[WMB] Williams: Q3 2026 Earnings Preview, Can Expansions Replace the Rate Tailwind?

Williams is a US natural gas infrastructure company that runs the Transco interstate pipeline and other regulated pipelines, deepwater Gulf gathering, and gathering and processing networks in the Northeast and the Haynesville, and it has started building on-site gas-fired power for data center customers. Ahead of its Q3 2026 earnings, the earnings calendar shows Williams reporting Q3 2026 (three months ended September 30, 2026) results on 2026-11-02[1]. In the latest disclosed quarter, the second quarter of 2026, Adjusted EBITDA was US$1.921 billion, up 6% year over year; adjusted earnings per share were US$0.50, up 8%; and available funds from operations (AFFO) were US$1.450 billion, up 10%, covering the dividend 2.26 times[2]. Debt-to-Adjusted EBITDA stood at 3.67x at quarter end, against 3.80x a year earlier[3]. In August the company raised its 2026 Adjusted EBITDA guidance to US$8.3 billion to US$8.5 billion and set growth capital spending guidance at US$7.3 billion to US$7.9 billion[4]; subtracting first-half Adjusted EBITDA of US$4.175 billion from the US$8.4 billion midpoint implies about US$4.225 billion for the second half, above the US$3.953 billion earned in the second half of 2025[5][6][7][8]. Analyst consensus compiled by the Drillr earnings calendar calls for third-quarter EPS of US$0.539 and revenue of US$2.994 billion; for the second quarter the consensus was US$0.502 and US$2.828 billion, against actual results of US$0.50 and US$3.053 billion[1], and consolidated revenue includes commodity sales and derivative gains and losses, so it tracks operating performance only loosely.

Three things matter most in this report. First, whether growth holds in the largest segment, Transmission, Power & Gulf (TP&G): its Adjusted EBITDA rose only 6.2% in the second quarter, far below the 17.2% of the first quarter, because the benefit of Transco's new rates showed up only early in the year[5][9], and the third quarter has no rate tailwind and falls in hurricane season, so it tests how much growth the expansion projects support on their own. Second, whether phase two of Socrates, the data center power project, reaches service in the fourth quarter as planned, and whether capital spending and leverage stay on plan: phase one's 200 MW came online on schedule and under budget[10], but first-half capital investment already reached US$3.284 billion, close to double the prior-year period[3], so any slip in execution would show up first in debt. Third, whether Haynesville gathering keeps growing once acquisitions are stripped out: West segment gathering volumes fell from 6.37 Bcf/d in the first quarter to 6.03 Bcf/d in the second[7], lower minimum volume commitment revenue offset part of the gain[9], and the company has just agreed to buy Haynesville gatherer Momentum Midstream for up to US$5.5 billion[11], so organic growth is the earliest reported evidence for that deal's premise.

Company Background and Business Structure

Williams' core asset is the Transco interstate pipeline, and together with Northwest Pipeline (NWP), MountainWest, deepwater Gulf gathering and gathering and processing networks in several shale basins, it forms a natural gas system that runs from supply basins to consuming markets[5]. Transco and the other regulated pipelines collect fixed reservation charges at rates set or approved by the Federal Energy Regulatory Commission (FERC), and that revenue is recognized over the contract term regardless of the volume actually transported[12]; on December 30, 2025, FERC approved Transco's rate case settlement, with the new rates effective March 1, 2026[13]. Starting in 2025, the company extended into Power Innovation, building on-site gas-fired generation and associated pipelines for data center customers; its first project, Socrates in New Albany, Ohio, totals 400 MW and is backed by a 10-year, primarily fixed-price power purchase agreement[14].

Williams reports four segments plus Other, and 2025 Adjusted EBITDA totaled US$7.750 billion. TP&G contributed US$3.710 billion, about 48%, covering regulated pipelines and storage, deepwater Gulf gathering and crude oil transportation, and the new power projects[5]; Northeast G&P contributed US$2.028 billion, about 26%, from gathering, processing and fractionation in the Marcellus and Utica, of which US$640 million was proportional EBITDA from joint ventures[6]; West contributed US$1.450 billion, about 19%, across the Haynesville, Wamsutter, Eagle Ford and other basins[7][15]; Gas & NGL Marketing Services contributed US$193 million, about 2%, and Other contributed US$369 million, mainly from upstream oil and gas interests[8]. The company sold its South Mansfield upstream interests in January 2026 and its Brazos Permian II equity-method investment in June[16], so its non-core assets keep shrinking.

Customer structure determines how stable each segment's revenue is. Pipeline and storage customers are local gas utilities, power plants, LNG exporters and producers that reserve firm capacity under long-term contracts, most of which also carry evergreen extension provisions[12]; gathering and processing customers are producers that pay by throughput, and some contracts carry minimum volume commitments, so this revenue moves with producers' drilling and completion pace[9]. In power, the company is advancing several projects with a single hyperscale data center customer, and management said the relationship carries no exclusivity[17].

Financial History and Current Position

The 2025 annual figures show a company moving from a steady fee-collecting phase into a heavy investment phase. Net income was US$2.768 billion in 2025 (US$2.346 billion in 2024), operating cash flow was US$5.898 billion (US$4.974 billion), capital expenditures were US$4.893 billion, almost double the US$2.573 billion of 2024, and common dividends were US$2.442 billion[18]. AFFO was US$5.858 billion that year, covering the dividend 2.40 times[19], which shows that operating cash flow still leaves a sizable cushion after dividends but can no longer fund growth capital spending on its own.

Quarterly results in the first half of 2026 show growth slowing. First-quarter Adjusted EBITDA was US$2.254 billion, up 13%, and AFFO was US$1.770 billion, up 22%[20], with the marketing segment contributing US$227 million from winter storms[8]; second-quarter Adjusted EBITDA was US$1.921 billion, up 6%, and GAAP net income was US$827 million, helped in part by a US$126 million net gain on the sale of Brazos Permian II[2][16]. First-half Adjusted EBITDA totaled US$4.175 billion, up about 10%, and capital investment excluding acquisitions was US$3.284 billion, against US$1.709 billion a year earlier[3]. Second-quarter operating cash flow was US$1.376 billion, down US$74 million, mainly because the company paid Transco rate refunds in April 2026[16].

The balance sheet and shareholder return policy remain within the company's stated ranges for now. Debt-to-Adjusted EBITDA was 3.67x at the end of the second quarter[3], against a long-term leverage target range of 3.5x to 4.0x[21]; management anticipates about 3.9x at the end of 2026 (counting only three months of Momentum contribution), or about 3.75x on a full-year run-rate basis[22]. The annualized 2026 dividend was raised 5% to US$2.10[23], and the full-year guidance midpoint corresponds to adjusted EPS of US$2.35 and AFFO of US$6.375 billion, covering the dividend 2.47 times[24]. On September 10, 2026, the company completed a US$2.75 billion senior notes offering with maturities from 2029 to 2056 and coupons between 5.000% and 6.400%[25].

Operating Model

On the revenue side, the core relationship is reserved capacity times rate, plus throughput times unit fee. Interstate pipeline revenue roughly equals firm reserved capacity times FERC-approved or negotiated rates, and reservation charges do not depend on volume[12], so growth comes mainly from expansion projects entering service and from rate changes, while the year-over-year benefit of Transco's new rates, effective March 1, 2026, appears only early in the year[13][9]. Gathering and processing revenue roughly equals throughput times unit fee plus minimum volume commitment shortfall payments; deepwater Gulf revenue moves with new field ramp-ups and hurricane shut-ins; and power revenue roughly equals megawatts in service times fixed-price power purchase contracts[14]. The marketing segment earns the margin on buying and selling gas, its profit is concentrated in winter, and the second and third quarters are often near zero[8].

On the profit side, the key features are relatively fixed costs and proportionally consolidated joint venture earnings. Segment Adjusted EBITDA equals service revenue plus commodity margins, minus operating and administrative costs, plus proportional EBITDA from equity-method investments; TP&G operating and administrative costs ran about US$270 million to US$300 million a quarter in 2025[5], and about 30% of Northeast G&P profit comes from joint ventures[6]. Moving from consolidated Adjusted EBITDA to earnings per share also requires deducting depreciation (US$2.347 billion in 2025)[18] and interest (a 2026 guidance midpoint of US$1.535 billion)[24], so new debt shows up in the income statement with a lag as interest expense.

Cash transmission determines how fast the expansion can proceed. At the 2026 guidance midpoint, AFFO of US$6.375 billion leaves about US$3.8 billion after US$2.585 billion of common dividends[24], far below growth capital spending of US$7.3 billion to US$7.9 billion[4], and the gap must be filled with new debt, asset sales and joint venture partner contributions. Capital is spent before revenue arrives, and power and pipeline projects typically take one to several years from construction to service, so leverage will be tight in 2026 and 2027, and management anticipates the larger earnings growth arriving from 2028 onward[26].

Industry and Competitive Position

Williams' primary advantage is Transco's route and its ability to expand along existing corridors. Transco links supply from the Gulf, the Haynesville and the Marcellus to load centers in the Southeast, Mid-Atlantic and Northeast; in the first half of 2026 the company signed Leidy Access and Garden Connector to serve Pennsylvania and New Jersey demand and upsized Power Express, which serves Virginia demand, to 800 MMcf/d[10], and these expansions are backed by long-term firm transportation agreements[15]. Its main pipeline competitors include interstate pipeline and gathering companies such as Kinder Morgan and Energy Transfer, but the available material does not provide directly comparable peer financial data.

In the supply basins, the Momentum acquisition would substantially enlarge Williams' Haynesville footprint. Momentum brings 6 Bcf/d of combined gathering capacity across four gathering areas, more than 4,000 miles of pipe and three take-or-pay pipelines with 4.05 Bcf/d of capacity, and the purchase price is about 8.5 times projected 2027 EBITDA[11]; management said the deal makes Williams the largest Haynesville gatherer connected to the Transco Gulf Coast system[10]. Alongside the acquisition, the company announced the US$1.5 billion Delta Access project with initial capacity of 2.25 Bcf/d and the Shelby Trough Connector with initial capacity of 750 MMcf/d[11].

Power Innovation is a rare integrated model in the sector that combines gas supply, pipeline and generation, but it also brings new competitors and risks. The company has announced more than 2.6 GW of power projects[21], including Neo, a US$2.3 billion project with 682 MW of installed capacity[20]; on the generation side it competes with independent power producers and electric utilities, and key equipment such as turbines and batteries depends on third-party supply[27]. The model's advantage is that customers get reliable power faster, while its limits are that revenue is concentrated in a few data center customers and that misjudging data center power demand could leave assets underused or stranded[27].

Core Debates

Williams' largest segment, Transmission, Power & Gulf, grew Adjusted EBITDA 17% in the first quarter but only 6% in the second, as the lift from Transco's settled rates faded. Without that rate tailwind, can expansions and Gulf volumes keep third-quarter growth near 6%?

This debate decides whether the company's predictable-growth story holds. TP&G contributes nearly half of Adjusted EBITDA, and most of its revenue comes from fixed reservation charges that do not depend on volume[5][12]; if growth stalls in the third quarter while expansion projects keep entering service, it would show that first-half growth relied more on a one-time rate adjustment and storm-driven storage revenue. The comparison base is the third quarter of 2025: TP&G Adjusted EBITDA of US$947 million, regulated revenue of US$930 million, gathering and storage revenue of US$237 million, and Transco average daily firm reserved capacity of 20.6 MMdth/d[5].

Current evidence shows growth slowing noticeably after the first quarter. First-quarter 2026 TP&G Adjusted EBITDA was US$1.010 billion, up about US$148 million, which the company attributed to Transco's higher net rates, expansion projects, new Gulf volumes from Shenandoah, Whale and Ballymore, and storm-driven storage revenue[23]; the second quarter fell to US$959 million, up only US$56 million, with regulated revenue of US$917 million (+2.8%), gathering and storage revenue of US$254 million (+16.5%), and operating and administrative costs of US$300 million (+4.9%)[5]. The company stated explicitly that Transco's higher net rates benefited only the year-to-date figures[9].

The segment's financial transmission runs from expansions entering service to new reservation fees, and from new Gulf field ramp-ups to throughput revenue, against relatively fixed costs. What remains unresolved is which of two readings is closer to the facts: one holds that expansions and Gulf volumes are enough to sustain mid-single-digit growth; the other holds that much of the first quarter's strong growth came from one-time rate and storm effects, and that expansions alone support mid-single-digit growth or less. The third quarter falls in hurricane season, and on the second-quarter call management listed hurricanes and weak summer gas prices as near-term uncertainties for full-year guidance[26].

In the third-quarter report, the points to watch are whether TP&G Adjusted EBITDA stays at or above US$947 million and approaches the roughly US$1.006 billion implied by the second-quarter growth rate, whether regulated revenue rises above US$956 million, and whether Transco firm reserved capacity exceeds the prior-year 20.6 MMdth/d[5]. TP&G Adjusted EBITDA below US$947 million would show expansion contributions offset by shut-ins or costs, and crude oil transportation volumes falling below the 196 Mbbls/d of the second quarter of 2025 would show hurricanes or field decline hitting the Gulf[5].

Williams brought the first 200 MW phase of Socrates, its first data-center power project, into service and plans phase two for the fourth quarter, while Blackstone committed US$5.34 billion for 49% of five power projects. Will the third-quarter report confirm phase two is on schedule and that capital spending and leverage remain on plan?

The power business pushes Williams from a fee-based pipeline company into a capital-intensive construction cycle. Revenue starts only at in-service, while capital spending and debt come first: capital investment excluding acquisitions was US$3.284 billion in the first half of 2026, against US$1.709 billion a year earlier, and US$1.642 billion in the second quarter alone[3]. The joint venture reduces the company's own funding but also gives the partner 49% of these projects' cash flow, and Socrates is the first test of whether the company can deliver on time and on budget.

The execution record so far is positive, but it rests on a single project. The annual report describes Socrates as a 400 MW on-site generation project that the company planned to bring into service in two phases in the third and fourth quarters of 2026[14]; in the second quarter, phase one's 200 MW came online on time and under budget 18 months after commercialization, and phase two remains on track for service before the end of 2026[10][28]. In the joint venture formed in July, Blackstone provides 59% of the five projects' expected capital, including 49% of US$4.4 billion of growth capital spending and about US$0.9 billion of additional consideration, in exchange for a 49% interest with a 6.35% target return, while the company keeps operatorship and a buyout right beginning in July 2033[29]; the company said this leaves it more than US$2 billion of available investment capacity through the end of 2027[17].

The financial transmission starts with equipment purchases and construction, passes through capital investment and megawatts in service, and ends as fixed-price power revenue booked in TP&G; Blackstone's funding lowers the company's net debt and leverage, but 49% of project cash flow goes to the minority partner, so the noncontrolling distributions deducted in AFFO will rise, and that line was US$73 million in the second quarter[19]. What remains unresolved is whether the Socrates experience carries over: later projects such as Apollo and Aquila are larger, are scheduled for service between the second half of 2027 and 2028[14], and depend more on third-party equipment, and the annual report also warns that misjudging data center power demand could leave assets underused or stranded[27].

In the third-quarter report, the points to watch are whether Socrates phase two remains on track for the fourth quarter, whether third-quarter capital investment falls in the roughly US$2.4 billion to US$2.8 billion range implied by full-year guidance[4][3], whether quarter-end leverage is consistent with the anticipated year-end level of about 3.9x[22], and whether new power projects and their financing are announced. A delay of Socrates phase two into 2027 would show power project execution risk higher than phase one suggested, and a year-end leverage outlook raised above 4.0x would show capital spending or acquisition funding drifting off plan.

Williams' West segment saw second-quarter gathering volumes slip from the first quarter, as lower minimum volume commitment revenue offset Haynesville growth, and the company agreed to buy Haynesville gatherer Momentum Midstream for up to US$5.5 billion. Can West still grow year over year in the third quarter once the acquisition is stripped out?

The Haynesville is the supply basin behind Williams' bet on Gulf Coast LNG and power demand. The Momentum acquisition and the two new projects, Delta Access and the Shelby Trough Connector, all rest on the premise that Haynesville production will keep growing[11], and management also anticipates Haynesville production growing by more than 10 Bcf/d over the next decade[10]. West's organic growth is the earliest and most direct reported evidence for that premise, and the comparison base is third-quarter 2025 Adjusted EBITDA of US$367 million and gathering volumes of 6.14 Bcf/d[7].

Current evidence shows West's growth slowing in the second quarter. Second-quarter 2026 West gathering volumes were 6.03 Bcf/d, above 5.94 Bcf/d a year earlier but below 6.37 Bcf/d in the first quarter; net revenue was US$454 million (+6.6%) and Adjusted EBITDA was US$359 million (+5.3%), against first-quarter Adjusted EBITDA of US$410 million (+15.8%)[7]. The company attributed the growth to Louisiana Energy Gateway, which entered service in the third quarter of 2025, and to the Rimrock and Saber acquisitions, and said lower minimum volume commitment revenue offset part of it[9]; the annual report had already flagged that Eagle Ford minimum volume commitment reductions would weigh on West results[15].

The financial transmission runs from Haynesville producers raising output to higher gathering volumes and throughput revenue, while minimum volume commitment reductions cut shortfall revenue; once Momentum is consolidated, it adds gathering and take-or-pay pipeline revenue, but roughly US$3.5 billion of cash and debt consideration will also raise interest expense[11]. Two questions remain unresolved. First, the two 2025 acquisitions still added year-over-year growth in the first half of 2026, and that base effect disappears from the third quarter, so organic growth may be weaker than first-half figures suggest. Second, the acquisition multiple is described inconsistently: the 8-K puts it at about 8.5 times projected 2027 EBITDA[11], while the call summary describes 8.5x as a current run-rate multiple[17], and the former implies 2027 EBITDA of about US$650 million. Management also listed weak summer gas prices as a full-year uncertainty[26].

In the third-quarter report, the points to watch are whether West Adjusted EBITDA excluding Momentum exceeds US$367 million, whether gathering volumes return above 6.14 Bcf/d[7], how the company explains the size of the decline in minimum volume commitment revenue, and which segment Momentum joins and how much it contributes in its first month. West Adjusted EBITDA below US$367 million would show minimum volume commitment roll-offs and weak gas prices outweighing volume growth, and a first-month Momentum contribution well below its implied annual scale without explanation would require the acquisition's premise to be re-examined.

Williams' Northeast gathering and processing business grew second-quarter Adjusted EBITDA 7.8%, but the gain came from rich-gas processing in the Ohio Valley and joint ventures while dry-gas gathering volumes were nearly flat. Can that growth continue in the third quarter?

Northeast G&P is the company's second-largest segment, with 2025 Adjusted EBITDA of US$2.028 billion[6], and on the second-quarter call management acknowledged deliberately conservative modeling of its growth[26][17]. Its growth rate decides whether the base business can carry overall growth before the power and Haynesville projects enter service; it grew only 1.9% in the first quarter and accelerated to 7.8% in the second, so the third quarter tests whether the acceleration lasts. The comparison base is third-quarter 2025 Adjusted EBITDA of US$505 million, plant inlet volumes of 1.90 Bcf/d, consolidated gathering volumes of 4.10 Bcf/d and joint venture proportional EBITDA of US$161 million[6].

Second-quarter growth came mainly from rich-gas processing and joint ventures rather than dry-gas gathering. In the second quarter of 2026, consolidated gathering volumes were 4.16 Bcf/d against 4.15 Bcf/d a year earlier; plant inlet volumes were 2.04 Bcf/d against 1.89 Bcf/d; NGL production was 166 Mbbls/d against 138 Mbbls/d; revenue was US$443 million against US$419 million, operating and administrative costs were US$109 million, slightly below US$113 million a year earlier, and joint venture proportional EBITDA was US$168 million against US$154 million[6]. The company attributed the growth to higher volumes at Ohio Valley Midstream and higher proportional EBITDA from Blue Racer and from Bradford within Appalachia Midstream[9]; in the first quarter it had cited lower volumes at Susquehanna Supply Hub[23].

The financial transmission runs from higher rich-gas output in the Ohio Valley to higher plant inlet volumes and NGL production, lifting processing and fractionation revenue that carries higher unit fees; joint venture volume growth flows into segment profit in proportion to ownership; and dry-gas gathering volumes move with gas prices. What remains unresolved is how much of the second-quarter acceleration came from a low base: the US$501 million of the second quarter of 2025 was that year's weakest quarter, and the third-quarter base of US$505 million is not high either[6], so the real test is whether the growth rate holds, not merely whether there is growth.

In the third-quarter report, the points to watch are whether Northeast G&P Adjusted EBITDA reaches the roughly US$544 million implied by the second-quarter growth rate, whether plant inlet volumes hold near 2.04 Bcf/d, whether dry-gas gathering volumes fall below the first quarter's 4.01 Bcf/d, and whether joint venture proportional EBITDA keeps growing year over year[6]. Adjusted EBITDA below US$505 million would show that rich-gas and joint venture growth has stopped, and consolidated gathering volumes below 4.01 Bcf/d would show weak gas prices starting to depress dry-gas production.

Risks and Falsifiers

Marketing seasonality is the hardest part of full-year guidance to predict. The marketing segment contributed US$227 million of Adjusted EBITDA in the first quarter of 2026, minus US$1 million in the second quarter, only US$11 million in the third quarter of 2025 and US$193 million for full-year 2025[8]; if the fourth quarter is mild, the marketing share of the US$8.3 billion to US$8.5 billion full-year guidance could fall short[4], and the third quarter itself offers little cushion. Third-quarter marketing Adjusted EBITDA of at least US$11 million, with full-year guidance maintained, would ease this concern.

Northeast pipeline projects face permitting and litigation risk. The annual report lists delayed or denied permits as a main obstacle to executing the plan[15], and on the first-quarter call management said litigation is delaying projects and raising costs[30]; projects such as Transco's Northeast Supply Enhancement, on which construction started in the first quarter, remain in this environment[20], and if key permits are revoked or delayed, Transco reservation revenue would be pushed back and the risk on capital already invested would rise. If the third-quarter report keeps the Northeast Supply Enhancement in-service timing and records no related impairment, this risk has not materialized.

Hurricanes and storage spreads are the direct risk to the volume-sensitive part of TP&G. Third-quarter hurricanes could shut in deepwater Gulf platforms while storage spreads narrow, pushing TP&G gathering and storage revenue (US$237 million in the third quarter of 2025) and segment Adjusted EBITDA (US$947 million) down year over year and offsetting reservation fee gains from expansions[5][26]. If third-quarter gathering and storage revenue is at least the second quarter's US$254 million and crude oil transportation volumes are at least the 238 Mbbls/d of the third quarter of 2025, this risk has not materialized[5].

Power project execution risk would show up first in capital spending and leverage. Power projects depend on third-party turbines, batteries and contractors, and if phase two or later projects slip or run over budget, capital spending comes first while revenue is delayed[27][26]; the exposed lines are capital investment (US$1.642 billion in the second quarter), debt-to-Adjusted EBITDA (3.67x)[3] and noncontrolling distributions in AFFO (US$73 million in the second quarter)[19]. If Socrates phase two enters service in the fourth quarter as planned, third-quarter capital investment falls between US$2.4 billion and US$2.8 billion, and the year-end leverage outlook stays at about 3.9x, this concern would ease[22].

Weak gas prices and minimum volume commitment reductions could stop West's organic growth. Weak summer gas prices could lead Haynesville producers to defer completions, and together with minimum volume commitment reductions on contracts such as Eagle Ford[15][26], West's organic revenue could stop growing, while the roughly US$3.5 billion of cash and debt consideration for Momentum would raise interest expense[11]. If third-quarter West Adjusted EBITDA excluding Momentum is at least US$387 million and gathering volumes are at least 6.14 Bcf/d, this concern does not hold[7].

Weak gas prices could also depress Northeast dry-gas production. If Marcellus dry-gas producers cut output, consolidated gathering volumes decline and the increment from rich-gas processing expansions slows, Northeast G&P growth could fall back to the first quarter's roughly 2%, exposing the segment's third-quarter 2025 Adjusted EBITDA base of US$505 million[6][23][26]. If third-quarter Adjusted EBITDA is at least US$544 million and gathering volumes are at least 4.10 Bcf/d, this concern is falsified[6].

What to Watch Next

• TP&G after the rate tailwind: segment Adjusted EBITDA against US$947 million in the third quarter of 2025 and US$959 million (+6.2%) in the second quarter of 2026; approaching about US$1.006 billion would support the expansion story, while a figure below US$947 million would show expansion contributions being offset.
• TP&G volumes: regulated revenue against US$930 million and crude oil transportation against 238 Mbbls/d in the third quarter of 2025; regulated revenue above US$956 million is the confirmation, and crude volumes below 196 Mbbls/d would show the Gulf taking a hit.
• Socrates phase two: phase one's 200 MW is in service and phase two is planned for the fourth quarter; a delay into 2027 would signal higher execution risk.
• Capital investment and leverage: US$1.642 billion and 3.67x in the second quarter; third-quarter capital investment of about US$2.4 billion to US$2.8 billion fits the plan, while a year-end leverage outlook above 4.0x would not.
• Haynesville organic growth: West Adjusted EBITDA excluding Momentum against US$367 million and gathering volumes against 6.14 Bcf/d in the third quarter of 2025; falling below would show minimum volume commitment roll-offs and weak gas prices outweighing volume growth.
• Momentum consolidation: signed at up to US$5.5 billion; watch which segment it joins and its first-month contribution, and treat a contribution far below its implied scale without explanation as a warning.
• Northeast rich-gas processing: Northeast G&P Adjusted EBITDA against US$505 million in the third quarter of 2025 and US$540 million in the second quarter of 2026; about US$544 million is the confirmation, and below US$505 million would show growth has stopped.
• Northeast dry gas: consolidated gathering volumes against 4.10 Bcf/d in the third quarter of 2025 and 4.01 Bcf/d in the first quarter of 2026; a drop below 4.01 Bcf/d would show weak gas prices depressing dry-gas output.

Conclusion

Williams' business is driven by three forces: fixed reservation fees on Transco and the other regulated pipelines provide a stable base, gathering and processing in the Gulf, the Haynesville and the Northeast add volume-sensitive growth, and data center power is a new growth line where capital comes first. First-half 2026 Adjusted EBITDA was US$4.175 billion, up about 10%, leverage was 3.67x at the end of the second quarter[3], and the company has raised full-year guidance to US$8.3 billion to US$8.5 billion[4]. The central unresolved relationship is whether, after the Transco rate tailwind fades and the base effect of the 2025 acquisitions disappears, expansion projects, rich-gas processing and organic Haynesville growth can deliver the roughly US$4.225 billion implied for the second half, while growth capital spending and acquisition funding keep leverage inside the 3.5x to 4.0x target range[21].

On outside views, coverage found since the latest results on August 3, 2026 consists only of earnings recaps, institutional ownership changes and news about project permitting litigation, and it contains no signed, verifiable independent commentary with a substantive judgment on the four debates above, so there are no outside interpretations to synthesize here and readers must rely on the company's own disclosures. That makes the third-quarter report itself the first direct evidence on these debates, rather than a choice between existing outside judgments.

If the third-quarter report shows TP&G Adjusted EBITDA near US$1 billion, Socrates phase two on track, West Adjusted EBITDA excluding acquisitions above US$367 million, Northeast G&P holding growth around 7%, and leverage still on a path to about 3.9x, it would materially strengthen the view that the base business can fund its own growth while the new businesses come online as planned[5][7][6][22]. Conversely, if TP&G falls back below US$947 million, dry-gas gathering volumes drop below 4.01 Bcf/d, Socrates phase two slips, or the year-end leverage outlook rises above 4.0x, it would show that first-half growth came more from one-time rate and weather effects and that capital spending risk has begun to materialize ahead of revenue.

Sources

[1] Drillr earnings calendar (updated 2026-10-21) · WMB 2026-11-02 Q3 2026 estimates · 2026-10-21 · Drillr earnings calendar · https://gateway.drillr.ai/mcp/private

[2] WMB 8-K filed 2026-08-03 (2Q26 results) · results highlights · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[3] WMB 8-K filed 2026-08-03 (2Q26 results) · summary financial information · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[4] WMB 8-K filed 2026-08-03 (2Q26 results) · 2026 financial guidance · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[5] WMB 8-K filed 2026-08-03 (2Q26 results) · Transmission, Power & Gulf quarterly detail · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[6] WMB 8-K filed 2026-08-03 (2Q26 results) · Northeast G&P quarterly detail · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[7] WMB 8-K filed 2026-08-03 (2Q26 results) · West quarterly detail · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[8] WMB 8-K filed 2026-08-03 (2Q26 results) · Gas & NGL Marketing Services and Other quarterly detail · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[9] WMB 8-K filed 2026-08-03 (2Q26 results) · segment results commentary · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[10] WMB earnings call 2026-08-04 (2Q26) · Power Innovation and pipeline milestones · 2026-08-04 · earnings-call · https://gateway.drillr.ai/mcp/private

[11] WMB 8-K filed 2026-08-03 (2Q26 results) · Momentum Midstream acquisition and Haynesville projects · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[12] WMB 10-K filed 2026-02-24 · revenue recognition: reservation charges · 2026-02-24 · 10-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=10-K&dateb=&owner=include&count=40

[13] WMB 10-K filed 2026-02-24 · Transco rate case settlement · 2026-02-24 · 10-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=10-K&dateb=&owner=include&count=40

[14] WMB 10-K filed 2026-02-24 · Power Innovation projects · 2026-02-24 · 10-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=10-K&dateb=&owner=include&count=40

[15] WMB 10-K filed 2026-02-24 · company outlook 2026 · 2026-02-24 · 10-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=10-K&dateb=&owner=include&count=40

[16] WMB 8-K filed 2026-08-03 (2Q26 results) · GAAP and non-GAAP variance explanation · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[17] WMB earnings call 2026-08-04 (2Q26) · Q&A on growth target and JV capacity · 2026-08-04 · earnings-call · https://gateway.drillr.ai/mcp/private

[18] WMB 10-K filed 2026-02-24 · consolidated statement of cash flows 2025 · 2026-02-24 · 10-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=10-K&dateb=&owner=include&count=40

[19] WMB 8-K filed 2026-08-03 (2Q26 results) · AFFO reconciliation by quarter · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[20] WMB 8-K filed 2026-05-04 (1Q26 results) · results highlights · 2026-05-04 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[21] WMB 8-K filed 2026-07-13 (Power Innovation JV) · press release · 2026-07-13 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[22] WMB earnings call 2026-08-04 (2Q26) · guidance and leverage · 2026-08-04 · earnings-call · https://gateway.drillr.ai/mcp/private

[23] WMB 8-K filed 2026-05-04 (1Q26 results) · segment drivers and 2026 guidance · 2026-05-04 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[24] WMB 8-K filed 2026-08-03 (2Q26 results) · 2026 guidance midpoint reconciliation · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[25] WMB 8-K filed 2026-09-10 (senior notes offering) · 2026-09-10 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[26] WMB earnings call 2026-08-04 (2Q26) · management-stated risks · 2026-08-04 · earnings-call · https://gateway.drillr.ai/mcp/private

[27] WMB 10-K filed 2026-02-24 · risk factors: power innovation projects · 2026-02-24 · 10-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=10-K&dateb=&owner=include&count=40

[28] WMB 8-K filed 2026-08-03 (2Q26 results) · CEO commentary on Power Innovation · 2026-08-03 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[29] WMB 8-K filed 2026-07-13 (Power Innovation JV) · investor presentation · 2026-07-13 · 8-K · https://www.sec.gov/cgi-bin/browse-edgar?action=getcompany&CIK=0000107263&type=8-K&dateb=&owner=include&count=40

[30] WMB earnings call 2026-05-05 (1Q26) · management-stated risks · 2026-05-05 · earnings-call · https://gateway.drillr.ai/mcp/private