce publicly the result of any revisions to any of the forward-looking statements to reflect future events or developments.
In addition to causing actual results to differ, the factors listed above and referred to below may cause Williams’, Transco’s, and NWP’s intentions to change from those statements of intention set forth in this report. Such changes in intentions may also cause results to differ. Williams, Transco, and NWP may change intentions, at any time and without notice, based upon changes in such factors, assumptions, or otherwise.
Because forward-looking statements involve risks and uncertainties, Williams, Transco, and NWP caution that there are important factors, in addition to those listed above, that may cause actual results to differ materially from those contained in the forward-looking statements. For a detailed discussion of those factors, see Part I, Item 1A. Risk Factors in the Annual Report on Form 10-K for the year ended December 31, 2025, as filed with the SEC on February 24, 2026, as may be supplemented by disclosures in Part II, Item 1A. Risk Factors in subsequent Quarterly Reports on Form 10‑Q.
5

Table of Contents
DEFINITIONS
The following is a listing of certain abbreviations, acronyms, and other industry terminology that may be used throughout this Form 10-Q.
Measurements:
Barrel or Bbl: One barrel of petroleum products that equals 42 U.S. gallons
Mbbls/d: One thousand barrels per day
Bcf : One billion cubic feet of natural gas
Bcf/d: One billion cubic feet of natural gas per day
MMcf/d: One million cubic feet of natural gas per day
British Thermal Unit (Btu): A unit of energy needed to raise the temperature of one pound of water by one degree Fahrenheit
MMBtu: One million British thermal units
Megawatt or MW: A unit of power equal to one million watts of Independent System Operator (ISO) electricity generating capacity, excluding battery energy storage systems
Dekatherms (Dth): A unit of energy equal to one million British thermal units
Mdth/d: One thousand dekatherms per day
MMdth: One million dekatherms or approximately one trillion British thermal units
MMdth/d: One million dekatherms per day
Government and Regulatory:
EPA: Environmental Protection Agency
Exchange Act, the: Securities and Exchange Act of 1934, as amended
FERC: Federal Energy Regulatory Commission
SEC: Securities and Exchange Commission
Securities Act, the: Securities Act of 1933, as amended
Other:
Note: References to numerical notes refer to the Combined Notes to Financial Statements.
EBITDA: Earnings before interest, taxes, depreciation, depletion, and amortization
Fractionation: The process by which a mixed stream of natural gas liquids is separated into constituent products, such as ethane, propane, and butane
GAAP: U.S. generally accepted accounting principles
LNG: Liquefied natural gas; natural gas which has been liquefied at cryogenic temperatures
MVC: Minimum volume commitments
NGLs: Natural gas liquids; natural gas liquids result from natural gas processing and crude oil refining and are used as petrochemical feedstocks, heating fuels, and gasoline additives, among other applications.
6

Table of Contents
Equity NGL margins: NGL revenues less Btu replacement cost, plant fuel, transportation, and fractionation
Registrants: The Williams Companies, Inc. (Williams), and Williams’ wholly owned subsidiaries Transcontinental Gas Pipe Line Company, LLC (Transco) and Northwest Pipeline LLC (NWP) are each individually referred to as a Registrant and collectively as the Registrants.
Appalachia Midstream Investments: Williams’ equity-method investments with an approximate average 66 percent interest in multiple gas gathering systems in the Marcellus Shale region
7

Table of Contents
PART I
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

8

Table of Contents
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.
9

Table of Contents
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.
10

Table of Contents
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.
11

Table of Contents
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.
12

Table of Contents
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.
13

Table of Contents
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.
14

Table of Contents
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.
15

Table of Contents
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.
16

Table of Contents
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.
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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.
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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.
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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.
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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.
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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,
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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
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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.
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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.
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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.
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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 |

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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.
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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 |

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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 |

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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.
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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%

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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.
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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.
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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).
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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.
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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
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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) |

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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
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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
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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.
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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.
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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
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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 |

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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 |

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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 |

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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.
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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
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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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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Combined Management’s Discussion and Analysis of Financial Condition and Results of Operations | Page
General | 50
Company Outlook | 52
Results of Operations | 57
Williams | 57
Transco | 68
NWP | 70
Management’s Discussion and Analysis of Financial Condition and Liquidity | 71

General
Williams is an energy company committed to being the leader in providing infrastructure that safely delivers natural gas products to reliably fuel the clean energy economy. Its operations are located in the United States.
Williams’ interstate natural gas pipeline strategy is to create value by maximizing the utilization of its pipeline capacity by providing high-quality, low-cost transportation of natural gas to large and growing markets. Williams’ gas pipeline businesses’ interstate transmission and storage activities are subject to regulation by the FERC. As such, Williams’ rates and charges for the transportation of natural gas in interstate commerce; the extension, expansion, or abandonment of jurisdictional facilities; and accounting, among other things, are subject to regulation. The rates are established primarily through the FERC’s ratemaking process, but Williams may also negotiate rates with its customers pursuant to the terms of its tariffs and FERC policy. Changes in commodity prices and volumes transported have limited near-term impact on these revenues because the majority of the cost of service is recovered through firm capacity reservation charges in transportation rates.
The ongoing strategy of Williams’ midstream operations is to safely and reliably operate large-scale midstream infrastructure where its assets can be fully utilized and drive low per-unit costs. Williams focuses on consistently attracting new business by providing highly reliable service to its customers. These services include natural gas gathering and processing, treating, compression and storage; NGL fractionation, transportation and storage; and crude oil production handling and transportation, as well as marketing services for NGL, crude oil, and natural gas.
Consistent with the manner in which Williams’ CODM evaluates performance and allocates resources, Williams’ operations are conducted, managed, and presented within the following reportable segments: Transmission, Power & Gulf; Northeast G&P; West; and Gas & NGL Marketing Services (See Note 1 – Description of Business and Basis of Presentation). All remaining business activities, including upstream operations and corporate activities, are included in Other.
Unless indicated otherwise, the following discussion and analysis of results of operations and financial condition and liquidity relates to Williams’ current continuing operations and should be read in conjunction with the financial statements and combined notes thereto of this Form 10-Q and the Annual Report on Form 10-K for the year ended December 31, 2025, as filed with the SEC on February 24, 2026.
Dividends
In June 2026, Williams paid a regular quarterly dividend of $0.525 per share.
Overview of Six Months Ended June 30, 2026
Net income (loss) attributable to The Williams Companies, Inc. for the six months ended June 30, 2026, increased $455 million compared to the six months ended June 30, 2025. Further discussion of the results is found in this report in the Results of Operations.
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Recent Developments
Momentum Midstream Acquisition
In July 2026, Williams agreed to acquire 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 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.
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. These operations were designated as held for sale at June 30, 2026. Williams expects to recognize a gain upon closing in the third quarter of 2026. See Note 3 – Divestitures.
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 the second quarter of 2026. See Note 3 – Divestitures.
Transco FERC Rate Case Filing
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. The refunds were paid in April 2026.
Sale of Mid-Continent Gathering Assets
In February 2026, Williams closed on the sale of certain gas gathering assets in the Mid-Continent region. These operations were designated as held for sale at December 31, 2025 and an impairment, within the West segment, was recognized. See Note 7 – Fair Value Measurements and Guarantees.
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Sale of South Mansfield Upstream Interests
In January 2026, Williams closed on the sale of its interests in certain upstream ventures in the South Mansfield area of the Haynesville Shale region, included in Other, for consideration of $398 million with additional contingent consideration to possibly be received through 2029. Upon closing, 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. See Note 3 – Divestitures.
Expansion Project Updates
Expansion projects placed into service for the current year are described below. Ongoing major expansion projects are discussed later in Company Outlook.
Transmission, Power & Gulf
Power Innovation- Socrates
The project consists of the Socrates North and South power generation facilities and associated gas pipeline infrastructure in New Albany, Ohio, which together have an expected 556 MW of capacity. Socrates South was placed into service in late July 2026. Socrates North remains under construction and is expected to be placed into service later in the fourth quarter of 2026. The project is supported by a 10‑year, primarily fixed‑price power purchase agreement, with an option for the customer to extend the term of the agreement. Williams has received necessary approvals from the Ohio Power Siting Board.
Naughton Coal-to-Gas Conversion
The project involves an expansion of NWP’s existing natural gas transmission system to provide year-round transportation capacity to a power plant in southwest Wyoming. NWP placed the project into service in April 2026, increasing NWP’s contracted capacity by 98 Mdth/d.
Company Outlook
Williams’ strategy is to provide a large-scale, reliable, and clean energy infrastructure designed to maximize the opportunities created by the vast supply of natural gas and natural gas products that exists in the United States. Williams accomplishes this by connecting the growing demand for cleaner fuels and feedstocks with our major positions in the premier natural gas and natural gas products supply basins. Williams continues to maintain a strong commitment to safety, environmental stewardship including seeking opportunities for renewable energy ventures, operational excellence, and customer satisfaction. Williams believes that accomplishing these goals will position it to deliver safe, reliable, clean energy services to its customers and an attractive return to shareholders. Williams’ business plan for 2026 includes a continued focus on earnings and cash flow growth.
In 2026, Williams’ operating results are expected to benefit from the continued growth in the Transmission, Power & Gulf segment, primarily reflecting the impacts of the Socrates Power Innovation project, as well as numerous expansion projects at Transco and the Gulf of America. Growth in 2026 will benefit from a full year of the Louisiana Energy Gateway expansion project as well as expected increases in Haynesville Shale volumes, including the recently announced Momentum acquisition. Additionally, Williams expects higher gathering and processing results in the Northeast. These increases are partially offset by the divestiture of the South Mansfield upstream joint venture, and lower expected Eagle Ford results in our West segment which relate to contractual step-downs in minimum volume commitments.
Williams seeks to maintain a strong financial position and liquidity, as well as manage a diversified portfolio of safe, clean, and reliable energy infrastructure assets that continue to serve key growth markets and supply basins in the United States. Williams’ growth capital and investment expenditures in 2026 are expected to range from $7.3 billion to $7.9 billion, excluding acquisitions and certain long-lead time equipment for power innovation projects which are backed by reimbursement from the customer if the equipment order is canceled. Growth capital
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spending in 2026 primarily includes the Power Innovation projects, Transco expansions, all of which are fully contracted with firm transportation agreements, projects supporting growth in the Haynesville Shale basin, and projects supporting the Northeast G&P business. Williams is investing capital in the Louisiana LNG and Driftwood Pipeline projects, as well as the development of its Wamsutter upstream oil and gas properties. In addition to growth capital and investment expenditures, Williams also remains committed to projects that maintain its assets for safe and reliable operations, as well as projects that reduce emissions, and meet legal, regulatory, and/or contractual commitments.
Potential risks and obstacles that could impact the execution of Williams’ plan include:
•A global recession, which could result in downturns in financial markets and commodity prices, as well as impact demand for natural gas and related products;
•Opposition to, and regulations affecting, our infrastructure projects, including the risk of delay or denial in permits and approvals needed for our projects;
•Counterparty credit and performance risk;
•Unexpected significant increases in capital expenditures or delays in capital project execution, including increases from inflation or delays caused by supply chain disruptions;
•Unexpected changes in customer drilling and production activities, which could negatively impact gathering and processing volumes;
•Lower than anticipated demand for natural gas and natural gas products which could result in lower-than-expected volumes, energy commodity prices, and margins;
•General economic, financial markets, or industry downturns, including increased inflation, interest rates, or tariffs;
•Physical damages to facilities, including damage to offshore facilities by weather-related events;
•Other risks set forth under Part I, Item 1A. Risk Factors in the Annual Report on Form 10-K for the year ended December 31, 2025, as filed with the SEC on February 24, 2026, as may be supplemented by disclosure in Part II, Item 1A. Risk Factors in subsequent Quarterly Reports on Form 10‑Q.
Expansion Projects
Williams’ ongoing major expansion projects include the following:
Transmission, Power & Gulf
Gillis West
In July 2026, Transco was authorized under its FERC blanket certificate to proceed with the project, which involves an expansion of Transco’s existing natural gas transmission system to provide incremental firm transportation capacity from receipt points in Louisiana to delivery points in Texas. Transco plans to place the project into service as early as the fourth quarter of 2026, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 115 Mdth/d.
Southeast Supply Enhancement
In January 2026, Transco received FERC approval for the project, which involves an expansion of Transco’s existing natural gas transmission system to provide incremental firm transportation capacity from receipt points in Virginia to delivery points in Virginia, North Carolina, South Carolina, Georgia, and Alabama. Transco plans to place the project into service as early as the third quarter of 2027, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 1,597 Mdth/d.
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Northeast Supply Enhancement
In August 2025, the FERC issued an order granting Transco’s petition for reissuance of the certificate authorization for the project, which involves an expansion of Transco’s existing natural gas transmission system to provide incremental firm transportation capacity from Transco’s Compressor Station 195 in Pennsylvania to the Rockaway Delivery Lateral transfer point in New York. In October and November 2025, Transco’s applications for Clean Water Act and related permits with the states of Pennsylvania, New York and New Jersey were approved. In August 2025, Transco executed precedent agreements with customers subscribing to all of the capacity under the project. Transco plans to place the project into service as early as the fourth quarter of 2027, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 400 Mdth⁄d.
Leidy Access
Transco plans to file an application with the FERC by fourth quarter of 2026 for the project, which involves an expansion of Transco’s existing natural gas transmission system to provide incremental firm transportation capacity on the Leidy Line. Transco plans to place the project into service as early as the fourth quarter of 2027, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 183 Mdth/d.
Line 200
In April 2023, Driftwood received FERC approval for Line 200, which will connect a pipeline to the Louisiana LNG facility. Williams will be the operator of the pipeline and plans to place the project into service as early as the second quarter of 2028. The pipeline has an expected capacity of 3,100 Mdth/d.
Pine Prairie Phase IV Expansion
In May 2026, Williams received the FERC approval for the project, which will involve an expansion of storage capacity and the injection and withdrawal capabilities of one of its existing storage facilities in the Gulf Coast region. Williams plans to place the project into service during the fourth quarter of 2028, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase working gas storage capacity by 10 Bcf.
Dalton Lateral II
Transco plans to file a certificate application for the project with the FERC in 2027. The project involves an expansion of Transco’s existing natural gas transmission system to provide incremental firm transportation capacity from Transco’s main line near existing Station 115 to an existing power plant in Georgia. Transco plans to place the project into service as early as the fourth quarter of 2029, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity up to 460 Mdth/d.
Power Express
Transco plans to file an application with the FERC as early as the second quarter 2027 for the project, which involves an expansion of Transco’s existing natural gas transmission system to provide incremental firm transportation capacity in Virginia. Transco plans to place the project into service as early as the third quarter of 2030, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 800 Mdth/d.
Ryckman Creek Lateral
In February 2026, NWP was authorized under its FERC blanket certificate to proceed with the project, which involves an expansion of NWP’s existing natural gas transmission system to provide incremental firm
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transportation capacity from a receipt point in northeast Oregon to multiple delivery points in southwest Wyoming. NWP plans to place the project into service as early as the fourth quarter of 2026. The project is expected to increase contracted capacity by 50 Mdth/d.
Huntingdon Connector
In May 2026, NWP was authorized under its FERC blanket certificate to proceed with the project, which involves an expansion of NWP’s existing natural gas transmission system that will provide year-round transportation capacity from the Sumas receipt point to various delivery points in Washington. NWP plans to place the project into service during the fourth quarter of 2026, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 78 Mdth/d.
Wild Trail
In March 2026, NWP received FERC approval for the project, which involves an expansion of NWP’s existing natural gas transmission system that will provide year-round transportation capacity from the White River Hub receipt point in western Colorado to various delivery points in southwest Wyoming and southern Colorado. The Wild Trail project is fully subscribed by an affiliate of NWP. NWP plans to place the project into service during the fourth quarter of 2027, assuming timely receipt of all necessary regulatory approvals. The project is expected to provide 83 Mdth/d of new firm transportation service through a combination of increasing capacity and utilizing existing capacity.
Kelso-Beaver Reliability
In November 2025, NWP received FERC approval for the project, which will provide year-round transportation capacity to various receipt and delivery points in Oregon. NWP plans to place the project into service during the fourth quarter of 2028, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 183 Mdth/d. In May 2026, NWP purchased the 17-mile Kelso-Beaver pipeline, a key milestone for this project.
Silver Spur
NWP plans to file an application with the FERC as early as the second half of 2027 for the project, which will provide year-round transportation capacity from the Rockies Supply hub at Opal, Wyoming to various delivery points in Idaho. NWP plans to place the project into service as early as second quarter of 2030, assuming timely receipt of all necessary regulatory approvals. The project is expected to increase capacity by 275 Mdth/d.
Power Innovation
Williams has agreed to provide committed power generation and associated gas pipeline infrastructure for four additional Power Innovation projects, Apollo, Aquila, Socrates the Younger, and Neo. The projects are backed by primarily fixed-price power purchase agreements, with options for the customer to extend the term of the agreements. The Apollo project, in Ohio, has a term of 12.5 years, and Williams expects the project to be placed into service in the second half of 2027 and to provide 490 MW of capacity. The Aquila project, in Utah, also has a term of 12.5 years, and Williams expects the project to be placed into service in the second half of 2027 and the first half of 2028 and to provide 520 MW of capacity. The Socrates the Younger project, in Ohio, has a term of 10 years, and Williams expects the project to be placed into service the second half of 2028 and to provide 340 MW of capacity. The Neo project, in Ohio, has a term of 12.5 years, and Williams expects the project to be placed into service in the second half of 2028 and to provide 682 MW of capacity. All expected in-service dates assume timely receipt of permits.
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West
Dorne
Williams will construct and operate a greenfield treating and dehydration facility with a capacity of 400 MMcf/d. This project is expected to be placed into service in the third quarter of 2027.
Shelby Trough Connector
The project is designed to provide access to growing Haynesville production in the Shelby Trough area through the construction of 64 miles of new lateral pipeline and additional compression facilities connecting to the Louisiana Energy Gateway system. The project is expected to provide 750 MMcf/d of transportation capacity, with expansion capabilities up to 1.5 Bcf/d, and is expected to be placed into service during the second quarter of 2028.
Delta Access
The project, which is subject to completion of the Momentum acquisition, is designed to provide additional transmission capacity to serve growing power generation and LNG demand through an expansion along the Transco corridor. The project is expected to provide 2,250 Mdth/d of transportation capacity, with additional expansion opportunities, and is expected to be placed into service during the first quarter of 2029.
Other
Lakeland Solar Project
Williams is constructing and will operate a 75 MW alternating current solar power facility interconnecting with Lakeland Electric in Florida. This project is expected to be placed in service in the fourth quarter of 2026.
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Management’s Discussion and Analysis (Continued)
Results of Operations
Williams’ Consolidated Overview
The following table and discussion is a summary of Williams’ consolidated results of operations for the three and six months ended June 30, 2026, compared to the three and six months ended June 30, 2025, and should be read in conjunction with the results of operations by segment, as discussed in further detail following this consolidated overview discussion.

| Three Months Ended June 30, |  | Change* |  | Six Months Ended June 30, |  | Change* |  |  |  |  |  |  |  |  |  |  |  |
| 2026 |  | 2025 |  | $ |  | % |  | 2026 |  | 2025 |  | $ |  | % |  |  |  |  |  |  |  |  |  |  |  |
| (Dollars in millions)
Revenues: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Service revenues | $ | 2,152 |  |  | $ | 2,041 |  |  | +111 |  |  | +5 | % |  | $ | 4,358 |  |  | $ | 4,044 |  |  | +314 |  |  | +8 | % |  |  |  |  |  |  |  |  |  |  |  |
Product sales and service revenues – commodity consideration | 807 |  |  | 704 |  |  | +103 |  |  | +15 | % |  | 1,990 |  |  | 1,811 |  |  | +179 |  |  | +10 | % |  |  |  |  |  |  |  |  |  |  |  |
Net gain (loss) from commodity derivatives | 94 |  |  | 36 |  |  | +58 |  |  | +161 | % |  | (265) |  |  | (26) |  |  | -239 |  |  | NM |  |  |  |  |  |  |  |  |  |  |  |
Total revenues | 3,053 |  |  | 2,781 |  |  |  |  |  |  | 6,083 |  |  | 5,829 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Costs and expenses: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Product costs and net processing commodity expenses | 515 |  |  | 478 |  |  | -37 |  |  | -8 | % |  | 1,073 |  |  | 1,121 |  |  | +48 |  |  | +4 | % |  |  |  |  |  |  |  |  |  |  |  |
Operating and maintenance expenses | 597 |  |  | 572 |  |  | -25 |  |  | -4 | % |  | 1,162 |  |  | 1,114 |  |  | -48 |  |  | -4 | % |  |  |  |  |  |  |  |  |  |  |  |
Depreciation, depletion, and amortization expenses | 592 |  |  | 605 |  |  | +13 |  |  | +2 | % |  | 1,176 |  |  | 1,190 |  |  | +14 |  |  | +1 | % |  |  |  |  |  |  |  |  |  |  |  |
General and administrative expenses | 180 |  |  | 168 |  |  | -12 |  |  | -7 | % |  | 373 |  |  | 362 |  |  | -11 |  |  | -3 | % |  |  |  |  |  |  |  |  |  |  |  |
Gain on sale of certain assets | (12) |  |  | — |  |  | +12 |  |  | NM |  | (194) |  |  | — |  |  | +194 |  |  | NM |  |  |  |  |  |  |  |  |  |  |  |
Other operating (income) expense – net | (1) |  |  | 13 |  |  | +14 |  |  | NM |  | (10) |  |  | 3 |  |  | +13 |  |  | NM |  |  |  |  |  |  |  |  |  |  |  |
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 |  |  | +17 |  |  | +12 | % |  | 320 |  |  | 297 |  |  | +23 |  |  | +8 | % |  |  |  |  |  |  |  |  |  |  |  |
Other investing income (loss) – net | 134 |  |  | 4 |  |  | +130 |  |  | NM |  | 158 |  |  | 12 |  |  | +146 |  |  | NM |  |  |  |  |  |  |  |  |  |  |  |
Interest expense | (371) |  |  | (350) |  |  | -21 |  |  | -6 | % |  | (747) |  |  | (699) |  |  | -48 |  |  | -7 | % |  |  |  |  |  |  |  |  |  |  |  |
Other income (expense) – net | 32 |  |  | 16 |  |  | +16 |  |  | +100 | % |  | 58 |  |  | 30 |  |  | +28 |  |  | +93 | % |  |  |  |  |  |  |  |  |  |  |  |
Income (loss) before income taxes | 1,136 |  |  | 757 |  |  |  |  |  |  | 2,292 |  |  | 1,679 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Less: Provision (benefit) for income taxes | 260 |  |  | 174 |  |  | -86 |  |  | -49 | % |  | 504 |  |  | 367 |  |  | -137 |  |  | -37 | % |  |  |  |  |  |  |  |  |  |  |  |
Net income (loss) | 876 |  |  | 583 |  |  |  |  |  |  | 1,788 |  |  | 1,312 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Less: Net income attributable to noncontrolling interests | 49 |  |  | 37 |  |  | -12 |  |  | -32 | % |  | 96 |  |  | 75 |  |  | -21 |  |  | -28 | % |  |  |  |  |  |  |  |  |  |  |  |
Net income (loss) attributable to The Williams Companies, Inc. | $ | 827 |  |  | $ | 546 |  |  | +281 |  |  | +51 | % |  | $ | 1,692 |  |  | $ | 1,237 |  |  | +455 |  |  | +37 | % |  |  |  |  |  |  |  |  |  |  |  |

_______
* + = Favorable change; - = Unfavorable change; NM = A percentage calculation is not meaningful due to a change in signs, a zero-value denominator, or a percentage change greater than 200.
57

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Management’s Discussion and Analysis (Continued)
Three months ended June 30, 2026 vs. three months ended June 30, 2025
Service revenues increased primarily due to:
•Higher revenues associated with expansion projects at the West and the Transmission, Power & Gulf segments;
•Higher volumes from the Northeast JV at the Northeast G&P segment;
•Increased Gulf Coast storage rates at the Transmission, Power & Gulf segment.
The net sum of Product sales and service revenues – commodity consideration, Product costs and net processing commodity expenses, and net realized gains and losses on commodity derivatives related to sales of product and shrink gas purchases for processing plants for the reportable segments comprise Commodity Margins. Service revenues - commodity consideration represent payments received in the form of commodities for processing services provided. Most of these commodity volumes are sold during the month processed and are offset within Product costs and net processing commodity expenses. The sum of Product sales and net realized gains and losses on commodity derivatives related to the upstream operations comprise Net realized product sales.
The Product sales and service revenues – commodity consideration increase primarily consists of:
•Higher marketing sales activities primarily related to higher NGL marketing sales activities and net gas marketing sales activities at the Gas & NGL Marketing Services segment;
•Higher product sales from upstream operations primarily related to higher volumes in the Wamsutter region, substantially offset by lower volumes from the January 2026 sale of interests in certain upstream ventures in the South Mansfield area of the Haynesville Shale region (See Note 3 – Divestitures), at Other.
As Williams is acting as agent for natural gas marketing customers, its natural gas marketing product sales are presented net of the related costs of those activities within the Gas & NGL Marketing Services segment.
Net gain (loss) from commodity derivatives includes realized and unrealized gains and losses from derivative instruments reflected within Total revenues primarily in the Gas & NGL Marketing Services segment, as well as upstream operations at Other (see Note 8 – Commodity Derivatives).
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.
The Product costs and net processing commodity expenses increase primarily consists of higher marketing activities related to NGLs at the Transmission, Power & Gulf and Gas & NGL Marketing Services segments.
Operating and maintenance expenses increased primarily due to higher employee-related costs and operating taxes.
Depreciation, depletion, and amortization expenses decreased primarily related to lower Transco rates at the Transmission, Power & Gulf segment and the sale of the South Mansfield interests at Other, partially offset by assets placed in service at the West segment.
Gain on sale of certain assets reflects an additional gain from the sale of the South Mansfield interests, at Other.
Other investing income (loss) – net reflects a gain from the sale of an equity-method investment in Brazos Permian II, LLC at the West segment.
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Management’s Discussion and Analysis (Continued)
Interest expense was unfavorably impacted by 2025 and 2026 debt issuances, partially offset by 2025 and 2026 debt retirements (see Note 6 – Debt and Banking Arrangements) and higher interest capitalized due to ongoing expansion projects.
Provision (benefit) for income taxes changed unfavorably primarily due to higher pre-tax income. See Note 5 – Provision (Benefit) for Income Taxes for a discussion of the effective tax rate compared to the federal statutory rate for both periods.
Six months ended June 30, 2026 vs. six months ended June 30, 2025
Service revenues increased primarily due to:
•Higher revenues associated with expansion projects at the Transmission, Power & Gulf and the West segments;
•Increased Transco transportation rates and Gulf Coast storage rates at the Transmission, Power & Gulf segment;
•Higher volumes from the Northeast JV at the Northeast G&P segment.
The Product sales and service revenues – commodity consideration increase primarily consists of:
•Higher marketing sales activities primarily related to higher net gas marketing sales activities and NGL marketing sales activities at the Gas & NGL Marketing Services segment; partially offset by
•Lower product sales from upstream operations primarily related to lower volumes from the sale of the South Mansfield interests; partially offset by higher volumes in the Wamsutter region, at Other.
Net gain (loss) from commodity derivatives includes realized and unrealized gains and losses from derivative instruments reflected within Total revenues primarily in the Gas & NGL Marketing Services segment, as well as upstream operations at Other.
The Product costs and net processing commodity expenses decrease primarily consists of lower marketing activities related to NGLs at the West and Gas & NGL Marketing Services segments.
Operating and maintenance expenses increased primarily due to higher operating taxes and employee-related expenses.
Depreciation, depletion, and amortization expenses decreased primarily related to lower Transco rates at the Transmission, Power & Gulf segment and the sale of the South Mansfield interests at Other, partially offset by assets placed in service at the West segment.
Gain on sale of certain assets reflects gains from the sale of the South Mansfield interests, at Other.
Other investing income (loss) – net reflects a gain from the sale of an equity-method investment in Brazos Permian II, LLC at the West segment.
Interest expense was unfavorably impacted by 2025 and 2026 debt issuances, partially offset by 2025 and 2026 debt retirements and higher interest capitalized due to ongoing expansion projects.
The favorable change in Other income (expense) – net includes an increase in equity AFUDC primarily as a result of capital projects at the regulated businesses.
Provision (benefit) for income taxes changed unfavorably primarily due to higher pre-tax income.
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Management’s Discussion and Analysis (Continued)
Period-Over-Period Operating Results – Williams’ Segments
Williams’ CODM evaluates segment operating performance based upon Modified EBITDA. Note 10 – Segment Disclosures includes a reconciliation of this non-GAAP measure to Income (loss) before income taxes. Management uses Modified EBITDA because it is an accepted financial indicator used by investors to compare company performance. In addition, management believes that this measure provides investors an enhanced perspective of the operating performance of Williams’ assets. Modified EBITDA should not be considered in isolation or as a substitute for a measure of performance prepared in accordance with GAAP.
Transmission, Power & Gulf

| Three Months Ended June 30, |  | Six Months Ended June 30, |  |
| 2026 |  | 2025 |  | 2026 |  | 2025 |  |
| (Millions)
Service revenues | $ | 1,237 |  |  | $ | 1,176 |  |  | $ | 2,524 |  |  | $ | 2,311 |  |  |
Product sales and service revenues – commodity consideration (1) | 152 |  |  | 136 |  |  | 307 |  |  | 274 |  |  |
Net realized gain (loss) from commodity derivatives (1) | (4) |  |  | — |  |  | (5) |  |  | (1) |  |  |
Segment revenues | 1,385 |  |  | 1,312 |  |  | 2,826 |  |  | 2,584 |  |  |
Product costs and net processing commodity expenses (1) | (135) |  |  | (119) |  |  | (271) |  |  | (242) |  |  |
Other segment costs and expenses | (327) |  |  | (339) |  |  | (659) |  |  | (666) |  |  |
Proportional Modified EBITDA of equity-method investments | 36 |  |  | 37 |  |  | 73 |  |  | 73 |  |  |
Transmission, Power & Gulf Modified EBITDA | $ | 959 |  |  | $ | 891 |  |  | $ | 1,969 |  |  | $ | 1,749 |  |  |
Commodity margins | $ | 13 |  |  | $ | 17 |  |  | $ | 31 |  |  | $ | 31 |  |  |

_______________
(1)Included as a component of Commodity margins.
Three months ended June 30, 2026 vs. three months ended June 30, 2025
Transmission, Power & Gulf Modified EBITDA increased primarily due to higher Service revenues and lower Other segment costs and expenses.
Service revenues increased primarily due to:
•A $16 million increase in Gulf Coast Storage’s revenues primarily associated with higher storage rates;
•A $13 million increase in Discovery’s revenues primarily in natural gas gathering revenues due to volumes from the Shenandoah expansion project that went in-service in July 2025;
•A $13 million increase in Transco’s revenues primarily associated with expansion projects placed in-service, notably Commonwealth Energy Connector in November 2025;
•A $6 million increase in MountainWest’s revenues primarily due to the Overthrust Westbound Compression expansion project that went in-service in November 2025.
Other segment costs and expenses decreased primarily due to:
•Favorable change in equity AFUDC primarily from Driftwood Pipeline’s Line 200 and other capital projects within the regulated businesses; partially offset by
•Higher operating expenses and administrative costs including higher employee-related costs.
60

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Management’s Discussion and Analysis (Continued)
Six months ended June 30, 2026 vs. six months ended June 30, 2025
Transmission, Power & Gulf Modified EBITDA increased primarily due to higher Service revenues.
Service revenues increased primarily due to:
•An $81 million increase in Transco’s revenues primarily associated with expansion projects placed in service, notably Commonwealth Energy Connector in November 2025, Texas Louisiana Energy Pathway in April 2025, Southeast Energy Connector in April 2025, and Alabama Georgia Connector in October 2025; as well as transportation rate increases and higher park and loan services;
•A $41 million increase in Gulf Coast Storage’s revenues primarily associated with higher storage rates and higher park and loan services;
•A $32 million increase in Discovery’s revenues primarily in natural gas gathering revenues due to volumes from the Shenandoah expansion project;
•A $14 million increase in the Eastern Gulf Coast region primarily due to higher crude oil transportation and natural gas gathering volumes from new wells at Blind Faith in the Ballymore field, partially offset by a decrease at Devil’s Tower related to lower volumes from the Kodiak field;
•A $14 million increase in NWP’s revenues primarily due to transportation rate increases;
•A $12 million increase in the Western Gulf Coast region primarily due to higher natural gas gathering and crude oil transportation volumes from the Whale expansion project that went in-service in January 2025;
•A $10 million increase in MountainWest’s revenues primarily due to the Overthrust Westbound Compression expansion project.
Other segment costs and expenses decreased primarily due to:
•Favorable change in equity AFUDC primarily from Driftwood Pipeline’s Line 200 and other capital projects within the regulated businesses; partially offset by
•Higher operating expenses and administrative costs including higher employee-related costs, and increased corporate allocations.
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Management’s Discussion and Analysis (Continued)
Northeast G&P

| Three Months Ended June 30, |  | Six Months Ended June 30, |  |
| 2026 |  | 2025 |  | 2026 |  | 2025 |  |
| (Millions)
Service revenues | $ | 529 |  |  | $ | 497 |  |  | $ | 1,033 |  |  | $ | 994 |  |  |
Product sales and service revenues – commodity consideration (1) | 18 |  |  | 44 |  |  | 57 |  |  | 102 |  |  |
Segment revenues | 547 |  |  | 541 |  |  | 1,090 |  |  | 1,096 |  |  |
Product costs and net processing commodity expenses (1) | (18) |  |  | (38) |  |  | (57) |  |  | (90) |  |  |
Other segment costs and expenses | (157) |  |  | (156) |  |  | (305) |  |  | (304) |  |  |
Proportional Modified EBITDA of equity-method investments | 168 |  |  | 154 |  |  | 336 |  |  | 313 |  |  |
Northeast G&P Modified EBITDA | $ | 540 |  |  | $ | 501 |  |  | $ | 1,064 |  |  | $ | 1,015 |  |  |
Commodity margins | $ | — |  |  | $ | 6 |  |  | $ | — |  |  | $ | 12 |  |  |

(1)Included as a component of Commodity margins.
Three months ended June 30, 2026 vs. three months ended June 30, 2025
Northeast G&P Modified EBITDA increased primarily due to higher Service revenues and higher Proportional Modified EBITDA of equity-method investments.
Service revenues increased primarily due to:
•A $22 million increase in revenues at the Northeast JV primarily related to higher gathering, processing, transportation, and fractionation volumes; and
•A $4 million increase in gathering revenues at Susquehanna Supply Hub primarily related to escalated gathering rates.
Proportional Modified EBITDA of equity-method investments increased at Blue Racer primarily driven by new MVC revenue, and higher transportation and fractionation volumes; and at Appalachia Midstream Investments primarily driven by escalated gathering rates and higher gathering volumes.
Six months ended June 30, 2026 vs. six months ended June 30, 2025
Northeast G&P Modified EBITDA increased primarily due to higher Proportional Modified EBITDA of equity-method investments and higher Service revenues, partially offset by lower Commodity margins.
Service revenues increased primarily due to:
•A $38 million increase in revenues at the Northeast JV primarily related to higher gathering, processing, transportation, and fractionation volumes;
•A $13 million increase in revenues associated with reimbursable expenses, which is offset by similar changes in the charges included in Other segment costs and expenses; partially offset by
•A $14 million decrease in gathering revenues at Susquehanna Supply Hub primarily related to lower volumes, partially offset by escalated rates.
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Management’s Discussion and Analysis (Continued)
Other segment costs and expenses in creased due higher operating expenses, including higher electricity and fuel, substantially offset by favorable changes in revaluation of a net imbalance liability due to changes in pricing.
Proportional Modified EBITDA of equity-method investments increased at Appalachia Midstream Investments primarily driven by higher gathering volumes and escalated gathering rates; and at Blue Racer primarily driven by new MVC revenue, higher gathering rates, and higher volumes.
Commodity margins decreased as a result of the expiration of a restructured gas purchase agreement in 2025.
West

| Three Months Ended June 30, |  | Six Months Ended June 30, |  |
| 2026 |  | 2025 |  | 2026 |  | 2025 |  |
| (Millions)
Service revenues | $ | 476 |  |  | $ | 446 |  |  | $ | 982 |  |  | $ | 884 |  |  |
Product sales and service revenues – commodity consideration (1) | 249 |  |  | 229 |  |  | 499 |  |  | 518 |  |  |
Net realized gain (loss) from commodity derivatives relating to service revenues | 1 |  |  | — |  |  | — |  |  | (1) |  |  |
Net realized gain (loss) from commodity derivatives relating to product sales (1) | (2) |  |  | 1 |  |  | (2) |  |  | — |  |  |
Net realized gain (loss) from commodity derivatives | (1) |  |  | 1 |  |  | (2) |  |  | (1) |  |  |
Segment revenues | 724 |  |  | 676 |  |  | 1,479 |  |  | 1,401 |  |  |
Product costs and net processing commodity expenses (1) | (219) |  |  | (201) |  |  | (438) |  |  | (455) |  |  |
Other segment costs and expenses | (181) |  |  | (166) |  |  | (346) |  |  | (321) |  |  |
Proportional Modified EBITDA of equity-method investments | 35 |  |  | 32 |  |  | 71 |  |  | 70 |  |  |
West Modified EBITDA | $ | 359 |  |  | $ | 341 |  |  | $ | 766 |  |  | $ | 695 |  |  |
Commodity margins | $ | 28 |  |  | $ | 29 |  |  | $ | 59 |  |  | $ | 63 |  |  |

________________
(1) Included as a component of Commodity margins.
Three months ended June 30, 2026 vs. three months ended June 30, 2025
West Modified EBITDA increased primarily due to higher Service revenues, partially offset by higher Other segment costs and expenses.
Service revenues increased primarily due to:
•A $47 million increase in the Haynesville Shale region primarily due to contributions from Louisiana Energy Gateway which was placed into service in the third quarter of 2025, as well as higher gathering volumes including those from the acquisition of Saber Midstream, LLC in June 2025; partially offset by
•A $9 million decrease in the Eagle Ford Shale region primarily due to lower MVC revenue and lower gathering volumes.
Other segment costs and expenses increased primarily due to higher operating and maintenance expenses, including operating taxes, associated with Louisiana Energy Gateway.
63

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Management’s Discussion and Analysis (Continued)
Six months ended June 30, 2026 vs. six months ended June 30, 2025
West Modified EBITDA increased primarily due to higher Service revenues, partially offset by higher Other segment costs and expenses.
Service revenues increased primarily due to:
•A $101 million increase in the Haynesville Shale region primarily due to contributions from Louisiana Energy Gateway which was placed into service in the third quarter of 2025, as well as higher gathering volumes including those from the acquisition of Saber Midstream, LLC in June 2025;
•A $13 million increase in the Piceance region primary due to higher commodity-price driven processing rates and higher volumes;
•A $10 million increase in the DJ Basin region primarily due to higher gathering volumes, including those associated with the acquisition of natural gas gathering and processing assets from Rimrock Energy Partners, LLC on January 31, 2025; partially offset by
•A $19 million decrease in the Eagle Ford Shale region primarily due to lower MVC revenue;
•A $10 million decrease in the Mid-Continent region primarily due to the sale of certain gas gathering assets in February 2026.
Other segment costs and expenses in creased primarily due to higher operating expenses, including operating taxes, associated with Louisiana Energy Gateway.
Gas & NGL Marketing Services

| Three Months Ended June 30, |  | Six Months Ended June 30, |  |
| 2026 |  | 2025 |  | 2026 |  | 2025 |  |
| (Millions)
Product sales (1) | $ | 548 |  |  | $ | 403 |  |  | $ | 1,401 |  |  | $ | 1,142 |  |  |
Net realized gain (loss) from commodity derivative instruments (1) | (29) |  |  | 2 |  |  | (156) |  |  | (33) |  |  |
Net unrealized gain (loss) from commodity derivative instruments | 119 |  |  | (16) |  |  | (73) |  |  | (9) |  |  |
Net gain (loss) from commodity derivatives | 90 |  |  | (14) |  |  | (229) |  |  | (42) |  |  |
Segment revenues | 638 |  |  | 389 |  |  | 1,172 |  |  | 1,100 |  |  |
Product costs (1) | (507) |  |  | (421) |  |  | (985) |  |  | (934) |  |  |
Net unrealized gain (loss) from commodity derivative instruments within Net processing commodity expenses | 1 |  |  | 12 |  |  | 1 |  |  | 2 |  |  |
Other segment costs and expenses | (19) |  |  | (18) |  |  | (53) |  |  | (57) |  |  |
Proportional Modified EBITDA of equity-method investments | 10 |  |  | 8 |  |  | 28 |  |  | 11 |  |  |
Gas & NGL Marketing Services Modified EBITDA | $ | 123 |  |  | $ | (30) |  |  | $ | 163 |  |  | $ | 122 |  |  |
Commodity margins | $ | 12 |  |  | $ | (16) |  |  | $ | 260 |  |  | $ | 175 |  |  |

________________
(1) Included as a component of Commodity margins.
Three months ended June 30, 2026 vs. three months ended June 30, 2025
Gas & NGL Marketing Services Modified EBITDA increased primarily due to a favorable change in Net unrealized gain (loss) from commodity derivative instruments and higher Commodity margins.
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Management’s Discussion and Analysis (Continued)
Commodity margins increased $28 million primarily due to:
•A $21 million increase in natural gas marketing margins, including $28 million of higher natural gas transportation capacity marketing margins driven by favorable net realized pricing spreads;
•A $7 million increase in NGL marketing margins including a favorable change in net realized gains and losses on sales of inventory driven by a favorable change in NGL prices.
Net unrealized gain (loss) from commodity derivative instruments within Segment revenues and Net processing commodity expenses changed from 2025 primarily due to a change in forward commodity prices relative to hedge positions in 2026 compared to 2025.
Six months ended June 30, 2026 vs. six months ended June 30, 2025
Gas & NGL Marketing Services Modified EBITDA increased primarily due to higher Commodity margins and Proportional Modified EBITDA of equity-method investments, partially offset by an unfavorable change in Net unrealized gain (loss) from commodity derivative instruments.
Commodity margins increased $85 million primarily due to:
•A $71 million increase in natural gas marketing margins, including $60 million of higher natural gas transportation capacity marketing margins and $11 million of higher natural gas storage marketing margins, both primarily driven by favorable net realized pricing spreads;
•A $14 million increase in NGL marketing margins including a favorable change in net realized gains and losses on sales of inventory driven by a favorable change in NGL prices.
Net unrealized gain (loss) from commodity derivative instruments within Segment revenues and Net processing commodity expenses changed from 2025 primarily due to a change in forward commodity prices relative to hedge positions in 2026 compared to 2025.
Proportional Modified EBITDA of equity-method investments increased driven by the investment in Cogentrix, which was purchased in March 2025.
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Management’s Discussion and Analysis (Continued)
Other

| Three Months Ended June 30, |  | Six Months Ended June 30, |  |
| 2026 |  | 2025 |  | 2026 |  | 2025 |  |
| (Millions)
Service revenues | $ | 4 |  |  | $ | 4 |  |  | $ | 8 |  |  | $ | 8 |  |  |
Product sales (1) | 138 |  |  | 137 |  |  | 281 |  |  | 292 |  |  |
Net realized gain (loss) from derivative instruments (1) | (13) |  |  | 9 |  |  | (18) |  |  | 7 |  |  |
Net unrealized gain (loss) from derivative instruments | 22 |  |  | 40 |  |  | (11) |  |  | 11 |  |  |
Net gain (loss) from commodity derivatives | 9 |  |  | 49 |  |  | (29) |  |  | 18 |  |  |
Net revenues from upstream operations, corporate, and other business activities. | 151 |  |  | 190 |  |  | 260 |  |  | 318 |  |  |
Other costs and expenses | (65) |  |  | (72) |  |  | (124) |  |  | (125) |  |  |
Gain on sale of certain assets | 12 |  |  | — |  |  | 194 |  |  | — |  |  |
Modified EBITDA from upstream operations, corporate, and other business activities | $ | 98 |  |  | $ | 118 |  |  | $ | 330 |  |  | $ | 193 |  |  |
Net realized product sales | $ | 125 |  |  | $ | 146 |  |  | $ | 263 |  |  | $ | 299 |  |  |

________________
(1) Included as a component of Net realized product sales.
Three months ended June 30, 2026 vs. three months ended June 30, 2025
Modified EBITDA from upstream operations, corporate, and other business activities decreased primarily due to:
•A $21 million decrease in Net realized product sales from our upstream operations consisting of a $25 million decrease driven by the January 2026 sale of certain South Mansfield upstream interests. There was a $4 million increase at the Wamsutter region due to higher production volumes, partially offset by lower net realized natural gas prices;
•An $18 million unfavorable change in Net unrealized gain (loss) from derivative instruments due to a change in forward commodity prices relative to hedge positions; partially offset by
•A $12 million additional Gain on sale of certain assets from the sale of the South Mansfield interests;
•A decrease of $7 million in Other costs and expenses primarily due to the absence of upstream operating expenses associated with the sale of the South Mansfield interests.
Six months ended June 30, 2026 vs. six months ended June 30, 2025
Modified EBITDA from upstream operations, corporate, and other business activities increased primarily due to:
•A $194 million Gain on sale of certain assets from the sale of the South Mansfield interests;
•A decrease in Other costs and expenses primarily due to lower upstream operating expenses associated with the sale of the South Mansfield interests, offset by an increase in upstream operating expenses related to Wamsutter region driven by higher production volumes; partially offset by
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Management’s Discussion and Analysis (Continued)
•A $36 million decrease in Net realized product sales from upstream operations consisting of a $43 million decrease driven by the sale of the South Mansfield interests. There was a $7 million increase at the Wamsutter region primarily due to higher production volumes, partially offset by lower net realized gas prices;
•A $22 million unfavorable change in Net unrealized gain (loss) from derivative instruments due to a change in forward commodity prices relative to hedge positions.
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Management’s Discussion and Analysis (Continued)
Transco - Results of Operations

|  | Six Months Ended June 30,
|  |  |  | Change* |  |
|  | 2026 |  | $ |  | % |  | 2025
|  | (Dollars in Millions)
Revenues: |  |  |  |  |  |  |  |
Natural gas transportation service revenues |  | $ | 1,454 |  |  | +70 |  |  | +5 | % |  | $ | 1,384 |
Natural gas storage service revenues |  | 117 |  |  | -1 |  |  | -1 | % |  | 118 |
Natural gas product sales |  | 54 |  |  | +10 |  |  | +23 | % |  | 44 |
Other service revenues |  | 26 |  |  | +11 |  |  | +73 | % |  | 15 |
Total revenues |  | 1,651 |  |  |  |  |  |  | 1,561 |
Costs and expenses: |  |  |  |  |  |  |  |
Natural gas product costs |  | 54 |  |  | -10 |  |  | -23 | % |  | 44 |
Operating and maintenance expenses |  | 252 |  |  | -11 |  |  | -5 | % |  | 241 |
Depreciation and amortization expenses |  | 290 |  |  | +25 |  |  | +8 | % |  | 315 |
General and administrative expenses |  | 115 |  |  | -5 |  |  | -5 | % |  | 110 |
Taxes, other than income taxes |  | 64 |  |  | -3 |  |  | -5 | % |  | 61 |
Other operating (income) expense – net |  | 9 |  |  | +12 |  |  | +57 | % |  | 21 |
Total costs and expenses |  | 784 |  |  |  |  |  |  | 792 |
Operating income (loss) |  | 867 |  |  |  |  |  |  | 769 |
Interest expense |  | (169) |  |  | -7 |  |  | -4 | % |  | (162) |
Interest income |  | 23 |  |  | +8 |  |  | +53 | % |  | 15 |
Allowance for equity and borrowed funds used during construction (AFUDC) |  | 29 |  |  | +14 |  |  | +93 | % |  | 15 |
Other income (expense) – net |  | 1 |  |  | +3 |  |  | NM |  | (2) |
Net income (loss) |  | $ | 751 |  |  | +116 |  |  | +18 | % |  | $ | 635 |

_______
* + = Favorable change; - = Unfavorable change; NM = A percentage calculation is not meaningful due to a change in signs, a zero-value denominator, or a percentage change greater than 200.
Six months ended June 30, 2026 vs. six months ended June 30, 2025
Variances due to the changes in natural gas prices and transportation volumes have little impact on revenues because, under our rate design methodology, the majority of overall cost of service is recovered through firm capacity reservation charges in Transco’s transportation rates.
Transco has cash out sales, which settle gas imbalances with shippers. In the course of providing transportation services to customers, Transco may receive different quantities of gas from shippers than the quantities delivered on behalf of those shippers. Additionally, Transco transports gas on various pipeline systems, which may deliver different quantities of gas on Transco’s behalf than the quantities of gas received from Transco. These transactions
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Management’s Discussion and Analysis (Continued)
result in gas transportation and exchange imbalance receivables and payables. Transco’s tariff includes a method whereby the majority of transportation imbalances are settled on a monthly basis through cash out sales or purchases. The net cash out activity has no impact on Transco’s operating income.
Revenues increased primarily due to:
•An increase in Natural gas transportation service revenues primarily due to placing the following projects into service:
◦The Commonwealth Energy Connector in November 2025;
◦The Texas Louisiana Energy Pathway in April 2025;
◦The Southeast Energy Connector in April 2025; and
◦The Alabama Georgia Connector in October 2025.
The increase in Natural gas transportation service revenues is also due to transportation rate increases and higher electric power revenue, partially offset by decreases in commodity revenues and short-term firm transportation. Electric power costs are recovered from Transco’s customers through transportation rates and are offset in Operating and maintenance expenses resulting in no net impact on Transco’s results of operations.
•An increase in Natural gas product sales due to higher cash-out pricing and volumes, which directly offsets in Natural gas product costs resulting in no net impact on our results of operations.
•An increase in Other service revenues due to higher park and loan services.
Operating and maintenance expenses increased primarily due to an increase in contractor service costs, higher electric power costs, and an increase in employee-related costs. Electric power costs are recovered from customers through transportation rates and are offset in Natural gas transportation service revenues resulting in no net impact on results of operations. This was partially offset by lower natural gas fuel expense due to favorable pricing.
Depreciation and amortization expenses decreased due to lower rates. This was partially offset by an increase related to new assets placed into service.
General and administrative expenses increased primarily due to higher employee-related costs.
Other operating (income) expense – net changed favorably primarily due to lower project feasibility costs.
Interest expense was primarily impacted by 2025 debt issuances and a retirement.
Interest income increased due to higher interest income on advances to Williams due to a higher note receivable balance during 2026.
Allowance for equity and borrowed funds used during construction (AFUDC) increased as a result of higher eligible capital expenditures.
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Management’s Discussion and Analysis (Continued)
NWP - Results of Operations

|  | Six Months Ended June 30,
|  |  |  | Change* |  |
|  | 2026 |  | $ |  | % |  | 2025
|  | (Dollars in Millions)
Revenues: |  |  |  |  |  |  |  |
Natural gas transportation service revenues |  | $ | 226 |  |  | +14 |  |  | +7 | % |  | $ | 212 |
Natural gas storage service revenues |  | 7 |  |  | -1 |  |  | -13 | % |  | 8 |
Other service revenues |  | 5 |  |  | +1 |  |  | +25 | % |  | 4 |
Total revenues |  | 238 |  |  |  |  |  |  | 224 |
Costs and expenses: |  |  |  |  |  |  |  |
Operating and maintenance expenses |  | 52 |  |  | -7 |  |  | -16 | % |  | 45 |
Depreciation and amortization expenses |  | 61 |  |  | -2 |  |  | -3 | % |  | 59 |
General and administrative expenses |  | 25 |  |  | -1 |  |  | -4 | % |  | 24 |
Taxes, other than income taxes |  | 8 |  |  | — |  |  | — | % |  | 8 |
Other operating (income) expense – net |  | (10) |  |  | — |  |  | — | % |  | (10) |
Total costs and expenses |  | 136 |  |  |  |  |  |  | 126 |
Operating income (loss) |  | 102 |  |  |  |  |  |  | 98 |
Interest expense |  | (17) |  |  | -3 |  |  | -21 | % |  | (14) |
Interest income |  | 7 |  |  | +5 |  |  | NM |  | 2 |
Allowance for equity and borrowed funds used during construction (AFUDC) |  | 6 |  |  | +2 |  |  | +50 | % |  | 4 |
Other income (expense) – net |  | 1 |  |  | — |  |  | — | % |  | 1 |
Net income (loss) |  | $ | 99 |  |  | +8 |  |  | +9 | % |  | $ | 91 |

_______
* + = Favorable change; - = Unfavorable change; NM = A percentage calculation is not meaningful due to a change in signs, a zero-value denominator, or a percentage change greater than 200.
Six months ended June 30, 2026 vs. six months ended June 30, 2025
Variances due to changes in natural gas prices and transportation volumes have little impact on revenues because, under our rate design methodology, the majority of overall cost of service is recovered through firm capacity reservation charges in NWP’s transportation rates.
Revenues increased primarily due to higher Natural gas transportation service revenues driven by rate increases effective April 1, 2025, and increased firm transportation revenues from new contracts executed at higher rates to replace expiring contracts.
Operating and maintenance expenses increased primarily due to higher contracted services related to integrity assessments.
Interest expense was primarily impacted by a 2025 debt issuance and retirement.
Interest income increased primarily due to higher interest income earned on advances to Williams, driven by higher outstanding balances in 2026.
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Management’s Discussion and Analysis (Continued)
Management’s Discussion and Analysis of Financial Condition and Liquidity
Outlook
As previously discussed in Company Outlook, Williams’ growth capital and investment expenditures in 2026 are expected to range from $7.3 billion to $7.9 billion, excluding acquisitions and certain long-lead time equipment for power innovation projects that are backed by reimbursement from the customer if the equipment order is canceled.
As previously discussed in Recent Developments, Williams received approximately $3.75 billion in July 2026 related to selling a 49 percent noncontrolling interest in five power innovation projects. Williams is expected to receive the remainder of the $5.34 billion of committed capital through early 2027. Also in July 2026, Williams agreed to acquire Momentum for total consideration of up to $5.5 billion, including approximately $2 billion of Williams common stock, subject to certain holding restrictions.
As of June 30, 2026, Williams, including consolidated subsidiaries, had $2.2 billion of long-term debt due within one year. Williams’ potential sources of liquidity available to address these maturities include cash on hand, proceeds from refinancing, the credit facility, or the commercial paper program, as well as proceeds from asset monetizations.
2026 Long-Term Debt Activity
On January 8, 2026, Williams issued $2.8 billion of long-term debt and on March 2, 2026, Williams retired $1.1 billion of long-term debt (see Note 6 – Debt and Banking Arrangements).
Liquidity
Williams expects to have sufficient liquidity to manage its businesses in 2026 based on forecasted levels of cash flow from operations and other sources of liquidity. Williams’ potential material internal and external sources and uses of liquidity are as follows:

Sources: |
| Cash and cash equivalents on hand
| Cash generated from operations
| Distributions from equity-method investees
| Utilization of the credit facility and/or commercial paper program
| Cash proceeds from issuance of debt and/or equity securities
| Proceeds from asset monetizations
Uses: |
| Working capital requirements
| Capital and investment expenditures
| Product costs
| Gas & NGL Marketing Services payments for transportation and storage capacity and gas supply
| Other operating costs, including human capital expenses
| Quarterly dividends to shareholders
| Repayments of borrowings under the credit facility and/or commercial paper program
| Debt service payments, including payments of long-term debt
| Distributions to noncontrolling interests
| Share repurchase program

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Management’s Discussion and Analysis (Continued)
As of June 30, 2026, Williams had $28.1 billion of long-term debt due after one year. Potential sources of liquidity available to address these maturities include cash generated from operations, proceeds from refinancing, the credit facility, the commercial paper program, and proceeds from asset monetizations.
Potential risks associated with Williams’ planned levels of liquidity discussed above include those previously discussed in Company Outlook.
As of June 30, 2026, Williams had a working capital deficit of $3.4 billion, including cash and cash equivalents and long-term debt due within one year.
Effective May 19, 2026, Williams, together with Transco and NWP, extended the maturity of the Williams Credit Agreement to 2031 and entered into the new 364-Day Credit Agreement. Transco and NWP are each subject to borrowing sublimits of $500 million under the existing facility and $100 million under the new facility. See Note 6 – Debt and Banking Arrangements.
Williams’ available liquidity is as follows:

|  | June 30, 2026
|  | (Millions)
Cash and cash equivalents |  | $ | 203 |
Capacity available under the Williams Credit Agreement, less amounts outstanding under Williams’ $3.5 billion commercial paper program (1)(2) |  | 3,275 |
Capacity available under the 364-Day Credit Agreement (2) |  | 1,000 |
|  | $ | 4,478 |

__________
(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 its commercial paper program. Williams had $475 million of Commercial paper outstanding at June 30, 2026. Through June 30, 2026, the highest amount outstanding under the commercial paper program and credit facility during 2026 was $735 million.
(2)Williams expects to be in compliance with the associated financial covenants for the June 30, 2026, reporting period.
Dividends
Williams increased the regular quarterly cash dividend to common stockholders from $0.500 per share paid in each quarter of 2025, to $0.525 per share paid in March and June 2026.
Distributions from Equity-Method Investees
The organizational documents of entities in which Williams has an equity-method investment generally require periodic distributions of their available cash to their members. In each case, available cash is reduced, in part, by reserves appropriate for operating their respective businesses.
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Management’s Discussion and Analysis (Continued)
Credit Ratings
The interest rates at which Williams is able to borrow money are impacted by its credit ratings, which are currently as follows:

Rating Agency |  | Outlook |  | Senior Unsecured Debt Rating
S&P Global Ratings |  | Stable |  | BBB+
Moody’s Investors Service |  | Positive |  | Baa2
Fitch Ratings |  | Positive |  | BBB

These credit ratings are included for informational purposes and are not recommendations to buy, sell, or hold Williams securities, and each rating should be evaluated independently of any other rating. No assurance can be given that the credit rating agencies will continue to assign Williams investment-grade ratings even if it meets or exceeds their current criteria for investment-grade ratios. A downgrade of its credit ratings might increase Williams’ future cost of borrowing and, if ratings were to fall below investment-grade, could require it to provide additional collateral to third parties, negatively impacting Williams’ available liquidity.
Sources (Uses) of Cash
The following table summarizes the sources (uses) of cash and cash equivalents for each of the periods presented in Williams’ Consolidated Statement of Cash Flows:

| Cash Flow |  | Six Months Ended June 30,
| Category |  | 2026 |  | 2025 |  |
|  |  | (Millions)
Sources of cash and cash equivalents: |  |  |  |  |  |  |
Net cash provided (used) by operating activities | Operating |  | $ | 2,979 |  |  | $ | 2,883 |  |  |
Proceeds from long-term debt | Financing |  | 2,790 |  |  | 2,994 |  |  |
Dispositions – net (Note 3) | Investing |  | 345 |  |  | — |  |  |
Proceeds from sale of business (Note 3) | Investing |  | 48 |  |  | — |  |  |
Uses of cash and cash equivalents: |  |  |  |  |  |  |
Capital expenditures | Investing |  | (3,193) |  |  | (1,984) |  |  |
Common dividends paid | Financing |  | (1,284) |  |  | (1,221) |  |  |
Payments of long-term debt | Financing |  | (1,119) |  |  | (975) |  |  |
Payments of commercial paper – net | Financing |  | (224) |  |  | (454) |  |  |
Dividends and distributions paid to noncontrolling interests | Financing |  | (140) |  |  | (131) |  |  |
Purchases of and contributions to equity-method investments | Investing |  | (91) |  |  | (179) |  |  |
Dispositions – net | Investing |  | — |  |  | (40) |  |  |
Other sources / (uses) – net | Financing and Investing |  | 29 |  |  | (50) |  |  |
Increase (decrease) in cash and cash equivalents |  |  | $ | 140 |  |  | $ | 843 |  |  |

Operating activities
The factors that determine Williams’ operating activities are largely the same as those that affect Net income (loss), with the exception of noncash items, such as Depreciation, depletion, and amortization, Provision (benefit) for deferred income taxes, Equity (earnings) losses, Gain on sale of certain assets, Net unrealized (gain) loss from
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Management’s Discussion and Analysis (Continued)
commodity derivative instruments, Gain on disposition of equity-method investments, Inventory write-downs, and Amortization of stock-based awards.
Williams’ Net cash provided (used) by operating activities for the six months ended June 30, 2026, increased from the six months ended June 30, 2025, primarily due to higher operating income (excluding noncash items previously discussed), partially offset by unfavorable changes in net operating working capital in 2026, which includes the payment of Transco’s rate refunds in 2026, and unfavorable changes in margin requirements.
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Item 3. Quantitative and Qualitative Disclosures About Market Risk
Interest Rate Risk
Williams’ current interest rate risk exposure, inclusive of subsidiaries, is related primarily to its debt portfolio. The debt portfolio is primarily comprised of fixed rate debt, which mitigates the impact of fluctuations in interest rates. Any borrowings under the credit facilities and any issuances under Williams’ commercial paper program could be at a variable interest rate and could expose it to the risk of increasing interest rates. The maturity of Williams’ long-term debt portfolio is partially influenced by the expected lives of its operating assets. Williams may utilize interest rate derivative instruments to hedge interest rate risk associated with future debt issuances (see Note 6 – Debt and Banking Arrangements).
Commodity Price Risk
Williams is exposed to commodity price risk through its natural gas and NGL marketing activities, including contracts to purchase, sell, transport, and store product. Williams routinely manages this risk with a variety of exchange-traded and OTC energy contracts such as forward contracts, futures contracts, and basis swaps, as well as physical transactions. Although many of the contracts used to manage commodity exposure are derivative instruments, these economic hedges are not designated or do not qualify for hedge accounting treatment.
Williams is also exposed to commodity prices through the upstream business and certain gathering and processing contracts. Williams uses derivative instruments to lock in forward sales prices on a portion of expected future production and to lock in NGL margin on a portion of commodity-exposed gathering and processing volumes. These economic hedges are not designated for hedge accounting treatment.
The fair value measurements and maturities of Williams’ commodity derivative assets (liabilities) at June 30, 2026 were as follows:

|  | Total Fair |  | Maturity
Fair Value Measurements Level (1) |  | Value |  | 2026 |  | 2027 - 2028 |  | 2029 - 2030+
|  | (Millions)
Level 1 (2) |  | $ | (144) |  |  | $ | (10) |  |  | $ | (73) |  |  | $ | (61) |
Level 2 |  | (115) |  |  | (2) |  |  | (80) |  |  | (33) |
Level 3 |  | (29) |  |  | (14) |  |  | (43) |  |  | 28 |
Fair value of contracts outstanding at June 30, 2026 |  | $ | (288) |  |  | $ | (26) |  |  | $ | (196) |  |  | $ | (66) |

_______________
(1)See Note 7 – Fair Value Measurements and Guarantees for discussion of valuation techniques by level within the fair value hierarchy. See Note 8 – Commodity Derivatives for the amount of change in fair value recognized in Williams’ Consolidated Statement of Comprehensive Income.
(2)Commodity derivative assets and liabilities exclude $245 million of net cash collateral in Level 1.
Value at Risk (VaR)
VaR is the maximum predicted loss in portfolio value over a specified time period that is not expected to be exceeded within a given degree of probability. Williams’ VaR may not be comparable to that of other companies due to differences in the factors used to calculate VaR. Williams’ VaR is determined using parametric models with 95 percent confidence intervals and one-day holding periods, which means that 95 percent of the time, the risk of loss in a day from a portfolio of positions is expected to be less than or equal to the amount of VaR calculated. Williams’ open exposure is managed in accordance with established policies that limit market risk and require daily reporting of predicted financial loss to management. Because Williams generally manages physical gas assets and economically protects its positions by hedging in the futures markets, its open exposure is generally mitigated. Williams employs daily risk testing, using both VaR and stress testing, to evaluate the risk of its positions.
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Williams actively monitors open commodity marketing positions and the resulting VaR and maintains a relatively small risk exposure as total buy volume is close to sell volume, with minimal open natural gas price risk.
The VaR associated with Williams’ integrated natural gas trading operations was $5 million at June 30, 2026 and $11 million at December 31, 2025. Williams had the following VaRs for the period shown:

|  | Six Months Ended June 30, 2026 |  |
|  | (Millions)
Average |  | $ | 11 |  |  |
High |  | 41 |  |  |
Low |  | 4 |  |  |

Williams’ non-trading portfolio primarily consists of commodity derivatives that hedge Williams’ upstream business and certain gathering and processing contracts. The VaR associated with these commodity derivatives was $7 million at June 30, 2026 and $2 million at December 31, 2025. Williams had the following VaRs for the period shown:

|  | Six Months Ended June 30, 2026 |  |
|  | (Millions)
Average |  | $ | 10 |  |  |
High |  | 18 |  |  |
Low |  | 1 |  |  |

Item 4. Controls and Procedures
Williams
Disclosure Controls and Procedures
Williams’ management, including the Principal Executive Officer and Principal Financial Officer, does not expect that disclosure controls and procedures (as defined in Rules 13a - 15(e) and 15d - 15(e) of the Exchange Act) (Disclosure Controls) or internal control over financial reporting (Internal Controls) will prevent all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within the company have been detected. These inherent limitations include the realities that judgments in decision-making can be faulty, and that breakdowns can occur because of simple errors or mistakes. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. The design of any system of controls also is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and not be detected. Williams monitors the Disclosure Controls and Internal Controls and makes modifications as necessary; Williams’ intent in this regard is that the Disclosure Controls and Internal Controls will be modified as systems change and conditions warrant.
Evaluation of Disclosure Controls and Procedures
An evaluation of the effectiveness of the design and operation of Williams’ Disclosure Controls was performed as of the end of the period covered by this report. This evaluation was performed under the supervision and with the
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participation of management, including the Principal Executive Officer and Principal Financial Officer. Based upon that evaluation, the Principal Executive Officer and Principal Financial Officer concluded that these Disclosure Controls are effective at a reasonable assurance level.
Changes in Internal Control Over Financial Reporting
There have been no changes during the second quarter of 2026 that have materially affected, or are reasonably likely to materially affect, Williams’ Internal Control over Financial Reporting.
Transco
Disclosure Controls and Procedures
Transco’s management, including the Principal Executive Officer and Principal Financial Officer, does not expect that disclosure controls and procedures (as defined in Rules 13a - 15(e) and 15d - 15(e) of the Exchange Act) (Disclosure Controls) or internal control over financial reporting (Internal Controls) will prevent all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within the company have been detected. These inherent limitations include the realities that judgments in decision-making can be faulty, and that breakdowns can occur because of simple errors or mistakes. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. The design of any system of controls also is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and not be detected. Transco monitors the Disclosure Controls and Internal Controls and makes modifications as necessary; Transco’s intent in this regard is that the Disclosure Controls and Internal Controls will be modified as systems change and conditions warrant.
Evaluation of Disclosure Controls and Procedures
An evaluation of the effectiveness of the design and operation of Transco’s Disclosure Controls was performed as of the end of the period covered by this report. This evaluation was performed under the supervision and with the participation of management, including the Principal Executive Officer and Principal Financial Officer. Based upon that evaluation, the Principal Executive Officer and Principal Financial Officer concluded that these Disclosure Controls are effective at a reasonable assurance level.
Changes in Internal Control Over Financial Reporting
There have been no changes during the second quarter of 2026 that have materially affected, or are reasonably likely to materially affect, Transco’s Internal Control over Financial Reporting.
NWP
Disclosure Controls and Procedures
NWP’s management, including the Principal Executive Officer and Principal Financial Officer, does not expect that disclosure controls and procedures (as defined in Rules 13a - 15(e) and 15d - 15(e) of the Exchange Act) (Disclosure Controls) or internal control over financial reporting (Internal Controls) will prevent all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within the company have been detected. These inherent
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limitations include the realities that judgments in decision-making can be faulty, and that breakdowns can occur because of simple errors or mistakes. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. The design of any system of controls also is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and not be detected. NWP monitors the Disclosure Controls and Internal Controls and makes modifications as necessary; NWP’s intent in this regard is that the Disclosure Controls and Internal Controls will be modified as systems change and conditions warrant.
Evaluation of Disclosure Controls and Procedures
An evaluation of the effectiveness of the design and operation of NWP’s Disclosure Controls was performed as of the end of the period covered by this report. This evaluation was performed under the supervision and with the participation of management, including the Principal Executive Officer and Principal Financial Officer. Based upon that evaluation, the Principal Executive Officer and Principal Financial Officer concluded that these Disclosure Controls are effective at a reasonable assurance level.
Changes in Internal Control Over Financial Reporting
There have been no changes during the second quarter of 2026 that have materially affected, or are reasonably likely to materially affect, NWP’s Internal Control over Financial Reporting
PART II. OTHER INFORMATION
Item 1. Legal Proceedings
Environmental
Certain reportable legal proceedings involving governmental authorities under federal, state, and local laws regulating the discharge of materials into the environment are described below. While it is not possible for Williams to predict the final outcome of the proceedings that are still pending, it does not anticipate a material effect on its consolidated financial position if it received an unfavorable outcome in any one or more of such proceedings. Williams’ threshold for disclosing material environmental legal proceedings involving a governmental authority where potential monetary sanctions are involved is $1 million.
Other environmental matters called for by this Item are described under the caption “Environmental Matters” in Note 9 – Contingencies included under Part I, Item 1. Financial Statements of this report, which information is incorporated by reference into this Item.
Other Litigation
The additional information called for by this Item is provided in Note 9 – Contingencies included under Part I, Item 1. Financial Statements of this report, which information is incorporated by reference into this Item.
Item 1A. Risk Factors
Part I, Item 1A. Risk Factors in the Annual Report on Form 10-K for the year ended December 31, 2025, as filed with the SEC on February 24, 2026, includes risk factors that could materially affect Williams’, Transco’s, and NWP’s businesses, financial condition, or future results. Those Risk Factors have not materially changed.
Item 2. Unregistered Sales of Equity Securities, Use of Proceeds, and Issuer Purchases of Equity Securities
In September 2021, Williams’ Board of Directors authorized a share repurchase program with a maximum dollar limit of $1.5 billion. Repurchases may be made from time to time in the open market, by block purchases, in privately negotiated transactions, or in such other manner as determined by management. Williams will also determine the timing and amount of any repurchases based on market conditions and other factors. The share
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repurchase program does not obligate Williams to acquire any particular amount of common stock, and it may be suspended or discontinued at any time. This share repurchase program does not have an expiration date. Williams’ purchases of its equity securities are as follows:

Period |  | Total Number of Shares Purchased |  | Average Price Paid Per Share |  | Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs |  | Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plans or Programs
April 1 - April 30, 2026 |  | — |  |  | $ | — |  |  | — |  |  | $ | 1,360,938,325 |
May 1 - May 31, 2026 |  | — |  |  | — |  |  | — |  |  | 1,360,938,325 |
June 1 - June 30, 2026 |  | — |  |  | — |  |  | — |  |  | 1,360,938,325 |
Total |  | — |  |  |  |  | — |  |  |

Item 5. Other Information
Unregistered Sales of Equity Securities
On August 3, 2026, Williams made an irrevocable election to issue 26,874,496 shares of its common stock, par value $1.00 per share, as consideration for its acquisition (the Acquisition) of the membership interests of M6 Midstream LLC pursuant to the terms of a Membership Interest Purchase Agreement entered into on July 17, 2026, with M6 Midstream Holdings LLC and M6 Midstream Blocker LLC. The Acquisition is subject to the satisfaction or waiver of certain customary conditions. Subject to the satisfaction or waiver of such conditions, the issuance of common stock will be made at closing of the Acquisition pursuant to an exemption from registration under Section 4(a)(2) of the Securities Act of 1933, as amended.
Rule 10b5-1 Trading Arrangements
During the three months ended June 30, 2026, no director or officer of Williams adopted or terminated a “Rule 10b5-1 trading arrangement,” and no director or officer of Williams adopted or terminated a “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408(a) of Regulation S-K.
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Item 6. Exhibits
Williams

Exhibit No. |  |  |  | Description
3.1 |  | — |  | Amended and Restated Certificate of Incorporation (filed on May 26, 2010, as Exhibit 3.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
3.2 |  | — |  | Certificate of Designations of Series B Preferred Stock of The Williams Companies, Inc. (filed on July 17, 2018, as Exhibit 3.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
3.3 |  | — |  | Certificate of Amendment dated August 10, 2018 (filed on August 10, 2018, as Exhibit 3.1 to The Williams Companies, Inc.’s current report on Form 8-K (File No. 001-04174) and incorporated herein by reference).
3.4 |  | — |  | By-laws of The Williams Companies, Inc., as last amended effective October 25, 2022 (filed on October 31, 2022, as Exhibit 3.4 to The Williams Companies, Inc.’s current report on Form 10-Q (File No. 001-04174) and incorporated herein by reference).
10.1§* |  | — |  | Form of 202 6 Restricted Stock Unit Agreement between The Williams C ompanies, Inc. and certain nonman agement directors.
31.1* |  | — |  | Certification of the Chief Executive Officer pursuant to Rules 13a-14(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(31) of Regulation S‑K, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2* |  | — |  | Certification of the Chief Financial Officer pursuant to Rules 13a-14(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(31) of Regulation S-K, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1** |  | — |  | Certification of the Chief Executive Officer and the Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS* |  | — |  | XBRL Instance Document. The instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the inline XBRL document.
101.SCH* |  | — |  | XBRL Taxonomy Extension Schema.
101.CAL* |  | — |  | XBRL Taxonomy Extension Calculation Linkbase.
101.DEF* |  | — |  | XBRL Taxonomy Extension Definition Linkbase.
101.LAB* |  | — |  | XBRL Taxonomy Extension Label Linkbase.
101.PRE* |  | — |  | XBRL Taxonomy Extension Presentation Linkbase.
104* |  | — |  | Cover Page Interactive Data File. The cover page Interactive Data File does not appear in the Interactive Data File because its XBRL tags are embedded within the inline XBRL document (contained in Exhibit 101).

* | Filed herewith.
** | Furnished herewith.
§ | Management contract or compensatory plan or arrangement.

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Transco
The following instruments are included as exhibits to this report.

Exhibit No. |  | Description
2 |  | Certificate of Conversion of Transcontinental Gas Pipeline Company, LLC dated December 22, 2008 and effective December 31, 2008 (filed on February 24, 2011 as Exhibit 2.1 to Transcontinental Gas Pipe Line Company, LLC’s annual report on Form 10-K (File No. 001-07584) and incorporated herein by reference).
3.5 |  | Certificate of Formation of Transcontinental Gas Pipe Line Company, LLC dated December 22, 2008 and effective December 31, 2008 (filed on February 24, 2011 as Exhibit 3.1 to Transcontinental Gas Pipe Line Company, LLC’s annual report on Form 10-K (File No. 001-07584) and incorporated herein by reference).
3.6 |  | Amended and Restated Operating Agreement of Transcontinental Gas Pipe Line Company, LLC dated February 17, 2010 (filed on October 28, 2010 as Exhibit 3.2 to Transcontinental Gas Pipe Line Company, LLC’s quarterly report on Form 10-Q (File No. 001-07584) and incorporated herein by reference).
31.3* |  | Certification of Principal Executive Officer pursuant to Rules 13a-14(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(31) of Regulation S-K, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.4* |  | Certification of Principal Financial Officer pursuant to Rules 13a-14(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(31) of Regulation S-K, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.2** |  | Certification of Principal Executive Officer and Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS* |  | XBRL Instance Document. The instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document.
101.SCH* |  | XBRL Taxonomy Extension Schema.
101.CAL* |  | XBRL Taxonomy Extension Calculation Linkbase.
101.DEF* |  | XBRL Taxonomy Extension Definition Linkbase.
101.LAB* |  | XBRL Taxonomy Extension Label Linkbase.
101.PRE* |  | XBRL Taxonomy Extension Presentation Linkbase.
104* |  | Cover Page Interactive Data File. The cover page interactive data file does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document (contained in Exhibit 101).

* | Filed herewith.
** | Furnished herewith.

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NWP
The following instruments are included as exhibits to this report.

Exhibit No. |  | Description
2 |  | Certificate of Conversion of Northwest Pipeline GP (filed July 3, 2013 as Exhibit 2.1 to Transcontinental Gas Pipeline Company, LLC and Northwest Pipeline LLC current report on Form 8-K (File No. 001-07414) and incorporated herein by reference).
3.7 |  | Certificate of Formation of Northwest Pipeline LLC (filed July 3, 2013 as Exhibit 2.2 to Transcontinental Gas Pipeline Company, LLC and Northwest Pipeline LLC current report on Form 8-K (File No. 001-07414) and incorporated herein by reference).
3.8 |  | Operating Agreement of Northwest Pipeline LLC (filed July 3, 2013 as Exhibit 3.1 to Transcontinental Gas Pipeline Company, LLC and Northwest Pipeline LLC current report on Form 8-K (File No. 001-07414) and incorporated herein by reference).
31.5* |  | Certification of Principal Executive Officer pursuant to Rules 13a-14(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended and Item 601(b)(31) of Regulation S-K, as adopted pursuant to Section 302 of The Sarbanes-Oxley Act of 2002.
31.6* |  | Certification of Principal Financial Officer pursuant to Rules 13a-14(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(31) of Regulation S-K, as adopted pursuant to Section 302 of The Sarbanes-Oxley Act of 2002.
32.3** |  | Certification of Principal Executive Officer and Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS* |  | XBRL Instance Document. The instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document.
101.SCH* |  | XBRL Taxonomy Extension Schema.
101.CAL* |  | XBRL Taxonomy Extension Calculation Linkbase.
101.DEF* |  | XBRL Taxonomy Extension Definition Linkbase.
101.LAB* |  | XBRL Taxonomy Extension Label Linkbase.
101.PRE* |  | XBRL Taxonomy Extension Presentation Linkbase.
104* |  | Cover Page Interactive Data File. The cover page interactive data file does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document (contained in Exhibit 101).

* | Filed herewith.
** | Furnished herewith.

82

The Williams Companies, Inc.
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

| T HE W ILLIAMS C OMPANIES, I NC.
| (Registrant)
| /s/ Mary A. Hausman
| Mary A. Hausman
| Vice President, Chief Accounting Officer and Controller (Duly Authorized Officer and Principal Accounting Officer)

August 3, 2026
83

Transcontinental Gas Pipe Line Company, LLC
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

| T RANSCONTINENTAL G AS P IPE L INE C OMPANY, LLC
| (Registrant)
| /s/ Billeigh W. Mark
| Billeigh W. Mark
| Controller (Principal Accounting Officer)

August 3, 2026
84

Northwest Pipeline LLC
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

| N ORTHWEST P IPELINE LLC
| (Registrant)
| /s/ Billeigh W. Mark
| Billeigh W. Mark
| Controller (Principal Accounting Officer)

August 3, 2026
85