TransAlta Corporation (TAC) | The Buildout — AI Infrastructure
The Verdict
TransAlta is a power generator. It owns hydro, wind, solar, battery storage and gas-fired plants across Canada, the United States and Western Australia, and sells the electricity. Its link to the AI buildout runs through Alberta, where the company's gas-fired steam units sit largely idle for economic reasons rather than technical limits, and where the Keephills legacy thermal site already has land, gas, transmission and water in place. Under an MOU with CPP Investments and Brookfield, TransAlta is the exclusive site and power provider, while the partners supply data-center capital. Management calls the structure capital-light. Beyond the steam units, the company points to a repowering pipeline at Keephills 1 and Sundance 5 for the next decade.
| Market Cap | — |
| Revenue (TTM) | $1.6B |
| Revenue Growth | −9.0% |
| EBITDA Margin (TTM) | 27.3% |
| Net Debt | $2.8B |
| Earnings Beats | 2 of 7 |
| P/E (TTM) | — |
| EV/EBITDA (TTM) | — |
What We Like
- Gas-fired steam units are designed for baseload operation above a 90% capacity factor but ran around 20% in 2025 — management attributes the gap to economic decisions, not capability.
- The Keephills MOU names CPP Investments and Brookfield, with TransAlta as exclusive site and power provider. Phase 1 is a roughly 230 MW load allocation, and management says up to a gigawatt or higher could be supported at the site.
- The Alberta hedge book sits above the forward curve: about 4.5 TWh hedged for the balance of 2026 and about 6.6 TWh for 2027, both near $64/MWh, against a guidance assumption of $40 to $60/MWh.
- Contracted tenor is lengthening. Centralia Unit 2 tolling runs to 2044, and the Colorado acquisition carries a 27-year weighted-average duration with full cost pass-through and about $110 million a year in expected EBITDA.
- Documented offtake includes Meta (100% of a Logan County, Oklahoma facility) and Amazon Energy (two PPAs, 100% of a Caddo County, Oklahoma facility), shifting the customer base toward large, long-dated counterparties.
What We’re Watching
- The AESO's underutilized-capacity determination gates the scale of the data-center strategy. Management said it hoped for clarity "in the next quarter or so" from the 2026-07-31 call, but cannot speak for the AESO.
- The Keephills MOU has not converted to definitive agreements. Management targets documents later in 2026; load ramp, risk sharing and the terms of a termination fee — acknowledged to exist — are undisclosed.
- Centralia Unit 2 is offline until conversion. The Class 3 estimate is due by end-2026, FID is targeted for Q1 2027 and in service for Q4 2028. Management calls the gap "a sizable impact to our adjusted EBITDA and free cash flow."
- Balance-sheet pressure: total debt of $2,986.3 million against $212.8 million of cash at 2026-06-30, an S&P negative outlook on the BB+ rating, and a $350 million equity raise closed in June 2026.
The thesis is intact but unproven. The contracted book keeps getting longer and the hedge book defends cash flow through 2027, while the AI-linked revenue line remains an option with no disclosed revenue today. Management's language hardened — the MOU is signed, Centralia is contracted to 2044 — yet the two items that would convert the story, an AESO designation and definitive Keephills agreements, are both still outstanding. The open question is how much of the gas-fired steam fleet the AESO designates, and on what timeline.
Earnings
In Q2 FY2026 TransAlta reported revenue of $343.1 million and a gross margin of 88.9%, with EBITDA of $174.7 million on the operating income plus D&A basis. Management separately reported adjusted EBITDA of $291 million and free cash flow of $143 million, with average fleet availability of 90.2%. Pricing was the standout: with Alberta spot averaging $29/MWh, the gas fleet realized $68/MWh, a 134% premium, on dispatch optimization during high-price hours.
| Metric | Q2 FY2026 | Q1 FY2026 | Q2 FY2025 | YoY |
|---|---|---|---|---|
| Revenue | $343M | $407M | $318M | +7.8% |
| Gross margin | 88.9% | 43.0% | 77.1% | +1180bps |
| EBITDA | $175M | $102M | $109M | +60.6% |
| EPS | $0.11 | $0.03 | $-0.24 | −146.8% |
| Alberta spot power price | $29/MWh | n/a | $40/MWh | -27.5% |
| Average fleet availability | 90.2% | n/a | n/a | — |
Hard to say. We cannot really speak for the AESO, Mark.. we are hopeful it will be in the next quarter or so, but we cannot speak on behalf of them as to the timing.— Joel E. Hunter, President & CEO, 2026-07-31
Management tone: Management's language hardened versus the prior period. The data-center thread moved from steady progress toward an MOU to a signed MOU with named partners and exclusive site and power provider status, and Centralia moved from an expected definitive agreement to a signed tolling agreement. Management was direct about what it does not control, including AESO timing and the low probability it assigns to a Centralia Unit 1 repowering. Where it was evasive was economics: asset-recycling specifics and MOU terms were declined, with management saying on the prior call that it was "really quite restricted on what we can actually say."
Management Guidance
Management reaffirmed 2026 guidance on the Q2 2026 call: adjusted EBITDA of $950 million to $1.1 billion and free cash flow of $350 million to $450 million, against an Alberta spot assumption of $40 to $60 per megawatt hour, with sustaining capital of $140 million to $160 million. The range excludes the Centralia 2(c) DOE order, whose costs are expected to be recovered, and excludes the Colorado acquisition, which adds to results on a close expected in Q4 2026. It embeds headwinds including the Centralia outage, lower Alberta prices, the Sarnia contract step-down and Ada decommissioning.
Trajectory
Quarterly revenue moved from $442 million in Q3 FY2025 to $436 million, then $407 million, then $343 million in Q2 FY2026, while the reported gross margin expanded to 88.9% in the latest quarter. The swing factor is price. Alberta spot fell from $63/MWh in 2024 to $44/MWh in 2025 and $29/MWh in Q2 2026, and Hydro segment EBITDA dropped $39 million year over year to $87 million on lower spot and hedge prices and lower intercompany emissions-credit sales. Hedges and optimization offset part of that: the gas fleet realized $68/MWh in Q2 2026, and about 4.5 TWh is hedged for the balance of 2026 with about 6.6 TWh for 2027, both near $64/MWh.
The Model
The model projects FY+1 revenue of $1,620 million and EBITDA of $1,037 million, a 64.0% margin. For FY+2 it projects revenue of $1,810 million and EBITDA of $1,169 million, a 64.6% margin. The FY+1 revenue figure sits close to trailing-twelve-month revenue of $1,628.2 million. The FY+2 revenue estimate carries a 12% spread across five independent runs, from $1,720 million at the low end to $1,940 million at the high end. Near term, the contracted and hedged book anchors the numbers; FY+2 depends on the data-center option converting, Colorado contributing, and Centralia moving toward its Q4 2028 in-service date.
| Metric | FY2025 | Next FY (E) | Following FY (E) |
|---|---|---|---|
| Revenue | $1.7B | $1.6B | $1.8B |
| YoY Growth | — | −6.0% | +11.7% |
| EBITDA | $447M | $1.0B | $1.2B |
| EBITDA Margin | 26.0% | 64.0% | 64.6% |
Projections are the median of 5 independent model runs.
Management reaffirmed 2026 guidance on the Q2 2026 call: adjusted EBITDA of $950 million to $1.1 billion and free cash flow of $350 million to $450 million, against an Alberta spot assumption of $40 to $60 per megawatt hour, with sustaining capital of $140 million to $160 million. The range excludes the Centralia 2(c) DOE order, whose costs are expected to be recovered, and excludes the Colorado acquisition, which adds to results on a close expected in Q4 2026. It embeds headwinds including the Centralia outage, lower Alberta prices, the Sarnia contract step-down and Ada decommissioning.
What Could Go Right — and Wrong
- An AESO designation of gas-fired steam capacity for data-center load converts Keephills into a served, existing generation source without new-build capital.
- Definitive Keephills agreements turn the roughly 230 MW Phase 1 allocation into contracted cash flow, with up to a gigawatt or higher contemplated at the site.
- The Colorado acquisition closes in Q4 2026 and adds about $110 million a year of contracted EBITDA at a 27-year weighted-average duration.
- Centralia Unit 2 reaches FID in Q1 2027 and in service in Q4 2028, restoring the earnings lost when the legacy contract ran off.
- Alberta forward prices keep improving as load growth arrives; management cites Cal 2029 around $81/MWh, inside its Investor Day range of $80 to $120.
- The AESO designates little or no gas-fired steam capacity, or delays its ruling, leaving the data-center thesis without a foundation.
- The Keephills MOU does not convert to definitive agreements, or converts on economics that leave TransAlta a modest share of the value.
- Alberta spot stays weak and the hedge book rolls off after 2027, exposing the merchant fleet to prices below its strikes; management notes forward liquidity runs only 12 to 18 months at best.
- The Centralia Class 3 estimate lands above the roughly US$600 million and 5.5x build multiple management cites, or permitting and WUTC approval push FID past Q1 2027.
- Leverage pressure intensifies while asset recycling, the Brookfield hydro option and Centralia cash flows all remain undated.
Looking Ahead
The next twelve months turn on conversions rather than results. Management has pointed to definitive data-center documents and bringing forward the Alberta data-center option later in 2026, an AESO determination it hoped for within a quarter or so of the July 31 call, and a Colorado close in Q4 2026. Centralia's Class 3 estimate lands by end-2026, ahead of a Q1 2027 FID and Q4 2028 in service. Asset recycling continues with no disclosed names or timing, the Brookfield hydro option remains undated, and the DOE's repeated 90-day orders keeping Centralia Unit 2 available continue to recur.
- Next quarter or so from 2026-07-31AESO capacity determination — Sets how much gas-fired steam capacity can serve data-center load.
- Later in 2026Keephills definitive documents — Tests whether the data-center MOU converts to signed agreements.
- Q4 2026Colorado acquisition close — Adds ~$110M/yr contracted EBITDA if approvals and Canyon Peak Power clear.
- By end-2026Centralia Class 3 estimate — Firms the capital number behind the ~US$600M conversion.
- Q1 2027Centralia Unit 2 FID — Go/no-go decision on the coal-to-gas conversion.
- Q4 2028Centralia Unit 2 in service — Restores earnings lost when the Centralia legacy contract expired.
Financials
Annual Summary
| Metric | FY2024 | FY2025 | TTM | YoY |
|---|---|---|---|---|
| Revenue | $2.1B | $1.7B | $1.6B | -16.7% |
| Gross Margin | 63.6% | 46.4% | 43.3% | 1,723bps |
| EBITDA | $816M | $447M | $444M | -45.2% |
| EBITDA Margin | 39.5% | 26.0% | 27.3% | 1,350bps |
| Net Income | $171M | −$102M | −$18M | -159.9% |
| Free Cash Flow | $346M | $287M | $327M | — |
| Net Cash | — | — | — | — |
Key Ratios (Trailing)
- P/E TTM—
- EV/EBITDA TTM—
- EV/Revenue TTM—
- Price/FCF TTM—
- Gross Margin (TTM)43.3%
- EBITDA Margin (TTM)27.3%
- Net Margin (TTM)-1.1%
- ROIC1.2%
- FCF Conversion73.5%
- SBC / Revenue0.0%
The Company
TransAlta is one of Canada's largest publicly traded power generators. It owns and operates hydro, wind, solar, battery storage and thermal generation across Canada, the United States and Western Australia, and sells the output. The reported fleet includes about 922 MW of net hydro capacity, about 2,559 MW of net wind and solar, 4,525 MW of net gas, and about 671 MW in the Energy Transition segment, which holds the remaining Centralia unit, the Skookumchuck hydro facility, retired units and mine reclamation. The 40-F lists counterparties including Puget Sound Energy, Meta Platforms, Amazon Energy, BHP Nickel West, New Brunswick Power, and Pembina Pipeline with PepsiCo Canada.
The company operates as an owner-operator with an optimization and marketing arm attached. Energy Marketing schedules and markets the merchant fleet in North America outside Alberta, handles gas procurement, transport and storage, and runs a stand-alone trading book. Management describes three simultaneous postures: a merchant-heavy Alberta portfolio cushioned by hedges, a contracting-up strategy that adds long-dated investment-grade gas, and a legacy-site repurposing strategy built around Keephills, Sundance and Centralia. Underneath runs balance-sheet work — asset recycling, the Brookfield hydro option, and an S&P negative outlook.
Business Segments
Competitive Landscape
TransAlta frames its data-center position around speed to power: the gas-fired steam units and the Keephills site already have land, gas, transmission and water, so they can serve load faster than new build. Management calls the steam units the most cost effective path and says using them first is "all about speed to power too for AI infrastructure." The record also shows the advantage is not exclusive. Neighbor evidence, labeled as inference in the source material, shows Pembina and Kineticor reaching FID on a 932 MW gas project dedicated to a Meta data center in Alberta, under the same AESO framework TransAlta describes.
- Disclosed as a counterparty — the Sarnia facility is fully contracted with Pembina Pipeline Corporation and PepsiCo Canada — and flagged in the supply-chain wiring as both customer and competitor. Neighbor evidence, labeled as inference, places Pembina with Kineticor on the 932 MW Greenlight Electricity Center dedicated to a Meta data center in Alberta.
- KineticorNamed only in neighbor read-through evidence as Pembina's partner on the 932 MW Greenlight Electricity Center for a Meta data center in Alberta. The source material labels that read as inference; no neighbor names TransAlta directly.
Supply Chain
TransAlta sits upstream of the AI buildout as an electricity supplier. It buys fuel and equipment, owns generation, and sells power under long-dated contracts to utilities, hyperscalers, industrial customers and infrastructure partners. No neighbor in the source material names TransAlta directly.
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