TransAlta adds US$1bn Colorado peakers as Alberta power margins tighten

TransAlta Corporation reaffirmed its 2026 financial guidance as stronger gas-generation earnings and active hedging helped offset weaker hydroelectric output, reduced energy-marketing contributions and difficult merchant-power conditions in Alberta. The Toronto Stock Exchange and New York Stock Exchange-listed power producer, which trades under $TA and $TAC, reported second-quarter revenue of C$487 million, adjusted EBITDA of C$291 million and free cash flow of C$143 million. Revenue increased 12% from the prior-year period, but adjusted EBITDA declined 17% and free cash flow fell 19%, demonstrating that the higher top line did not translate into stronger underlying cash generation. TransAlta Corporation is simultaneously preparing to complete a US$1 billion acquisition of two fully contracted natural gas-fired peaking plants near Denver, Colorado, supported by a C$350 million common-share offering and US$750 million of assumed project debt. The transaction could improve the company’s long-term contract profile, but investors must weigh that benefit against near-term dilution, lower existing-portfolio cash flow and the capital required for Centralia and Alberta data-centre developments.

Net earnings attributable to common shareholders reached C$35 million, or C$0.12 per share, compared with a C$112 million loss a year earlier. The improvement partly reflects the absence of several accounting and fair-value pressures that affected the prior-year result, while adjusted net earnings remained unchanged at C$54 million. Cash flow from operating activities fell to C$62 million from C$157 million because of working-capital movements and lower funds generated by the operating portfolio.

TransAlta maintained its full-year outlook for adjusted EBITDA of between C$950 million and C$1.05 billion and free cash flow of between C$350 million and C$450 million. The company generated C$495 million of adjusted EBITDA and C$245 million of free cash flow during the first six months, placing it near the midpoint of the annual adjusted EBITDA range and more than halfway through the free-cash-flow target.

Why TransAlta’s revenue increased while adjusted EBITDA and free cash flow declined

TransAlta’s second-quarter revenue increased by C$54 million even though portfolio production declined 2% to 4,720 gigawatt-hours. The result indicates that reported revenue benefited from factors beyond physical electricity generation, including contract pricing, hedging, environmental attributes and differences in the contribution from individual plants and markets.

Adjusted EBITDA fell from C$349 million to C$291 million because weaker results from hydroelectric generation, energy marketing and the Energy Transition segment outweighed improvement in gas generation. The comparison also included stronger prior-year hydro conditions and earnings from activities that did not repeat at the same level during 2026.

Hydro adjusted EBITDA declined 31% to C$87 million. Hydroelectric earnings can vary with water availability, reservoir conditions, market prices and the timing of environmental-credit recognition, even though hydro assets carry no direct fuel cost and can provide valuable electricity during periods of peak demand.

Wind and Solar adjusted EBITDA was broadly stable at C$90 million, compared with C$89 million a year earlier. The segment’s resilience helped offset pressure elsewhere and demonstrates the portfolio benefit of owning generation technologies with different production profiles and commodity exposures.

Gas adjusted EBITDA increased 11% to C$142 million. The improvement reflects TransAlta’s expanded gas fleet, contracted facilities and its ability to optimize dispatch and fuel positions across several North American electricity markets. The February acquisition of Far North Power Corporation also added 310 megawatts of gas-fired capacity in Ontario, although not every asset contributed for the full comparative period.

Energy Marketing adjusted EBITDA declined to C$10 million from C$26 million. Marketing earnings depend on market volatility, price differences between regions and time periods, customer contracts and the ability to optimize generation, fuel and transmission positions. Reduced volatility can limit those opportunities even when electricity demand remains stable.

The Energy Transition segment moved to an adjusted EBITDA loss of C$2 million from income of C$19 million. Centralia Unit 2 generated no electricity during the first half, although the United States Department of Energy has ordered the facility to remain available through September 12. The plant’s continued availability creates costs without providing the normal operating contribution expected from a dispatched generation facility.

Portfolio availability declined to 90.2% from 91.6%. The change was not severe, but each percentage point of unavailable capacity can reduce the company’s ability to capture favorable prices or meet contractual requirements, particularly during periods of high system demand.

TransAlta said its Alberta hedging strategy produced realized electricity prices above spot-market prices. The company also used environmental credits generated by hydro and wind facilities to substantially offset the carbon-compliance obligations of its merchant natural gas fleet. These tools protected earnings but could not fully overcome the difficult Alberta market and lower contributions from several operating segments.

The distinction between revenue growth and cash-flow quality is therefore important. TransAlta produced higher reported revenue and positive net income, but the decline in adjusted EBITDA, funds from operations and free cash flow shows that its existing portfolio generated less recurring economic value than it did during the corresponding 2025 quarter.

How the US$1 billion Colorado acquisition changes TransAlta’s contract profile

TransAlta agreed to acquire Mountain Peak Power and Canyon Peak Power from an indirect subsidiary of Blackstone Inc. for a total transaction value of US$1 billion. The two natural gas-fired peaking facilities have combined capacity of 318 megawatts and are located near Denver, Colorado.

Mountain Peak Power has 162 megawatts of capacity and entered commercial operation in September 2025. Canyon Peak Power will provide another 156 megawatts and is expected to enter service during the third quarter of 2026. Closing is targeted for early in the fourth quarter, subject to Canyon Peak reaching commercial operation, regulatory approvals and other customary conditions.

Both facilities are fully contracted under tolling agreements with investment-grade counterparties for more than 25 years. Their weighted average remaining contract duration is approximately 27 years, and the agreements provide pass-through treatment for fuel, operating, maintenance and capital costs.

Under a tolling arrangement, the customer generally controls when the plant operates while paying the owner for capacity and other contracted services. Passing fuel and major operating costs through to customers can reduce the generator’s exposure to gas prices and short-term electricity-market volatility.

TransAlta expects the facilities to contribute approximately US$80 million, or about C$110 million, of annual adjusted EBITDA. Estimated annual free cash flow is approximately US$33 million, equivalent to roughly C$45 million, before potential upside from availability incentives and corporate synergies.

The acquisition price therefore represents approximately 12.5 times projected adjusted EBITDA and more than 30 times initial projected free cash flow. Those multiples are high compared with an uncontracted merchant plant, but the valuation reflects the unusually long contract duration, investment-grade customers and pass-through cost protection.

The company expects the transaction to produce immediate low-to-mid single-digit free-cash-flow-per-share accretion. Achieving that target will depend on Canyon Peak beginning commercial service as planned, both plants meeting availability requirements and TransAlta delivering expected insurance, tax and operational efficiencies.

The acquisition establishes a physical position in Colorado, a state where electricity demand is expected to grow from population, electrification and digital infrastructure. Peaking facilities can become increasingly valuable in power systems containing more variable wind and solar generation because they can start when renewable production falls or demand rises unexpectedly.

The assets remain natural gas-fired facilities with long commercial lives. Their economics could therefore be affected by future emissions rules, carbon pricing, permitting requirements or technology changes, even though the current contracts provide substantial protection against fuel and operating-cost movements.

The transaction’s strongest strategic feature is the shift from merchant exposure toward contracted earnings. TransAlta’s second-quarter results show the variability that can arise from Alberta prices, hydro conditions and marketing opportunities, while the Colorado assets are intended to provide more predictable cash flow over several decades.

Why the C$350 million equity raise protects leverage but dilutes existing shareholders

TransAlta is assuming US$750 million of senior secured project debt attached to the Colorado facilities and funding the remaining equity purchase price from its C$350 million bought-deal common-share offering. The project debt is non-recourse, investment grade and designed to amortize over the contract periods.

The company issued approximately 18.23 million shares at C$19.20 each. Based on TransAlta’s latest quarterly weighted average of approximately 302 million common shares, the offering represents dilution of roughly 6%, although the precise ownership impact depends on the share count used after closing and any additional issuances. This percentage is an inference from the company’s disclosed offering and quarterly share figures.

Issuing equity avoids placing the full acquisition cost on TransAlta’s corporate balance sheet. It also helps preserve financial flexibility for Centralia, data centres and other growth projects at a time when the existing portfolio is producing less free cash flow than a year earlier.

The trade-off is that future earnings and free cash flow will be distributed across more shares. The acquisition must therefore generate enough incremental cash flow to exceed the dilution created by the offering.

TransAlta expects low-to-mid single-digit free-cash-flow-per-share accretion, suggesting management believes the contracted assets will add value even after incorporating the additional shares. The relatively modest projected accretion leaves limited room for construction delays, underperformance or unexpected costs.

The share proceeds were temporarily used to reduce amounts drawn under the company’s syndicated credit facility while TransAlta waits for the acquisition to close. This reduces interest costs during the interim and prevents the cash from remaining idle, although the funds will ultimately be required for the transaction.

The Colorado facilities could also become a funding source for TransAlta’s wider development portfolio. Management intends to redeploy contracted cash flows into projects such as the Centralia coal-to-gas conversion and the proposed Keephills data-centre development.

That strategy relies on a portfolio-financing model in which stable mature assets support investment in projects that have not yet begun contributing. It can create attractive growth when project returns exceed the cost of capital, but it can also increase financial pressure if several developments require funding at the same time.

Why Centralia and Keephills could become TransAlta’s next contracted growth engines

TransAlta plans to convert the 700-megawatt Centralia Unit 2 facility in Washington from coal to natural gas. The converted plant will supply Puget Sound Energy under a 16-year fixed-price tolling agreement extending through December 2044.

The conversion is expected to require approximately US$600 million of capital and achieve commercial operation during the second half of 2028, subject to permitting and construction. TransAlta has estimated a build multiple of approximately 5.5 times, implying a potentially attractive contracted return if the project is delivered within the forecast cost.

Using the existing Centralia site allows TransAlta to reuse transmission, water, land and parts of the current generating infrastructure. The approach could reduce development time and land disturbance compared with constructing a new gas facility at an undeveloped location.

The United States Department of Energy’s orders requiring the coal unit to remain available have complicated the transition. Centralia produced no power during the first half, but TransAlta must maintain the facility in a condition that complies with the federal order while continuing preparations for the gas conversion.

At Keephills in Alberta, TransAlta has entered a memorandum of understanding with Canada Pension Plan Investment Board and Brookfield to advance a phased data-centre development. TransAlta would be the exclusive site and electricity provider, with the first phase contemplating an approximately 230-megawatt long-term power purchase agreement.

The partners are also evaluating additional phases that could increase total demand to as much as one gigawatt. The location includes zoned land and access to existing electricity transmission, natural gas, water and on-site generation infrastructure, making it suitable for a large digital-infrastructure campus.

The project remains subject to regulatory approvals and definitive binding agreements. The memorandum creates a negotiating framework but does not yet guarantee that a 230-megawatt contract or the full one-gigawatt development will proceed.

A successful Keephills development could materially increase Alberta electricity demand and give TransAlta another long-term contracted customer. It could also improve the economics of existing generation and infrastructure that have been affected by weak merchant pricing.

The project would require coordination across power supply, transmission, water, construction and computing infrastructure. Data-centre developers may also demand increasingly strict emissions and renewable-energy standards, requiring TransAlta to combine reliable gas generation with hydroelectricity, wind, environmental attributes or other lower-carbon resources.

Centralia and Keephills represent two versions of the same strategy. TransAlta is attempting to transform existing sites into long-duration contracted infrastructure rather than relying primarily on short-term merchant electricity prices.

What Alberta exposure and lower market volatility mean for the TAC investment case

TransAlta entered 2026 expecting lower contributions from its Alberta merchant gas fleet because of weaker hedge prices and higher natural gas costs. Its annual outlook assumes an Alberta spot electricity price of between C$40 and C$60 per megawatt-hour, with every C$1 change expected to affect adjusted EBITDA by approximately C$2 million.

The company hedged roughly 1,990 gigawatt-hours of second-quarter production at an average price of approximately C$65 per megawatt-hour. That position helped TransAlta realize prices above the Alberta spot market and reduced the immediate effect of weak market conditions.

Hedging protects cash flow but can also limit upside when market prices rise above contracted levels. The value of the program depends on the company balancing earnings stability against participation in future price recovery.

TransAlta mothballed Sheerness Unit 1 on April 1 for a period of up to two years. Management retains the ability to restart the plant if electricity-market fundamentals improve or if it secures an attractive contract.

The decision demonstrates that not every unit can earn an acceptable return under current Alberta conditions. Mothballing reduces operating expenses but also removes capacity that could otherwise benefit from a sudden increase in prices.

Management expects Alberta fundamentals to improve as data centres and other large industrial loads begin entering the system. The timing remains uncertain because projects must obtain transmission access, regulatory approvals, financing and final customer commitments.

The Colorado acquisition helps reduce dependence on that forecast by adding assets whose revenues are contractually supported. It does not eliminate Alberta exposure because TransAlta continues to own a substantial portfolio of gas, hydro, wind and storage assets in the province.

TransAlta’s New York-listed shares traded near US$12.49 on July 31, down approximately 2.9% from the previous close after reaching an intraday high of US$12.99. The decline suggests investors focused on weaker quarterly cash flow and the execution demands surrounding the acquisition and development portfolio, although no single explanation for a trading-session move can be confirmed.

The cautious reaction is understandable. TransAlta is asking shareholders to accept immediate dilution in exchange for long-term contracted growth while its existing portfolio is generating less adjusted EBITDA and free cash flow.

The strategic case remains credible because the Colorado assets, Centralia contract and potential Keephills development could create a more predictable earnings base. The financial outcome will depend on disciplined construction, reliable plant availability and whether projected per-share accretion survives the transaction’s debt, equity and operating requirements.

Key takeaways from TransAlta’s second-quarter results and Colorado expansion

• TransAlta Corporation reported second-quarter revenue of C$487 million, an increase of 12%, despite a 2% decline in portfolio electricity production.
• Adjusted EBITDA fell 17% to C$291 million, while free cash flow declined 19% to C$143 million because weaker hydro, marketing and Energy Transition results outweighed stronger gas-generation earnings.
• Net earnings improved to C$35 million from a C$112 million loss, but unchanged adjusted net earnings show that the improvement partly reflected non-operating and comparative accounting items.
• TransAlta maintained 2026 guidance for C$950 million to C$1.05 billion of adjusted EBITDA and C$350 million to C$450 million of free cash flow.
• The proposed US$1 billion Colorado acquisition adds two natural gas peaking plants with 318 megawatts of capacity and approximately 27 years of weighted average contracted life.
• Mountain Peak Power and Canyon Peak Power are expected to contribute approximately US$80 million of annual adjusted EBITDA and US$33 million of free cash flow.
• TransAlta issued 18.23 million shares for approximately C$350 million, creating roughly 6% dilution based on the latest weighted average share count while protecting the corporate balance sheet.
• Centralia’s planned US$600 million coal-to-gas conversion is supported by a 16-year tolling agreement and targets commercial operation during the second half of 2028.
• The Keephills data-centre framework contemplates an initial 230-megawatt power agreement and could eventually scale to one gigawatt, but it remains subject to approvals and definitive contracts.
• The outlook for $TAC and $TA depends on whether long-duration contracted projects can offset weaker merchant-power economics and generate enough cash flow to exceed equity dilution and project-financing costs.