Highlights

• Adjusted EBITDA increased about 16% to $553 million, while Net Income fell to $67 million from $153 million.

• Adjusted funds from operations were $306 million, and sustaining Capital guidance rose to $350 million to $370 million.

• The company reiterated growth targets to 2030 and cited a 250 megawatt Supply agreement for an Alberta data centre.

Capital Power Corporation (TSX:CPX) reported its third quarter financial results on Monday, November second, with an update that combined stronger operating earnings, softer Cash Flow metrics and a higher spending estimate for plant upkeep this year. The Edmonton-based independent power producer also reiterated its growth ambitions through the end of the decade and pointed to early signs that a global shortage of gas turbines may be starting to ease. The release arrived at the start of a heavy week of reporting for Canadian power and Utility names.

Operating Earnings Up, Net Income Down

Adjusted EBITDA for the quarter rose by about sixteen per cent to roughly five hundred and fifty-three million dollars, compared with about four hundred and seventy-seven million dollars a year earlier. Two United States Natural Gas Assets acquired in mid two thousand twenty-five, along with the Canadian flexible generation segment, drove the improvement. Lower Alberta spot prices and a weaker outcome from hedges at a California gas plant reduced the benefit.

Net income dropped to about sixty-seven million dollars, or thirty-seven cents per share, from roughly one hundred and fifty-three million dollars, or ninety-four cents. The decline was driven mostly by unrealized Fair Value losses on Commodity Derivatives and emission credits, which totalled about eighty-nine million dollars this quarter against a modest gain a year ago, as well as higher depreciation. Because such mark-to-market items do not reflect cash earned, management and analysts tend to focus on adjusted funds from operations.

Adjusted funds from operations were about three hundred and six million dollars, or one dollar and ninety-four cents per share, down from about three hundred and sixty-nine million dollars. Heavier sustaining capital spending, slightly higher net finance expense and current income tax expense, compared with a recovery in the prior year, explained the decline. Revenue and other income were roughly eight hundred and thirty-one million dollars, down from about one point two billion dollars.

The Maintenance Bill and Guidance

The company raised its estimate for sustaining Capital Expenditure this year to between three hundred and fifty and three hundred and seventy million dollars, from a prior range of two hundred and ninety to three hundred and thirty million. The increase reflects unplanned outage work, mainly in the American flexible generation fleet, and a planned outage that was moved forward from next year into the final quarter. Management said a significant portion relates to insurable events and expects insurance recoveries and manufacturer concessions to offset much of the cash impact across this year and next.

Guidance for adjusted funds from operations of between eight hundred and ninety million and one billion and ten million dollars, and for adjusted EBITDA of between roughly one point five six and one point seven six billion dollars, was maintained, with year-to-date results sitting in the lower to middle portion of each range. The company has also changed how it treats Clean Technology investment tax credits, which are now included in adjusted funds from operations; a Credit of about one hundred and seventy-four million dollars recognized in the second quarter lifts the nine-month figure.

Business Model and Contract Cover

Capital Power owns about twelve gigawatts of generation capacity across roughly thirty-five facilities in Canada and the United States, spanning natural gas, renewables and battery storage. About three quarters of expected adjusted EBITDA this year is supported by long-term contracts, all power purchase agreements are with investment-grade counterparties, and more than seventy per cent are with utilities or system operators. Over the past year and a half the company delivered roughly two gigawatts of contracted capacity with a weighted average contract life of around fifteen years.

That mix offers visibility but retains exposure to merchant markets in Alberta and parts of the American east, where capacity and energy prices respond to weather and tightening supply. Readers following Utility Stocks will recognise how producers such as this one differ from regulated distribution utilities, since returns come from contract structures and market performance rather than from commission-approved rate bases.

Growth Projects and Data Centre Demand

The pipeline includes a long-term energy supply agreement signed in July for two hundred and fifty megawatts of capacity and energy to support a data centre in Alberta, an expansion at the East Windsor Facility in Ontario that received approval to operate after the quarter ended, and two North Carolina solar projects in commissioning with completion targeted for the final quarter. Pre-feasibility work on a small modular reactor project in Alberta, undertaken with a provincial power generator, is also reported to be on track. The extension of a summer tolling agreement at an Arizona plant to the late two thousand thirties, including a modest capacity uprate, adds to contracted cash flow.

Chief executive officer Avik Dey told reporters that the shortage of natural gas turbines, driven by data centre demand, shows early signs of easing but cautioned that it is too soon to call a durable trend. The company aims to grow adjusted funds flow per share by eight to ten per cent by two thousand thirty and to deliver total Shareholder returns of thirteen to fifteen per cent, and it plans to concentrate more on upgrading and expanding existing sites while being selective with acquisitions.

Alberta Context and Capital Allocation

Alberta remains central to the company's identity, even as the American portfolio has grown. The repowering of the Genesee site continues to feature in disclosures, and legal costs linked to a contractor dispute over construction work there were recorded again this quarter, though they are small relative to overall earnings. Settlement of previously disputed off-coal compensation with the provincial government has also removed one source of uncertainty. The stated shift toward expanding existing sites reflects a view that brownfield projects usually carry lower permitting risk and shorter timelines than new acquisitions at elevated asset prices.

Dividend, Macro Backdrop and Risks

The declared quarterly Dividend was about seventy cents per share, up from roughly sixty-nine cents a year earlier, and the annual increase of two per cent earlier this year was the thirteenth consecutive one. For income-focused investors using TFSA or RRSP accounts, the Bank of Canada policy rate and long-term bond yields are key reference points, as they shape both the Cost of Capital for power projects and the appeal of dividend payers relative to fixed income.

Several risks deserve attention. Unplanned outages can erode availability and cash flow, and insurance recoveries may arrive later than expected. Alberta spot prices have been lower, which pressures merchant margins. Construction timelines for new generation depend on equipment supply, and policy on emissions, capacity markets and data centre interconnection can change.

Next catalysts include progress on the data centre supply arrangement, commissioning of the solar projects, insurance recoveries and the pace of capital allocation toward expansions rather than acquisitions. Capital Power is a constituent of the [S&P/TSX Composite Index], and its latest figures will be read alongside other third quarter disclosures from power and utility companies in the coming days.